UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

~~______________________________________________________________________________________________________________________________________________~~


Form 10-Q

~~______________________________________________________________________________________________________________________________________________~~

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

For the quarterly period ended~~September~~ June 30, ~~2017~~2020

☐ 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.~~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.)

~~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)

______________________________________________________________________________________________________________________________________________

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


Title of each class	Trading Symbol	Name of each exchange on which registered
Common stock, par value $0.01 per share	BASX*	The OTCQX Best Market*

* Until December 2, 2019, Basic Energy Services, Inc.’s common stock traded on the New York Stock Exchange under the symbol “BAS”. On December 3, 2019, Basic Energy Service, Inc.’s common stock began trading on the OTCQX® Best Market tier of the OTC Markets Group Inc. Deregistration under Section 12(b) of the Act became effective on March 16, 2020.

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	☐
~~Accelerated~~Non-accelerated filer			☒	Smaller reporting company	☒

~~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~~.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 ☐~~ ☒No☐

There were ~~26,028,149~~24,938,700 shares of the registrant’s common stock outstanding as of ~~November 3, 2017.~~ August 7, 2020.

BASIC ENERGY SERVICES, INC.

Index to Form 10-Q



Part I. FINANCIAL INFORMATION			41
Item 1. Financial Statements			41
Consolidated Balance Sheets as of ~~September~~June 30, ~~2017~~2020 (Unaudited) and December 31, ~~2016~~2019			41
Consolidated Statements of Operations for the three and ~~nine~~six months ended ~~September~~June 30 ~~2017~~, 2020 and ~~2016~~2019 (Unaudited)			52
Consolidated Statements of Stockholders’ Equity for the ~~nine~~three and six months ended ~~September 30, 2017~~June 3 0 , 2020 and 2019 (Unaudited)			63
Consolidated Statements of Cash Flows for the ~~nine~~six months ended ~~September~~June 30 ~~2017~~, 2020 and ~~2016~~2019 (Unaudited)			74
Notes to the Unaudited Consolidated Financial Statements			85
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			1926
Management’s Overview			1926
Segment Overview			2027
Operating Cost Overview			2329
Critical Accounting Policies and Estimates			2329
Results of Operations			2329
Liquidity and Capital Resources			2632
Other Matters			2734
Item 3. Quantitative and Qualitative Disclosures About Market Risk			2734
Item 4. Controls and Procedures			2734
Part II. OTHER INFORMATION			2735
Item 1. Legal Proceedings			2735
Item 1A. Risk Factors			2735
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			37
Item 5. Other Information			37
Item 6. Exhibits			2838
Signatures			2840

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. These statements are subject to risks and uncertainties. These statements may relate to, but are not limited to, information or assumptions about us, our capital and other expenditures, dividends, financing plans, capital structure, cash flows, pending legal or regulatory proceedings and claims, future economic performance, operating income, costs savings and management's plans, strategies, goals and objectives for future operations and goals. 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,~~“expect,” “anticipate,” “project,” “intend,” “plan,” ~~“expect,~~“seek,” ~~“indicate”~~“could,” “should,” “may,” “potential” 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•the recent sustained decline in, or substantial volatility of, oil orand natural gas prices, and any related changes in expenditures by our customers;

•our ability to successfully execute, manage and integrate acquisitions, including the recent acquisition of C&J Well Services, Inc.;

•our ability to satisfy our liquidity needs, including our ability to generate sufficient liquidity or cash flow or to obtain sufficient financing to fund our operations or otherwise meet our obligations as they come due in the future;

•local and global impacts of the COVID-19 pandemic;

•negative impacts of the delisting of our common stock from the New York Stock Exchange;

•competition within our industry;

•the effects of future acquisitions or dispositions on our business;

•uncertainties about our ability to successfully execute our business and financial plans and strategies;

•our access to current or future financing arrangements, including ability to raise funds in the capital market or from other financing sources;

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

~~competition within~~ •availability and cost of equipment;

•our ~~industry;~~ability to maintain acceptable pricing for our services;

•our ability to reduce administrative and capital expenses;

•general economic and market conditions;

•operating hazards and other risks incidental to our ~~access to current or future financing arrangements;~~services;

•energy efficiency and technology trends;

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

•our borrowing capacity, covenant compliance under instruments governing any of our existing or future indebtedness and cash flows; and

•environmental and other governmental regulations.

Our forward-looking statements speak only as of the date of this quarterly report. 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. All forward-looking statements included herein are expressly qualified in their entirety by the cautionary statements contained or referred to in this section.

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.

PART I — FINANCIAL INFORMATION

ITEM 1.FINANCIAL STATEMENTS

Basic Energy Services, Inc.

Consolidated Balance Sheets

(in thousands, except share and per share data)


	September 30, 2017			December 31, 2016
	(Unaudited)							June 30, 2020		December 31, 2019
ASSETS							ASSETS	(Unaudited)
Current assets:							Current assets:
Cash and cash equivalents	$	43,168		$	98,875		Cash and cash equivalents	$	10,957	$	36,217
Restricted cash	47,680			2,429
Trade accounts receivable, net of allowance of $1,907 and $0, respectively	168,220			108,655
Accounts receivable - related parties	22			31
Income tax receivable	3,010			1,271
Inventories	35,255			35,691

Trade accounts receivable, net of allowances of $6,633 and $2,208, for June 30, 2020, and December 31, 2019, respectively							Trade accounts receivable, net of allowances of $6,633 and $2,208, for June 30, 2020, and December 31, 2019, respectively	70,933		99,626

Inventories, net							Inventories, net	10,214		20,262
Prepaid expenses	24,470			15,575			Prepaid expenses	6,115		6,407
Assets held for sale							Assets held for sale	13,415		55,149
Other current assets	5,224			2,003			Other current assets	2,602		2,727

Total current assets	327,049			264,530			Total current assets	114,236		220,388
Property and equipment, net	516,371			488,848			Property and equipment, net	249,648		297,113
Operating lease right of use assets							Operating lease right of use assets	11,567		14,540
Deferred debt costs, net of amortization	2,038			—			Deferred debt costs, net of amortization	1,066		2,198
Goodwill							Goodwill	8,309		—
Intangible assets, net of amortization	3,280			3,458			Intangible assets, net of amortization	6,424		2,603

Other assets	12,407			11,324			Other assets	15,594		13,632
Total assets	$	861,145		$	768,160		Total assets	$	406,844	$	550,474
LIABILITIES AND STOCKHOLDERS' EQUITY							LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:							Current liabilities:
Accounts payable	$	89,550		$	47,959		Accounts payable	$	52,765	$	58,022
Accrued expenses	62,076			51,329			Accrued expenses	44,160		41,962
Current portion of long-term debt, net	50,849			38,468
Current portion of long-term debt							Current portion of long-term debt	17,606		18,738
Derivative liability							Derivative liability	12,763		—
Accrued short-term insurance reserves							Accrued short-term insurance reserves	17,238		15,002
Operating lease right-of-use liabilities, current portion							Operating lease right-of-use liabilities, current portion	4,336		4,906
Liabilities associated with assets held for sale							Liabilities associated with assets held for sale	1,009		5,248
Other current liabilities	3,626			2,065			Other current liabilities	1,817		4,306
Total current liabilities	206,101			139,821			Total current liabilities	151,694		148,184
Long-term debt, net	269,330			184,752
Deferred tax liabilities	389			—
Long-term debt, net of discounts and deferred financing costs of $25,513 and $8,795, at June 30, 2020, and December 31, 2019, respectively							Long-term debt, net of discounts and deferred financing costs of $25,513 and $8,795, at June 30, 2020, and December 31, 2019, respectively	300,405		308,365
Accrued long-term insurance reserves							Accrued long-term insurance reserves	24,445		20,204
Deferred compensation							Deferred compensation	11,056		10,838
Operating lease right-of-use liabilities, long-term portion							Operating lease right-of-use liabilities, long-term portion	7,573		9,634
Asset retirement obligations							Asset retirement obligations	10,614		9,044
Deferred tax liability							Deferred tax liability	628		—
Other long-term liabilities	30,753			29,179			Other long-term liabilities	2,482		3,082
Commitments and contingencies
Total liabilities							Total liabilities	508,897		509,351
Series A Participating Preferred Stock; $0.01 par value; 5,000,000 authorized and 118,805 and 0 shares outstanding at June 30, 2020, and December 31, 2019, respectively							Series A Participating Preferred Stock; $0.01 par value; 5,000,000 authorized and 118,805 and 0 shares outstanding at June 30, 2020, and December 31, 2019, respectively	22,000		—
Stockholders' equity:							Stockholders' equity:
Preferred stock; $0.01 par value; 5,000,000 shares authorized; none designated or issued at September 30, 2017 and December 31, 2016	—			—
Common stock; $0.01 par value; 80,000,000 shares authorized; 26,096,370 shares issued and 26,028,149 shares outstanding at September 30, 2017; 26,095,431 shares issued and 25,998,844 shares outstanding at December 31, 2016	261			261
Common stock; $0.01 par value; 198,805,000 and 80,000,000 shares authorized at June 30, 2020, and December 31, 2019, respectively; 27,912,059 and 27,912,059 shares issued and 24,938,700 and 24,904,485 shares outstanding at June 30, 2020, and December 31, 2019, respectively							Common stock; $0.01 par value; 198,805,000 and 80,000,000 shares authorized at June 30, 2020, and December 31, 2019, respectively; 27,912,059 and 27,912,059 shares issued and 24,938,700 and 24,904,485 shares outstanding at June 30, 2020, and December 31, 2019, respectively	279		279
Additional paid-in capital	433,181			417,624			Additional paid-in capital	493,649		472,594
Accumulated deficit	(76,413		)	—
Treasury stock, at cost, 68,221 and 96,587 shares at September 30, 2017 and December 31, 2016, respectively	(2,457		)	(3,477		)
Retained deficit							Retained deficit	(612,648)		(423,169)
Treasury stock, at cost, 2,973,359 and 3,007,574 shares at June 30, 2020, and December 31, 2019, respectively							Treasury stock, at cost, 2,973,359 and 3,007,574 shares at June 30, 2020, and December 31, 2019, respectively	(5,333)		(8,581)
Total stockholders' equity	354,572			414,408			Total stockholders' equity	(124,053)		41,123
Total liabilities and stockholders' equity	$	861,145		$	768,160		Total liabilities and stockholders' equity	$	406,844	$	550,474

See accompanying notes tounauditedconsolidated financial statements.

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,
	2020		2019		2020		2019
Revenues:
Well Servicing	$	47,318	$	58,518	$	105,459	$	120,502
Water Logistics	33,254		51,031		77,635		106,632
Completion & Remedial Services	9,065		38,426		34,946		74,031
Total revenues	89,637		147,975		218,040		301,165
Expenses:					—		—
Well Servicing	39,385		46,162		90,202		94,970
Water Logistics	25,582		35,529		58,701		72,828
Completion & Remedial Services	9,646		27,369		30,828		52,385
General and administrative, including stock-based compensation of $78 and $3,329 in the three months ended June 30, 2020 and 2019, respectively, and $1,414 and $6,604 in the six months ended June 30, 2020 and 2019, respectively	30,445		30,186		65,515		61,941
Impairments	—		—		99,628		—
Depreciation and amortization	12,853		17,296		27,619		33,478
(Gain) loss on disposal of assets	(474)		580		(511)		1,277
Total expenses	117,437		157,122		371,982		316,879
Operating loss	(27,800)		(9,147)		(153,942)		(15,714)
Other income (expense):
Interest expense	(12,775)		(10,358)		(23,393)		(20,972)
Interest income	—		114		62		360
Gain (loss) on derivative	502		—		(3,050)		—
Other income	40		48		70		345
Loss from continuing operations before income taxes	(40,033)		(19,343)		(180,253)		(35,981)
Income tax (expense) benefit	308		28		4,099		1,879
Loss from continuing operations	(39,725)		(19,315)		(176,154)		(34,102)
Loss from discontinued operations	(4,873)		(8,462)		(13,325)		(21,151)
Net loss	$	(44,598)	$	(27,777)	$	(189,479)	$	(55,253)

Net loss from continuing operations per share, basic and diluted	$	(1.59)	$	(0.71)	$	(7.06)	$	(1.26)
Net loss from discontinued operations per share, basic and diluted	$	(0.20)	$	(0.31)	$	(0.53)	$	(0.78)
Net loss per share of common stock, basic and diluted	$	(1.79)	$	(1.02)	$	(7.59)	$	(2.04)

Three Months Ended September 30, Nine Months Ended September 30,
2017 2016 2017 2016
(Successor) (Predecessor) (Successor) (Predecessor)
Revenues:
Completion and remedial services $ 123,650
$ 49,425
$ 311,466
$ 125,348
Water logistics

52,333
47,178
153,279
142,919
Well servicing 54,629
43,160
156,302
118,891
Contract drilling 2,848
1,847
7,728
4,812
Total revenues 233,460
141,610
628,775
391,970
Expenses:

Completion and remedial services 84,481
40,292
232,932
107,941
Water logistics

41,281
39,268
124,399
119,053
Well servicing 43,219
35,028
125,931
101,345
Contract drilling 2,547
1,683
6,818
4,612
General and administrative, including stock-based compensation of $5,891 and $2,238 in the three months ended September 30, 2017 and 2016 and $16,615 and $7,355 for the nine months ended September 30, 2017 and 2016, respectively 39,235
30,065
109,478
86,706
Restructuring costs —
10,470
—
10,470
Depreciation and amortization 29,478
53,142
80,846
164,141
Goodwill impairment —
646
—
646
(Gain) loss on disposal of assets 26
(128 ) (664 ) 133
Total expenses 240,267
210,466
679,740
595,047
Operating loss (6,807 ) (68,856 ) (50,965 ) (203,077 )
Other income (expense):

Interest expense (8,892 ) (23,953 ) (27,181 ) (67,188 )
Interest income 5
14
23
23
Bargain purchase gain on acquisition —
662
—
662
Other income 109
37
344
378
Loss before income taxes (15,585 ) (92,096 ) (77,779 ) (269,202 )
Income tax benefit (expense) 1,740
(1 ) 1,366
3,883
Net loss $ (13,845 ) $ (92,097 ) $ (76,413 ) $ (265,319 )
Loss per share of common stock:
Basic $ (0.53 ) $ (2.16 ) $ (2.94 ) $ (6.32 )
Diluted $ (0.53 ) $ (2.16 ) $ (2.94 ) $ (6.32 )

See accompanying notes tounauditedconsolidated financial statements.

Basic Energy Services, Inc.

Consolidated Statements of Stockholders’ Equity

(in thousands, except share data)


	Common Stock					Additional		Treasury							Total
	Issued	Common		Paid-In			Treasury		Treasury		Retained		Stockholders'
	Shares	Stock		Capital			Shares		Stock		Deficit		Equity
Balance - December 31, 2019	27,912,059	$	279	$	472,594		3,007,574		$	(8,581)	$	(423,169)	$	41,123
Issuances of restricted stock	—	—		—			—		—		—		—
Amortization of equity-classified share-based compensation	—	—		1,336			—		—		—		1,336
Treasury stock, net	—	—		(3,263)			(72,879)		3,256		—		(7)
Capital contribution	—	—		22,904			—		—		—		22,904
Net loss	—	—		—			—		—		(144,881)		(144,881)
Balance - March 31, 2020 (unaudited)	27,912,059	$	279	$	493,571		2,934,695		$	(5,325)	$	(568,050)	$	(79,525)
Issuances of restricted stock	—	—		—			—		—		—		—
Amortization of equity-classified share-based compensation	—	—		78			—		—		—		78
Treasury stock, net	—	—		—			38,664		(9)		—		(9)

Net loss	—	—		—			—		—		(44,598)		(44,598)
Balance - June 30, 2020 (unaudited)	27,912,059	$	279	$	493,649		2,973,359		$	(5,333)	$	(612,648)	$	(124,053)







	Common Stock					Additional		Treasury							Total
	Issued	Common		Paid-In			Treasury		Treasury		Retained		Stockholders'
	Shares	Stock		Capital			Shares		Stock		Deficit		Equity
Balance - December 31, 2018	26,990,034	$	270	$	464,264		242,322		$	(3,835)	$	(241,271)	$	219,428
Issuances of restricted stock	277,865	3		(3)			—		—		—		—
Amortization of equity-classified share-based compensation	—	—		3,275			—		—		—		3,275
Treasury stock, net	—	—		(163)			68,227		(180)		—		(343)

Net loss	—	—		—			—		—		(27,476)		(27,476)
Balance - March 31, 2019 (unaudited)	27,267,899	$	273	$	467,373		310,549		$	(4,015)	$	(268,747)	$	194,884
Issuances of restricted stock	644,160	6		(6)			—		—		—		—
Amortization of equity-classified share-based compensation	—	—		3,329			—		—		—		3,329
Treasury stock, net	—	—		—			596,194		(1,340)		—		(1,340)
Exercise of stock options	—	—		—			—		—		—		—
Net loss	—	—		—			—		—		(27,777)		(27,777)
Balance - June 30, 2019 (unaudited)	27,912,059	$	279	$	470,696		906,743		$	(5,355)	$	(296,524)	$	169,096

Additional Total
Common Stock Paid-In Treasury Accumulated Stockholders'
Shares Amount Capital Stock Deficit Equity
Balance - December 31, 2016 26,095,431
$ 261
$ 417,624
$ (3,477 ) $ —
$ 414,408
Issuance of stock 939
—
��
—
—
—
Amortization of share-based compensation —
—
16,615
—
—
16,615
Treasury stock, net —
—
(1,058 ) 1,020
—
(38 )
Net loss —
—
—
—
(76,413 ) (76,413 )
Balance - September 30, 2017 (unaudited) 26,096,370
$ 261
$ 433,181
$ (2,457 ) $ (76,413 ) $ 354,572

See accompanying notes tounauditedconsolidated financial statements.

Basic Energy Services, Inc.

Consolidated Statements of Cash Flows

(Unaudited)

(in thousands)


	Six Months Ended June 30,
	2020		2019

Cash flows from operating activities:
Net loss	$	(189,479)	$	(55,253)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities
Depreciation and amortization	27,619		56,489
Asset impairment	97,115		—
Inventory and other write-downs	4,846		—
Loss on derivative	3,050		—
Accretion on asset retirement obligation	998		172
Change in allowance for doubtful accounts	4,425		322
Amortization of deferred financing costs	2,251		1,155
Amortization of debt discount	2,181		525
Non-cash compensation	1,233		6,851
Loss on disposal of assets	2,297		1,797
Deferred income taxes	(3,984)		—
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable	62,963		9,228
Inventories	2,903		4,554
Prepaid expenses and other current assets	2,192		4,778
Other assets	651		46
Accounts payable	(14,130)		(21,548)
Income tax receivable	—		891
Other liabilities	(4,901)		(3,068)
Accrued expenses	(7,842)		4,311
Net cash (used in) provided by operating activities	(5,612)		11,250
Cash flows from investing activities:
Purchase of property and equipment	(5,947)		(33,359)
Proceeds from sale of assets	44,952		5,009
Payments for other long-term assets	(768)		—
Payments for businesses, net of cash acquired	(59,350)		—
Net cash used in investing activities	(21,113)		(28,350)
Cash flows from financing activities:
Proceeds from debt	38,000		—
Repayments of debt	(34,770)		(17,334)
Change in treasury stock including restricted stock issuances	(16)		(1,683)
Deferred loan costs and other financing activities	(1,749)		(469)
Net cash (used in) provided by financing activities	1,465		(19,486)
Net decrease in cash, cash equivalents and restricted cash	(25,260)		(36,586)
Cash and cash equivalents - beginning of period	36,217		90,300
Cash and cash equivalents - end of period	$	10,957	$	53,714
Noncash investing and financing activity:
Capital leases and notes issued for equipment	$	498	$	7,588
Change in accrued property and equipment	(131)		1,348
Issuance of Series A Participating Preferred Stock	22,000		—
Issuance of derivative liability	9,713		—
Change in asset retirement obligations	$	8	$	108

Nine Months Ended September 30,
2017 2016
(Successor) (Predecessor)
Cash flows from operating activities:
Net loss $ (76,413 ) $ (265,319 )
Adjustments to reconcile net loss to net cash
provided by (used in) operating activities:
Depreciation and amortization 80,846
164,141
Goodwill impairment —
646
Bargain purchase gain on acquisition —
(662 )
Accretion on asset retirement obligation 119
109
Change in allowance for doubtful accounts 1,907
(690 )
Amortization of deferred financing costs 14
6,085
Amortization of debt discounts 5,649
(209 )
Non-cash compensation 16,615
7,355
(Gain) loss on disposal of assets (664 ) 133
Deferred income taxes 389
(4,403 )
Changes in operating assets and liabilities, net of acquisitions:
Accounts receivable (61,463 ) 7,038
Inventories 437
3,274
Income tax receivable (1,740 ) 555
Prepaid expenses and other current assets (9,446 ) 1,245
Other assets (1,083 ) (837 )
Accounts payable 32,865
(13,962 )
Other liabilities 3,046
(4,770 )
Accrued expenses 10,747
28,466
Net cash provided by (used in) operating activities 1,825
(71,805 )
Cash flows from investing activities:
Purchase of property and equipment (48,295 ) (22,907 )
Proceeds from sale of assets 7,834
2,781
Net cash used in investing activities (40,461 ) (20,126 )
Cash flows from financing activities:
Payments of debt (33,649 ) (37,962 )
Proceeds from debt 64,000
165,000
Change in restricted cash (45,251 ) (28,677 )
Shares added to treasury stock as a result of net share settlements due to vesting of restricted stock

(38 ) (640 )
Deferred loan costs and other financing activities (2,133 ) (18,184 )
Net cash (used in) provided by financing activities (17,071 ) 79,537
Net decrease in cash and equivalents (55,707 ) (12,394 )
Cash and cash equivalents - beginning of period 98,875
46,732
Cash and cash equivalents - end of period $ 43,168
$ 34,338

See accompanying notes tounauditedconsolidated financial statements.

BASIC ENERGY SERVICES, INC.

Notes to Consolidated Financial Statements

~~September~~June 30, ~~2017~~2020 (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 ~~footnotes~~notes required by accounting principles generally accepted in the United States for complete financial statements. Certain information relating to ~~our~~the Company's 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, ~~2016.~~2019. 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.

~~Emergence from Chapter 11~~

In connection with the Company’s emergence from its bankruptcy cases (the "Chapter 11 Cases"), on December 23, 2016 (the "Effective Date"), the Company applied the provisions of fresh start accounting, pursuant to Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 852, Reorganizations, to its consolidated financial statements. We elected to apply fresh start accounting effective December 31, 2016, to coincide with the timing of our normal December accounting period close.

The implementation of the First Amended Joint Prepackaged Chapter 11 Plan of Basic Energy Services, Inc. and its Affiliated Debtors (as confirmed, the "Prepackaged Plan") and the application of fresh start accounting materially changed the carrying amounts and classifications reported in our consolidated financial statements and resulted in the Company becoming a new entity for financial reporting purposes. Accordingly, our consolidated financial statements for periods prior to December 31, 2016 will not be comparable to our consolidated financial statements as of December 31, 2016 or for periods subsequent to December 31, 2016.

References to “Successor” or “Successor Company” refer to the Company on or after December 31, 2016, after giving effect to the implementation of the Prepackaged Plan and the application of fresh start accounting. References to “Predecessor” or “Predecessor Company” refer to the Company prior to December 31, 2016. Additionally, references to periods on or after December 31, 2016 refer to the Successor and references to periods prior to December 31, 2016 refer to the Predecessor.

~~Liquidity and Capital Resources~~

As of September 30, 2017, our primary capital resources were utilization of capital leases and borrowings under our $100.0 million accounts receivable securitization facility (the “New ABL Facility”). As of September 30, 2017, we had $64.0 million in borrowings under the New ABL Facility. At September 30, 2017, we had unrestricted cash and cash equivalents of $43.2 million compared to $98.9 million as of December 31, 2016. An additional amount of $47.7 million is classified as restricted cash. 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.

On October 27, 2017, the Company entered into Amendment No. 1 (“Amendment No. 1”) to the New ABL Facility. Among other things, Amendment No. 1 (i) increased the aggregate commitments under the Credit Agreement from $100 million to $120 million, (ii) appointed CIT Bank, N.A. to serve as syndication agent and (iii) added new lenders and amended the commitment schedule to the Credit Agreement.

Nature of Operations

~~Basic~~The Company provides a wide range of ~~well site~~wellsite services to oil and natural gas drilling and producing companies, including ~~completion~~Well Servicing, Water Logistics and ~~remedial services, water logistics, well servicing and contract drilling.~~Completion & Remedial Services. These services are primarily provided ~~using Basic’s~~by the Company's fleet of equipment. ~~Basic’s~~The Company’s operations are concentrated in ~~the~~ major United States onshore oil and natural gas producing regions located in Texas, California, New Mexico, Oklahoma, ~~North Dakota, Wyoming,~~ Arkansas, Kansas, Louisiana, ~~California,~~Wyoming, North Dakota and Colorado. The Company's scope of operations was expanded effective beginning March 9, 2020, with the ~~Rocky Mountains and Appalachia.~~

acquisition of C&J Well Services, Inc. See Note 2. Acquisition, for further discussion.

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of ~~Basic and its wholly owned subsidiaries. Basic has no variable interest in any non-consolidated organization, entity, partnership or contract.~~the Company's subsidiaries, for which the Company holds a majority voting interest. All intercompany transactions and balances have been eliminated.

Other Reclassifications

~~Accounting~~ Certain reclassifications have been made to prior period amounts to conform to the current period presentation. A majority of the reclassifications were related to discontinued operations. These reclassifications do not impact net income (loss) and do not reflect a material change to the information previously presented in our consolidated financial statements. See Note 3. Discontinued Operations for further discussion on amounts included in loss from discontinued operations.

Estimates, Risks and ~~Assumptions~~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 and liabilities ~~revenue,~~ and ~~expenses. Critical~~disclosures of contingent liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Management uses historical and other pertinent information to determine these estimates. Actual results could differ from those estimates. Areas where critical accounting estimates are made by management include impairments of long-lived assets, certain financial instruments, acquisition purchase price allocation, litigation, and self-insured risk reserves. For further discussion of impairments of long-lived assets, see Note 13. Impairments.

Inventories

For rental and fishing tools, inventories consisting mainly of grapples and controls are stated at lower of cost or net realizable value. Other inventories, consisting mainly of manufacturing raw materials, rig components, repair parts, drilling and completion materials and gravel, are held for use in the operations of the Company and are stated at lower of cost or net realizable value, with cost being determined on the first-in, first-out method.

In addition to comparing the carrying amount of inventory to its market value, the Company also makes a comparison between volume of inventory and demand for the ultimate production into which inventory will be

converted and increases reserves for excess and obsolete inventory. For further discussion on impairments of inventory see Note 13. Impairments.

Assets Held for Sale

Assets are classified as held for sale when, among other factors, they are identified and marketed for sale in their present condition, management is committed to their disposal, and the sale of the asset is probable within one year. For the quarter ended June 30, 2020, the company classified to assets held for sale $4.2 million of certain rig construction assets, associated with our Taylor manufacturing facility, the majority of which are expected to be sold in the third quarter of 2020. Also included in assets classified as held for sale were certain property, plant and equipment assets of our pressure pumping operations and contract drilling operations that were classified as discontinued operations beginning in late 2019. For further discussion on the pressure pumping and contract drilling assets, see Note 3. Discontinued Operations.

COVID-19 and Commodity Price Collapse Impact on Company Liquidity; Going Concern

Beginning in March 2020, as a result of multiple significant factors impacting supply and demand in the global oil and natural gas markets, including a global outbreak of coronavirus (“COVID-19”), and actions by members of the Organization of the Petroleum Exporting Countries (“OPEC”) and other foreign countries, including Russia, the posted price for West Texas Intermediate oil declined sharply. Oil demand has significantly deteriorated through the first six months of 2020, in part, as a result of outbreak of COVID-19 and corresponding preventative measures taken to mitigate the spread of the virus. This decline in demand coincided with the announcement of price reductions and possible production increases by members OPEC and other oil exporting nations. Although OPEC and other oil exporting nations ultimately agreed to cut production, and commodity prices have improved during early third quarter of 2020, the downward pressure on commodity prices has remained and could continue in the foreseeable future.

Oil and natural gas commodity prices are expected to continue to be volatile. Despite improvements in early third quarter of 2020, the collapse in the demand for oil caused by this unprecedented global health and economic crisis, coupled with oil oversupply, has had a material adverse impact on the demand for our services and the prices we can charge for our services.

The decline in our customers’ demand for our services has also had a material adverse impact on our financial condition, results of operations and cash flows during the first half of 2020. Demand for our products and services will continue to decline if our customers further revise their capital budgets downward and adjust their operations in response to lower oil prices. We cannot predict the duration or effects of these current conditions, but if the price of oil further declines or remains at current levels for a lengthy period, our business, financial condition, results of operations, cash flows, and prospects will continue to be materially and adversely affected. The impact of these conditions on our estimates of future operating cash flows resulted in additional impairments of long-lived and intangible assets as of March 31, 2020. For further discussion of impairments of long-lived assets, see Note 13. Impairments.

Based on our current operating and commodity price forecasts and capital structure, we believe that if certain financial ratios or cash dominion covenants were to come into effect under our debt instruments, we will have difficulty complying with certain of such obligations. Certain covenants, such as consolidated fixed charge coverage ratio and cash dominion provisions in the revolving credit facility (the "ABL Facility") spring into effect under certain triggers defined in the ABL Credit Agreement, as amended, for so long as such applicable trigger period is in effect. Additionally, certain triggers in the ABL Facility increase certain financial and borrowing base reporting requirements for so long as such applicable trigger period is in effect. Failure to comply, for example, with a “springing” consolidated fixed charge coverage ratio requirement under the ABL Facility would result in an event of default under the ABL Facility, which would result in a cross-default under the Senior Notes. If an event of default were to occur, our lenders could, in addition to other remedies such as charging default interest, accelerate the maturity of the outstanding indebtedness, making it immediately due and payable, and we may not have sufficient liquidity to repay those amounts.

We had the $9.4 million minimum availability under the ABL Facility as of June 30, 2020. To maintain compliance with certain of the minimum availability covenant requirements as of June 30, 2020, in early July 2020 we repaid the $2.6 million amount of borrowings that was previously outstanding, and advanced $2.3 million of our available cash balance to the Administrative Agent. During the remainder of July 2020, and as of August 7, 2020, we are currently subject to increased financial and borrowing base information reporting and have made additional advances totaling $10.7 million of our available cash balance to the Administrative Agent as needed to maintain compliance with the minimum availability covenant requirements.

Management has taken several steps to generate additional liquidity, including through reducing operating and administrative costs through employee headcount reductions, closing operating locations, employee furloughs and other cost reduction measures, and the suspension of growth capital expenditures in our continuing business operations with the goal of preserving margins and improving working capital. Management may implement further similar cost and capital expenditure reductions, as necessary.

Due to the uncertainty of future oil and natural gas prices and the effects the outbreak of COVID-19 will have on our future results of operations, operating cash flows and financial condition, there is substantial doubt as to the ability of the Company to continue as a going concern. Additional steps management would implement to alleviate this substantial doubt would include additional sales of non-strategic assets, obtaining waivers of debt covenant requirements from our lenders, restructuring or refinancing our debt agreements, or obtaining equity financing. There can be no assurances that, if required, the Company would be able to successfully sell assets, obtain waivers, restructure its indebtedness, or complete any strategic transactions in the current environment.

Management has prepared these consolidated financial statements in accordance with U.S. generally accepted accounting principles applicable to a going concern, which ~~significant judgment~~contemplates that assets will be realized and liabilities will be discharged in the normal course of business as they become due. These consolidated financial statements do not reflect the adjustments to the carrying values of assets and liabilities and the reported revenues and expenses and balance sheet classifications that would be necessary if the Company was unable to realize its assets and settle its liabilities as a going concern in the normal course of operations. Such adjustments could be material and adverse to the financial results of the Company.

2. Acquisition

On March 9, 2020, the Company entered into a Purchase Agreement (the “Purchase Agreement”) with Ascribe Investments III LLC, a Delaware limited liability company (“Ascribe”), NexTier Holding Co., a Delaware corporation (“Seller”) and C&J Well Services, Inc., a Delaware corporation, and wholly owned subsidiary of Seller (“CJWS”), whereby the Company acquired all of the issued and outstanding shares of capital stock of CJWS, such that CJWS became a wholly-owned subsidiary of the Company. CJWS is ~~used,~~the third largest rig servicing provider in the U.S., with a leading footprint in California and a strong customer base. Following the acquisition of CJWS, the Company has expanded its footprint in the Permian, California and other key oil basins.

Pursuant to the Purchase Agreement, among other things, (i) Seller transferred and delivered to the Company and the Company purchased and acquired from Seller, all of the issued and outstanding shares of capital stock of CJWS held by Seller (the "Stock Purchase"); (ii) as a portion of the consideration for the Stock Purchase, Ascribe, on behalf of the Company, conveyed to Seller certain 10.75% senior secured notes due October 2023 (the "Senior Notes") issued by the Company to Ascribe in an aggregate par value amount equal to $34.4 million (the "Ascribe Senior Notes"); and (iii) Ascribe entered into an Exchange Agreement, dated March 9, 2020, with the Company (the "Exchange Agreement") pursuant to which, among other things, Ascribe exchanged the Ascribe Senior Notes for (a) 118,805 shares of newly issued preferred stock, designated as "Series A Participating Preferred Stock," par value $0.01 per share, of the Company (the "Series A Preferred Stock") and, (b) an amount in cash for accrued interest on the Ascribe Senior Notes approximately equal to $1.5 million (the "Exchange Transaction" and, together with the Stock Purchase and the other transactions contemplated by the Purchase Agreement, the "CJWS Transaction"). For further discussion of the Series A Preferred Stock, see Note 9. Series A Participating Preferred Stock.

Pursuant to the Purchase Agreement, at closing Seller received consideration in the aggregate amount of $95.7 million comprised of (a) cash consideration equal to $59.4 million (subject to customary reductions for indebtedness and transaction expenses, as well as post-closing working capital adjustments) and (b) the Ascribe Senior Notes transferred to Seller by Ascribe (on behalf of the Company) as described above. In connection with the CJWS Transaction, pursuant to the Purchase Agreement, Ascribe has certain contingent obligations to the Seller to make Seller whole on the par value of the Ascribe Senior Notes as of the earlier of the first anniversary of the closing of the Stock Purchase, a bankruptcy of the Company, or a change of control of the Company (the "Make-Whole Payment"). Considering this contingent Make-Whole Payment by Ascribe to the Seller, the fair value of the Ascribe Senior Notes issued to the Seller on March 9, 2020, was $36.3 million. If Ascribe is required to pay the Make-Whole Payment to Seller pursuant to the Purchase Agreement, the Company will be required to reimburse to Ascribe the amount of such Make-Whole Payment (such amount, the "Make-Whole Reimbursement Amount") either (i) in cash (a) to the extent the Company has available cash (as determined by an independent committee of the Company's board of directors) and (b) subject to satisfaction of certain "Payment Conditions" set forth in the ABL Credit Agreement (as defined below) or (ii) if the Company is unable to pay the full Make-Whole Reimbursement Amount in cash pursuant to clause "(i)" of this paragraph, in additional Senior Notes as permitted under the Indenture. In consideration of providing the Make-Whole Payment to Seller, the Company paid Ascribe $1 million in

cash at the closing of the CJWS Transaction. The Company's obligation to Ascribe associated with the Make-Whole Reimbursement Amount is reflected as a derivative instrument in accordance with Accounting Standards Codification ("ASC") No. 815 "Derivatives and Hedging" ("ASC 815") with an initial fair value of approximately $9.7 million based on a risk-adjusted market differential between the fair value of the Ascribe Senior Notes and their $34.4 million par value as of the March 9, 2020, closing date. Changes in fair value of the Make-Whole Reimbursement Amount each period are "marked to market" and charged or credited to Gain (Loss) on Derivative in the accompanying consolidated statements of operations. The fair value of the Make-Whole Reimbursement Amount liability as of June 30, 2020, is approximately $12.8 million and results in $3.1 million of derivative loss during the six months ended June 30, 2020. The Make-Whole Reimbursement Amount liability is classified as a derivative liability, a current liability in the accompanying balance sheet.

Of the cash consideration paid to the Seller, $15 million was funded from a Senior Secured Promissory Note to Ascribe. For a further discussion of the Exchange Agreement and the Senior Secured Promissory Note, see Note 6. Long-Term Debt and Interest Expense.

The CJWS Transaction was considered an acquisition of a business in accordance with ASC 805 "Business Combinations" and the Company applied the acquisition method of accounting. The Company's preliminary allocation of the purchase price, including preliminary working capital adjustments, to the estimated fair value of the CJWS net assets is as follows (in thousands):


	March 9, 2020
Current assets	$	42,061
Property and equipment	63,418
Operating lease right of use asset	734
Other assets	1,859
Intangible asset	4,000
Goodwill	18,874
Total assets acquired	130,946

Current liabilities	24,742
Long-term liabilities	12,051
Total liabilities assumed	36,793
Net assets acquired	$	94,153

The allocation of the purchase price to CJWS's net tangible assets and liabilities and identifiable intangible assets as of March 9, 2020, is preliminary and subject to revisions to the fair value calculations for the identifiable assets and liabilities. The final purchase price allocation could differ from the preliminary allocation noted in the summary above. The preliminary allocation of purchase price includes approximately $18.9 million allocated to nondeductible goodwill recorded to our well servicing and water logistics segments based on relative fair values of these acquired lines of business. The acquired property and equipment is stated at fair value, and depreciation on the acquired property and equipment is computed using the straight-line method over the estimated useful lives of each asset. We depreciate our assets over the following depreciable lives:


Buildings			20 to 30 years
Machinery and equipment			3 to 15 years
Automobiles and trucks			3 to 7 years

The acquired intangible assets represent approximately $4 million for the CJWS trade name that is stated at estimated fair value and is amortized on a straight-line basis over the estimated useful life of 15 years.

For the six month period ended June 30, 2020, our revenues and pretax earnings included $65.1 million and $3.4 million (excluding the impact of asset impairments of $35.2 million), respectively, associated with the CJWS acquired operations after the closing on March 9, 2020. In addition, CJWS Transaction-related costs of approximately $9 million were incurred during the six month period ended June 30, 2020, consisting of external legal and consulting fees and due diligence costs. These costs have been recognized in general and administrative expense in the consolidated statements of operations.

The pro forma information presented below has been prepared to give effect to the CJWS Transaction as if it had occurred at the beginning of the periods presented. The pro forma information includes the impact from the allocation of the acquisition purchase price on depreciation and amortization and the impact on interest expense

associated with acquisition financing. It also excludes the impact of ~~any changes in estimates would have a significant effect~~the CJWS Transaction acquisition costs charged to earnings during the 2020 period. The pro forma information is presented for illustration purposes only and is based on ~~our consolidated financial statements. Actual results and outcomes may vary from management's estimates and assumptions. Examples of critical accounting~~ estimates and assumptions ~~include:~~the Company deemed appropriate. The following pro forma information is not necessarily indicative of the results that would have been achieved if the CJWS Transaction had occurred in the past, and should not be relied upon as an indication of the operating results that the Company would have achieved if the transaction had occurred at the beginning of the periods presented, and our operating results, or the future results that we will achieve, may be different from those reflected in the pro forma information below (in thousands, except per share and average share outstanding information).


	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020		2019
Revenues	$	89,637	$	253,979	$	275,845	$	511,809
Loss from continuing operations	(39,725)		(27,098)		$	(161,227)	$	(48,952)

Net loss from continuing operations per
Net loss from continuing operations per share, basic and diluted	$	(1.59)	$	(1.00)	$	(6.47)	$	(1.81)

Weighted average shares outstanding, basic and diluted	24,957,478		27,203,635		24,935,693		27,028,041

•

3. Discontinued Operations

During the third and fourth quarters of 2019, the Company's management decided to divest all of its contract drilling rigs, and a majority of pressure pumping equipment and related ancillary equipment, respectively, assets having a combined net book value of $91.8 million. The majority of the real estate and equipment was sold during late 2019 and the first half of 2020, with the remaining pumping and related assets classified as Assets ~~lives used~~Held for Sale on our Consolidated Balance Sheet. The Company is pursuing additional transactions to ~~determine depreciation~~divest the remainder of these non-strategic assets later during 2020, however the Company recorded an impairment on the remaining assets of $2.3 million at March 31, 2020. A complete summary of our discontinued operations is included in Note 2. Discontinued Operations of the Financial Statements and ~~amortization~~Supplementary Data in our most recent Annual Report on Form 10-K.

The operating results of the pressure pumping operations and contract drilling operations, which were historically included in the Completions & Remedial Services and Other Services segments, respectively, have been reclassified as discontinued operations in the Consolidated Statement of Operations for the three and six month periods ended June 30, 2020 and 2019, and are detailed in the table below (in thousands):


	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020		2019





Revenues	$	25	$	41,872	$	120	$	85,884

Direct expenses	892		34,105		2,411		74,824
General and administrative	4,203		4,615		6,168		8,383
Depreciation and amortization	—		11,694		—		23,010
Impairment expense	—		—		2,330
Loss (gain) on disposal of assets	(84)		(237)		2,671		521
Total expenses	5,011		50,177		13,580		106,738

Operating loss	(4,986)		(8,305)		(13,460)		(20,854)
Other income (expense):
Interest expense	—		(159)		—		(302)
Interest income	—		—		—		—
Other income	113		2		135		5
Loss from discontinued operations	$	(4,873)	$	(8,462)	$	(13,325)	$	(21,151)

Interest expense in discontinued operations is related to interest expense on finance lease assets that operated in the discontinued Completions & Remedial Services and Other Services segments. Impairment expense was recorded during the three month period ended March 31, 2020, associated with certain non-strategic assets with

carrying values that were in excess of current estimated selling price. General and administrative expense consisted primarily of bad debt expense recorded on customer receivables from discontinued operations.

During the six month period ended June 30, 2020, a portion of the assets identified as of December 31, 2019, were disposed. Remaining assets and liabilities related to the divested operations are included in the consolidated balance sheets and consist as follows (in thousands):


	June 30, 2020		December 31, 2019
Assets-held-for-sale
Inventories	$	—	$	2,069
Right of use assets	1,001		1,659
Property, plant and equipment, net	7,744		50,496
Total assets-held-for-sale-future-use	$	8,745	$	54,224
Liabilities related to Assets-held-for-sale
Right of use liabilities	$	1,009	$	1,659
Capital leases	—		3,589
Total Liabilities related to Assets-held-for-sale discontinued operations	$	1,009	$	5,248

Applicable Consolidated Statements of Cash Flow information related to the discontinued operations for the six months ended June 30, 2020, and 2019 are detailed in the table below (in thousands):


	Six Months Ended June 30,
	2020		2019
Cash Flows from Discontinued Operations
Net cash provided (used) by operating activities	$	(8,188)	$	2,980
Net cash provided (used) in investing activities	$	40,514	$	(6,743)

Cash capital expenditures and finance lease additions related to discontinued operations were $8.3 million and $1.5 million, respectively, for the six months ended June 30, 2019. The Company did 0t have any cash or lease additions related to discontinued operations for the six months ended June 30, 2020. Proceeds from sale of assets related to discontinued operations totaled $40.5 million and $1.5 million for the six months ended June 30, 2020 and 2019, respectively.

4. Property and Equipment

The following table summarizes the components of property and equipment ~~and intangible assets;~~

•~~Fair value of property and equipment and intangible assets;~~

•~~Allowance for doubtful accounts;~~

•~~Litigation and self-insured risk reserves;~~

•~~Stock-based compensation; and~~

•~~Potential outcome of income tax events that have been recognized on our consolidated financial statements or returns.~~

~~2. Property and Equipment~~

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


	September 30, 2017		December 31, 2016			June 30, 2020		December 31, 2019
Land	$	20,876	$	21,010	Land	$	22,902	$	15,682
Buildings and improvements	39,899		39,588		Buildings and improvements	39,196		30,902
Well service units and equipment	109,568		96,365		Well service units and equipment	59,337		130,318
Frac equipment/test tanks	109,375		75,506
Disposal facilities					Disposal facilities	89,213		87,763
Fluid services equipment					Fluid services equipment	80,839		79,024
Rental equipment					Rental equipment	47,825		60,886
Pumping equipment	112,638		85,247		Pumping equipment	35,303		47,083
Water logistics equipment	75,253		57,359
Disposal facilities	51,256		47,507
Contract drilling equipment	11,064		12,257
Rental equipment	33,966		32,582
Light vehicles	19,835		12,722		Light vehicles	17,244		26,630
Fracturing/test tanks					Fracturing/test tanks	6,266		6,153
Brine and fresh water stations					Brine and fresh water stations	5,341		4,340
Other					Other	4,483		3,948
Software	727		641		Software	924		896
Other	4,122		3,885
Construction equipment	1,818		1,485
Brine and fresh water stations	2,697		2,694
	593,094		488,848
Property and equipment, gross					Property and equipment, gross	408,873		493,625
Less accumulated depreciation and amortization	76,723		—		Less accumulated depreciation and amortization	(159,225)		(196,512)
Property and equipment, net	$	516,371	$	488,848	Property and equipment, net	$	249,648	$	297,113

~~Basic~~ The Company is obligated under various ~~capital~~finance leases for certain vehicles and equipment that expire at various dates during the next five years. The table below summarizes the gross amount of property and equipment

and related accumulated amortization recorded under ~~capital~~finance leases and included above ~~consists of the following~~ (in thousands):


	June 30, 2020		December 31, 2019
Fluid services equipment	$	33,061	$	34,499
Pumping equipment	10,671		16,576
Light vehicles	8,996		19,563
Rental equipment	878		1,130

Well service units and equipment	193		—
Property and equipment under finance lease, cost	53,799		71,768
Less accumulated amortization	(19,894)		(27,727)
Property and equipment under finance lease, net	$	33,905	$	44,041

September 30, 2017 December 31, 2016
Pumping equipment $ 55,778
$ 12,806
Water logistics equipment 36,967
29,372
Light vehicles 12,484
5,729
Contract drilling equipment 783
999
Well service units and equipment 63
—
Construction equipment 28
28
106,103
48,934
Less accumulated amortization 11,985
—
Property and equipment under capital lease, net $ 94,118
$ 48,934

~~Amortization of assets held under capital leases is included in depreciation~~During the six month period ended June 30, 2020, and ~~amortization expense~~due to significant factors impacting supply and demand in the ~~consolidated statements~~global oil and natural gas markets, the Company assessed certain of ~~operations. Amortization amounts consisted~~its Property and Equipment assets for impairment. For further discussion, see Note 13. Impairments.

5. Goodwill and Intangible Assets

In connection with the March 9, 2020 acquisition of CJWS, the ~~following~~Company recorded goodwill of $18.9 million, which was initially allocated to its Well Servicing and Water Logistics reporting units based on their respective fair values. Activity during the period ended June 30, 2020, associated with goodwill by reporting units is as follows (in thousands):

Three Months Ended September 30, Nine Months Ended September 30,
2017 2016 2017 2016
(Successor) (Predecessor) (Successor) (Predecessor)
Lease amortization expense $ 5,657
$ 8,618
$ 13,245
$ 27,420


	Well Servicing		Water Logistics		Completion & Remedial		Total
Balance as of December 31, 2019	$	—	$	—	$	—	$	—
Additions to goodwill	10,565		8,309		—		18,874
Goodwill impairments	(10,565)		—		—		(10,565)
Balance as of June 30, 2020	$	—	$	8,309	$	—	$	8,309

~~3. Intangible Assets~~

~~Basic~~The Company had trade names of ~~$3.4~~$7.2 million and $3.2 million as of ~~each of September~~June 30, ~~2017~~2020, and December 31, ~~2016.~~2019, respectively. In connection with the CJWS Transaction, the Company recorded intangible assets for CJWS trade name and Goodwill. Trade names have a 15-year life and are tested for impairment when triggering events are identified.

~~Basic’s~~During the six month period ended June 30, 2020, and due to significant factors impacting supply and demand in the global oil and natural gas markets, the Company assessed certain of its intangible assets and goodwill for impairment. For further discussion, see Note 13. Impairments.

The Company’s intangible assets subject to amortization were as follows (in thousands):


						June 30, 2020		December 31, 2019

	September 30, 2017		December 31, 2016
Trade names	$	3,410	$	3,410	Trade names	$	7,230	$	3,230
Other intangible assets	48		48		Other intangible assets	48		48
	$	3,458	$	3,458
Intangible assets					Intangible assets	7,278		3,278
Less accumulated amortization	178		—		Less accumulated amortization	(854)		(675)
Intangible assets subject to amortization, net	$	3,280	$	3,458	Intangible assets subject to amortization, net	$	6,424	$	2,603

Amortization expense of intangible assets for the three and six months ended ~~September~~June 30, ~~2017~~2020 and ~~2016~~2019, was as follows (in thousands):


	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020			2019
Intangible asset amortization expense	$	123	$	60	$	179		$	119

Three Months Ended September 30, Nine Months Ended September 30,
2017 2016 2017 2016
(Successor) (Predecessor) (Successor) (Predecessor)
Intangible amortization expense $ 59
$ 2,227
$ 178
$ 6,455

4.6. Long-Term Debt and Interest Expense

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


	June 30, 2020		December 31, 2019
10.75% Senior Notes due 2023	$	300,000	$	300,000
ABL Facility	2,558		—
Senior Secured Promissory Note	15,000		—
Finance leases and other notes	25,966		35,898
Unamortized discounts and deferred financing costs	(25,513)		(8,795)
Total long-term debt	318,011		327,103
Less current portion	17,606		18,738
Total non-current portion of long-term debt	$	300,405	$	308,365

September 30, 2017 December 31, 2016
Credit facilities:
Term Loan $ 162,938
$ 164,175
New ABL Facility 64,000
—
Capital leases and other notes 106,674
78,046
Unamortized discounts, premiums, and deferred debt costs (13,433 ) (19,001 )
Total principal amount of debt instruments, net 320,179
223,220
Less current portion 50,849
38,468
Long-term debt $ 269,330
$ 184,752

The Company was in compliance with the debt covenants under its existing debt agreements as of June 30, 2020.

Debt Discounts and Issuance Costs

The following discounts and issuance costs on debt represent the unamortized discount to fair value of ~~our~~the Senior Notes, the Senior Secured Promissory Note, and the unamortized debt issuance costs on Senior Notes(in thousands). For discussion of the change in unamortized discount on Senior Notes, see discussion below.


	June 30, 2020		December 31, 2019
Unamortized discount on Senior Notes	$	12,591	$	2,156
Unamortized discount on Senior Secured Promissory Note	7,177		—

Unamortized deferred debt issuance costs	5,745		6,639
Total unamortized discounts and deferred financing costs	$	25,513	$	8,795

Interest Expense

The Company’s interest expense for the three and six months ended June 30, 2020 and 2019, consisted of the following (in thousands):


	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020		2019

Cash payments for interest	$	17,443	$	18,818	$	18,671	$	20,428
Change in accrued interest	(8,024)		(9,334)		196		(1,186)

Amortization of discounts	1,660		263		2,181		525
Amortization of deferred debt costs	1,664		591		2,251		1,155
Commitment and other fees paid	11		13		22		24

Other	21		7		72		26
Interest expense - continuing operations	$	12,775	$	10,358	$	23,393	$	20,972

Senior Secured Notes

On October 2, 2018, the Company issued $300 million aggregate principal amount of 10.75% senior secured notes due October 2023 (the “Senior Notes”) in an offering exempt from registration under the Securities Act. The Senior Notes were issued at a price of 99.042% of par to yield 11%. The Senior Notes are secured by a first-priority lien on substantially all of the assets of the Company and the subsidiary guarantors other than accounts receivable, inventory and certain related assets. Net proceeds from the offering of approximately $290 million were used to repay the Company’s existing indebtedness under the Amended and Restated Term Loan Agreement, to repay the Company’s outstanding borrowings under its previous credit facility (the "Prior ABL Facility"), and for general corporate purposes.

Indenture

The Company’s Senior Notes were issued under and are governed by an indenture, dated as of October 2, 2018 (the “Indenture”), by and among the Company, the guarantors named therein (the “Guarantors”), and UMB Bank, N.A. as Trustee and Collateral Agent (the “Trustee”). The Senior Notes are jointly and severally, fully and unconditionally guaranteed (the “Guarantees”) on a senior secured basis by the Guarantors and are secured by first priority liens on substantially all of the Company’s and the Guarantors’ assets, other than accounts receivable, inventory and certain related assets.

The Indenture contains covenants that limit the ability of the Company and certain subsidiaries to:

•incur additional indebtedness or issue preferred stock;

•pay dividends or make other distributions to its stockholders;

•repurchase or redeem capital stock or subordinated indebtedness and certain refinancings thereof;

•make certain investments;

•incur liens;

•enter into certain types of transactions with affiliates;

•limit dividends or other payments by restricted subsidiaries to the Company; and

•sell assets or consolidate or merge with or into other companies.

These limitations are subject to a number of important qualifications and exceptions. Upon an Event of Default (as defined in the Indenture), the Trustee or the holders of at least 25% in aggregate principal amount of the outstanding Senior Notes may declare the entire principal, premium, if any, and accrued and unpaid interest, if any, on all the Senior Notes to be due and payable immediately.

At any time on or prior to October 15, 2020, the Company may redeem up to 35% of the aggregate principal amount of the Senior Notes at a redemption price equal to 110.8% of the principal amount, plus accrued and unpaid interest, if any, to the redemption date, with an amount of cash not greater than the net proceeds from certain equity offerings. At any time prior to October 15, 2020, the Company may redeem the Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the Senior Notes plus a “make-whole” premium plus accrued and unpaid interest, if any, to the redemption date. The Company may also redeem all or a part of the Senior Notes at any time on or after October 15, 2020, at the redemption prices set forth in the Indenture, plus accrued and unpaid interest, if any, to the redemption date.

The Company may redeem all, but not less than all, of the Senior Notes in connection with a company sale transaction, at a redemption price of 105.4% of principal for a company sale that occurs on or after April 15, 2019, and on or before October 15, 2019, or 108.1% of principal amount for a company sale that occurs after October 15, 2019, and before October 15, 2020, in each case plus accrued and unpaid interest, if any, to the redemption date. If the Company experiences a change of control, the Company may be required to offer to purchase the Senior Notes at a purchase price equal to 101% of the principal amount, plus accrued and unpaid interest, if any, to the purchase date.

The Senior Notes and the Guarantees rank equally in right of payment with all of the Company’s and the Guarantors’ existing and future unsubordinated indebtedness, effectively senior to all of the Company’s and the Guarantors’ existing and future indebtedness to the extent of the value of the collateral securing the Senior Notes but junior to other indebtedness that is secured by liens on assets other than collateral for the Senior Notes to the extent of the value of such assets, and senior to all of the Company’s and the Guarantors’ future subordinated indebtedness.

Pursuant to a collateral rights agreement, the Senior Notes and Guarantees are secured by first priority liens, subject to limited exceptions, on the collateral securing the Senior Notes, consisting of substantially all of the property and assets now owned or hereafter acquired by the Company and the Guarantors, except for certain excluded property described in the Indenture.

As discussed in Note 2. Acquisition, pursuant to the Purchase Agreement and as a portion of the consideration for the Stock Purchase, Ascribe, on behalf of the Company, conveyed to Seller Senior Notes with an aggregate par amount equal to $34.4 million (the "Ascribe Senior Notes") and Ascribe entered into an Exchange Agreement dated March 9, 2020, with the Company pursuant to which, among other things, Ascribe exchanged the Ascribe Senior Notes for (a) 118,805 shares of Series A Preferred Stock and (b) an amount in cash for accrued interest on the Ascribe Senior Notes approximately equal to $1.5 million, representing the accrued (but unpaid) interest, from and including the most recent date to which interest had been paid pursuant to the terms of the Senior Notes but excluding the date of the closing of the CJWS Transaction, on the aggregate principal amount of the Ascribe Senior Notes. Pursuant to the Exchange Agreement, the Company issued a Senior Secured Promissory Note on March 9, 2020, in favor of Ascribe in an aggregate principal amount equal to $15 million. See discussion of the Senior Secured Promissory Note below. For further discussion of the Series A Preferred Stock, see Note 9. Series A Participating Preferred Stock.

If Ascribe is required to pay the Make-Whole Payment to Seller, described in Note 2. Acquisitions, pursuant to the Purchase Agreement, the Company will be required to reimburse to Ascribe the amount of such Make-Whole Payment (such amount, the "Make-Whole Reimbursement Amount") either (i) in cash (a) to the extent the Company has available cash (as determined by an independent committee of the Company's board of directors) and (b) subject to satisfaction of certain "Payment Conditions" set forth in the ABL Credit Agreement (as defined below) or (ii) if the Company is unable to pay the full Make-Whole Reimbursement Amount in cash pursuant to clause "(i)" of this paragraph, in additional Senior Notes as permitted under the Indenture.

The conveyance of the $34.4 million in Ascribe Senior Notes to Seller by Ascribe, along with other aspects of the Exchange Agreement and Purchase Agreement considered in the aggregate, was deemed for accounting purposes to be an effective extinguishment of the existing Ascribe Senior Notes pursuant to ASC 470-50 "Debt - Modifications and Extinguishments" ("ASC 470-50"). and a reissuance of a new issue of Ascribe Senior Notes as of March 9, 2020. The new issue of Ascribe Senior Notes was recorded at its estimated fair value based on the bond market pricing discount of 37% at March 9, 2020, resulting in a net carrying value at time of reissuance of $21.6 million, net of discount. This discount is amortized over the remaining term of the Ascribe Senior Notes through 2023. The deemed reissuance of Ascribe Senior Notes, along with the issuance of the Senior Secured Promissory Note and the Series A Preferred Stock, each also recorded at their estimated fair values, resulted in a net debt extinguishment gain of $22.9 million, net of transaction fees paid to Ascribe. As Ascribe was a beneficial owner of the Company prior to the acquisition, the net extinguishment gain was accounted for as a capital contribution as an adjustment within Additional Paid-In Capital as part of Stockholders' Equity.

ABL Facility

On October 2, 2018, the Company terminated the Prior ABL Facility and Amended and Restated Term Loan Agreement and entered into an ABL Credit Agreement (the ~~"Term Loan Agreement"~~“Initial ABL Credit Agreement”) among the Company, as borrower (in such capacity, the “Borrower”) and the ~~short-term and long-term portions~~lenders from time to time party thereto (collectively, the “ABL Lenders”). Pursuant to the ABL Credit Agreement, the ABL Lenders extended to the Borrower a revolving credit facility in the initial maximum aggregate principal amount of ~~the fair value discount of capital leases (in thousands):~~

September 30, 2017 December 31, 2016
Unamortized discount on Term Loan $ 9,758
$ 11,401
Unamortized discount on Capital Leases - short-term 1,657
1,600
Unamortized discount on Capital Leases - long-term 1,936
6,000
Unamortized deferred debt costs 82
—
$ 13,433
$ 19,001

~~On September 29, 2017, Basic terminated its~~$150 million (reduced to $75 million ~~credit facility and entered into~~pursuant to the ~~New~~subsequent amendments described below), subject to borrowing base capacity (the “ABL Facility”). The ABL Facility ~~pursuant to (i)~~includes a Receivables Transfer Agreement (the “Transfer Agreement”) entered into by and among Basic Energy Services, L.P. (“BES LP”), as the initial originator and Basic Energy Receivables, LLC (the “SPE”), as the transferee and (ii) the Credit Agreement.

Under the Transfer Agreement, BES LP will sell or contribute, on an ongoing basis, its accounts receivable and related security and interests in the proceeds thereof (the “Transferred Receivables”) to the SPE. The SPE will finance a portionsublimit for letters of ~~its purchase of the accounts receivable through borrowings, on a revolving basis,~~credit of up to ~~$100~~$50 million ~~(with~~in the ~~ability~~aggregate, and for borrowings on same-day notice under swingline loans subject to ~~request~~a sublimit of the lesser of (a) $15 million (reduced to $7.5 million pursuant to the subsequent amendments described below) and (b) the aggregate commitments of the ABL Lenders. The ABL Facility also provides capacity for base rate protective advances up to $10 million at the discretion of the Administrative Agent and provisions relating to overadvances.

The Initial ABL Credit Agreement was amended pursuant to a Limited Consent and First Amendment to ABL Credit Agreement (the "First Amendment"), dated as of March 9, 2020, in connection with the CJWS Transaction and which, among other things, reduced aggregate commitments from $150 million to $120 million, and expanded the definition of the borrowing base to also include eligible pledged cash which can be advanced to the Administrative Agent as necessary. The ABL Credit Agreement was further amended pursuant to a Second Amendment to ABL Credit Agreement dated as of June 15, 2020 (the "Second Amendment"), which, among other things, (i) further reduced aggregate commitments from $120 million to $75 million, (ii) made proportionate downward adjustments to certain of the Availability (as defined in the ABL Credit Agreement) thresholds that can trigger certain springing covenants such as consolidated fixed charge coverage ratio and cash dominion provisions, and (iii) included additional requirements for the Company, such as prepayment requirements for cash accumulation over a specified threshold, an increase in the ~~size~~applicable rates on outstanding borrowings, as well as provisions precluding defensive ABL Credit Agreement drawdowns. In connection with the reductions in the aggregate commitment effected by the First Amendment and Second Amendment, certain deferred financing cost assets of $1.1 million were charged to interest expense during the six months ended June 30, 2020. The Initial ABL Credit Agreement, as amended by the First Amendment and the Second Amendment, and as may be further amended, restated, supplemented, or otherwise modified to date, is hereafter defined as the "ABL Credit Agreement."

Borrowings under the ABL Facility bear interest at a rate per annum equal to an applicable rate, plus, at Borrower’s option, either (a) a base rate or (b) a LIBOR rate. The applicable rate is fixed from the Second Amendment effective date to July 1, 2020. Following July 1, 2020, the applicable rate is determined by reference to the average daily availability as a percentage of the ~~New~~borrowing base during the fiscal quarter immediately preceding such applicable quarter. The applicable rate was increased as set forth in the Second Amendment.

Principal amounts outstanding under the ABL Facility will be due and payable in full on the maturity date, October 2, 2023, which is five years from the closing of the facility; provided that if the Senior Notes have not been redeemed by ~~$50 million)~~July 3, 2023, then the maturity date shall be July 3, 2023. We had the $9.4 million minimum availability under the ABL Facility as of June 30, 2020. To avoid triggering certain of the consolidated fixed charge coverage ratios and cash dominion covenants which spring into effect under certain minimum availability covenant requirements defined in the ABL Credit Agreement, as amended, as of June 30, 2020, in early July 2020 we repaid the $2.6 million amount of borrowings that was previously outstanding, and ~~such borrowings will be secured by~~advanced $2.3 million of our available cash balance to the ~~accounts receivable. The SPE will finance its purchase~~Administrative Agent. During the remainder of July 2020, and as of August 7, 2020, we are currently subject to increased financial and borrowing base information reporting and we have made additional advances totaling $10.7 million of our available cash balance to the Administrative Agent as needed to maintain compliance with the minimum availability covenant requirements.

Substantially all of the ~~remaining portion~~domestic subsidiaries of the ~~accounts receivable~~Company guarantee the borrowings under the ABL Facility, and Borrower guarantees the payment and performance by ~~issuing subordinated promissory notes to BES LP and/or by contributing the remaining portion~~each specified loan party of the accounts receivables in exchange for equity in the SPE in the amount of the purchase price of the receivable not paid in cash. BES LP will be responsible for the servicing, administration and collection of the accounts receivable, with all collections going into lockbox accounts. The Company has provided a customaryits obligations under its guaranty ~~of performance to the administrative agent~~ with respect to ~~certain~~swap obligations. All obligations ~~of BES LP and any successor servicer~~ under the ~~New ABL Facility. In connection with entering into the New~~ ABL Facility ~~on September 29, 2017,~~and the related guarantees are secured by a perfected first-priority security interest in substantially all accounts receivable, inventory, and certain other assets, not including equity interests. As of June 30, 2020, the Company amended the Term Loan Agreement to permit, among other things, (i) the acquisition of the Transferred Receivables by the SPE pursuant to the Transfer Agreement, free and clear of the liens under the Term Loan Agreement and (ii) the transactions contemplated under each of the Transfer Agreement and Credit Agreement. The Company consolidates the foregoing entities, and all intercompany activity is eliminated upon consolidation.

On October 27, 2017, the Company entered into Amendment No. 1. Among other things, Amendment No. 1 (i) increased the aggregate commitments under the Credit Agreement from $100 million to $120 million, (ii) appointed CIT Bank, N.A. to serve as syndication agent and (iii) added new lenders and amended the commitment schedule to the Credit Agreement.

~~As of September 30, 2017, Basic~~ had ~~$45.2~~$36.8 million of letters of credit outstanding under the ABL Facility.

The Senior Secured Promissory Note

Pursuant to the Exchange Agreement, the Company issued a Senior Secured Promissory Note on March 9, 2020, in favor of Ascribe in an aggregate principal amount equal to $15 million (the "Senior Secured Promissory Note"). Interest on the Senior Secured Promissory Note is payable monthly, at an initial interest rate of 10% per annum, increasing by an additional 2% per annum beginning on January 1, 2021, and on January 1 of each succeeding year thereafter until the Senior Secured Promissory Note matures on October 15, 2023. The Senior Secured Promissory Note is secured by ~~restricted cash borrowed under~~a lien upon certain of the ~~New ABL Facility. Basic had borrowings under~~Company's existing and after-acquired property, which are also secured by the ~~New ABL Facility~~Company's existing Senior Secured Notes. As a part of ~~$64.0~~the Exchange Agreement and pursuant to ASC 470-50, the Senior Secured Promissory Note was recorded at its estimated fair value, resulting in a net carrying value, net of discount, of $7 million as at time of ~~September 30, 2017, giving Basic $30.9~~issuance. This discount is amortized using the effective interest method over the remaining term of the Senior Secured Promissory Note. The proceeds of the Senior Secured Promissory Note were used to finance a portion of the purchase price consideration paid in connection with the Stock Purchase. Such proceeds were net of approximately $0.5 million of ~~available borrowing capacity under~~associated fees related to the ~~New ABL Facility.~~

~~Basic’s interest expense consisted~~issuance of the ~~following (in thousands):~~Senior Secured Promissory Note, which were considered in the determination of the $22.9 million net extinguishment gain discussed above.

Three Months Ended September 30, Nine Months Ended September 30,
2017 2016 2017 2016
(Successor) (Predecessor) (Successor) (Predecessor)
Cash payments for interest $ 7,611
$ 5,899
$ 16,919
$ 38,459
Commitment and other fees paid —
1,008
187
2,280
Amortization of debt issuance costs and discounts 1,850
1,528
5,731
5,876
Change in accrued interest 57
15,493
4,934
20,503
Capitalized interest (660 ) —
(660 ) —
Other 34
25
70
70
$ 8,892
$ 23,953
$ 27,181
$ 67,188

5.7. Fair Value Measurements

The following is a summary of the carrying amounts, net of discounts, and estimated fair values of ~~our financial instruments~~the Company's Senior Notes, Senior Secured Promissory Note, and the Make-Whole Reimbursement Amount as of ~~September~~June 30, ~~2017~~2020, and December 31, ~~2016:~~2019 (in thousands, except hierarchy level):

Fair Value September 30, 2017 December 31, 2016
Hierarchy Level Carrying Amount Fair Value Carrying Amount Fair Value
(In thousands)
Term Loan 3 $ 153,180
$ 157,016
$ 152,838
$ 152,838


		June 30, 2020						December 31, 2019
	Hierarchy Level	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Fair Value of Debt
10.75% Senior Notes due 2023	1	$	287,409	$	126,533	$	297,844	$	213,246
Senior Secured Promissory Note	3	$	7,823	$	6,159	$	—	$	—
Fair Value of Derivative Instrument
Make-Whole Reimbursement Amount	3	$	12,763	$	12,763	$	—	$	—

The fair value of the ~~Term Loan Agreement~~Senior Secured Promissory Note as of June 30, 2020, was calculated in accordance with ASC 820 "Fair Value Measurements" considering its subordination as to security to the Senior Secured Notes as well as the difference between the stated interest rate of the Senior Secured Promissory Note and market rates.

As a result of the CJWS Transaction, the Company has a Make-Whole Reimbursement derivative in place, which is ~~based upon~~classified as a short-term derivative financial instrument on our ~~discounted cash flows model using a third-party discount rate.~~consolidated balance sheet. Changes in the fair value of derivative instruments subsequent to the initial measurement are recorded as Loss on Derivative in the accompanying consolidated statement of operations. The ~~carrying amount~~estimated fair value of the Company’s derivative liability is determined at discrete points in time derived from the fair value of our ~~New ABL Facility approximates~~Senior Notes, which resulted in the Company classifying the derivative liability as Level 3. The Company recorded a loss of $3.1 million as a result of the change in fair value ~~due to its variable-rate characteristics.~~of the Make-Whole Reimbursement derivative in the six month period ended June 30, 2020.

The carrying amounts of cash and cash equivalents, ~~trade~~ accounts receivable, accounts ~~receivable-related parties, capital leases, accounts~~ payable and other accrued ~~expenses~~liabilities approximate fair value due to the short maturities of these instruments. The Company did not have any additional assets or liabilities that were measured at fair value on a recurring basis as of June 30, 2020, or December 31, 2019.

During the six months ended June 30, 2020, our Well Servicing segment recorded certain impairments related to the expected decreased operating cash flows as a result of the impact of low crude oil prices and the corresponding decrease in customer demand for our services as of that date. For further discussion of these impairments, see Note 13. Impairments.

8. Commitments and Contingencies

Environmental

~~Basic~~The Company is subject to various federal, state and local environmental laws and regulations that establish standards and requirements for protection of the environment. ~~Basic~~The Company cannot predict the future impact of such standards and requirements, which are subject to change and can have retroactive effectiveness. ~~Basic~~The Company 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~~the Company has not been fined, cited or notified of any environmental violations that would have a material adverse effect upon its financial position, liquidity or capital resources. However, management ~~does recognize~~recognizes 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.~~maintain compliance. The amount of such future expenditures is not determinable due to several factors, including the unknown magnitude of possible ~~contamination,~~regulation or liabilities, the unknown timing and extent of the corrective actions which may be required, the determination of ~~Basic’s~~the Company’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~~the Company is a party to litigation or other legal proceedings that ~~Basic~~the Company considers to be a part of the ordinary course of business. ~~Basic~~The Company 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.

State Tax

In 2014, the Company 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 was issued in the second quarter of 2018 for this audit, and the Company will appeal the preliminary report through the redetermination process. Based upon the Company's analysis, the potential liability associated with this audit ranges from $6 million to $24 million. This range could potentially change in future periods as the appeal and redetermination process progresses. Net of good faith payments made by the Company, the Company currently has recorded a $3.6 million liability. Interest expense associated with the taxes for the six months ended June 30, 2020, of $0.1 million, is included in approximately $2.0 million of accrued interest on the liability.

On August 15, 2019, the Company was notified by the Oklahoma Tax Commission (the "OTC") that the tax court had issued findings, conclusions, and recommendations in an on-going tax case related to tax years 2006 through 2008. Based on the ruling and the advice of our Oklahoma tax counsel, the Company decided to negotiate a settlement with the OTC. The Company's analysis is that the potential liability associated with the settlement may range from $2.3 million to $3.5 million. The Company recorded $2.5 million of income tax and interest payable, which is included as accrued expenses on our consolidated balance sheets.

Self-Insured Risk Accruals

~~Basic~~The Company 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~~The amount of these accruals as of June 30, 2020, includes $7.5 million of worker's compensation related impact of the March 9, 2020, acquisition of CJWS. The Company 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~~rigs and pumping services equipment. The Company has deductibles per occurrence for workers’ compensation, general liability claims, ~~automobile liability~~ and medical and dental coverage of ~~$5.0~~$2 million, ~~$1.0 million, $1.0~~$1 million, and ~~$400,000,~~$0.4 million, respectively. ~~Basic~~The Company has a $1 million deductible per occurrence for automobile liability. The Company maintains accruals in the accompanying consolidated balance sheets related to self-insurance retentions based upon third-party data and claims history.

At September 30, 2017 and December 31, 2016, self-insured risk accruals totaled approximately $32.5 million and $35.0 million, respectively, and are included in accrued expenses and other long-term liabilities.

~~7. Stockholders’ Equity~~

~~Common~~9. Series A Participating Preferred Stock

In ~~February 2017, Basic granted certain members~~connection with the CJWS Transaction and pursuant to the Exchange Agreement, as partial consideration for the Exchange Transaction, on March 9, 2020, the Company issued to Ascribe 118,805 shares of ~~management 801,322 performance-based~~newly issued preferred stock, designated as "Series A Participating Preferred Stock," par value 0.01 per share, of the Company (the "Series A Preferred Stock"). The Series A Preferred Stock was issued in exchange for the Ascribe Senior Notes having a par value of $34.4 million. The Series A Preferred Stock constituted 83% of the equity interest in the Company. Upon consummation of the Exchange Transaction, the Company's public stockholders owned approximately 14.94% of the equity interests in the Company, and Ascribe held approximately 85.06%.

Each share of Series A Preferred Stock is entitled to (i) dividends in an amount per share equal to 1,000 times the per share amount of each dividend declared on the Company's common stock; (ii) 1,000 votes on all matters

submitted to a vote of the holders of the Company's common stock; and (iii) upon any liquidation, dissolution or winding up of the Company, an amount equal to 1,000 times the per share amount to be distributed to each share of the Company's common stock. Each share of Series A Preferred Stock is convertible at the option of the Company or the holder into 1,000 shares of Company common stock.

On May 6, 2020, the Company's stockholders, and the holders of common stock voting separately, approved the proposal to increase the number of authorized shares of common stock by 118,805,000, to allow for the conversion of Series A Preferred Stock shares to common shares.

As a result of Ascribe's effective controlling equity interest in the Company, and in accordance with ASC No. 480 "Distinguishing Liabilities from Equity" ("ASC 480"), the Series A Preferred Stock is classified outside of permanent equity in the Company's balance sheet as of June 30, 2020. The Series A Preferred Stock was recorded at the fair value, approximately $22 million as of March 9, 2020, based on the trading price of the Company common shares, plus a control premium.

10. Stockholders' Equity

On May 6, 2020, the Company's stockholders voted to amend the Company's Second Amended and Restated Certificate of Incorporation to, among other items, increase the number of authorized shares of common stock from 80,000,000 shares to 198,805,000 shares.

11. Incentive Plan

During the three month period ended June 30, 2020 and 2019, compensation expenses related to share-based arrangements under the Management Incentive Plan (the "MIP") and Long Term Incentive Plan ("LTIP"), including restricted stock, restricted stock units and ~~320,532 performance-based~~ stock option awards, ~~which each vest over a three-year period. In August 2017, Basic granted certain members of management 6,476 stock options, 16,190~~were approximately $0.1 million and $3.3 million, respectively.

During the six month period ended June 30, 2020 and 2019, compensation expenses related to share-based arrangements under the MIP and the LTIP, including restricted stock, ~~units, 6,476 performance-based stock options and 16,190 performance-based restricted stock units.~~

~~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~~stock option awards, were approximately $1.4 million and $6.6 million, respectively.

The Company did 0t recognize a ~~total of 1,032 shares of common stock through net share settlements~~tax benefit for compensation expense recognized during the ~~first nine months~~three and six month periods ended June 30, 2020 and 2019.

At June 30, 2020, there was $0.5 million unrecognized compensation expense related to non-vested share-based compensation arrangements granted under the MIP. That cost is expected to be recognized over a weighted average period of ~~2017~~1.9 years.

12.Revenues and ~~issued 29,398 shares from treasury stock~~Customer Receivables

The Company's revenues are generated by services, which are consumed as provided by its customers on their sites. As a decentralized organization, contracts for ~~accelerated vestings~~the Company's services are negotiated on a regional level and ~~stock grants~~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 the Company's jobs may require performance obligations which extend over a longer period of time and are not invoiced until all performance obligations in the ~~first nine months~~contract are complete, such as plugging a well, fishing services, and pad site preparation jobs. Because these jobs are performed on the customer's job site, and the Company is contractually entitled to bill for its 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 as WIP or accounts receivable. Contract Assets are typically invoiced within 30 to 60 days of ~~2017 (Successor). Basic acquired 220,391 shares~~recognizing revenue.

As of ~~common stock through~~June 30, 2020, accounts receivable related to products and services, net ~~share settlements during~~of associated allowance for credit losses, were $70.9 million compared to $99.6 million at December 31, 2019. At June 30, 2020, the ~~first nine months~~Company had $3.4 million of ~~2016 (Predecessor).~~contract assets and $0.7 million of contract liabilities on its consolidated balance sheet compared to $1.0 million of contract assets and $0.9 million of contract liabilities on its consolidated balance sheet at December 31, 2019. Contract assets are included in Trade Accounts Receivables, and contract liabilities are included in Other Current Liabilities on our consolidated balances sheets.

~~Stock Offering~~

~~In August 2017, Basic commenced an at-the-market public offering (the "ATM Program"), under which it could have sold shares~~For accounts receivable related to products and services, the Company estimates its expected credit losses by reviewing and monitoring updated customer credit scores and risk ratings provided by third party and internal resources, considering the future impact of the current business and industry environment, and reviewing the historical loss experience by type of customer. During the six month period ended June 30, 2020, the Company considered the impact of the sharp decline in the West Texas Intermediate oil price on the credit quality of its ~~common stock having an aggregate value~~customers and included this impact in its allowance for credit losses as of upJune 30, 2020. In addition, the Company included in its allowance for credit losses the impact of the approximately $39.5 million of accounts receivable from the acquisition of CJWS as of the March 9, 2020, closing date. The following table presents activity in the allowance for credit losses (in thousands):


	Six Months Ended June 30, 2020
Balance as of December 31, 2019	$	2,208
Provision for expected credit losses, net of recoveries	4,425
Initial allowance for expected credit losses on purchased customer receivables	—
Balance as of June 30, 2020	$	6,633

The Company does not have any long-term service contracts, nor does it have revenue expected to ~~$50 million. Basic terminated the ATM Program on September 30, 2017.~~be recognized in any future year related to remaining performance obligations or contracts with variable consideration related to undelivered performance obligations.

~~8. Incentive Plan~~

The following table ~~reflects compensation activity related~~sets forth certain financial information with respect to the ~~management incentive plan~~Company’s disaggregation of revenues by geographic location and type (in thousands):


	Reportable Segments

	Well Servicing		Water Logistics		Completion & Remedial Services		Discontinued Operations		Total
Three Months Ended June 30, 2020
Primary Geographical Markets

Central	$	18,945	$	20,421	$	3,939	$	20	$	43,325
Western	28,619		14,128		5,729		5		48,481
Corporate (Intercompany)	(246)		(1,295)		(603)		—		(2,144)
Total	$	47,318	$	33,254	$	9,065	$	25	$	89,662

Major Products or Service Line
Well Servicing	27,291		—		—		—		27,291
Plugging	12,823		—		—		—		12,823
Transport/Vacuum	—		23,313		—		—		23,313
Production and Disposal Facilities	—		4,357		—		—		4,357
Hot Oiler	—		1,859		—		—		1,859
RAFT	—		—		6,759		—		6,759
Coiled Tubing	—		—		1,451		—		1,451
Snubbing	—		—		334		—		334
Taylor Industries - Manufacturing	1,914		—		—		—		1,914
Discontinued Operations	—		—		—		25		25
Other	5,290		3,725		521		—		9,536
Total	$	47,318	$	33,254	$	9,065	$	25	$	89,662


	Well Servicing		Water Logistics		Completion & Remedial Services		Discontinued Operations		Total
Three Months Ended June 30, 2019
Primary Geographical Markets
Central	51,431		48,146		19,815		42,113		161,505
Western	11,253		5,528		19,811		770		37,362
Corporate (Intercompany)	(4,166)		(2,643)		(1,200)		(1,011)		(9,020)
Total	$	58,518	$	51,031	$	38,426	$	41,872	$	189,847
Major Products or Service Line
Well Servicing	47,431		—		—		—		47,431
Plugging	6,868		—		—		—		6,868
Transport/Vacuum	—		29,054		—		—		29,054
Production and Disposal Facilities	—		8,667		—		—		8,667
Hot Oiler	—		5,171		—		—		5,171
RAFT	—		—		18,703		—		18,703
Coiled Tubing	—		—		16,273		—		16,273
Snubbing	—		—		1,282		—		1,282
Taylor Industries - Manufacturing	1,513		—		—		—		1,513
Discontinued Operations	—		—		—		41,872		41,872
Other	2,706		8,139		2,168		—		13,013
Total	$	58,518	$	51,031	$	38,426	$	41,872	$	189,847



	Well Servicing		Water Logistics		Completion & Remedial Services		Discontinued Operations		Total
Six Months Ended June 30, 2020
Primary Geographical Markets
Central	58,965		58,838		17,123		115		135,041
Western	48,281		22,333		19,325		5		89,944
Corporate (Intercompany)	(1,787)		(3,536)		(1,502)		—		(6,825)
Total	$	105,459	$	77,635	$	34,946	$	120	$	218,160
Major Products or Service Line
Well Servicing	73,098		—		—		—		73,098
Plugging	21,367		—		—		—		21,367
Transport/Vacuum	—		51,425		—		—		51,425
Production and Disposal Facilities	—		11,749		—		—		11,749
Hot Oiler	—		5,913		—		—		5,913
RAFT	—		—		21,203		—		21,203
Coiled Tubing	—		—		10,421		—		10,421
Snubbing	—		—		758		—		758
Taylor Industries - Manufacturing	3,694		—		—		—		3,694
Discontinued Operations	—		—		—		120		120
Other	7,300		8,548		2,564		—		18,412
Total	$	105,459	$	77,635	$	34,946	$	120	$	218,160


	Well Servicing		Water Logistics		Completion & Remedial Services		Discontinued Operations		Total
Six Months Ended June 30, 2019
Primary Geographical Markets
Central	106,317		99,863		40,294		85,579		332,053
Western	24,072		12,071		36,401		2,072		74,616
Corporate (Intercompany)	(9,887)		(5,302)		(2,664)		(1,767)		(19,620)
Total	$	120,502	$	106,632	$	74,031	$	85,884	$	387,049
Major Products or Service Line
Well Servicing	95,539		—		—		—		95,539
Plugging	13,761		—		—		—		13,761
Transport/Vacuum	—		59,801		—		—		59,801
Production and Disposal Facilities	—		17,737		—		—		17,737
Hot Oiler	—		11,951		—		—		11,951
RAFT	—		—		38,374		—		38,374
Coiled Tubing	—		—		28,836		—		28,836
Snubbing	—		—		2,477		—		2,477
Taylor Industries - Manufacturing	6,478		—		—		—		6,478
Discontinued Operations	—		—		—		85,884		85,884
Other	4,724		17,143		4,344		—		26,211
Total	$	120,502	$	106,632	$	74,031	$	85,884	$	387,049

13. Impairments

In connection with the preparation of the June 30, 2020 financial statements, we recorded the following impairment charges (in thousands):


	Six Months Ended June 30, 2020
Goodwill	$	10,565

Well Servicing inventory	4,846
Well Servicing units and equipment	84,217



Total	$	99,628

Impairment of Goodwill

Goodwill recorded in connection with the March 9, 2020, acquisition of CJWS totaled $18.9 million and was recorded as part of our Well Servicing and Water Logistics reporting units. Beginning in March 2020, we experienced a reduction in demand for our services due to the significantly decreased price of crude oil as a result of multiple significant factors impacting supply and demand in the global oil and natural gas markets, including a global outbreak of the COVID-19 virus and the announced price reductions and possible production increases by members of OPEC and other oil exporting nations. For further discussion of these factors that occurred subsequent to our March 9, 2020, acquisition of CJWS, see Note 1. Basis of Presentation and Nature of Operations - COVID-19 and Commodity Price Collapse Impact on Liquidity: Going Concern. As a result, as of March 31, 2020, we updated our internal long-term outlook for each of these reporting units, and determined that the current decreased energy industry outlook was an indicator requiring further analysis for impairment of goodwill and that it was more likely than not that the fair value of certain reporting units were less than their carrying value. Therefore, we performed an interim goodwill impairment test.

As part of the first step of goodwill impairment testing, we updated our assessment of future cash flows, using historical data supplemented by current and anticipated market conditions and applying expected long-term growth rates, discount rates, and terminal values that we considered reasonable for each reporting unit. We calculated a present value of the cash flows to arrive at an estimate of fair value using a combination of the income approach and the market approach. The income approach estimates the fair value by discounting each reporting unit's estimated future cash flows using an estimate of the discount rate, or expected return, that a marketplace participant would have required as of the valuation date. The market approach includes the use of comparative multiples to corroborate the discounted cash flow approach. The market approach involves significant judgement in the selection of the appropriate peer group companies and valuation multiples. Based on these key assumptions, we determined that the fair value of the Well Servicing reporting unit was less than its carrying values indicating an impairment of the $10.6 million of goodwill recorded for this reporting unit. As its expected long-term cash flows associated with services performed for producing wells was not as significantly impacted by the current market conditions, the fair value of the Water Logistics reporting unit significantly exceeded its carrying value and therefore resulted in no impairment. The amount of impairment is calculated based on the difference between the fair value and carrying value in accordance with ASC 350 "Intangibles - Goodwill and Other" and including the impact of Accounting Standards Update 2017-04, "Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment."

Impairments of Other Assets

In addition, the March 2020 reduction in demand for our services for each of our businesses was an indicator that certain long-lived tangible and identified intangible assets may be impaired. Recoverability testing performed at the total segment asset group level (the lowest level of discrete and identifiable cash flows) as of March 31, 2020, using a probability weighted estimate of undiscounted future cash flows using expected long-term growth rates indicated that for our Well Servicing and Completion & Remedial Services segments, certain long-lived assets, within the overall reporting unit, were not recoverable. For these segments, estimated fair values using an income approach were calculated by discounting each segment's probability weighted estimated future cash flows using an estimate of the discount rate and terminal values. The estimated fair value of Well Servicing segment assets was determined to be below their carrying value and as a result, as of March 31, 2020, we recorded impairments of property and equipment assets totaling $84.2 million and impairments of component parts inventory assets totaling $4.8 million associated with our Well Servicing segment. The difference between the carrying value of the asset group and its indicated fair value was recorded as an impairment. The estimated fair value of our Completion & Remedial Services segment exceeded its carrying value, resulting in no impairment of this segment. A recoverability analysis was also performed on the long-lived assets of the Water & Logistics segment along with identified

intangible assets, and we concluded that the carrying value for these assets were recoverable from estimated future cash flows.

14. Income Taxes

The deferred tax liabilities acquired with the acquisition of CJWS provided a source of future taxable income which allowed the Company to recognize a tax benefit on a portion of the long-lived asset impairment recorded during the three months ended March 31, 2020, as well as the Company's other deferred tax assets, and is the primary driver of the tax benefit for the ~~nine-month period ending September~~six months ended June 30, ~~2017 (dollar amounts in thousands):~~

Compensation expense for three months ended September 30, 2017 Compensation expense for nine months ended September 30, 2017 Unrecognized compensation expense Weighted average remaining life Fair value of share based awards vested

Restricted stock $ 4,880
$ 13,708
$ 36,744
1.9 $ 101
Restricted stock options $ 1,011
$ 2,907
$ 9,320
9.3 $ —

2020. During the ~~three~~same period of 2019, we filed an amended 2007 federal tax return to claim an income tax refund from the carry-back and ~~nine months ended September 30, 2017 and 2016, there was no excess tax benefit related to equity incentive compensation. Awards granted prior to~~recovery of workers’ compensation expenses that were components of our Net Operating Losses ("NOLs") generated over the ~~Effective Date were subsequently cancelled. All outstanding awards at September 30, 2017 were granted after~~past 10 years.

The issuance of the ~~Effective Date~~Series A Preferred Stock as part of the ~~Prepackaged Plan or during the current nine-month period, and relate~~acquisition of CJWS resulted in an ownership change pursuant to Internal Revenue Code Section 382 on March 9, 2020. The Section 382 limitation impacts the Company's ~~newly issued shares~~ability to utilize certain pre-acquisition tax attributes, including NOLs. The projected impact of ~~common stock.~~

~~Stock Option Awards~~

~~The fair value of each stock option~~the ownership change is ~~estimated on the date of grant using the Black-Scholes-Merton option-pricing model. Stock options granted under~~to reduce the Company's ~~management incentive plan~~available Federal NOLs from $900.7 million as of December 31, 2019 to an estimated $312 million as of June 30, 2020, which begin to expire ~~ten~~in 2032. The Company also has $336.8 million ($18.3 million net deferred tax asset) of NOLs for state income tax purposes, which begin to expire in 2020. Federal NOLs generated after 2017 are carried forward indefinitely but usage is limited to 80% of taxable income, while NOLs generated prior to 2018 continue to be carried forward for 20 years ~~from the date they are granted,~~ and ~~vest over~~have no limitation on utilization. The annual utilization limits for state income tax purposes vary on a ~~three-year service period.~~state-by-state basis.

~~The following table reflects changes during the nine-month period and~~We provide a ~~summary of stock options outstanding at September 30, 2017:~~

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 323,770
$ 36.55

Options granted 333,484
41.80

Options forfeited (2,158 ) 36.55

Options exercised —
—

Outstanding, end of period 655,096
$ 39.22
9.3 $ —
Exercisable, end of period 1,080
$ 36.55
9.2 $ —
Vested or expected to vest, end of period 655,096
$ 39.22
9.3 $ —

~~There were no stock options exercised during the nine months ended September 30, 2017 and 2016.~~

~~Restricted Stock Unit Awards~~

~~A summary~~valuation allowance when it is more likely than not that some portion of the ~~status~~deferred tax assets will not be realized. As of ~~Basic’s non-vested restricted stock units at September~~June 30, ~~2017 and changes during the~~ ~~nine~~ ~~months ended September 30, 2017 is presented in the following table:~~2020, a valuation allowance of $131.4 million was recorded against deferred tax assets for all jurisdictions that are not expected to be realized.

Weighted Average
Number of Grant Date Fair
Non-vested Units Shares Value Per Share
Non-vested at beginning of period 539,606
$ 36.55
Granted during period 860,402
41.37
Vested during period (2,698 ) 36.55
Forfeited during period (2,698 ) 36.55
Non-vested at end of period 1,394,612
$ 39.53

~~Restricted Stock Awards~~

On May 25, 2017, 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 26,700. These grants are subject to vesting over a ten-month period and are subject to accelerated vesting under certain circumstances.

~~PhantomStock Awards~~

On March 15, 2017, the Board approved grants of phantom restricted stock awards to certain key employees. The number of phantom shares issued was 42,820. These grants remain subject to vesting annually in one-third increments over a two-year period, with the first portion vested on March 15, 2017, and are subject to accelerated vesting in certain circumstances.

On June 1, 2017 the Board approved grants of phantom restricted stock awards to certain key employees. The number of phantom shares issued was 79,440. Basic granted an additional 7,580 phantom shares during the third quarter of 2017. These grants remain subject to vesting annually in one-third increments over a three-year period, with the first portion vesting on March 15, 2018, and are subject to accelerated vesting in certain circumstances.

~~9. Related Party Transactions~~

~~Basic had receivables from employees of approximately $22,000 and $31,000 as of September 30, 2017 and December 31, 2016, respectively.~~

~~10. Earnings~~15. Loss Per Share

The following table sets forth the computation of unaudited basic and diluted loss per share for the three and six months ended June 30, 2020 and 2019 (in thousands, except share and per share data):


	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020		2019
	(Unaudited)						(Unaudited)

Numerator (both basic and diluted):
Loss from continuing operations	$	(39,725)	$	(19,315)	$	(176,154)	$	(34,102)
Loss from discontinued operations, net of tax	(4,873)		(8,462)		(13,325)		(21,151)
Net loss available to common stockholders	$	(44,598)	$	(27,777)	$	(189,479)	$	(55,253)
Denominator:
Denominator for basic and diluted earnings per share	24,957,478		27,203,635		24,935,693		27,028,041

Basic and diluted loss per common share from continuing operations:	$	(1.59)	$	(0.71)	$	(7.06)	$	(1.26)
Basic and diluted loss per common share from discontinued operations:	$	(0.20)	$	(0.31)	$	(0.53)	$	(0.78)
Basic and diluted loss per common share available to stockholders:	$	(1.79)	$	(1.02)	$	(7.59)	$	(2.04)

Three Months Ended September 30, Nine Months Ended September 30,
2017 2016 2017 2016

(Unaudited) (Unaudited)

(Successor) (Predecessor) (Successor) (Predecessor)
Numerator (both basic and diluted):

Net loss $ (13,845 ) $ (92,097 ) $ (76,413 ) $ (265,319 )
Denominator:
Denominator for basic loss per share 26,001,062
42,689,773
26,000,326
41,957,755
Denominator for diluted loss per share 26,001,062
42,689,773
26,000,326
41,957,755
Basic loss per common share: $ (0.53 ) $ (2.16 ) $ (2.94 ) $ (6.32 )
Diluted loss per common share: $ (0.53 ) $ (2.16 ) $ (2.94 ) $ (6.32 )

The Company has issued potentially dilutive instruments such as the Series A Preferred Stock, ~~options~~unvested restricted stock and ~~warrants of 2,721,720 were excluded from~~common stock options. However, the ~~computation~~Company did not include these instruments in its calculation of diluted ~~loss~~ per share information, because to include them would be anti-dilutive due to the net loss incurred during the periods presented.

The following table sets forth weighted average shares outstanding of potentially dilutive instruments for the three and ~~nine~~six months ended ~~September~~June 30, ~~2017 because the effect would~~2020 and 2019:


	Three Months Ended June 30,			Six Months Ended June 30,
	2020	2019	2020	2019
	(Unaudited)			(Unaudited)
Stock options	226,640	511,558	226,640	511,558
Series A Preferred stock	118,805,000	—	73,763,544	—
Warrants	2,066,576	2,066,576	2,066,576	2,066,576
Weighted average unvested restricted stock	301,390	325,619	361,074	166,769
Total	121,399,606	2,903,753	76,417,834	2,744,903

16. Business Segment Information

The Company’s reportable business segments are Well Servicing, Water Logistics, and Completion & Remedial Services. These segments have been ~~anti-dilutive. Unvested restricted shares~~selected based on changes in management’s resource allocation and performance assessment in making decisions regarding the Company. Prior to December 2019, the Company operated an Other Services segment, which was comprised of ~~26,700~~contract drilling services and ~~12,421 were excluded~~manufacturing and rig servicing. Contract drilling was discontinued as a service in the third quarter of 2019, and manufacturing rig servicing was realigned with Well Servicing. Our Pumping Services Division, which was included in the Completion & Remedial Services segment was discontinued in the fourth quarter of 2019. Costs related to other business activities, primarily corporate headquarters functions, are disclosed separately from the ~~calculation~~3 operating segments as "Corporate and Other." The Company evaluates segment performance on earnings before interest expense and income taxes. Products are transferred between segments and geographic areas on a basis intended to reflect as nearly as possible the market value of ~~diluted earnings per share for~~ the ~~three and nine months ended September 30, 2017, respectively, because~~products. Prior period segment information has been retrospectively revised to reflect the effect would have been anti-dilutive. Unvested restricted stock awards of 1,371,098 and 826,597 were excluded from the computation of diluted loss per share for the three and nine months ended September 30, 2016, as the effect would have been anti-dilutive.

~~11. Business Segment Information~~Company's current segmentation.

The following table sets forth certain financial information with respect to ~~Basic’s~~the Company’s reportable segments for the three and six months ended June 30, 2020 and 2019 (in thousands):


	Well Servicing		Water Logistics		Completion & Remedial Services		Corporate and Other		Continuing Operations Total		Discontinued Operations
Three Months Ended June 30, 2020
Operating revenues	$	47,318	$	33,254	$	9,065	$	—	$	89,637	$	25
Direct operating costs	(39,385)		(25,582)		(9,646)		—		(74,613)		(892)
Segment profits	7,933		7,672		(581)		—		15,024		(867)
Depreciation and amortization	1,638		6,111		3,736		1,368		12,853		—
Capital expenditures	172		1,324		348		(23)		1,821		—

Three Months Ended June 30, 2019
Operating revenues	$	58,518	$	51,031	$	38,426	$	—	$	147,975	$	41,872
Direct operating costs	(46,162)		(35,529)		(27,369)		—		(109,060)		(34,105)
Segment profits	12,356		15,502		11,057		—		38,915		7,767
Depreciation and amortization	4,053		5,359		6,561		1,323		17,296		11,695
Capital expenditures	5,304		7,518		1,304		220		14,346		3,915

Completion
and Remedial Water Well Contract Corporate
Services Logistics Servicing Drilling and Other Total
Three Months Ended September 30, 2017 (Unaudited) (Successor)
Operating revenues $ 123,650
52,333
54,629
2,848
—
$ 233,460
Direct operating costs (84,481 ) (41,281 ) (43,219 ) (2,547 ) —
(171,528 )
Segment profits $ 39,169
11,052
11,410
301
—
$ 61,932
Depreciation and amortization $ 13,860
7,703
5,319
495
2,101
$ 29,478
Capital expenditures (excluding acquisitions) $ 11,285
10,055
6,884
12
672
$ 28,908
Three Months Ended September 30, 2016 (Unaudited) (Predecessor)
Operating revenues $ 49,425
47,178
43,160
1,847
—
$ 141,610
Direct operating costs (40,292 ) (39,268 ) (35,028 ) (1,683 ) —
(116,271 )
Segment profits $ 9,133
7,910
8,132
164
—
$ 25,339
Depreciation and amortization $ 18,383
15,584
13,491
3,109
2,575
$ 53,142
Capital expenditures (excluding acquisitions) $ 3,178
8,244
2,622
69
182
$ 14,295
Nine Months Ended September 30, 2017 (Unaudited) (Successor)
Operating revenues $ 311,466
153,279
156,302
7,728
—
$ 628,775
Direct operating costs (232,932 ) (124,399 ) (125,931 ) (6,818 ) —
(490,080 )
Segment profits $ 78,534
28,880
30,371
910
—
$ 138,695
Depreciation and amortization $ 38,013
21,127
14,589
1,357
5,760
$ 80,846
Capital expenditures (excluding acquisitions) $ 69,342
26,392
20,377
30
1,920
$ 118,061
Identifiable assets $ 263,407
135,338
107,511
8,643
346,246
$ 861,145
Nine Months Ended September 30, 2016 (Unaudited) (Predecessor)
Operating revenues $ 125,348
142,919
118,891
4,812
—
$ 391,970
Direct operating costs (107,941 ) (119,053 ) (101,345 ) (4,612 ) —
(332,951 )
Segment profits $ 17,407
23,866
17,546
200
—
$ 59,019
Depreciation and amortization $ 56,782
48,133
41,669
9,603
7,954
$ 164,141
Capital expenditures (excluding acquisitions) $ 4,689
14,422
6,076
182
2,689
$ 28,058
Identifiable assets $ 308,989
216,202
200,451
43,566
233,840
$ 1,003,048


	Well Servicing		Water Logistics		Completion & Remedial Services		Corporate and Other		Continuing Operations Total		Discontinued Operations
Six Months Ended June 30, 2020
Operating revenues	$	105,459	$	77,635	$	34,946	$	—	$	218,040	$	120
Direct operating costs	(90,202)		(58,701)		(30,828)		—		(179,731)		(2,411)
Segment profits	15,257		18,934		4,118		—		38,309		(2,291)
Depreciation and amortization	3,519		13,132		8,028		2,940		27,619		—
Capital expenditures	1,854		3,461		1,007		(3)		6,319		—
Identifiable assets	$	33,933	$	134,234	$	78,448	$	151,484	$	398,099	$	8,745

Six Months Ended June 30, 2019
Operating revenues	$	120,502	$	106,632	$	74,031	$	—	$	301,165	$	85,884
Direct operating costs	(94,970)		(72,828)		(52,385)		—		(220,183)		(74,824)
Segment profits	25,532		33,804		21,646		—		80,982		11,060
Depreciation and amortization	7,845		10,372		12,699		2,562		33,478		23,011
Capital expenditures	11,544		15,051		5,528		446		32,569		9,726
Identifiable assets	$	84,483	$	97,966	$	129,235	$	263,731	$	575,415	$	126,420

The following table reconciles the segment profits reported above to the operating loss as reported in the consolidated statements of operations for the three and six months ended June 30, 2020 and 2019 (in thousands):


	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		2020		2019
Segment profits	$	15,024	$	38,915	$	38,309	$	80,982
General and administrative expenses	(30,445)		(30,186)		(65,515)		(61,941)

Depreciation and amortization	(12,853)		(17,296)		(27,619)		(33,478)
Gain (loss) on disposal of assets	474		(580)		511		(1,277)
Asset impairment	—		—		(99,628)		—
Operating loss	$	(27,800)	$	(9,147)	$	(153,942)	$	(15,714)

Three Months Ended September 30, Nine Months Ended September 30,
2017 2016 2017 2016
(Successor) (Predecessor) (Successor) (Predecessor)
Segment profits $ 61,932
$ 25,339
$ 138,695
$ 59,019
General and administrative expenses (39,235 ) (30,065 ) (109,478 ) (86,706 )
Restructuring costs —
(10,470 ) —
(10,470 )
Depreciation and amortization (29,478 ) (53,142 ) (80,846 ) (164,141 )
Gain (loss) on disposal of assets (26 ) 128
664
(133 )
Goodwill impairment —
(646 ) —
(646 )
Operating loss $ (6,807 ) $ (68,856 ) $ (50,965 ) $ (203,077 )

~~12. Supplemental Schedule of Cash Flow Information~~

~~The following table reflects non-cash financing and investing activity during the following periods:~~

Nine Months Ended September 30,
2017 2016
(In thousands)
Capital leases and notes issued for equipment $ 61,040
$ 5,151
Asset retirement obligation additions (retirements) (30 ) (21 )
Change in accrued property and equipment 8,726
—

Basic paid no income taxes during the nine months ended September 30, 2017 and 2016. Basic paid interest of approximately $16.9 million and $38.5 million during the nine months ended September 30, 2017 and 2016, respectively.

~~13.~~17.Recent Accounting Pronouncements

Standards Adopted in 2020.

In June 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2016-13, "Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments" ("ASU ~~2014-09 - “Revenue from Contracts with Customers (Topic 606)"~~ ~~represents~~2016-13"). ASU 2016-13 requires a ~~comprehensive revenue recognition standard~~financial asset (or a group of financial assets) measured at amortized cost basis to ~~supersede existing revenue recognition guidance and align GAAP more closely with International Financial Reporting Standards (IFRS).~~

~~The core principle~~be presented at the net amount expected to be collected, utilizing an expected loss methodology in place of the ~~new guidance is that a company should recognize revenue to match~~previously used incurred loss methodology. ASU 2016-13 will result in the ~~delivery~~more timely recognition of ~~goods or services to customers to the consideration the company expects~~losses on financial instruments not accounted for at fair value through net income. The provisions require credit impairments to be ~~entitled~~measured over the contractual life of an asset and developed with consideration for past events, current conditions, and forecasts of future economic information. In addition, the ASU requires credit losses relating to available-for-sale debt securities to be recorded through an allowance for credit losses. The amendments in ~~exchange~~this ASU broaden the information that an entity must consider in developing its expected credit loss estimate for ~~those goods~~assets measured either collectively or ~~services.~~individually. The new standard creates a five step model that requires companies to exercise judgment when considering the terms of a contract and all relevant facts and circumstances. 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 plan to adopt the standard using the full retrospective method to restate each prior period presented.

The standard will be effective for Basic beginning January 1, 2018. In preparation to adopt the standard, we are performing a detailed review of key contracts with customers which are representative of our revenue streams. While we are still in the process of performing the review and analysis of our contracts to support our assessments, the substantial majority of our services are performed at a point in time, revenue is recognized at the time of performance, and this is expected remain unchanged. We do not incur significant contract costs.

~~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~~fiscal years, and for interim periods within those fiscal ~~years. Basic has begun~~years, beginning after December 15, 2022, with early adoption permitted. The Company early adopted this standard on January 1, 2020, using the prospective transition method, and the standard did not have a project to identify all operating leases greater than one year and implementing new leasing software to track operating and capital leases. Basic expects to recognize additional right-of-use assets and liabilities related to operating leases with terms longer than one year.material impact on our consolidated financial statements upon its adoption.

In August ~~2016,~~2018, the FASB issued ASU ~~2016-15-"Statement~~2018-15 "Intangibles — Goodwill and Other - Internal Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract" ("ASU 2018-15"). ASU 2018-15 clarifies the accounting for implementation costs in cloud computing arrangements. We adopted ASU 2018-15 on its January 1, 2020, effective date, using the prospective transition method, and this standard did not have a material impact on our consolidated financial statements.

Standards Not Yet Adopted

In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes” ("ASU 2019-12"). ASU 2019-12 intends to simplify various aspects related to accounting for income taxes and removes certain exceptions to the general principles in the standard. Additionally, the ASU clarifies and amends existing guidance to improve consistent application of ~~Cash Flows (Topic 230): Classification~~its requirements. The amendments of ~~Certain Cash Receipts and Cash Payments."~~ ~~This standard is~~ASU 2019-12 are effective ~~for Basic~~ for fiscal years beginning after December 15, ~~2017.~~2020, and interim periods within those fiscal years. Early adoption is permitted. The Company is currently evaluating the impact of this pronouncement on its consolidated financial statements.

amendments in this update are intended to clarify cash flow treatment of certain cash flows with the objective of reducing diversity in practice. Basic intends to adopt this standard as of January 1, 2018, and does not expect significant changes to the cash flow statement as a result.

In ~~November 2016~~March 2020, the FASB issued ASU ~~2016-18- "Statement~~2020-04, “Reference Rate Reform (Topic 848)” ("ASU 2020-04"), which provides optional expedients and exceptions for applying US GAAP to contracts, hedging relationships, and other transactions affected by the discontinuation 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~~London Interbank Offered Rate (“LIBOR”) or by another reference rate expected to 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.~~discontinued. 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 intends to adopt this standard~~all entities as of ~~January 1, 2018, and does not expect significant changes to~~March 12, 2020, through December 31, 2022. We are currently evaluating the ~~cash flow statement as a result.~~impacts of the provisions of ASU 2020-04 on our consolidated financial statements.

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

Management’s Overview

We provide a wide range of ~~well site~~wellsite services to oil and natural gas drilling and producing companies, including ~~completion~~Well Servicing, Water Logistics and ~~remedial~~Completion & Remedial Services. The Company's scope of operations was expanded effective beginning March 9, 2020, with the acquisition of C&J Well Services, Inc. ("CJWS"), which is expected to significantly increase revenues and operating cash flows in future periods.

Beginning in March 2020, as a result of multiple significant factors impacting supply and demand in the global oil and natural gas markets, including a global outbreak of coronavirus (“COVID-19”), and actions by members of the Organization of the Petroleum Exporting Countries (“OPEC”) and other foreign countries, including Russia, the posted price for West Texas Intermediate oil declined sharply. Oil demand has significantly deteriorated, in part, as a result of the outbreak of COVID-19 and corresponding preventative measures taken to mitigate the spread of the virus. This decline in demand coincided with the announcement of price reductions and possible production increases by members of OPEC and other oil exporting nations. Although OPEC and other oil exporting nations ultimately agreed to cut production, the downward pressure on commodity prices has remained and could continue in the foreseeable future.

The COVID-19 pandemic and oil and natural gas market volatility have resulted in a significant decrease in oil prices and significant disruption and uncertainty in the oil and natural gas market. Oil and natural gas commodity prices are expected to continue to be volatile. The collapse in the demand for oil caused by this unprecedented global health and economic crisis, coupled with oil oversupply, has had a material adverse impact on the demand for our services ~~well servicing, water logistics~~ and ~~contract drilling. Our emergence from bankruptcy,~~the prices we can charge for our services.

The decline in our customers’ demand for our services has also had a material adverse impact on our financial condition, results of operations and ~~various market fluctuations,~~cash flows during the first half of 2020. Demand for our products and services will continue to be affected if our customers continue to revise their capital budgets downward and adjust their operations in response to lower oil prices. We cannot predict the duration or effects of this decrease, but if the price of oil further declines or remains depressed for a lengthy period, our business, financial condition, results of operations, cash flows, and prospects will continue to be materially and adversely affected. The impact of these conditions on our estimates of future operating cash flows resulted in significant impairments of long-lived and intangible assets as of March 31, 2020.

Management has taken steps to generate additional liquidity, including through reducing operating and administrative costs and capital expenditures in our continuing business operations with the goal of preserving margins and improving working capital and may ~~make~~implement further cost and capital expenditure reductions, as necessary.

Pursuant to the CJWS acquisition, our ~~revenues, expenses and income not directly comparable between periods.~~

~~Our total hydraulic horsepower (“hhp”)~~weighted average number of fluid service trucks increased to ~~523,000 at~~1,416 in the ~~end of the third~~second quarter of ~~2017 compared to 444,000 for~~2020 from 814 in the ~~third~~second quarter of ~~2016. Weighted average horsepower increased to 520,000 for the third quarter of 2017 from 444,000 in the third quarter of 2016.~~2019. Our weighted average number of ~~water logistics trucks decreased to 947~~Well Servicing rigs increased from 308 in the ~~third~~second quarter of ~~2017 from 962~~2019 to 576 in the ~~third~~second quarter of ~~2016.~~2020. Our ~~weighted average number~~consolidated financial results and operational data for the six months ended June 30, 2020, includes the impact of ~~well servicing rigs remained constant at 421 during~~ the ~~third quarter~~acquisition of ~~2017 compared to~~CJWS for the ~~third quarter~~portion of ~~2016.~~the period following the closing of the transaction.

Our operating revenues from each of our segments, and their relative percentages of our total revenues, consisted of the following for the six months ended June 30, 2020 and 2019 (dollars in ~~millions)~~thousands):


	Three Months Ended June 30,												Six Months Ended June 30,
	2020					2019				2020				2019
Revenues:
Well Servicing	$	47,318	53%	$	58,518	40%	$	105,459	48%		$	120,502	40%
Water Logistics	33,254		37%	51,031		34%	77,635		36%		106,632		35%
Completion & Remedial Services	9,065		10%	38,426		26%	34,946		16%		74,031		25%
Revenues from continuing operations	$	89,637	100%	$	147,975	100%	$	218,040	100%		$	301,165	100%

Revenues from continuing operations	$	89,637	100%	$	147,975	78%	$	218,040	100%		$	301,165	78%
Revenues from discontinued operations	25		—%	41,872		22%	120		—%		85,884		22%
Total Revenues	$	89,662	100%	$	189,847	100%	$	218,160	100%		$	387,049	100%

Nine Months Ended September 30, 2017
2017 2016
(Successor) (Predecessor)
Revenues:
Completion and remedial services $ 311.5
50 % $ 125.3
32 %
Water logistics

$ 153.3
24 % $ 142.9
36 %
Well servicing $ 156.3
25 % $ 118.9
31 %
Contract drilling $ 7.7
1 % $ 4.8
1 %
Total revenues $ 628.8
100 % $ 392.0
100 %

During 2019 and through the ~~fourth~~second quarter of ~~2015,~~2020, oil prices ~~declined~~have remained depressed and a significant further decrease in prices occurred during March 2020 and, despite modest improvement during the second quarter of 2020, has continued to be below 2019 levels below $50 per barrel (WTI Cushing) and dropped to levels below $30 in early 2016 before rebounding in late 2016. During 2017, oil prices gradually improved with pricing in the low-$50 range by the end of the third quarter. As a result of the overall increase in pricing, our customers’ activity levels and utilizationthrough June 2020. Many of our ~~equipment~~customers are under pressure to reduce production and have ~~gradually improved. General improvement in customer confidence has caused~~cut their capital programs for the ~~North American onshore drilling rig count to slowly rise, resulting in an increase in completion-related activity during the first nine months~~remainder of 2017. 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 2017.

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.2020.

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, segment revenue, ~~per truck, segment profits per truck~~pipeline volumes, trucking volumes and segment profits as a percent of revenues; and

~~Contract Drilling~~•Completion & Remedial Services — ~~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.~~costs excluding depreciation and impairments. 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 Acquisitionsand Divestitures

~~During~~On March 9, 2020, the ~~year ended December 31, 2016~~Company entered into a Purchase Agreement (the “Purchase Agreement”) with Ascribe Investments III LLC, a Delaware limited liability company (“Ascribe”), NexTier Holding Co., a Delaware corporation (“Seller”) and ~~through~~C&J Well Services, Inc., a Delaware corporation, and wholly owned subsidiary of Seller (“CJWS”), which expanded the ~~first nine months~~Company's scope of ~~2017, we did not enter into or complete any business acquisitions or divestitures.~~operations. For further discussion, see Note 2. Acquisition.

Segment Overview

~~Completion and Remedial Services~~

During the first nine months of 2017, 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 523,000 at September 30, 2017 and 444,000 at September 30, 2016, respectively. Weighted average horsepower increased to 520,000 for the third quarter of 2017 from 444,000 in the third quarter of 2016.

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. During the extended period of decreased spending by oil and gas companies in 2015 and 2016, we discounted our rates to remain competitive, which caused lower segment profits. As activity has improved in the first nine months of 2017, we have regained pricing increases and higher utilization of equipment.

The following is an analysis of our completion and remedial services segment for each of the quarters in 2016, the full year ended December 31, 2016 and the quarters ended March 31, 2017, June 30, 2017 and September 30, 2017 (dollars in thousands):

Segment
Revenues Profits %
2016: (Predecessor)
First Quarter $ 39,696
12 %
Second Quarter $ 36,228
9 %
Third Quarter $ 49,424
18 %
Fourth Quarter $ 59,219
14 %
Full Year $ 184,567
14 %
2017: (Successor)
First Quarter $ 80,431
16 %
Second Quarter $ 107,385
24 %
Third Quarter $ 123,650
32 %

The increase in completion and remedial services revenue to $123.7 million in the third quarter of 2017 from $107.4 million in the second quarter of 2017 resulted primarily from the addition of new equipment and higher prices in our coil tubing and fracing operations. Segment profits as a percentage of revenue increased to 32% in the third quarter of 2017 from 24% in second quarter of 2017 on the incremental effect of higher revenues and improved pricing and utilization of our equipment.

~~Water Logistics~~

During the first nine months of 2017, 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. These services are necessary for our customers and usually have a stable demand, but produce lower relative segment profits 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, 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.

The following is an analysis of our water logistics operations for each of the quarters in 2016, the full year ended December 31, 2016 and the quarters ended March 31, 2017, June 30, 2017 and September 30, 2017 (dollars in thousands):

Weighted Segment
Average Revenue Profits Per
Number of Per Water Water
Water Logistics Trucking Logistics Logistics Segment
Trucks Hours Truck Truck Profits %
2016: (Predecessor)
First Quarter 985
521,500
$ 51
$ 10
18 %
Second Quarter 976
474,400
$ 47
$ 7
15 %
Third Quarter 962
499,900
$ 49
$ 8
17 %
Fourth Quarter 944
503,200
$ 52
$ 7
13 %
Full Year 966
1,999,000
$ 199
$ 31
16 %
2017: (Successor)

First Quarter 935
484,300
$ 54
$ 9
17 %
Second Quarter 943
473,500
$ 54
$ 10
18 %
Third Quarter 947
483,300
$ 55
$ 12
21 %

Revenue per water logistics truck increased to $55,000 in the third quarter of 2017 compared to $54,000 in second quarter of 2017 on increased levels of disposal well utilization and construction services revenues. Segment profit percentage increased to 21% in the third quarter of 2017 from 18% in the second quarter of 2017 primarily due to the incremental effect of higher revenues and rate increases.

Well Servicing

During the first ~~nine~~six months of ~~2017,~~2020, our ~~well servicing~~Well Servicing segment represented ~~25%~~53% of our revenues. Revenue in our ~~well servicing~~Well Servicing segment is derived from maintenance, workover, completion ~~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 typically charge our ~~well servicing~~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 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~~level of our ~~well servicing~~Well Servicing rigs on a weekly basis by calculating a rig utilization rate based on a 55-hour ~~work week~~workweek per rig. ~~Our fleet remained constant in 2016 and 2017 at a weighted average number of 421 rigs.~~

The following is an analysis of ~~our well servicing operations~~the Well Servicing segment for each of the quarters in ~~2016,~~2019 and the full year ended December 31, ~~2016~~2019, and the quarters ended March 31, ~~2017,~~2020 and June 30, ~~2017~~2020. This table does not include revenues and ~~September 30, 2017 (dollars in thousands):~~profits associated with rig manufacturing operations:


												Weighted Average Number of Rigs	Rig hours	Rig Utilization Rate	Revenue Per Rig Hour	Profits per Rig hour	Segment Profits %
	Weighted
	Average		Rig		Revenue
	Number		Utilization		Per Rig		Profits Per
	of Rigs	Rig hours	Rate		Hour		Rig hour		Profits %
2016: (Predecessor)
2019:											2019:
First Quarter	421	108,400	36	%	$	321	$	44	11	%	First Quarter	310	165,000	74%	$336	$73	22%
Second Quarter	421	113,700	38	%	$	308	$	44	14	%	Second Quarter	308	155,200	70%	$353	$78	22%
Third Quarter	421	136,600	45	%	$	313	$	60	19	%	Third Quarter	307	149,000	68%	$381	$90	24%
Fourth Quarter	421	146,200	49	%	$	300	$	43	14	%	Fourth Quarter	306	126,200	58%	$369	$53	14%
Full Year	421	504,900	42	%	$	310	$	47	14	%	Full Year	308	595,400	68%	$359	$74	21%
2017: (Successor)
2020:											2020:
First Quarter	421	157,600	52	%	$	307	$	49	16	%	First Quarter	396	139,100	49%	$397	$51	13%
Second Quarter	421	162,300	54	%	$	321	$	69	21	%	Second Quarter	576	91,900	22%	$490	$81	17%
Third Quarter	421	165,200	55	%	$	329	$	69	21	%

Rig utilization was ~~55% in the third quarter of 2017, up from 54%~~22% in the second quarter of ~~2017.~~2020, down from 49% in the first quarter of 2020. The ~~higher~~decreased utilization rate in the ~~third~~second quarter of ~~2017~~2020 resulted from ~~an increase in well servicing hours caused by increases~~a decrease in customer demand and activity, ~~in selected basins offset by significant weather, including Hurricane Harvey.~~

primarily for our 24-hour rig packages. Our segment profit percentage ~~remained constant at 21%~~increased to 17% for ~~the third quarter of 2017 compared to~~ the second quarter of ~~2017, on consistent levels~~2020 compared to 13% in the first quarter of ~~utilization and pricing.~~2020, reflecting the higher margin operations acquired with the CJWS acquisition.

~~Contract Drilling~~Water Logistics

During the first ~~nine~~six months of ~~2017,~~2020, our ~~contract drilling~~Water Logistics segment represented approximately 1%37% of our revenues. Revenues ~~from~~in our ~~contract drilling~~Water Logistics segment are ~~derived primarily~~earned from the sale, transportation, storage and disposal of fluids used in the drilling, production and maintenance of ~~new~~oil and natural gas wells.

~~Within this~~ Revenues also include water treatment, wellsite construction and maintenance services. The Water Logistics segment ~~we charge our drilling rig customers~~has a ~~“daywork” daily rate, or “footage” at an established rate per number of feet drilled. We measure the activity~~base level of business consisting of transporting and disposing of saltwater produced as a by-product of the production of oil and natural gas. These services are necessary for our customers and have a stable demand but typically produce lower relative segment profits than other parts of our Water Logistics segment. Water Logistics for completion and workover projects typically require fresh or brine water for making drilling ~~rigs~~mud, circulating fluids or fracturing fluids used during a job, 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 ~~a weekly basis~~most drilling and workover projects, the add-on services associated with drilling and workover activity enable us to generate higher segment profits. The higher segment profits are due to the relatively small incremental labor costs associated with providing these services in addition to our base Water Logistics operations. We typically price fluid services by ~~calculating a rig utilization rate based on a seven-day work week per rig. Our contract drilling rig fleet had a weighted average~~the job, by the hour or by the quantities sold, disposed of ~~11 rigs during the third quarter of 2017.~~ or hauled.

The following is an analysis of our ~~contract drilling~~Water Logistics operations for each of the quarters in 2019, the full year ended December 31, 2019, and the quarters ended March 31, 2020 and June 30, 2020 (dollars in thousands):


	Pipeline Volumes (in bbls)	Trucking Volumes (in bbls)	Weighted Average Number of Fluid Service Trucks	Truck Hours	Revenue	Segment Profits %
2019:
First Quarter	3,050,000	6,620,000	818	424,100	$55,601	33%
Second Quarter	3,174,000	6,778,000	814	403,200	$51,031	30%
Third Quarter	3,807,000	6,956,000	795	382,500	$48,451	28%
Fourth Quarter	4,132,000	6,785,000	767	360,300	$44,733	25%
Full Year	14,163,000	27,139,000	799	1,570,100	$199,816	29%
2020:
First Quarter	3,620,000	5,825,000	908	374,300	$44,381	25%
Second Quarter	3,275,000	4,077,000	1,416	301,500	$33,254	23%

Revenue for the Water Logistics segment decreased to $33.3 million in the second quarter of 2020, including the impact from the acquisition of CJWS, compared to $44.4 million in the first quarter of 2020, as a result of decreased levels of demand for our services. Segment profit percentage decreased to 23% in the second quarter of 2020 from 25% in the first quarter of 2020.

Completion & Remedial Services

During the first six months of 2020, our Completion & Remedial Services segment represented approximately 10% of our revenues. Revenues from our Completion & Remedial Services segment are derived from a variety of services designed to complete and stimulate oil and natural gas production or place cement slurry within the wellbores. Our Completion & Remedial Services segment includes rental and fishing tool operations, coiled tubing services, nitrogen services and snubbing.

The following is an analysis of our Completion & Remedial Services segment for each of the quarters in ~~2016,~~2019, the full year ended December 31, ~~2016~~2019, and the quarters ended March 31, ~~2017,~~2020 and June 30, ~~2017 and September 30, 2017~~2020 (dollars in thousands):


	RAFT Stores	Coiled Tubing HHP	Revenues	Segment Profits %
2019:
First Quarter	13	25,250	$35,605	30%
Second Quarter	13	25,250	$38,426	29%
Third Quarter	13	25,300	$38,273	33%
Fourth Quarter	13	25,300	$28,164	27%
Full Year	13	25,300	$140,468	30%
2020:
First Quarter	23	25,300	$25,881	18%
Second Quarter	23	25,300	$9,065	(6)%

Weighted
Average Rig
Number of Operating Revenue Per Profits Per Segment
Rigs Days Drilling Day Drilling Day Profits %
2016: (Predecessor)
First Quarter 12
91
$ 16.5
$ (0.6 ) (4 )%
Second Quarter 12
91
$ 16.1
$ 1.0
6 %
Third Quarter 12
92
$ 20.1
$ 1.8
9 %
Fourth Quarter 12
139
$ 17.5
$ 0.8
(2 )%
Full Year 12
413
$ 17.5
$ 0.8
2 %
2017: (Successor)
First Quarter 12
135
$ 20.5
$ 2.6
13 %
Second Quarter 11
91
$ 23.3
$ 2.8
12 %
Third Quarter 11
92
$ 31.0
$ 3.3
11 %

~~Revenue per drilling day increased~~The decrease in Completion & Remedial Services revenue to ~~$31,000 in the third quarter of 2017 compared to $23,300~~$9.1 million in the second quarter of ~~2017. The increase in revenue per drilling day~~2020 from $25.9 million in the ~~third~~first quarter of ~~2017 was due to an increase~~2020 resulted from declines in ~~rig trucking revenues~~our RAFT and ~~utilization.~~coiled tubing lines of business. Segment ~~profit~~profits as a percentage of revenue decreased to ~~11% in the third quarter~~a segment loss of ~~2017 compared to segment profit of 12%~~6% in the second quarter of ~~2017.~~2020 from a segment profit of 18% in the first quarter of 2020 as a result of the declines in oil prices and competitive pricing pressures coupled with higher personnel cost from retention due to customers delaying work.

Operating Cost Overview

Our operating costs are comprised primarily of labor costs, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance. ~~The~~Management has taken steps to generate additional liquidity, including through reducing operating costs in our continuing business operations with the goal of preserving margins and may implement further cost reductions, as necessary. A majority of our employees are paid on an hourly basis. We also ~~incur costs to~~ employ personnel to supervise our activities, 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. Insurance is generally a fixed cost regardless of utilization and can vary depending on the number of rigs, trucks and other equipment in our fleet, as well as employee payroll, and our safety record. 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 1. ~~Basis~~3. Summary of ~~Presentation and Nature of Operations~~Significant Accounting Policies of the Financial Statements and Supplementary Data in our most recent Annual Report on Form 10-K.

Acquisition Purchase Price Allocations - We account for acquisitions of businesses using the acquisition method of accounting in accordance with ASC 805, which requires the allocation of the purchase price consideration based on the fair values of the assets and liabilities acquired. We estimate the fair values of the assets and liabilities acquired using accepted valuation methods, and, in many cases, such estimates are based on our judgments as to the future operating cash flows expected to be generated from the acquired assets throughout their estimated useful lives. Following the March 9, 2020 acquisition of CJWS, we have accounted for the various assets (including intangible assets) and liabilities acquired and issued as consideration based on our estimate of their fair values. Goodwill represents the excess of acquisition purchase price consideration over the estimated fair values of the net assets acquired. Our estimates and judgments of the fair value of acquired businesses could prove to be inexact, and the use of inaccurate fair value estimates could result in the improper allocation of the acquisition purchase price consideration to acquired assets and liabilities, which could result in asset impairments, the recording of previously unrecorded liabilities, and other financial statement adjustments. The difficulty in estimating the fair values of acquired assets and liabilities is increased during periods of economic uncertainty.

Results of Operations

The following is a comparison of our results of continuing operations for the three and ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to the three and ~~nine~~six months ended ~~September~~June 30, 2016. The implementation of the First Amended Joint Prepackaged Chapter 11 Plan of Basic Energy Services, Inc. and its Affiliated Debtors and the application of fresh start accounting materially changed the carrying amounts and classifications reported in our consolidated financial statements and resulted in the Company becoming a new entity for financial reporting purposes. Accordingly, our consolidated financial statements for periods prior to December 31, 2016 will not be comparable to our consolidated financial statements as of December 31, 2016 or for periods subsequent to December 31, 2016.2019. For additional segment-related information and trends, please read “Segment Overview” above.

Three Months Ended ~~September~~June 30, ~~2017~~2020 Compared to Three Months Ended ~~September~~June 30, ~~2016~~2019

Revenues. Revenues ~~increased~~from continuing operations decreased by ~~65%~~$58.3 million to ~~$233.5~~$89.6 million during the ~~third quarter of 2017~~three months ended June 30, 2020, from ~~$141.6~~$148.0 million during the same period in ~~2016.~~2019, despite the impact of $46.7 million of revenues added from CJWS. This ~~increase~~decrease was primarily due to ~~increased demand for our services~~decreased activity, particularly by our Water Logistics and Completion & Remedial Services segments' customers, ~~particularly completion~~as exploration and remedial services, compared to the same period in 2016, when our customers were working with reduced capital budgets. After a prolonged period of lower oil prices, our customers have gradually increasedproduction companies are significantly reducing their capital ~~and operating spending levels.~~expenditure activity due to current low oil commodity pricing.

~~Completion and remedial services~~Well Servicing revenues ~~increased~~decreased by ~~150%~~19% to ~~$123.7~~$47.3 million during the ~~third quarter of 2017~~three months ended June 30, 2020, compared to $49.4 million in the same period in 2016. 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 coil tubing lines of business. Total hydraulic horsepower increased to 523,000 at September 30, 2017 from 444,000 at September 30, 2016 primarily due to the acquisition of 74,000 HHP and two newbuild coiled tubing units which came online during the third quarter of 2017. Weighted average horsepower increased to 520,000 for the third quarter of 2017 from 444,000 in the third quarter of 2016.

Water logistics revenues increased by 11% to $52.3 million during the third quarter of 2017 compared to $47.2 million in the same period in 2016. Our revenue per water logistics truck increased 12% to $55,000 in the third quarter of 2017 compared to $49,000 in the same period in 2016 mainly due to increases in trucking activity, disposal utilization and pricing. Our weighted average number of water logistics trucks decreased to 947 during the third quarter of 2017 compared to 962 in the same period in 2016.

~~Well servicing revenues increased by 27% to $54.6 million during the third quarter of 2017 compared to $43.2~~$58.5 million during the same period in ~~2016.~~2019. The ~~increase~~overall decrease included the addition of $29.9 million of revenues contributed by the acquisition of CJWS, and was driven by ~~an increase in utilization of our equipment, primarily due to increases~~a decreases in customer demand. Our weighted average number of ~~well servicing~~active Well Servicing rigs ~~remained constant at 421~~increased to 576 during the ~~third quarter~~three months ended June 30, 2020, compared to 308 during the same period of ~~2017 and 2016.~~2019. Utilization ~~increased~~decreased to ~~55%~~22% in the ~~third quarter of 2017,~~three months ended June 30, 2020, compared to ~~45%~~70% in the comparable ~~quarter~~period of ~~2016.~~2019 due to declines in production related activity. Revenue per rig hour in the ~~third quarter of 2017~~three months ended June 30, 2020, was ~~$329,~~$490, increasing from ~~$313~~$353 in the comparable ~~quarter~~period of ~~2016~~2019, due to the impact of the higher per rig rate ~~increases~~from CJWS California operations.

Water Logistics revenues decreased by 35% to ~~customers.~~

~~Contract drilling revenues increased by 54% to $2.8~~$33.3 million during the ~~third quarter~~three months ended June 30, 2020, including a $12.8 million increase resulting from the acquisition of ~~2017~~CJWS, compared to ~~$1.8~~$51.0 million in the same period in ~~2016. The~~2019, mainly due to decreases in trucking activity. Pipeline water volumes increased to 3.3 million barrels or 45% of total disposal volumes during the three months ended June 30, 2020, compared to 3.2 million barrels or 32% of total disposal volumes during the three months ended June 30, 2019.Our weighted average number of ~~rig operating days remained constant at 92~~fluid service trucks increased to 1,416 during the three months ended June 30, 2020, compared to 814 in the ~~third quarter of 2017 and 2016.~~same period in 2019.

Completion & Remedial Services revenues decreased by 76% to $9.1 million during the three months ended June 30, 2020 compared to $38.4 million in the same period in 2019. The ~~increase~~overall decrease in revenue between these periods was despite $4.1 million in revenues from the CJWS acquisition. The decrease was due to ~~an increase in drilling activity and rig trucking~~decreased activity in ~~the Permian Basin.~~ our rental and fishing tool and coiled tubing lines of business.

three months ended June 30, 2020, from ~~$116.3~~$109.1 million in the same period in ~~2016,~~2019, primarily due to ~~increases~~decreases in activity and corresponding ~~increases~~decreases in employee headcount and wages to adapt to current activity levels. Such decrease included $35.6 million of additional operating expenses following the acquisition of CJWS.

Direct operating expenses for the ~~completion and remedial services~~Well Servicing segment ~~increased~~decreased by ~~110%~~15% to ~~$84.5~~$39.4 million during the ~~third quarter of 2017~~three months ended June 30, 2020, compared to ~~$40.3~~$46.2 million for the same period in ~~2016~~2019, with CJWS adding $24.0 million, reflecting the offsetting reductions in operating expenses due ~~primarily~~ to ~~increased activity levels overall, especially in our pumping and coil tubing services.~~decreased demand. Segment profits ~~increased~~decreased to ~~32%~~17% of revenues during the ~~third quarter of 2017 compared to 18%~~three months ended June 30, 2020, from 22% for the same period in ~~2016,~~2019, due to ~~the improved utilization~~decreased activity levels and $1.6 million of ~~equipment, price increases and incremental margins from a higher revenue base.~~ severance payments.

Direct operating expenses for the ~~water logistics~~Water Logistics segment ~~increased~~decreased by 5%28% to ~~$41.3~~$25.6 million during the ~~third quarter of 2017~~three months ended June 30, 2020, compared to ~~$39.3~~$35.5 million for the same period in ~~2016, mainly due to activity levels improving in 2017.~~2019, despite an increase of $8.8 million following the acquisition of CJWS. Segment profits were ~~21%~~23% of revenues during the ~~third quarter of 2017~~three months ended June 30, 2020, compared to ~~17%~~30% for the same period in ~~2016,~~2019, due to ~~an increase~~the decrease in ~~incremental margins from a higher revenue base.~~demand.

Direct operating expenses for the ~~well servicing~~Completion & Remedial Services segment ~~increased~~decreased by ~~23%~~65% to ~~$43.2~~$9.6 million during the ~~third quarter of 2017~~three months ended June 30, 2020, compared to ~~$35.0~~$27.4 million for the same period in ~~2016. The~~2019, and included the $2.8 million increase ~~in direct operating expenses corresponds to increased workover and plugging activity levels.~~from the acquisition of CJWS. Segment ~~profits increased to 21%~~loss was 6% of revenues during the ~~third quarter of 2017~~three months ended June 30, 2020, compared to ~~19%~~segment profits of ~~revenues during~~29% for the ~~third quarter of 2016~~same period in 2019, due to ~~improved utilization of our equipment, price increases~~higher personnel cost relative to revenue levels and ~~incremental margins from a higher revenue base.~~due to customers delaying work. and $0.3 million in severance payments.

~~Direct operating~~General and Administrative Expenses. General and administrative expenses ~~for the contract drilling segment~~ increased ~~51%~~marginally to ~~$2.5~~$30.4 million during the ~~third quarter of 2017 compared to $1.7~~three months ended June 30, 2020, from $30.2 million for the same period in 2016, due to increased pricing and rig moving activity. Segment profits increased to 11% of revenues during the third quarter of 2017 from a segment profit of 9% during the third quarter of 2016 due to an increase in pricing.

~~General and Administrative Expenses.~~2019. General and administrative expenses ~~increased by 31% to $39.2~~added following the acquisition of CJWS totaled $7.8 million, which offset administrative cost reductions. Stock-based compensation expense was $0.1 million and $3.3 million during the ~~third quarter~~three months ended June 30, 2020 and 2019, respectively. During the three months ended June 30, 2019, one-time costs included charges related to consulting fees of ~~2017 from $30.1~~$0.9 million for reclamation of tax refund for the 2007 tax year.

Depreciation and AmortizationExpenses. Depreciation and amortization expenses were $12.9 million during the three months ended June 30, 2020, compared to $17.3 million for the same period in ~~2016.~~2019. The ~~increase was partially~~decrease is mainly related to the reduced asset base due to ~~stock-based compensation~~impairments and reduced capital spending during the three months ended June 30, 2020.

Interest Expense. Interest expense ~~which was $5.9 million and $2.2~~increased to $12.8 million during the third quarters of 2017 and 2016, respectively. In addition, during the third quarter of 2017 legal and professional fees related to due diligence on corporate development activities totaled $3.7 million.

~~Depreciation and AmortizationExpenses.~~ ~~Depreciation and amortization expenses were $29.5 million during the third quarter of 2017 compared to $53.1~~three months ended June 30, 2020 from $10.4 million for the same period in ~~2016. The decrease in depreciation~~2019. Interest expense consisted primarily of interest on our Senior Notes, promissory notes, finance leases, and amortization ~~expense is due~~of our debt discounts and deferred financing costs, and included a $1.1 million write off of deferred financing cost assets following amendment to the ~~revaluation of our asset base as of December 31, 2016 as part of the adoption of the fresh start accounting associated with our emergence from bankruptcy.~~ABL Facility.

~~Interest Expense.~~ ~~Interest expense decreased to $8.9 million~~Income Tax Benefit. Income tax benefit during the ~~third quarter of 2017 compared to $24.0~~three months ended June 30, 2020, was $0.3 million ~~during the third quarter of 2016. The decrease in interest expense is primarily due to the cancellation of our unsecured notes as part of our emergence from bankruptcy.~~

~~Income Tax Benefit.~~ ~~There was an income tax benefit of $1.7 million during the third quarter of 2017~~ compared to an income tax benefit of ~~$1,000~~zero for the same period in 2016. The $1.7 million tax benefit in 2017 resulted from the Company’s decision to accelerate unused alternative minimum tax credit carryforwards in accordance with the 2015 Protecting Americans from Tax Hikes (PATH) Act, resulting in expected tax refunds of $1.7 million. Excluding the impact of the valuation allowance, our2019. Our effective tax ~~rate~~rates on continuing operations during the ~~third quarter of 2017~~three month periods ended June 30, 2020 and ~~2016 was~~2019, were approximately ~~36%.~~ 0.8% and 0.1%, respectively.

~~Nine~~Six Months Ended ~~September~~June 30, ~~2017~~2020 Compared to ~~Nine~~Six Months Ended ~~September~~June 30, ~~2016~~2019

Revenues. Revenues ~~increased~~from continuing operations decreased by ~~60%~~$83.1 million to ~~$628.8~~$218.0 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, from ~~$392.0~~$301.2 million during the same period in ~~2016.~~2019, despite the impact of $65.1 million of revenues added from CJWS following the March 9, 2020, closing of the CJWS acquisition. This ~~increase~~decrease was primarily due to ~~increased demand for our services~~decreased activity, particularly by our Water Logistics and Completion & Remedial Services segments' customers, ~~particularly completion~~as exploration and ~~remedial services, compared~~production companies are significantly reducing their capital expenditure activity due to ~~the same period in 2016, when our customers were working with reduced capital budgets and ramping down projects. After the prolonged period of lower~~current low oil ~~prices, our customers have gradually begun~~commodity pricing.

Well Servicing revenues decreased by 12% to ~~increase capital budgets.~~

~~Completion and remedial services revenues increased by 148% to $311.5~~$105.5 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to $125.3 million in the same period in 2016. 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 coil tubing lines of business. Total hydraulic horsepower increased to 523,000 at September 30, 2017 from 444,000 at September 30, 2016 due to the acquisition of 74,000 HHP and two newbuild coiled tubing units which came online during the third quarter of 2017. Weighted average horsepower increased to 520,000 as of September 30, 2017 compared to 444,000 as of September 30, 2016.

~~Water logistics revenues increased by 7% to $153.3 million during the nine months ended September 30, 2017 compared to $142.9~~$120.5 million during the same period in ~~2016. Our revenue per water logistics truck increased 11% to $163,000 in~~2019. The overall decrease included the ~~nine months ended September 30, 2017 compared to $147,000 in~~addition of $41.2 million of revenues contributed by the ~~same period in 2016 mainly due to increases in trucking~~

~~activity, disposal utilization~~acquisition of CJWS, and ~~pricing. Our weighted average number of water logistics trucks decreased to 942 during the nine months ended September 30, 2017 compared to 974 in the same period in 2016.~~

~~Well servicing revenues increased by 31% to $156.3 million during the nine months ended September 30, 2017 compared to $118.9 million during the same period in 2016. The increase~~ was driven by ~~an increase in utilization of our equipment, primarily due to increases~~a decreases in customer demand. Our weighted average number of ~~well servicing~~active Well Servicing rigs ~~remained constant at 421~~increased to 486 during the ~~nine~~six months ended ~~September~~June 30, ~~2017 and 2016.~~2020, compared to 309 during the same period of 2019. Utilization ~~was 54%~~decreased to 36% in the ~~nine~~six months ended ~~September~~June 30, ~~2017,~~2020, compared to ~~40%~~72% in the comparable ~~quarter~~period of ~~2016.~~2019 due to declines in production related activity. Revenue per rig hour in the ~~nine~~six months ended ~~September~~June 30, ~~2017 increased to $319,~~2020, was $434, increasing from ~~$314~~$345 in the comparable period of ~~2016.~~ 2019, due to the impact of the higher per rig rate from CJWS California operations.

~~Contract drilling~~Water Logistics revenues ~~increased~~decreased by ~~61%~~27% to ~~$7.7~~$77.6 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, including a $17.1 million increase resulting from the acquisition of CJWS, compared to ~~$4.8~~$106.6 million in the same period in ~~2016. The~~2019, mainly due to decreases in trucking activity. Pipeline water volumes increased to 6.9 million barrels or 41% of total disposal volumes during the six months ended June 30, 2020, compared to 6.2 million barrels or 32% of total disposal volumes during the six months ended June 30, 2019.Our weighted average number of ~~rig operating days~~fluid service trucks increased ~~16%~~ to ~~$318~~1,162 during the six months ended June 30, 2020, compared to 816 in the ~~nine~~same period in 2019.

Completion & Remedial Services revenues decreased by 53% to $34.9 million during the six months ended ~~September~~June 30, ~~2017~~2020 compared to ~~$274~~$74.0 million in the ~~nine months ended September 30, 2016.~~same period in 2019. The ~~increase~~overall decrease in revenue ~~and rig operating days~~between these periods was despite $6.8 million in revenues from the CJWS acquisition. The decrease was due to ~~an increase in drilling~~decreased activity in ~~the Permian Basin.~~ our rental and fishing tool and coiled tubing lines of business.

Direct Operating Expenses. Direct operating expenses, which primarily consist of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance, ~~increased~~decreased to ~~$490.1~~$179.7 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, from ~~$333.0~~$220.2 million in the same period in ~~2016,~~2019, primarily due to ~~increases~~decreases in activity and corresponding ~~increases~~decreases in employee headcount and wages to adapt to current activity levels. Such decrease included $51.4 million of additional operating expenses following the acquisition of CJWS.

Direct operating expenses for the ~~completion and remedial services~~Well Servicing segment ~~increased~~decreased by ~~116%~~5% to ~~$232.9~~$90.2 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to ~~$107.9~~$95.0 million for the same period in ~~2016~~2019, with CJWS adding $34.7 million, reflecting the offsetting reductions in operating expenses due ~~primarily~~ to ~~increased activity levels overall, especially in our pumping and coil tubing services.~~decreased demand. Segment profits ~~increased~~decreased to ~~25%~~14% of revenues during the ~~nine~~six months ended ~~September~~June 30, ~~2017 compared to 14%~~2020, from 22% for the same period in ~~2016,~~2019, due to ~~the improved utilization price increases,~~decreased activity levels and ~~incremental margins from a higher revenue base.~~ $4.0 million of severance payments.

Direct operating expenses for the ~~water logistics~~Water Logistics segment ~~increased~~decreased by 4%19% to ~~$124.4~~$58.7 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to ~~$119.1~~$72.8 million for the same period in ~~2016, mainly due to activity levels improving in 2017.~~2019, despite an increase of $11.8 million following the acquisition of CJWS. Segment profits were ~~19%~~24% of revenues during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to ~~17%~~32% for the same period in ~~2016,~~2019, due to ~~higher levels of disposal utilization and pricing.~~the decrease in demand.

Direct operating expenses for the ~~well servicing~~Completion & Remedial Services segment ~~increased~~decreased by ~~24%~~41% to ~~$125.9~~$30.8 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to ~~$101.3~~$52.4 million for the same period in ~~2016. The~~2019, and included the $4.8 million increase ~~in direct operating expenses corresponds to increased workover and plugging activity levels.~~from the acquisition of CJWS. Segment profits ~~increased to 19%~~were 12% of revenues during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020, compared to ~~15% of revenues during~~29% for the same period in ~~2016~~2019, due to ~~improved utilization of our equipment, price increases~~the decreased activity levels and ~~incremental margins from a higher revenue base.~~$0.9 million in severance payments.

~~Direct operating~~

General and Administrative Expenses. General and administrative expenses ~~for the contract drilling segment~~ increased ~~48%~~by 6% to ~~$6.8~~$65.5 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017 compared to $4.6~~2020, from $61.9 million for the same period in ~~2016,~~2019. This increase was due to $9.1 million of increased activity and rig operating days. Segment profits increased to 12% of revenues during the nine months ended September 30, 2017 from a segment profit of 4% during the nine months ended September 30, 2016 due to an increase in drilling projects in 2017.

~~General and Administrative Expenses.~~ ~~General~~general and administrative expenses ~~increased by 26% to $109.5~~added following the acquisition of CJWS, and $10.6 million of legal and professional acquisition transaction related expenses which offset administrative cost reductions. Stock-based compensation expense was $1.4 million and $6.6 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017 from $86.7~~2020 and 2019, respectively. During the six months ended June 30, 2019, one-time costs included charges related to consulting fees of $0.9 million for reclamation of tax refund for the 2007 tax year.

Depreciation and AmortizationExpenses. Depreciation and amortization expenses were $27.6 million during the six months ended June 30, 2020, compared to $33.5 million for the same period in ~~2016.~~2019. The ~~increase was partially due~~decrease is mainly related to ~~increased stock-based compensation expense which was $16.6 million and $7.4 million~~reduced capital spending during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020.

Impairments of Goodwill and 2016, respectively. In addition, during the nine-month period of 2017, legal and professional fees related to due diligence on corporate development activities totaled $3.7 million, and professional fees related to implementation of fresh start accounting totaled $668,000.

~~Depreciation and AmortizationExpenses.~~ ~~Depreciation and amortization expenses were $80.8 million during the nine months ended September 30, 2017 compared to $164.1 million~~Other Long-Lived Assets. Beginning in March 2020, we experienced a reduction in demand for ~~the same period in 2016. The decrease in depreciation and amortization expense is~~our services due to the ~~revaluation~~decreased price of ~~our asset base~~crude oil as a result of ~~December 31, 2016 as part~~multiple significant factors impacting supply and demand in the global oil and natural gas markets. Goodwill recorded in connection with the March 9, 2020, acquisition of ~~the adoption of the fresh start accounting associated with our emergence from bankruptcy.~~

~~Interest Expense.~~ ~~Interest expense decreased to $27.2~~CJWS totaled $18.9 million during the nine months ended September 30, 2017 compared to $67.2 million during the nine months ended September 30, 2016. The decrease in interest expense is primarily due to the cancellation of our unsecured notesand was recorded as part of our ~~emergence from bankruptcy.~~ Well Servicing and Water Logistics reporting units. As of March 31, 2020, due to the reduction in demand for our services, we determined that the fair value of the Well Servicing reporting unit was less than its carrying values indicating an impairment of the $10.6 million of goodwill recorded for this reporting unit. Related to these market conditions at March 31, 2020, we recorded impairments of certain tangible long-lived assets totaling $84.2 million and impairments of certain parts inventory totaling $4.8 million associated with our Well Servicing segment, as we determined that the carrying value of certain long-lived assets within the overall asset group for this segment were not recoverable. The Company also recorded $2.3 million in impairments related to asset held for sale which are part of discontinued operations.

~~Income Tax Benefit.~~ ~~There was a net income tax benefit of $1.4~~Interest Expense. Interest expense increased to $23.4 million during the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2020 from $21.0 million for the six months ended June 30, 2019, respectively. Interest expense consisted primarily of interest on our Senior Notes, promissory notes, finance leases, and amortization of our debt discounts and deferred financing costs, and included a $1.1 million write off of deferred financing cost assets following amendment to the ABL Facility.

Income Tax Benefit. Income tax benefit during the six months ended June 30, 2020, was $4.1 million compared to an income tax benefit of ~~$3.9~~$1.9 million for the same period in ~~2016. Of the $1.4 million net~~2019. The tax benefit ~~for~~during the ~~nine-month period, $1.7 million of tax benefit in 2017 resulted~~six months ended June 30, 2020, was generated from the Company’s decision to accelerate unused alternative minimum tax credit carryforwards in accordance with the 2015 Protecting Americans from Tax Hikes (PATH) Act, resulting in expected refunds of $1.7 million, partially offset by tax expense in the first quarter of 2017. Excluding the impact of long-lived asset impairments recorded during the ~~valuation allowance, our~~period and the composition of deferred tax liabilities acquired as part of the March 9, 2020, acquisition of CJWS. During the same period of 2019, we filed an amended 2007 federal tax return under section 172(f) of the Internal Revenue Code of 1986, as amended, which allowed us to claim a refund of $1.9 million of 2007 taxes. Our effective tax ~~rate~~rates on continuing operations during ~~each of~~ the ~~nine months~~six month periods ended ~~September~~June 30, ~~2017~~2020 and ~~2016 was~~2019, were approximately ~~36%.~~ 2.3% and 5.2%, respectively.

Liquidity and Capital Resources

~~As of September 30, 2017, our~~Our current primary capital resources ~~were utilization of capital leases and borrowings~~are cash flow from our operations, availability under our ~~$100.0 million accounts receivable securitization~~revolving credit facility (the ~~“New ABL Facility”~~"ABL Facility"), ~~and from net cash provided by operations. As of September 30, 2017, we had unrestricted cash~~the ability to enter into finance leases, the ability to incur additional secured indebtedness, and cash ~~equivalents~~on hand of ~~$43.2~~$11.0 million ~~compared to $98.9~~at June 30, 2020. We had the $9.4 million minimum availability under the ABL Facility as of ~~December 31, 2016. An additional~~June 30, 2020. To maintain compliance with certain of the minimum availability covenant requirements as of June 30, 2020, in early July 2020 we repaid the $2.6 million amount of ~~$47.7~~borrowings that was previously outstanding, and advanced $2.3 million ~~is classified~~of our available cash balance to the Administrative Agent. During the remainder of July 2020, and as ~~restricted~~of August 7, 2020, we are currently subject to increased financial and borrowing base information reporting and we have made additional advances totaling $10.7 million of our available cash balance to ~~collateralize insurance reserves.~~the Administrative Agent as needed to maintain compliance with the minimum availability covenant requirements. We have utilized, and expect to utilize in the future, bank and ~~capital~~finance lease ~~financing~~financing and sales of ~~equity~~non-strategic assets to obtain capital resources. ~~When appropriate,~~On June 15, 2020, the Company entered into the Second Amendment to the ABL Credit Agreement, pursuant to which, among other things, the Company reduced the Aggregate Commitments (as defined in the Credit Agreement) from $120 million to $75 million.

See Note 6. Long-Term Debt and Interest Expense for a description of our long-term debt and balances outstanding as of June 30, 2020 and December 31, 2019. As of August 7, 2020, there were no amounts drawn on the ABL facility. Based on our Senior Notes obligations, we expect to incur interest payments of approximately $16.1 million due October 2020. In addition, we incur interest payments on the Senior Secured Promissory Note of $125,000 each month. Classified as a derivative liability, a current liability in the accompanying balance sheet, our Make-Whole Reimbursement Amount liability had a fair value of approximately $12.8 million as of June 30, 2020.

As a result of weak energy sector conditions and lower demand for our products and services, our operational results, working capital and cash flows have been negatively impacted during the first half of 2020. Based on our current operating and commodity price forecasts and capital structure, we believe that if certain financial ratios or covenants were to come into effect under our debt instruments, we will ~~consider~~have difficulty complying with certain of such obligations. Certain covenants, such as consolidated fixed charge coverage ratio and cash dominion provisions in the ABL Facility spring into effect under certain triggers defined in the ABL Credit Agreement for so long as such applicable trigger period is in effect. Additionally, certain triggers in the ABL Facility increase certain financial and borrowing base reporting requirements for so long as such applicable trigger period is in effect. Failure to comply, for example, with a “springing” consolidated fixed charge coverage ratio requirement under the ABL Facility would result in an event of default under the ABL Facility, which would result in a cross-default under the Senior Notes. If an event of default were to occur, our lenders could, in addition to other remedies such as charging default interest, accelerate the maturity of the outstanding indebtedness, making it immediately due and payable, and we may not have sufficient liquidity to repay those amounts. As of June 30, 2020, there were no existing events of default under, and we are in compliance with, all of our debt instruments.

Management has taken several steps to generate additional liquidity, including through reducing operating and administrative costs through employee headcount reductions, closing operating locations, employee furloughs and other cost reduction measures, and the suspension of growth capital expenditures in our continuing business operations with the goal of preserving margins and improving working capital. Management has made plans for further similar cost and capital expenditure reductions, as necessary.

As market conditions warrant and subject to our contractual restrictions, liquidity position and other factors, we may from time to time access the capital markets or seek to recapitalize, refinance or otherwise restructure our capital structure. We may accomplish this through open market or privately negotiated transactions, which may include, among other things, repurchases of our common stock or outstanding debt, debt-for-debt or debt-for-equity exchanges, refinancings, private or public equity or ~~private~~debt raises and rights offerings. Many of these alternatives may require the consent of current lenders, stockholders or noteholders, and there is no assurance that we will be able to execute any of these alternatives on acceptable terms or at all. The amounts involved in any such transaction, individually or in the aggregate, may be material. Recent adverse changes in the capital markets could make it difficult to obtain additional capital or obtain it at attractive rates. If we are unable to maintain or obtain access to capital, we could experience a reduction of liquidity and this may result in difficulty funding our operations, repaying our short-term borrowings, and paying interest on long-term debt and ~~equity offerings and non-recourse~~other obligations.

Share Repurchase Program

On May 31, 2019, we announced that the Board authorized a share repurchase plan whereby we may repurchase up to $5 million of our outstanding shares of common stock beginning on June 4, 2019, for a period of 12 months. Prior to the plan's termination, we were authorized to repurchase our common stock from time to time in open market purchases or in private transactions ~~to meet our liquidity needs.~~

~~Net Cash Used~~ in ~~Operating Activities~~accordance with applicable federal securities laws. As permitted under the plan, authorization was terminated by the Board on May 18, 2020.

Cash Flow Summary

Cash used in operating activities was $5.6 million for the six months ended June 30, 2020, compared to cash provided by operating activities ~~was $1.8 million for the nine months ended September 30, 2017, an increase compared to cash used in operating activities~~ of ~~$71.8~~$11.3 million during the same period in ~~2016.~~2019. Operating cash flow ~~provided~~ in the first ~~nine~~six months of ~~2017 improved~~2020 decreased compared to the same period in 2019 due to lower cash operating margins in the current environment.

Cash used in investing activities was $21.1 million for the six months ended June 30, 2020, compared to cash used in investing activities of $28.4 million during the same period in ~~2016~~2019. Investing cash flow in the first six months of 2020 decreased compared to the same period in 2019 due to ~~stronger operating results~~lower capital expenditures and ~~working capital levels.~~higher proceeds from the sales of non-strategic assets offset by acquisitions.

Cash provided by financing activities was $1.5 million for the six months ended June 30, 2020, compared to cash used in financing activities of $19.5 million during the same period in 2019. Financing cash flows in the first six

months of 2020 increased compared to the same period in 2019 primarily due to proceeds of $15 million from the Senior Secured Promissory Note issued in connection with the CJWS Transaction.

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 or no access to additional ~~financing.~~

financing to operate or expand our business.

Capital Expenditures

Cash capital expenditures during the first ~~nine~~six months of ~~2017~~2020 were ~~$57.0~~$5.9 million, compared to ~~$22.9~~$33.4 million in the same period of ~~2016. Cash capital expenditures for the nine months ended September 30, 2017 were $48.3 million, with an additional $8.7 million of accrued capital expenditures.~~2019. We added ~~$61.0~~$0.5 million of leased assets through our ~~capital~~finance lease program and other financing arrangements during the first ~~nine~~six months of ~~2017~~2020 compared to ~~$5.2~~$7.6 million of leased asset additions in the same period in ~~2016.~~ 2019. Proceeds from sales of non-strategic assets totaled $45.0 million during the period, more than offsetting capital expenditures during the first six months of 2020. The Company continues to seek to sell remaining non-strategic assets in future periods.

We currently have planned capital expenditures for the full year of ~~2017~~2020 of ~~under $135.0~~approximately $11 million, including ~~capital~~finance leases of ~~$70.0~~less than $1 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 $43.2 million at September 30, 2017. We had $64.0 million of borrowings under the New ABL Facility as of September 30, 2017, of which $45.2 million of cash is held in restricted cash as collateral for letters of credit, giving us approximately $30.9 million of available borrowing capacity subject to covenant constraints under our New ABL Facility. In 2017, 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 $162.9 million aggregate outstanding principal amount of loans as of September 30, 2017.

On April 13, 2017, the Company filed a universal shelf registration statement on Form S-3 covering up to $1 billion of securities. In August 2017, Basic commenced an at-the-market public offering (the "ATM Program"), under which it could have sold shares of its common stock having an aggregate value of $50 million. Basic terminated the ATM Program on September 30, 2017.

~~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 September 30, 2017 (in thousands):

Obligations Due in
Periods Ended September 30,
Contractual Obligations Total 2017 2018 to 2019 2020 to 2021 Thereafter
Term Loan Agreement $ 162,938
$ 413
$ 3,300
$ 159,225
$ —
New ABL Facility 64,000
—
—
64,000
—
Capital leases and other financing arrangements 106,674
12,419
76,910
17,249
96
Operating leases 18,741
1,510
8,926
6,407
1,898
Asset retirement obligation 2,524
548
498
533
945
Total $ 354,877
$ 14,890
$ 89,634
$ 247,414
$ 2,939

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.

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 September 30, 2017, Basic had approximately $669.5 million of net operating loss carryforwards ("NOL"), for federal income tax purposes, which begin to expire in 2031 and $250.4 million of NOLs for state income tax purposes which begin to expire in 2017.

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 September 30, 2017, a valuation allowance of $228.3 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~~Our consideration of recent accounting pronouncements is included in Note ~~13.~~ 17. Recent Accounting Pronouncements to the consolidated financial statements included in this quarterly report.

Impact of Inflation on Operations

~~Management is of~~Inflation in the ~~opinion that inflation~~United States has been relatively low in recent years and did not ~~had~~have a ~~significant~~material impact on our ~~business.~~results of operations for the six months ended June 30, 2020, or the year ended December 31, 2019. Although the impact of inflation has been insignificant in recent years, it is still a factor in the U.S. economy, and we tend to experience inflationary pressure on the cost of our equipment, materials and supplies during periods of increasing oil and natural gas prices and increasing activity in our areas of operations.

ITEM 3. 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As ~~of September 30, 2017,~~a “smaller reporting company”, we ~~had no material changes~~are not required to ~~the disclosure on~~provide this ~~matter made in our Annual Report on Form 10-K for the year ended December 31, 2016.~~ information.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

~~Based on their evaluation~~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 ~~report,~~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 ~~(as defined in Rules 13a-15(e) and 15d-15(e) under~~were effective as of June 30, 2020, at the Exchange Act) are effective to ensure that information required to be disclosed in 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 effective to ensure that information required to be disclosed in such reports is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.reasonable assurance level.

Changes in Internal Control Over Financial Reporting

~~During~~As discussed above in this Quarterly Report on Form 10-Q, on March 9, 2020, we acquired all of the issued and outstanding shares of capital stock of CJWS. We are currently integrating CJWS into our internal control over financial reporting processes. In executing this integration, we are analyzing, evaluating, and where necessary,

making changes in control and procedures related to the CJWS business, which we expect to complete within one year after the date of acquisition. Total assets of CJWS represented approximately 22% of our consolidated total assets as of June 30, 2020, and CJWS revenues following the March 9, 2020 acquisition date represented approximately 30% of our consolidated revenues for the six month period ended June 30, 2020.

Other than the changes described above, during the most recent fiscal quarter, there have been no changes, including the impact of COVID-19, 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. We may make changes in our internal control procedures from time to time in the future.

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, individually or in the aggregate, to result in a material adverse effect on our financial condition, results of operations or liquidity. The information regarding litigation and environmental matters described in Note 8. Commitments and Contingencies of the notes to our unaudited consolidated financial statements included in this Quarterly Report on Form 10-Q is incorporated herein by reference.

ITEM 1A. RISK FACTORS

~~For information regarding risks that may affect~~During the quarter ended June 30, 2020, there have been no material changes in our ~~business, see the~~ risk factors ~~included~~disclosed in Part I, Item 1A. Risk Factors in our ~~most recent~~ Annual Report on Form 10-K for the year ended December 31, 2019, our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, and our Current Report on Form 8-K, filed with the Securities and Exchange Commission on May 15, 2020, other than the following:

The ongoing spread of COVID-19 and recent developments in the global oil and gas markets have and will continue to adversely affect our business and financial condition.

The impacts of COVID-19 and the significant drop in commodity prices have had an unprecedented impact on the global economy and our business. We expect that our business will continue to be adversely affected by the COVID-19 pandemic and lower commodity prices. The responses of governmental authorities and companies to reduce the spread of COVID-19 have significantly reduced global economic activity. Various containment measures, including large-scale travel bans, border closures, quarantines, shelter-in-place orders and business and government shutdowns, have resulted in the slowing of economic growth and a reduced demand for oil and natural gas and the disruption of global manufacturing supply chains.

In addition, recent actions by Saudi Arabia and Russia have caused a worldwide oversupply in oil and natural gas. After OPEC and a group of oil producing nations led by Russia failed in March 2020 to agree on oil production cuts, Saudi Arabia announced that it would cut oil prices and increase production, leading to a sharp further decline in oil and natural gas prices. While OPEC, Russia and other oil producing countries reached an agreement in April 2020 to reduce production levels, and U.S. production has declined, oil prices remain low on account of an oversupply of oil and natural gas, with a simultaneous decrease in demand as a result of the impact of COVID-19 on the global economy.

As our customers, commodity markets and the U.S. and global economies have been negatively impacted by the these factors, we may continue to experience lower demand for our services. Demand for our services will continue to decline as our customers revise their capital budgets downward and adjust their operations in response to lower oil prices.

Oil and natural gas prices are expected to continue to be volatile as a result of the ongoing COVID-19 outbreak, and as changes in oil and natural gas inventories, industry demand and economic performance are reported. We cannot predict when prices will improve and stabilize or how long the pandemic will last or the time it will take for economic activity to return to prior levels.

Should COVID-19 continue to spread globally or within the U.S., and should the suggested and mandated social quarantining and work from home orders continue, our business, financial condition and results of operations could be materially and adversely impacted. The decline in commodity prices and demand for our services could lead to additional material impairments of our goodwill and other long-lived assets. It is impossible to predict the severity and longevity of the impact of COVID-19 on the general economy and the oil and gas industry. These risks could have a material adverse impact on our financial position, results of operations and cash flows. Basic will

continue to monitor the developments relating to COVID-19 and the volatility in oil prices closely, and will follow health and safety guidelines as they evolve.

The combination of the COVID-19 pandemic and the related significant decline in global oil and gas prices have significantly impacted the Company’s ability to access the capital markets or obtain financing.

The COVID-19 pandemic and decline in the price of oil and natural gas described above has increased volatility and caused negative pressure in the capital and credit markets. As a result, and in light of our debt incurrence restrictions in our existing debt documents, we may not have access in the current environment to the capital markets or financing on terms we would find favorable, if at all.

The Company’s ability to continue as a going concern could impact our ability to obtain capital financing and adversely affect the price of our common stock.

Due to the uncertainty of future oil and natural gas prices and the effects the outbreak of COVID-19 will have on our future results of operations, operating cash flows and financial condition, there is substantial doubt as to the ability of the Company to continue as a going concern. Management has taken several steps to generate additional liquidity, including through reducing operating and administrative costs through employee headcount reductions, closing operating locations, employee furloughs and other cost reduction measures, and the suspension of growth capital expenditures in our continuing business operations with the goal of preserving margins and improving working capital. However, there can be no assurance that these steps will be sufficient to mitigate the impact of the COVID-19 pandemic until energy commodity prices recover to levels that can sustain our ongoing business and enable us to meet our financial covenants and day-to-day obligations in the long term.

Management may implement further similar cost and capital expenditure reductions, as necessary. These additional steps may include sales of non-strategic assets, obtaining waivers of debt covenant requirements from our lenders, restructuring or refinancing our debt agreements, or obtaining equity financing. There can be no assurances that, if required, the Company would be able to successfully sell assets, obtain waivers, restructure its indebtedness, or complete any strategic transactions in the current environment.

If we cannot continue as a going concern, our stockholders would likely lose most or all of their investment in us. Reports raising substantial doubt as to a company’s ability to continue as a going concern are generally viewed unfavorably by analysts and investors and could have a material adverse effect on the Company’s business, financial position, results of operations and liquidity.

Global oil and natural gas prices may not return to pre-COVID-19 levels for several months or years, if ever.

There can be no assurance that demand for oil and natural gas will return to pre-COVID-19 levels or, if it does, that it will return to those levels at any time in the foreseeable future. In addition, even if that demand increases, the significant amount of oil currently in storage, combined with the stated oil price strategy of Saudi Arabia and Russia, could result in the continuation of low commodity prices and low demand for our services for a significant period of time. The continuation of the current price environment for a sustained period would have a significant negative impact on the Company and its operations.

In connection with the CJWS Transaction, we may be obligated to make a Make-Whole Payment to Ascribe which, if made in cash, could materially and adversely affect our liquidity and, if made in Senior Notes, would increase our indebtedness.

In connection with the CJWS Transaction, pursuant to the Purchase Agreement, Ascribe has certain contingent obligations to the Seller to make Seller whole on the par value of the Ascribe Senior Notes as of the earlier of the first anniversary of the closing of the Stock Purchase, a bankruptcy of us, or a change of control of us. If Ascribe is required to pay the Make-Whole Payment to Seller pursuant to the Purchase Agreement, we will be required to reimburse to Ascribe the amount of such Make-Whole Payment, either (i) in cash (a) to the extent we have available cash (as determined by an independent committee of our board of directors) and (b) subject to satisfaction of certain “Payment Conditions” set forth in the ABL Credit Agreement or (ii) if we are unable to pay the full Make-Whole Reimbursement Amount in cash pursuant to clause “(i)” above, in additional Senior Notes as permitted under the ~~heading “Risk Factors.”~~Indenture. As of June 30, 2020, the fair value of the Make-Whole Reimbursement Amount liability was approximately $12.8 million. If we make a Make Whole Payment in cash, we could experience a material and adverse reduction in liquidity and may have difficulty funding our operations, repayment of short-term borrowings, payments of interest and other obligations. In addition, we may not have sufficient funds, or be permitted under the terms of the ABL Credit Agreement, to make a Make-Whole Payment in cash. In such event, we will be required to issue additional Senior Notes to Ascribe equal to the Male-Whole Reimbursement Amount. Such issuance will increase our indebtedness under the Senior Notes. See “Our indebtedness could restrict our operations and make

us more vulnerable to adverse economic conditions” under Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019.

Our ability to generate cash is substantially dependent upon the performance by customers and contract counterparties, and any material nonpayment or nonperformance by our customers or contractual counterparties could have a materially adverse effect on our financial condition and results of operations.

As a result of the disruptions caused by the COVID-19 pandemic and the volatility in the energy markets, we believe we are exposed to heightened credit and performance risk of our customers and contractual counterparties. Some of our customers and contractual counterparties may be highly leveraged and subject to their own operating and regulatory risks, which increases the risk that they may default on their obligations to us. Furthermore, we may be faced with general downward pricing pressure from customers requesting discounts or other pricing concessions and as our competitors compete for fewer jobs. Our ability to generate cash is substantially dependent upon the performance by customers. Any material nonpayment or nonperformance by our customers or our contractual counterparties could have a materially adverse effect on our financial condition 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

The following table summarizes stock repurchases for the three months ended June 30, 2020 (in thousands except share and per share data):


	Issuer Purchases of Equity Securities
Period:	Total Number of Shares Purchased (1)	Average Price Paid Per Share (1)		Total Number of Shares Purchased as Part of Publicly Announced Program (2)	Approximate Dollar Value of Shares that May Yet be Purchased Under the Program (2)
April 1 - April 30	—	$	—	—	$	—
May 1 - May 31	33,871	0.25		—	—
June 1 - June 30	—	—		—	—
Total	33,871	$	0.25	—	$	—

(1) “Total Number of Shares Purchased” were repurchased from various employees to provide such employees the cash amounts necessary to pay certain tax liabilities associated with the vesting of restricted shares and restricted stock units owned by them. The shares were repurchased on various dates based on the closing price per share on the date of repurchase.

(2) On May 31, 2019, we announced that our Board of Directors has authorized the repurchase of up to $5 million of the Company's outstanding shares of common stock from time to time in open market or private transactions, at the Company’s discretion. This authorization was terminated effective May 18, 2020.

ITEM 5. OTHER INFORMATION

Not applicable

ITEM 6. EXHIBITS


Exhibit
No.		Description

~~Exhibit~~2.1*
~~No.~~	~~Description~~

2.1*	~~First Amended Joint Prepackaged Chapter 11 Plan~~Purchase Agreement, dated as of March 9, 2020, by and among the Company, Ascribe III Investments LLC, Basic Energy Services, Inc., NexTier holding Co. and ~~its Affiliated Debtors, dated December 7, 2016~~C&J Well Services, Inc. (Incorporated by reference to Exhibit ~~2.1~~2.3 to the Company’s ~~Current~~Annual 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-K10-K (SEC File No. 001-32693) filed on ~~December 12, 2016)~~March 13, 2020).
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*		Certificate of Amendment to the Company’s Second Amended and Restated Certificate of Incorporation (Incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on May 12, 2020).
3.3*		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).
10.13.4		~~Credit~~Certificate of Designations (Incorporated by reference to Exhibit 3.1 to Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on March 11, 2020).
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 ~~Security~~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 ~~September 29, 2017,~~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).
4.4*		Indenture, dated as of October 2, 2018, by and among Basic Energy ~~Receivables,~~Services, Inc., the subsidiary guarantors party thereto and UMB Bank, N.A., as trustee and collateral agent (Incorporated by reference to Exhibit 4.1 of the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on October 9, 2018).
4.5*		Form of 10.75% Senior Secured Note due 2023 (included as Exhibit A in Exhibit 4.4).
4.6*		First Supplemental Indenture, dated as of August 22, 2019, by and among Agua Libre Midstream LLC, ~~as borrower,~~Agua Libre Holdco LLC, Agua Libre Asset Co LLC, Basic Energy Services, ~~L.P.~~Inc., ~~as initial servicer,~~ the ~~Company, as performance guarantor, the lenders~~subsidiary guarantors party thereto and ~~UBS AG, Stamford Branch,~~UMB Bank, N.A., as ~~administrative agent~~trustee and collateral agent (Incorporated by reference to Exhibit 4.6 to the Company’s Quarterly Report on Form 10-Q (SEC File No. 001-32693) filed on November 1, 2019).
4.7#		Second Supplemental Indenture, dated as of April 1, 2020, by and among C&J Well Services, Inc., KVS Transportation, Inc, Indigo Injection #3, LLC, Basic Energy Services, Inc., the subsidiary guarantors party thereto and UMB Bank, N.A., as trustee and collateral agent.
10.1*		Second Amendment to ABL Credit Agreement, dated as of June 15, 2020, by and among the Company, the guarantors party thereto, the financial institutions party thereto and Bank of America, N.A. (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on ~~October 2, 2017)~~June 16, 2020).
10.2*10.2#		~~Receivables Transfer~~Supplement No. 2 to Security Agreement, dated as of ~~September 29, 2017,~~April 1, 2020, by and among Basic Energy Services, ~~L.P.~~Inc., as ~~initial originator~~Borrower, the other Debtors party thereto, and ~~Basic Energy Receivables, LLC,~~UMB Bank, N.A., as ~~transferee (Incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on October 2, 2017)~~collateral agent.
10.3*10.3#		~~Amendment No. 1~~Bridge Note Guaranty Supplement, dated as of ~~September 29, 2017~~April 1, 2020, to the Amended and Restated Term Loan Credit Agreement dated December 23, 2016, among the Company, as borrower, each lender from time to time party thereto and U.S. Bank National Association, as administrative agent (IncorporatedSenior Secured Promissory Note issued by ~~reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K (SEC File No. 001-32693) filed on October 2, 2017)~~Basic Energy Services, Inc. in favor of Ascribe III Investments LLC.
31.1#
~~31.1#~~	Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange ~~Act~~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~~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~~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~~2002.
101.CAL#		Inline XBRL Calculation Linkbase Document
101.DEF#		Inline 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#		Inline XBRL Labels Linkbase Document
101.PRE#		Inline XBRL Presentation Linkbase Document
101.SCH#		Inline XBRL Schema Document
104 #		Cover Page Interactive Data File (Embedded within the Inline XBRL document and included in Exhibit 101).

*Incorporated by reference

#Filed with this report

##Furnished with this report

†Management contract or compensatory plan or arrangement

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~~Keith L. Schilling
Name:		~~T. M. “Roe” Patterson~~Keith L. Schilling
Title:		President, Chief Executive Officer and
		Director (Principal Executive Officer)

By:		/s/ ~~Alan Krenek~~David S. Schorlemer
Name:		~~Alan Krenek~~David S. Schorlemer
Title:		~~Senior~~Executive Vice President, Chief Financial Officer, ~~Treasurer~~
		Treasurer and Secretary (Principal Financial ~~Officer)~~Officer and

~~By:~~	~~/s/ John Cody Bissett~~
~~Name:~~	~~John Cody Bissett~~
~~Title:~~	~~Vice President, Controller and Chief Accounting Officer~~
	(Principal Accounting Officer)

Date: ~~November 6, 2017~~

August 7, 2020



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
	(Successor)			(Predecessor)			(Successor)			(Predecessor)
Revenues:
Completion and remedial services	$	123,650		$	49,425		$	311,466		$	125,348
Water logistics	52,333			47,178			153,279			142,919
Well servicing	54,629			43,160			156,302			118,891
Contract drilling	2,848			1,847			7,728			4,812
Total revenues	233,460			141,610			628,775			391,970
Expenses:
Completion and remedial services	84,481			40,292			232,932			107,941
Water logistics	41,281			39,268			124,399			119,053
Well servicing	43,219			35,028			125,931			101,345
Contract drilling	2,547			1,683			6,818			4,612
General and administrative, including stock-based compensation of $5,891 and $2,238 in the three months ended September 30, 2017 and 2016 and $16,615 and $7,355 for the nine months ended September 30, 2017 and 2016, respectively	39,235			30,065			109,478			86,706
Restructuring costs	—			10,470			—			10,470
Depreciation and amortization	29,478			53,142			80,846			164,141
Goodwill impairment	—			646			—			646
(Gain) loss on disposal of assets	26			(128		)	(664		)	133
Total expenses	240,267			210,466			679,740			595,047
Operating loss	(6,807		)	(68,856		)	(50,965		)	(203,077		)
Other income (expense):
Interest expense	(8,892		)	(23,953		)	(27,181		)	(67,188		)
Interest income	5			14			23			23
Bargain purchase gain on acquisition	—			662			—			662
Other income	109			37			344			378
Loss before income taxes	(15,585		)	(92,096		)	(77,779		)	(269,202		)
Income tax benefit (expense)	1,740			(1		)	1,366			3,883
Net loss	$	(13,845	)	$	(92,097	)	$	(76,413	)	$	(265,319	)
Loss per share of common stock:
Basic	$	(0.53	)	$	(2.16	)	$	(2.94	)	$	(6.32	)
Diluted	$	(0.53	)	$	(2.16	)	$	(2.94	)	$	(6.32	)



	September 30, 2017			December 31, 2016
Credit facilities:
Term Loan	$	162,938		$	164,175
New ABL Facility	64,000			—
Capital leases and other notes	106,674			78,046
Unamortized discounts, premiums, and deferred debt costs	(13,433		)	(19,001		)
Total principal amount of debt instruments, net	320,179			223,220
Less current portion	50,849			38,468
Long-term debt	$	269,330		$	184,752



	September 30, 2017		December 31, 2016
Unamortized discount on Term Loan	$	9,758	$	11,401
Unamortized discount on Capital Leases - short-term	1,657		1,600
Unamortized discount on Capital Leases - long-term	1,936		6,000
Unamortized deferred debt costs	82		—
	$	13,433	$	19,001



	Compensation expense for three months ended September 30, 2017		Compensation expense for nine months ended September 30, 2017		Unrecognized compensation expense		Weighted average remaining life	Fair value of share based awards vested

Restricted stock	$	4,880	$	13,708	$	36,744	1.9	$	101
Restricted stock options	$	1,011	$	2,907	$	9,320	9.3	$	—



			Weighted Average
	Number of		Grant Date Fair
Non-vested Units	Shares		Value Per Share
Non-vested at beginning of period	539,606		$	36.55
Granted during period	860,402		41.37
Vested during period	(2,698	)	36.55
Forfeited during period	(2,698	)	36.55
Non-vested at end of period	1,394,612		$	39.53



	Completion
	and Remedial			Water		Well		Contract		Corporate
	Services			Logistics		Servicing		Drilling		and Other	Total
Three Months Ended September 30, 2017 (Unaudited)	(Successor)
Operating revenues	$	123,650		52,333		54,629		2,848		—	$	233,460
Direct operating costs	(84,481		)	(41,281	)	(43,219	)	(2,547	)	—	(171,528		)
Segment profits	$	39,169		11,052		11,410		301		—	$	61,932
Depreciation and amortization	$	13,860		7,703		5,319		495		2,101	$	29,478
Capital expenditures (excluding acquisitions)	$	11,285		10,055		6,884		12		672	$	28,908
Three Months Ended September 30, 2016 (Unaudited)	(Predecessor)
Operating revenues	$	49,425		47,178		43,160		1,847		—	$	141,610
Direct operating costs	(40,292		)	(39,268	)	(35,028	)	(1,683	)	—	(116,271		)
Segment profits	$	9,133		7,910		8,132		164		—	$	25,339
Depreciation and amortization	$	18,383		15,584		13,491		3,109		2,575	$	53,142
Capital expenditures (excluding acquisitions)	$	3,178		8,244		2,622		69		182	$	14,295
Nine Months Ended September 30, 2017 (Unaudited)	(Successor)
Operating revenues	$	311,466		153,279		156,302		7,728		—	$	628,775
Direct operating costs	(232,932		)	(124,399	)	(125,931	)	(6,818	)	—	(490,080		)
Segment profits	$	78,534		28,880		30,371		910		—	$	138,695
Depreciation and amortization	$	38,013		21,127		14,589		1,357		5,760	$	80,846
Capital expenditures (excluding acquisitions)	$	69,342		26,392		20,377		30		1,920	$	118,061
Identifiable assets	$	263,407		135,338		107,511		8,643		346,246	$	861,145
Nine Months Ended September 30, 2016 (Unaudited)	(Predecessor)
Operating revenues	$	125,348		142,919		118,891		4,812		—	$	391,970
Direct operating costs	(107,941		)	(119,053	)	(101,345	)	(4,612	)	—	(332,951		)
Segment profits	$	17,407		23,866		17,546		200		—	$	59,019
Depreciation and amortization	$	56,782		48,133		41,669		9,603		7,954	$	164,141
Capital expenditures (excluding acquisitions)	$	4,689		14,422		6,076		182		2,689	$	28,058
Identifiable assets	$	308,989		216,202		200,451		43,566		233,840	$	1,003,048



	Nine Months Ended September 30, 2017
	2017				2016
	(Successor)				(Predecessor)
Revenues:
Completion and remedial services	$	311.5	50	%	$	125.3	32	%
Water logistics	$	153.3	24	%	$	142.9	36	%
Well servicing	$	156.3	25	%	$	118.9	31	%
Contract drilling	$	7.7	1	%	$	4.8	1	%
Total revenues	$	628.8	100	%	$	392.0	100	%



			Segment
	Revenues		Profits %
2016: (Predecessor)
First Quarter	$	39,696	12	%
Second Quarter	$	36,228	9	%
Third Quarter	$	49,424	18	%
Fourth Quarter	$	59,219	14	%
Full Year	$	184,567	14	%
2017: (Successor)
First Quarter	$	80,431	16	%
Second Quarter	$	107,385	24	%
Third Quarter	$	123,650	32	%



	Obligations Due in
	Periods Ended September 30,
Contractual Obligations	Total		2017		2018 to 2019		2020 to 2021		Thereafter
Term Loan Agreement	$	162,938	$	413	$	3,300	$	159,225	$	—
New ABL Facility	64,000		—		—		64,000		—
Capital leases and other financing arrangements	106,674		12,419		76,910		17,249		96
Operating leases	18,741		1,510		8,926		6,407		1,898
Asset retirement obligation	2,524		548		498		533		945
Total	$	354,877	$	14,890	$	89,634	$	247,414	$	2,939