UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_____________________________________________

Form 10-Q

_____________________________________________

(Mark One)



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

For the Quarterly Period Ended ~~June~~September 30, 2015



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

Commission file number: 001-08038

_____________________________________________

KEY ENERGY SERVICES, INC.

(Exact name of registrant as specified in its charter)

_____________________________________________



Maryland		04-2648081
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1301 McKinney Street, Suite 1800, Houston, Texas		77010
(Address of principal executive offices)		(Zip Code)

(713) 651-4300

(Registrant’s telephone number, including area code)

None

(Former name, former address and former fiscal year, if changed since last report)

____________________________________________

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No ¨

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

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

As of ~~July 27,~~October 30, 2015, the number of outstanding shares of common stock of the registrant was ~~157,583,222.~~157,570,063.

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KEY ENERGY SERVICES, INC.

QUARTERLY REPORT ON FORM 10-Q

For the Quarter Ended ~~June~~September 30, 2015



Part I — Financial Information

Item 1.	Financial Statements	3

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2829

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3940

Item 4.	Controls and Procedures	3941

Part II — Other Information

Item 1.	Legal Proceedings	4042

Item 1A.	Risk Factors	4143

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	4143

Item 3.	Defaults Upon Senior Securities	4143

Item 4.	Mine Safety Disclosures	4143

Item 5.	Other Information	4143

Item 6.	Exhibits	4143

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

In addition to statements of historical fact, this report contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Statements that are not historical in nature or that relate to future events and conditions are, or may be deemed to be, forward-looking statements. These “forward-looking statements” are based on our current expectations, estimates and projections about Key Energy Services, Inc. and its wholly owned and controlled subsidiaries, our industry and management’s beliefs and assumptions concerning future events and financial trends affecting our financial condition and results of operations. In some cases, you can identify these statements by terminology such as “may,” “will,” “should,” “predicts,” “expects,” “believes,” “anticipates,” “projects,” “potential” or “continue” or the negative of such terms and other comparable terminology. These statements are only predictions and are subject to substantial risks and uncertainties and are not guarantees of performance. Future actions, events and conditions and future results of operations may differ materially from those expressed in these statements. In evaluating those statements, you should carefully consider the information above as well as the risks outlined in “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2014 and “Part II - Item 1A. Risk Factors” in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2015.

We undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date of this report except as required by law. All of our written and oral forward-looking statements are expressly qualified by these cautionary statements and any other cautionary statements that may accompany such forward-looking statements.

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PART I — FINANCIAL INFORMATION


ITEM 1.	FINANCIAL STATEMENTS

Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(in thousands, except share amounts)


	June 30, 2015			December 31, 2014			September 30, 2015			December 31, 2014
	(unaudited)						(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	225,481		$	27,304		$	199,117		$	27,304
Accounts receivable, net of allowance for doubtful accounts of $4,973 and $2,925, respectively	181,234			289,466
Accounts receivable, net of allowance for doubtful accounts of $23,597 and $2,925, respectively							129,328			289,466
Inventories	35,143			30,171			31,949			30,171
Other current assets	79,520			86,854			80,269			86,854
Total current assets	521,378			433,795			440,663			433,795
Property and equipment	2,548,319			2,555,515			2,421,627			2,555,515
Accumulated depreciation	(1,410,785		)	(1,320,257		)	(1,415,801		)	(1,320,257		)
Property and equipment, net	1,137,534			1,235,258			1,005,826			1,235,258
Goodwill	561,039			582,739			—			582,739
Other intangible assets, net	12,917			14,500			7,034			14,500
Other non-current assets	56,910			56,471			40,501			56,471
TOTAL ASSETS	$	2,289,778		$	2,322,763		$	1,494,024		$	2,322,763
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	44,566		$	77,631		$	36,131		$	77,631
Current portion of long-term debt	3,150			—			3,150			—
Other current liabilities	110,223			164,227			99,025			164,227
Total current liabilities	157,939			241,858			138,306			241,858
Long-term debt	961,080			737,691			961,566			737,691
Workers' compensation, vehicular and health insurance liabilities	28,593			29,690			28,885			29,690
Deferred tax liabilities	178,263			228,394			40,044			228,394
Other non-current liabilities	27,005			27,067			32,542			27,067
Commitments and contingencies
Equity:
Common stock, $0.10 par value; 200,000,000 shares authorized, 157,654,235 and 153,557,108 shares issued and outstanding	15,765			15,356
Common stock, $0.10 par value; 200,000,000 shares authorized, 157,697,732 and 153,557,108 shares issued and outstanding							15,770			15,356
Additional paid-in capital	963,612			960,647			964,817			960,647
Accumulated other comprehensive loss	(36,764		)	(37,280		)	(42,030		)	(37,280		)
Retained earnings (deficit)	(5,715		)	119,340			(645,876		)	119,340
Total equity	936,898			1,058,063			292,681			1,058,063
TOTAL LIABILITIES AND EQUITY	$	2,289,778		$	2,322,763		$	1,494,024		$	2,322,763

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

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Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(in thousands, except per share data)

(unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
REVENUES	$	197,496		$	350,595		$	465,295		$	706,736		$	176,857		$	365,798		$	642,152		$	1,072,534
COSTS AND EXPENSES:
Direct operating expenses	158,841			262,883			363,371			521,185			174,505			272,112			537,876			793,297
Depreciation and amortization expense	45,896			52,184			93,107			103,279			45,270			50,924			138,377			154,203
General and administrative expenses	50,710			57,881			118,354			110,747			45,314			65,224			163,668			175,971
Impairment expense	21,352			28,687			43,052			28,687			649,944			60,792			692,996			89,479
Operating loss	(79,303		)	(51,040		)	(152,589		)	(57,162		)	(738,176		)	(83,254		)	(890,765		)	(140,416		)
Interest expense, net of amounts capitalized	17,058			13,426			30,400			26,980			21,704			13,417			52,104			40,397
Other (income) loss, net	(248		)	(2,733		)	4,184			(2,802		)	5,915			348			10,099			(2,454		)
Loss before income taxes	(96,113		)	(61,733		)	(187,173		)	(81,340		)	(765,795		)	(97,019		)	(952,968		)	(178,359		)
Income tax benefit	30,734			9,537			62,118			17,245			125,634			34,790			187,752			52,035
NET LOSS	$	(65,379	)	$	(52,196	)	$	(125,055	)	$	(64,095	)	$	(640,161	)	$	(62,229	)	$	(765,216	)	$	(126,324	)
Loss per share:
Basic and diluted	$	(0.42	)	$	(0.34	)	$	(0.80	)	$	(0.42	)	$	(4.06	)	$	(0.41	)	$	(4.90	)	$	(0.82	)
Weighted average shares outstanding:
Basic and diluted	156,347			153,496			155,586			153,157			157,605			153,550			156,266			153,327

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

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Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income

(in thousands)

(unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
NET LOSS	$	(65,379	)	$	(52,196	)	$	(125,055	)	$	(64,095	)	$	(640,161	)	$	(62,229	)	$	(765,216	)	$	(126,324	)
Other comprehensive income (loss):
Foreign currency translation income (loss)	1,213			3,264			516			(2,001		)
Other comprehensive loss:
Foreign currency translation loss													(5,266		)	(7,010		)	(4,750		)	(9,011		)
COMPREHENSIVE LOSS	$	(64,166	)	$	(48,932	)	$	(124,539	)	$	(66,096	)	$	(645,427	)	$	(69,239	)	$	(769,966	)	$	(135,335	)

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

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Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(in thousands)

(unaudited)


	Six Months Ended						Nine Months Ended
	June 30,						September 30,
	2015			2014			2015			2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(125,055	)	$	(64,095	)	$	(765,216	)	$	(126,324	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization expense	93,107			103,279			138,377			154,203
Impairment expense	43,052			28,687			692,996			89,479
Bad debt expense	1,362			1,151			1,832			1,484
Accretion of asset retirement obligations	309			294			468			447
Loss (income) from equity method investments	(13		)	79			(6		)	221
Amortization and write-off of deferred financing costs and premium	2,061			1,121			3,335			1,682
Deferred income tax benefit	(12,546		)	(7,707		)	(126,752		)	(30,066		)
Loss on disposal of assets, net	4,374			3,452			5,713			3,760
Share-based compensation	6,636			7,101			8,198			9,277
Excess tax expense from share-based compensation	2,950			1,221			3,301			1,240
Changes in working capital:
Accounts receivable	106,829			46,970			157,815			51,585
Other current assets	6,602			(2,419		)	5,643			(3,410		)
Accounts payable, accrued interest and accrued expenses	(88,277		)	(13,781		)	(107,576		)	(12,050		)
Share-based compensation liability awards	1,119			1,587			(55		)	(578		)
Other assets and liabilities	(43,708		)	328			(38,911		)	(14,866		)
Net cash provided by (used in) operating activities	(1,198		)	107,268			(20,838		)	126,084
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(32,675		)	(69,429		)	(38,907		)	(108,120		)
Proceeds from sale of fixed assets	9,950			7,239			11,500			12,288
Proceeds from notes receivable	595			2,150			595			3,990
Net cash used in investing activities	(22,130		)	(60,040		)	(26,812		)	(91,842		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments of long-term debt	—			(3,573		)	(788		)	(3,573		)
Proceeds from long-term debt	305,550			—			305,550			—
Proceeds from borrowings on revolving credit facility	130,000			115,000			130,000			220,000
Repayments on revolving credit facility	(200,000		)	(160,000		)	(200,000		)	(225,000		)
Payment of deferred financing costs	(11,072		)	—			(11,072		)	—
Repurchases of common stock	(312		)	(2,211		)	(313		)	(2,239		)
Excess tax expense from share-based compensation	(2,950		)	(1,221		)	(3,301		)	(1,240		)
Net cash provided by (used in) financing activities	221,216			(52,005		)	220,076			(12,052		)
Effect of changes in exchange rates on cash	289			(81		)	(613		)	6,896
Net increase (decrease) in cash and cash equivalents	198,177			(4,858		)
Net increase in cash and cash equivalents							171,813			29,086
Cash and cash equivalents, beginning of period	27,304			28,306			27,304			28,306
Cash and cash equivalents, end of period	$	225,481		$	23,448		$	199,117		$	57,392

See the accompanying notes which are an integral part of these condensed consolidated financial statements.

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Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS

NOTE 1. GENERAL

Key Energy Services, Inc., and its wholly owned subsidiaries (collectively, “Key,” the “Company,” “we,” “us,” “its,” and “our”) provide a full range of well services to major oil companies, foreign national oil companies and independent oil and natural gas production companies. Our services include rig-based and coiled tubing-based well maintenance and workover services, well completion and recompletion services, fluid management services, fishing and rental services, and other ancillary oilfield services. Additionally, certain of our rigs are capable of specialty drilling applications. We operate in most major oil and natural gas producing regions of the continental United States and have operations in Mexico, Colombia, Ecuador, the Middle East and Russia. In addition, we have a technology development and control systems business based in Canada.

The accompanying unaudited condensed consolidated financial statements were prepared using generally accepted accounting principles in the United States of America (“GAAP”) for interim financial information and in accordance with the rules and regulations of the Securities and Exchange Commission (the “SEC”). The condensed December 31, 2014 balance sheet was prepared from audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2014 (the “2014 Form 10-K”). Certain information relating to our organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in this Quarterly Report on Form 10-Q. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our 2014 Form 10-K.

The unaudited condensed consolidated financial statements contained in this report include all normal and recurring material adjustments that, in the opinion of management, are necessary for a fair presentation of our financial position, results of operations and cash flows for the interim periods presented herein. The results of operations for the ~~six~~nine months ended ~~June~~September 30, 2015 are not necessarily indicative of the results expected for the full year or any other interim period, due to fluctuations in demand for our services, timing of maintenance and other expenditures, and other factors.

We have evaluated events occurring after the balance sheet date included in this Quarterly Report on Form 10-Q and through the date on which the unaudited condensed consolidated financial statements were issued, for possible disclosure of a subsequent event.

NOTE 2. SIGNIFICANT ACCOUNTING POLICIES AND ESTIMATES

The preparation of these unaudited condensed consolidated financial statements requires us to develop estimates and to make assumptions that affect our financial position, results of operations and cash flows. These estimates may also impact the nature and extent of our disclosure, if any, of our contingent liabilities. Among other things, we use estimates to (i) analyze assets for possible impairment, (ii) determine depreciable lives for our assets, (iii) assess future tax exposure and realization of deferred tax assets, (iv) determine amounts to accrue for contingencies, (v) value tangible and intangible assets, (vi) assess workers’ compensation, vehicular liability, self-insured risk accruals and other insurance reserves, (vii) provide allowances for our uncollectible accounts receivable, (viii) value our asset retirement obligations, and (ix) value our equity-based compensation. We review all significant estimates on a recurring basis and record the effect of any necessary adjustments prior to publication of our financial statements. Adjustments made with respect to the use of estimates relate to improved information not previously available. Because of the limitations inherent in this process, our actual results may differ materially from these estimates. We believe that the estimates used in the preparation of these interim financial statements are reasonable.

There have been no material changes or developments in our evaluation of accounting estimates and underlying assumptions or methodologies that we believe to be a “Critical Accounting Policy or Estimate” as disclosed in our 2014 Form 10-K.

Recent Accounting Developments

ASU 2015-03. In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The objective of this ASU is to simplify presentation of debt issuance costs by requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this update. The ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those annual periods, with early adoption permitted. We adopted ASU 2015-03 in the second quarter of 2015 using the retrospective transition method. As a result, $10.7 million of unamortized deferred financing costs on our December 31, 2014 balance sheet was reclassified from non-current assets to a direct deduction of long-term debt. The adoption of this standard did not affect our results of operations or cash flows.

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ASU 2014-09. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). The objective of this ASU is to establish the principles to report useful information to users of financial statements about the nature, amount, timing, and uncertainty of revenue from contracts with customers. The core principle is to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 must be adopted using either a full retrospective method or a modified retrospective method. During a July 2015 meeting, the FASB affirmed a proposal to defer the effective date of the new revenue standard for all entities by one year. As a result, ASU 2014-09 is effective for the Company for interim and annual reporting periods beginning after December 15, 2017 with early adoption permitted for interim and annual reporting periods beginning after December 15, 2016. We are currently evaluating the standard to determine the impact of its adoption on the consolidated financial statements.

NOTE 3. ASSETS HELD FOR SALE

In April 2015, we announced our decision to exit markets in which we participate outside of North America. Our strategy is to sell or relocate the assets of the businesses operating in these markets. During the second quarter of 2015, certain assets of our Oman business unit, which is included in our International reporting segment, met the criteria for assets held for sale. We expect the sale of these assets to occur before the end of 2015. We recorded a $21.4 million impairment of fixed assets to reduce the carrying value of these assets to the fair market value. ~~The~~

In the third quarter of 2015, we transferred four rigs from Ecuador to the U.S. and sold the remaining operating assets of our Ecuadorian business unit at auction and recorded an impairment of $4.1 million to reduce the carrying of those assets to the price at which they were sold.

Additionally, during the third quarter of 2015, the assets and related liabilities of our Bahrain business unit and certain assets of our Colombian business unit, which are included in our International reporting segment, and our Enhanced Oilfield Technology business unit, which is included in our Fishing and Rental reporting segment, met the criteria for assets held for sale. In Bahrain, we are negotiating to sell our subsidiary for $4.9 million. We expect this sale ~~includes $3.6 million~~to be complete before the end of 2015. In Colombia, we relocated one rig to the U.S. in the third quarter of 2015 and plan to sell or relocate thirteen rigs to the U.S. in the fourth quarter. We plan to sell the remaining property and equipment, net, and ~~$0.6~~inventories of our Colombian business unit in the fourth quarter of 2015. We are also planning to sell certain assets of our Enhanced Oilfield Technology business unit and expect this sale to be complete before the end of 2015. We recorded an impairment of $7.0 million, $25.3 million and $6.0 million for our Bahraini, Colombian and Enhanced Oilfield Technology business units, respectively, to reduce the carrying value of ~~inventories which are included in other non-current~~these assets and ~~other current~~related liabilities to the fair market value.

The following assets ~~respectively,~~and related liabilities are classified as held for sale on our ~~June~~September 30, 2015 condensed consolidated balance sheet.



	Bahrain		Oman		Colombia		Enhanced Oilfield Technology		Total
	(in thousands)
Current assets:
Cash and cash equivalents	$	1,576	$	—	$	—	$	—	$	1,576
Accounts receivable	385		—		—		—		385
Inventories	—		591		83		1,791		2,465
Other current assets	660		—		—		—		660
Total current assets	2,621		591		83		1,791		5,086
Property and equipment, net	2,421		3,631		4,014		1,209		11,275
Other non-current assets	137		—		—		—		137
Total assets	$	5,179	$	4,222	$	4,097	$	3,000	$	16,498
Current liabilities:			—		—		—		—
Accounts payable	149		—		—		—		149
Other current liabilities	46		—		—		—		46
Total current liabilities	195		—		—		—		195
Other non-current liabilities	84		—		—		—		84
Net Assets	$	4,900	$	4,222	$	4,097	$	3,000	$	16,219

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NOTE 4. EQUITY

A reconciliation of the total carrying amount of our equity accounts for the ~~six~~nine months ended ~~June~~September 30, 2015 is as follows:


	COMMON STOCKHOLDERS																				COMMON STOCKHOLDERS
	Common Stock					Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings (Deficit)				Total			Common Stock						Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings (Deficit)				Total
	Number of Shares		Amount at Par							Accumulated Other Comprehensive Loss			Number of Shares					Total			Amount at Par						Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings (Deficit)				Total
	(in thousands)																				(in thousands)
Balance at December 31, 2014	153,557		$	15,356		Additional Paid-in Capital		$	960,647			$	(37,280	Retained Earnings (Deficit)	)		$	119,340			$	1,058,063	153,557			$	15,356			$	960,647			$	(37,280	)		$	119,340			$	1,058,063
Foreign currency translation	—		—			—				516				—				516			—		—				—				(4,750		)		—				(4,750		)
Common stock purchases	(145	)	(15		)	(297		)		—				—				(312		)	(147	)	(15		)		(298		)		—				—				(313		)
Share-based compensation	4,242		424			6,212				—				—				6,636			4,288		429				7,769				—				—				8,198
Tax expense from share-based compensation	—		—			(2,950		)		—				—				(2,950		)	—		—				(3,301		)		—				—				(3,301		)
Net loss	—		—			—				—				(125,055		)		(125,055		)	—		—				—				—				(765,216		)		(765,216		)
Balance at June 30, 2015	157,654		$	15,765		$	963,612			$	(36,764	)		$	(5,715	)		$	936,898
Balance at September 30, 2015																					157,698		$	15,770			$	964,817			$	(42,030	)		$	(645,876	)		$	292,681

A reconciliation of the total carrying amount of our equity accounts for ~~six~~nine months ended ~~June~~September 30, 2014 is as follows:


	COMMON STOCKHOLDERS																				COMMON STOCKHOLDERS
	Common Stock					Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings				Total			Common Stock						Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings				Total
	Number of Shares		Amount at Par							Accumulated Other Comprehensive Loss			Number of Shares					Total			Amount at Par						Additional Paid-in Capital				Accumulated Other Comprehensive Loss				Retained Earnings				Total
	(in thousands)																				(in thousands)
Balance at December 31, 2013	152,331		$	15,233		Additional Paid-in Capital		$	953,306			$	(15,414	Retained Earnings	)		$	297,968			$	1,251,093	152,331			$	15,233			$	953,306			$	(15,414	)		$	297,968			$	1,251,093
Foreign currency translation	—		—			—				(2,001		)		—				(2,001		)	—		—				—				(9,011		)		—				(9,011		)
Common stock purchases	(283	)	(28		)	(2,183		)		—				—				(2,211		)	(288	)	(29		)		(2,210		)		—				—				(2,239		)
Share-based compensation	1,537		154			6,947				—				—				7,101			1,516		152				9,125				—				—				9,277
Tax expense from share-based compensation	—		—			(1,221		)		—				—				(1,221		)	—		—				(1,240		)		—				—				(1,240		)
Net loss	—		—			—				—				(64,095		)		(64,095		)	—		—				—				—				(126,324		)		(126,324		)
Balance at June 30, 2014	153,585		$	15,359		$	956,849			$	(17,415	)		$	233,873			$	1,188,666
Balance at September 30, 2014																					153,559		$	15,356			$	958,981			$	(24,425	)		$	171,644			$	1,121,556

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NOTE 5. OTHER BALANCE SHEET INFORMATION

The table below presents comparative detailed information about other current assets at ~~June~~September 30, 2015 and December 31, 2014:

June 30, 2015 December 31, 2014
(in thousands)
Other current assets:
Deferred tax assets $ 14,688
$ 11,823
Prepaid current assets 21,770
28,218
Reinsurance receivable 9,131
9,200
VAT asset 17,452
18,889
Current assets held for sale 591
—
Other 15,888
18,724
Total $ 79,520
$ 86,854

~~The table below presents comparative detailed information about other non-current assets at~~ ~~June 30, 2015~~ ~~and~~ ~~December 31, 2014~~:

June 30, 2015 December 31, 2014
(in thousands)
Other non-current assets:
Deferred tax assets $ 32,875
$ 35,238
Reinsurance receivable 9,561
9,537
Deposits 9,457
10,125
Equity method investments 1,000
987
Non-current assets held for sale 3,631
—
Other 386
584
Total $ 56,910
$ 56,471

~~The table below presents comparative detailed information about other current liabilities at~~ ~~June 30, 2015~~ ~~and~~ ~~December 31, 2014~~:

June 30, 2015 December 31, 2014
(in thousands)
Other current liabilities:
Accrued payroll, taxes and employee benefits $ 19,394
$ 32,477
Accrued operating expenditures 18,858
45,899
Income, sales, use and other taxes 17,546
25,892
Self-insurance reserve 30,448
31,359
Accrued interest 17,869
15,241
Accrued insurance premiums 1,189
7,515
Share-based compensation and other liabilities 4,919
5,844
Total $ 110,223
$ 164,227



	September 30, 2015		December 31, 2014
	(in thousands)
Other current assets:
Deferred tax assets	$	10,142	$	11,823
Prepaid current assets	19,460		28,218
Reinsurance receivable	8,941		9,200
VAT asset	14,997		18,889
Current assets held for sale	5,086		—
Other	21,643		18,724
Total	$	80,269	$	86,854

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The table below presents comparative detailed information about other non-current ~~liabilities~~assets at ~~June~~September 30, 2015 and December 31, 2014:

June 30, 2015 December 31, 2014
(in thousands)
Other non-current liabilities:
Asset retirement obligations $ 12,608
$ 12,525
Environmental liabilities 5,531
5,730
Accrued rent —
263
Accrued sales, use and other taxes 6,145
5,411
Other 2,721
3,138
Total $ 27,005
$ 27,067



	September 30, 2015		December 31, 2014
	(in thousands)
Other non-current assets:
Deferred tax assets	$	11,279	$	35,238
Reinsurance receivable	9,375		9,537
Deposits	7,352		10,125
Equity method investments	993		987
Non-current assets held for sale	11,412		—
Other	90		584
Total	$	40,501	$	56,471

The table below presents comparative detailed information about other current liabilities at September 30, 2015 and December 31, 2014:



	September 30, 2015		December 31, 2014
	(in thousands)
Other current liabilities:
Accrued payroll, taxes and employee benefits	$	28,115	$	32,477
Accrued operating expenditures	13,736		45,899
Income, sales, use and other taxes	7,240		25,892
Self-insurance reserve	30,425		31,359
Accrued interest	12,315		15,241
Accrued insurance premiums	315		7,515
Current liabilities held for sale	195		—
Share-based compensation and other liabilities	6,684		5,844
Total	$	99,025	$	164,227

The table below presents comparative detailed information about other non-current liabilities at September 30, 2015 and December 31, 2014:



	September 30, 2015		December 31, 2014
	(in thousands)
Other non-current liabilities:
Asset retirement obligations	$	12,711	$	12,525
Environmental liabilities	5,425		5,730
Accrued rent	—		263
Accrued sales, use and other taxes	11,751		5,411
Non-current liabilities held for sale	84		—
Other	2,571		3,138
Total	$	32,542	$	27,067

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NOTE 6. GOODWILL AND OTHER INTANGIBLE ASSETS

The changes in the carrying amount of goodwill for the ~~six~~nine months ended ~~June~~September 30, 2015 are as follows:


	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services		International		Total			U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Total
	(in thousands)														(in thousands)
December 31, 2014	$	297,719	$	24,479	$	82,695		$	173,463	$	4,383	$	582,739		$	297,719		$	24,479		$	82,695		$	173,463		$	4,383		$	582,739
Goodwill impairment	—		—		(21,700		)	—		—		(21,700		)	(297,719		)	(24,479		)	(82,695		)	(173,463		)	(4,383		)	(582,739		)
June 30, 2015	$	297,719	$	24,479	$	60,995		$	173,463	$	4,383	$	561,039
September 30, 2015															$	—		$	—		$	—		$	—		$	—		$	—

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The components of our other intangible assets as of ~~June~~September 30, 2015 and December 31, 2014 are as follows:


	June 30, 2015			December 31, 2014			September 30, 2015			December 31, 2014
	(in thousands)						(in thousands)
Noncompete agreements:
Gross carrying value	$	2,269		$	2,269		$	2,269		$	2,269
Accumulated amortization	(1,860		)	(1,710		)	(1,935		)	(1,710		)
Net carrying value	409			559			334			559
Patents, trademarks and tradenames:
Gross carrying value	3,129			3,106			1,435			3,106
Accumulated amortization	(283		)	(263		)	(293		)	(263		)
Net carrying value	2,846			2,843			1,142			2,843
Customer relationships and contracts:
Gross carrying value	59,079			59,045			58,797			59,045
Accumulated amortization	(53,571		)	(52,303		)	(53,923		)	(52,303		)
Net carrying value	5,508			6,742			4,874			6,742
Developed technology:
Gross carrying value	8,494			8,494			4,074			8,494
Accumulated amortization	(4,340		)	(4,138		)	(3,390		)	(4,138		)
Net carrying value	4,154			4,356			684			4,356
Customer backlog:
Gross carrying value	779			779			779			779
Accumulated amortization	(779		)	(779		)	(779		)	(779		)
Net carrying value	—			—			—			—
Total:
Gross carrying value	73,750			73,693			67,354			73,693
Accumulated amortization	(60,833		)	(59,193		)	(60,320		)	(59,193		)
Net carrying value	$	12,917		$	14,500		$	7,034		$	14,500

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Of our intangible assets at ~~June~~September 30, 2015, ~~$2.7~~$1.0 million are indefinite-lived tradenames ~~and patents~~ which are not subject to amortization. The weighted average remaining amortization periods and expected amortization expense for the next five years for our definite lived intangible assets are as follows:


	Weighted average remaining amortization period (years)	Expected Amortization Expense												Weighted average remaining amortization period (years)	Expected Amortization Expense
	Weighted average remaining amortization period (years)	Remainder of 2015		2016		2017		2018		2019		2020		Weighted average remaining amortization period (years)	Remainder of 2015		2016		2017		2018		2019		2020
		(in thousands)													(in thousands)
Noncompete agreements	1.3	$	149	$	260	$	—	$	—	$	—	$	—	1.1	$	74	$	260	$	—	$	—	$	—	$	—
Trademarks	2.9	20		40		40		17		—		—		2.7	10		40		40		17		—		—
Customer relationships and contracts	3.6	1,237		1,876		1,392		431		341		231		3.4	617		1,869		1,387		431		341		229
Developed technology	15.5	199		398		398		398		324		221		3.7	45		179		179		179		102		—
Total expected intangible asset amortization expense		$	1,605	$	2,574	$	1,830	$	846	$	665	$	452		$	746	$	2,348	$	1,606	$	627	$	443	$	229

Certain of our other intangible assets are denominated in Russian Rubles and, as such, the values of these assets are subject to fluctuations associated with changes in exchange rates. Amortization expense for our intangible assets was $0.8 million and $2.6 million for the three months ended ~~June~~September 30, 2015 and 2014, respectively, and ~~$1.6~~$2.4 million and $~~5.2~~7.8 million for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, respectively.

As a result of the planned sale of certain of our Enhanced Oilfield Technology business units assets, we will no longer be using a certain developed technology patent. As a result, we fully impaired the $3.4 million patent. In addition, we will no longer use our Edge tradename. As a result, we fully impaired the $1.5 million tradename. Both the Edge tradename and Enhanced Oilfield Technology developed technology patent were part of our Fishing and Rental Services segment.

We perform an analysis of goodwill impairment on an annual basis unless an event occurs that triggers additional interim testing. The decline in market value of our stock during the fourth quarter of 2014 was determined to be a triggering

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event making it necessary to perform the first step of the goodwill impairment test for our U.S. Rig Services, Coiled Tubing Services, Fishing and Rental Services, ~~and~~ Fluid Management Services and International segments. Based on the results of our step one analysis, the fair value of our U.S. Rig Services, Fluid Management Services and Fishing and Rental Services segments exceeded their carrying values, but the analysis indicated potential impairment in our Coiled Tubing Services segment. Step two of the goodwill impairment testing for the Coiled Tubing Services segment was performed preliminarily during the fourth quarter of 2014 and our analysis concluded that $19.1 million of goodwill was impaired. During the first quarter of 2015, we engaged outside consultants to assist us in finalizing our step two testing. Based on the additional analysis performed, we concluded that there was an additional $21.7 million of goodwill that was impaired.

The additional decline in market value of our stock during the third quarter of 2015 as well as the persistent low oil prices and the affect that low oil prices have on our industry were also determined to be triggering events making it necessary to perform testing for possible goodwill impairment for our U.S. Rig Services, Coiled Tubing Services, Fishing and Rental Services, Fluid Management Services and International segments. Our analysis concluded that the remaining $561.0 million of goodwill of these segments was fully impaired. Also, during our goodwill analysis, there was an indication of impairment of fixed assets in our Coiled Tubing Services segment. See “Note 7. Impairment of Fixed Assets” for further discussion.

NOTE 7. IMPAIRMENT OF FIXED ASSETS

The decline in market value of our common stock in comparison to the carrying value of our assets during the third quarter of 2015 as well as the persistent low oil prices and the affect that low oil prices have on our industry were determined to be goodwill testing triggering events. These triggering events required us to perform step one of the goodwill impairment test to identify potential impairment. Our step one testing indicated potential impairment in our Coiled Tubing Services segment which required us to perform step two of the goodwill impairment test to determine the amount of impairment, if any. Our preliminary step two testing performed during the third quarter of 2015, using a discounted cash flow model to determine fair value, concluded that certain fixed assets were impaired. As a result, we recorded an estimated pre-tax charge of $45.0 million in the third quarter of 2015. During the fourth quarter of 2015, we will engage with outside consultants to assist us in finalizing the analysis needed to complete our step two testing and any adjustment to the amount recorded, which may be material, will be recorded at that time.

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NOTE 8. LONG-TERM DEBT

As of ~~June~~September 30, 2015 and December 31, 2014, the components of our long-term debt were as follows:


	June 30, 2015			December 31, 2014			September 30, 2015			December 31, 2014
	(in thousands)						(in thousands)
6.75% Senior Notes due 2021	$	675,000		$	675,000		$	675,000		$	675,000
Term Loan Facility due 2020	315,000			—			314,212			—
Senior Secured Credit Facility revolving loans due 2016	—			70,000			—			70,000
Debt issuance costs and unamortized premium (discount) on debt, net	(25,770		)	(7,309		)	(24,496		)	(7,309		)
Total	964,230			737,691			964,716			737,691
Less current portion	(3,150		)	—			(3,150		)	—
Long-term debt	$	961,080		$	737,691		$	961,566		$	737,691

6.75% Senior Notes due 2021

We have outstanding $675.0 million of 6.75% Senior Notes due 2021 (the “2021 Notes”). The 2021 Notes are general unsecured senior obligations and are effectively subordinated to all of our existing and future secured indebtedness. The 2021 Notes are or will be jointly and severally guaranteed on a senior unsecured basis by certain of our existing and future domestic subsidiaries. Interest on the 2021 Notes is payable on March 1 and September 1 of each year. The 2021 Notes mature on March 1, 2021.

On or after March 1, 2016, the 2021 Notes will be subject to redemption at any time and from time to time at our option, in whole or in part, at the redemption prices below (expressed as percentages of the principal amount redeemed), plus accrued and unpaid interest to the applicable redemption date, if redeemed during the twelve-month period beginning on March 1 of the years indicated below:



Year	Percentage
2016	103.375	%
2017	102.250	%
2018	101.125	%
2019 and thereafter	100.000	%

At any time and from time to time prior to March 1, 2016, we may, at our option, redeem all or a portion of the 2021 Notes at a redemption price equal to 100% of the principal amount plus a premium with respect to the 2021 Notes plus accrued and unpaid interest to the redemption date. The premium is the excess of (i) the present value of the redemption price of 103.375% of the principal amount, plus all remaining scheduled interest payments due through March 1, 2016 discounted at the treasury rate plus 0.5% over (ii) the principal amount of the note. If we experience a change of control, subject to certain exceptions, we must give holders of the 2021 Notes the opportunity to sell to us their 2021 Notes, in whole or in part, at a purchase price equal to 101% of the aggregate principal amount, plus accrued and unpaid interest to the date of purchase.

We are subject to certain negative covenants under the Indenture. The Indenture limits our ability to, among other things:

incur additional indebtedness and issue preferred equity interests;

pay dividends or make other distributions or repurchase or redeem equity interests;

make loans and investments;

enter into sale and leaseback transactions;

sell, transfer or otherwise convey assets;

create liens;

enter into transactions with affiliates;

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enter into agreements restricting subsidiaries’ ability to pay dividends;

designate future subsidiaries as unrestricted subsidiaries; and

consolidate, merge or sell all or substantially all of the applicable entities’ assets.

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apply to us as a result of achieving an investment grade rating will not be restored, even if the investment rating assigned to the 2021 Notes later falls below investment grade. We were in compliance with these covenants as of ~~June~~September 30, 2015.

Credit Facilities due 2020

On June 1, 2015, we entered into a $100.0 million asset-based revolving credit facility (“ABL Facility”) due February 28, 2020 and a $315.0 million term loan facility (“Term Loan Facility”) due June 1, 2020 (together, the “Facilities”). The Facilities replaced our existing $400 million 2011 Credit Facility (defined below).

The ABL Facility bears interest at an annual rate on outstanding borrowings of LIBOR plus 4.5%, with a fee on unused commitments ranging from 1.00% to 1.25% based on utilization. The Term Loan Facility was issued at an original issue discount of 3.0% with an annual rate of LIBOR plus 9.25% with a 1.00% LIBOR floor and a quarterly principal payment of $787,500 that will begin in the third quarter of 2015. The original issue discount of $9.4 million and $11.1 million of deferred financing costs will be amortized over the term of the Facilities.

The Facilities contain customary representations and warranties and certain affirmative and negative covenants, including covenants that restrict our ability to take certain actions without the permission of the Facilities lenders or as permitted under the Facilities including the incurrence of debt, the granting of liens, the making of investments, the payment of dividends and the sale of assets. The Facilities also contain financial covenants requiring that we maintain an asset coverage ratio of at least 1.5 to 1.0 and that liquidity, as defined in the Facilities agreements, must not be less than $100.0 million. The ABL also includes a fixed charge coverage ratio of at least 1.0 to 1.0, which is tested only if excess availability under the ABL falls below a specified threshold or upon the occurrence of certain other events. Additionally, in certain situations, we may be required to offer to prepay some principal amounts under the Term Loan Facility including 50% of our fiscal excess cash flow, as defined in the Term Loan Facility agreement. In the event of a change in control, as defined in the Term Loan Facility agreement, the Company must offer to prepay all term loans (i) at a price of 101% of the amount outstanding if, after giving effect to such change of control, the asset coverage ratio is at least 1.5 to 1.0 or (ii) at a price equal to the greater of 101% of the amount outstanding and the applicable prepayment premium provided for in the Term Loan Facility if, after giving effect to such change of control, the asset coverage ratio is less than 1.5 to 1.0.

We were in compliance with covenants of the Facilities as of ~~June~~September 30, 2015. As of ~~June~~September 30, 2015, we have no borrowings outstanding under the ABL Facility and $48.2 million of letters of credit outstanding with borrowing capacity of ~~$44.4~~$30.5 million available subject to covenant constraints under our ABL Facility.

The weighted average interest rates on the outstanding borrowings under the ABL Facility and Term Loan Facility for the three and ~~six~~nine month periods ended ~~June~~September 30, 2015 were as follows:



	~~June 30, 2015~~
	~~(in thousands)~~
~~ABL Facility~~	—
~~Term Loan Facility~~	~~10.38~~	%



	Three Months Ended		Nine Months Ended
	September 30, 2015		September 30, 2015
	(in thousands)
ABL Facility	—	%	—	%
Term Loan Facility	10.25	%	10.28	%

Senior Secured Credit Facility

On June 1, 2015, in connection with entering into the ABL Facility and the Term Loan Facility, we terminated our senior secured revolving bank credit facility, dated as of March 31, 2011, as amended through December 5, 2014 (the “2011 Credit Facility”), which was scheduled to mature no later than March 31, 2016. The 2011 Credit Facility provided for a senior secured credit facility consisting of a revolving credit facility, letter of credit sub-facility and swing line facility of up to an aggregate principal amount of $400.0 million. The 2011 Credit Facility was terminated without any prepayment penalties. The remaining unamortized deferred financing costs of $0.8 million were written off at the time of the termination.

The interest rate per annum applicable to the 2011 Credit Facility was, at our option, (i) adjusted LIBOR plus the applicable margin or (ii) the higher of (x) JPMorgan’s prime rate, (y) the Federal Funds rate plus 0.5% and (z) one-month adjusted LIBOR plus 1.0%, plus in each case the applicable margin for all other loans. The applicable margin for LIBOR loans had ranged from 225 to 300 basis points, and the applicable margin for all other loans had ranged from 125 to 200 basis points, depending upon our consolidated total leverage ratio as defined in the 2011 Credit Facility. Unused commitment fees on the facility was equal to 0.5%. The weighted average interest rates on the outstanding borrowings under the 2011 Credit Facility were ~~3.14%~~zero and ~~2.88%~~3.01% for the three-month periods ended ~~June~~September 30, 2015 and ~~June~~September 30, 2014, respectively, and the weighted average interest rates on the outstanding borrowings under the 2011 Credit Facility were ~~3.15%~~3.14% and ~~2.88%~~2.92% for ~~six~~the nine months ended ~~June~~September 30, 2015 and ~~June~~September 30, 2014, respectively.

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Letter of Credit Facility

On November 7, 2013, we entered into an uncommitted, unsecured $15.0 million letter of credit facility to be used solely for the issuances of performance letters of credit. As of ~~June~~September 30, 2015, $2.0 million of letters of credit were outstanding under the facility.

NOTE 8.9. OTHER (INCOME) LOSS

The table below presents comparative detailed information about our other income and expense, shown on the condensed consolidated statements of operations as “other (income) loss, net” for the periods indicated:


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
	(in thousands)												(in thousands)
Interest income	$	(25	)	$	(30	)	$	(40	)	$	(48	)	$	(61	)	$	(12	)	$	(99	)	$	(60	)
Foreign exchange (gain) loss	333			(1,377		)	1,593			(11		)
Foreign exchange loss													2,472			1,118			4,065			1,107
Allowance for collectibility of notes receivable	—			—			3,950			—			3,755			—			7,705			—
Other, net	(556		)	(1,326		)	(1,319		)	(2,743		)	(251		)	(758		)	(1,572		)	(3,501		)
Total	$	(248	)	$	(2,733	)	$	4,184		$	(2,802	)	$	5,915		$	348		$	10,099		$	(2,454	)

NOTE 9.10. INCOME TAXES

We are subject to U.S. federal income tax as well as income taxes in multiple state and foreign jurisdictions. Our effective tax rates for the three months ended~~June 30, 2015~~ ~~and~~ ~~2014~~ ~~were 32.0% and 15.4%, respectively, and 33.2% and 21.2% for the six months ended June~~ September 30, 2015 and 2014 were 16.4% and 35.9%, respectively, and 19.7% and 29.2% for the nine months ended September 30, 2015 and 2014, respectively. Excluding the impact of non-deductible goodwill impairment expense and valuation allowances recorded against deferred tax assets in the third quarter, our effective tax rates for the three and nine month periods ended September 30, 2015, were 31.7% and 32.1%, respectively. Our effective tax rate varies due to the mix of pre-tax profit between the U.S. and international taxing jurisdictions with varying statutory rates, the impact of permanent differences, including goodwill impairment expense, and discrete tax adjustments, such as valuation allowances against deferred tax assets and tax expense or benefit recognized for uncertain tax positions. The variance between our effective rate and the U.S. statutory rate reflects international profits and losses subject to varying statutory rates, the impact of permanent items, ~~mainly non-deductible expenses such as fines and penalties,~~including goodwill impairment expense and expenses subject to statutorily imposed limitations such as meals and entertainment expenses, plus the impact of state income ~~taxes.~~taxes and discrete tax adjustments, such as valuation allowances against deferred tax assets and tax expense or benefit recognized for uncertain tax positions.

The Company assesses the realizability of its deferred tax assets each period by considering whether it is more likely than not that all or a portion of the deferred tax assets will not be realized. In the third quarter we concluded that it is more likely than not that all or a portion of the deferred tax assets related to the net operating loss carryforwards of certain of our international businesses will not be realized. As a result, we recorded a valuation allowance in the amount of $23.0 million against the net deferred tax asset as of September 30, 2015.

As of ~~June~~September 30, 2015 and December 31, 2014, we had $1.0 million of unrecognized tax benefits, net of federal tax benefit, which, if recognized, would impact our effective tax rate. We recognized a tax expense of less than $0.1 million for the three months ended ~~June~~September 30, 2015 and 2014, related to these items. We have substantially concluded all U.S. federal and state tax matters through the year ended December 31, 2012.

We record interest and penalties related to unrecognized tax benefits as income tax expense. We have accrued a liability of ~~$1.0~~$0.1 million for the payment of interest and penalties as of ~~June~~September 30, 2015 and December 31, 2014. We believe that it is reasonably possible that $0.6 million of our currently remaining unrecognized tax positions, each of which is individually insignificant, may be recognized in the next twelve months as a result of a lapse of statute of limitations and settlement of ongoing audits. No release of our deferred tax asset valuation allowance was made during the three or ~~six~~nine months ended ~~June~~September 30, 2015 and 2014.

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NOTE ~~10.~~11. COMMITMENTS AND CONTINGENCIES

Litigation

Various suits and claims arising in the ordinary course of business are pending against us. We conduct business throughout the continental United States and may be subject to jury verdicts or arbitrations that result in outcomes in favor of the plaintiffs. We are also exposed to various claims abroad. We continually assess our contingent liabilities, including potential litigation liabilities, as well as the adequacy of our accruals and our need for the disclosure of these items, if any. We establish a provision for a contingent liability when it is probable that a liability has been incurred and the amount is reasonably estimable. We have ~~$0.2~~$1.5 million of other liabilities related to litigation that is deemed probable and reasonably estimable as of ~~June~~September 30, 2015. We do not believe that the disposition of any of these matters will result in an additional loss materially in excess of amounts that have been recorded.

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and violations of the California meal and break period laws, among other claims. Two of the five cases have been consolidated in United States District Court for the Central District of California. A hearing on the class certification motion ~~is scheduled for~~was held August 10, 2015. As of October 30, 2015, no decision has been made by the court. One of the remaining cases has been stayed pending outcome of the class certification motion. The fourth case is waiting for a decision regarding whether it will move forward in California state court or in federal court. The fifth case is an enforcement action for civil penalties based on California’s Private Attorneys General Act, which is pending in California state court. We have investigated the claims in all five lawsuits, and intend to vigorously defend them. At this time, we cannot estimate any possible loss or range of loss.

In January 2014, the SEC advised Key that it is investigating possible violations of the U.S. Foreign Corrupt Practices Act (“FCPA”) involving business activities of Key’s operations in Russia. In April 2014, we became aware of an allegation involving our Mexico operations that, if true, could potentially constitute a violation of certain of our policies, including our Code of Business Conduct, the FCPA and other applicable laws. On May 30, 2014, Key voluntarily disclosed the allegation involving our Mexico operations and certain information from the Company’s initial investigation to both the SEC and Department of Justice (“DOJ”). A Special Committee of our Board of Directors ~~is investigating~~conducted an investigation regarding this allegation as well as possible violations of the FCPA involving business activities of our operations in Russia. The ~~fact-finding portion of the~~ Special Committee’s ~~investigation,~~independent review, which also included a review of certain aspects of the Company’s operations in Colombia, as well as a risk assessment with regard to our other international locations, has been ~~completed and the Special Committee is in the process of concluding its work.~~completed. We ~~continue~~are continuing to cooperate with ~~the investigations by~~ the SEC and DOJ. At this time we are unable to predict the ultimate resolution of these matters with these agencies and, accordingly, cannot reasonably estimate any possible loss or range of loss.

In August 2014, two class action lawsuits were filed in the U.S. District Court, Southern District of Texas, Houston Division, individually and on behalf of all other persons similarly situated against the Company and certain officers of the Company, alleging violations of federal securities laws, specifically, violations of Section 10(b) and Rule 10(b)-5, Section 20(a) of the Securities Exchange Act of 1934. Those lawsuits were styled as follows: Sean Cady, Individually and on Behalf of All Other Persons Similarly Situated v. Key Energy Services, Inc., Richard J. Alario, and J. Marshall Dodson, No. 4:14-cv-2368, filed on August 15, 2014; and Ian W. Davidson, Individually and on Behalf of All Other Persons Similarly Situated v. Key Energy Services, Inc., Richard J. Alario, and J. Marshall Dodson, No. 4.14-cv-2403, filed on August 21, 2014. On December 11, 2014, the Court entered an order that consolidated the two lawsuits into one action, along with any future filed tag-along actions brought on behalf of purchasers of Key Energy Services, Inc. common stock. The order also appointed Inter-Local Pension Fund as the lead plaintiff in the class action and approved the law firm of Spector Roseman Kodroff & Willis, P.C. as lead counsel for the consolidated class and Kendall Law Group, LLP, as local counsel for the consolidated class. The lead plaintiff filed the consolidated amended complaint on February 13, 2015. Among other changes, the consolidated amended complaint adds Taylor M. Whichard III and Newton W. Wilson III as defendants, and ~~expands~~seeks to represent a class of purchasers of the ~~class period to include the timeframe~~Company's stock between September 4, 2012 and July 17, 2014. Defendants Key Energy Services, Inc., Richard J. Alario, J. Marshall Dodson and Newton W. Wilson III filed a Motion to Dismiss on April 14, 2015. Defendant Taylor M. Whichard III filed a Joinder in Motion and Motion to Dismiss on the same date. Lead plaintiff filed an opposition to that motion, and all defendants filed reply briefs in support of the motion. The court has not ruled upon it. Because this case is in the early stages, we cannot predict the outcome at this time. Accordingly, we cannot estimate any possible loss or range of loss.

In addition, in a letter dated September 4, 2014, a purported shareholder of the Company demanded that the Board commence an independent internal investigation into and legal proceedings against each member of the Board, a former member of the Board and certain officers of the Company for alleged violations of Maryland and/or federal law. The letter alleges that the Board and senior officers breached their fiduciary duties to the Company, including the duty of loyalty and due care, by (i) improperly accounting for goodwill, (ii) causing the Company to potentially violate the FCPA, resulting in an investigation by the SEC, (iii) causing the Company to engage in improper conduct related to the Company’s Russia

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operations; and (iv) making false statements regarding, and failing to properly account for, certain contracts with Pemex. As described in the letter, the purported shareholder believes that the legal proceedings should seek recovery of damages in an unspecified amount allegedly sustained by the Company. The Board of Directors referred the demand letter to the Special Committee. We cannot predict the outcome of this matter.

In March 2015, two collective action lawsuits were filed in the Southern District of Texas, Corpus Christi Division, individually and on behalf of all others similarly situated, alleging violations of the Fair Labor Standards Act of 1938 (“FLSA”). We have answered the lawsuits and asserted affirmative defenses. Because the cases are in the early stages, we cannot predict the outcomes at this time. Accordingly, we cannot estimate any possible loss or range of loss for either case.

In April 2015, a collective action lawsuit was filed in the Middle District of Pennsylvania, individually and on behalf of similarly situated employees, alleging violations of the Pennsylvania Minimum Wage Act and the FLSA. This lawsuit was dismissed, without prejudice, on April 30, 2015.

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Act. We have answered the lawsuit and asserted affirmative defenses. Because the case is in the early stages, we cannot predict the outcome at this time. Accordingly, we cannot estimate any possible loss or range of loss of this case.

Self-Insurance Reserves

We maintain reserves for workers’ compensation and vehicle liability on our balance sheet based on our judgment and estimates using an actuarial method based on claims incurred. We estimate general liability claims on a case-by-case basis. We maintain insurance policies for workers’ compensation, vehicle liability and general liability claims. These insurance policies carry self-insured retention limits or deductibles on a per occurrence basis. The retention limits or deductibles are accounted for in our accrual process for all workers’ compensation, vehicular liability and general liability claims. As of ~~June~~September 30, 2015 and December 31, 2014, we have recorded ~~$59.0~~$59.3 million and $61.0 million, respectively, of self-insurance reserves related to workers’ compensation, vehicular liabilities and general liability claims. Partially offsetting these liabilities, we had $18.3 million and $18.7 million of insurance receivables as of ~~June~~September 30, 2015 and December 31, 2014., respectively. We believe that the liabilities we have recorded are appropriate based on the known facts and circumstances and do not expect further losses materially in excess of the amounts already accrued for existing claims.

Environmental Remediation Liabilities

For environmental reserve matters, including remediation efforts for current locations and those relating to previously disposed properties, we record liabilities when our remediation efforts are probable and the costs to conduct such remediation efforts can be reasonably estimated. As of ~~June~~September 30, 2015 and December 31, 2014, we have recorded ~~$5.5~~$5.4 million and $5.7 million, respectively, for our environmental remediation liabilities. We believe that the liabilities we have recorded are appropriate based on the known facts and circumstances and do not expect further losses materially in excess of the amounts already accrued.

NOTE ~~11.~~12. LOSS PER SHARE

Basic loss per share is determined by dividing net loss attributable to Key by the weighted average number of common shares actually outstanding during the period. Diluted loss per common share is based on the increased number of shares that would be outstanding assuming conversion of potentially dilutive outstanding securities using the treasury stock and “as if converted” methods.

The components of our loss per share are as follows:


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
	(in thousands, except per share amounts)												(in thousands, except per share amounts)
Basic and Diluted EPS Calculation:
Numerator
Net loss	$	(65,379	)	$	(52,196	)	$	(125,055	)	$	(64,095	)	$	(640,161	)	$	(62,229	)	$	(765,216	)	$	(126,324	)
Denominator
Weighted average shares outstanding	$	156,347		$	153,496		$	155,586		153,157			$	157,605		$	153,550		$	156,266		153,327
Basic and diluted loss per share	$	(0.42	)	$	(0.34	)	$	(0.80	)	$	(0.42	)	$	(4.06	)	$	(0.41	)	$	(4.90	)	$	(0.82	)

Stock options, warrants and stock appreciation rights (“SARs”) are included in the computation of diluted loss per share using the treasury stock method. Restricted stock awards are legally considered issued and outstanding when granted and are included in basic weighted average shares outstanding. The diluted earnings per share calculations for the three ~~and six~~ months ended ~~June~~September 30, 2015 exclude the potential exercise of 1.0 million stock options and 0.3 million SARs and for the nine

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months ended September 30, 2015 exclude the potential exercise of 1.3 million stock options and 0.3 million SARs as they would be anti-dilutive due to net loss during the period. The diluted earnings per share calculations for the three months ended ~~June~~September 30, 2014 exclude the potential exercise of 1.3 million stock options and 0.3 million SARs and for the ~~six~~nine months ended ~~June~~September 30, 2014 exclude the potential exercise of 1.4 million stock options and 0.3 million SARs as they would be anti-dilutive due to net loss during the period. No events occurred after ~~June~~September 30, 2015 that would materially affect the number of weighted average shares outstanding.

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NOTE ~~12.~~13. SHARE-BASED COMPENSATION

We recognized employee share-based compensation expense of ~~$2.1~~$0.8 million and ~~$2.4~~less than $0.1 million during the three months ended ~~June~~September 30, 2015 and 2014, respectively, and the related income tax benefit recognized was ~~$0.7~~$0.2 million and less than $0.1 million for the same periods. We recognized employee share-based compensation expense of ~~$6.2~~$6.9 million and $7.1 million during the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, respectively, and the related income tax expense recognized was ~~$2.2~~$2.4 million and $2.3 million, respectively, for the same period. We did not capitalize any share-based compensation during the three and ~~six~~nine months ended ~~June~~September 30, 2015 and ~~2014~~.2014.

The unrecognized compensation cost related to our unvested restricted stock as of ~~June~~September 30, 2015 is estimated to be ~~$10.3~~$8.3 million and is expected to be recognized over a weighted-average period of ~~1.5~~1.3 years. All outstanding stock options are vested and there are no unrecognized cost related to our stock options as of ~~June~~September 30, 2015. No phantom stock was outstanding as of ~~June~~September 30, 2015.

During May 2015, we issued 598,860 restricted stock units to our outside directors under the Key Energy Services, Inc. 2014 Equity and Cash Incentive Plan that was approved by our stockholders on May 15, 2014. These restricted stock units vested immediately and we recognized $1.6 million of expense related to these awards. Additionally, during May 2014, we recognized $1.6 million of expense related to similar awards.

In the first quarter of 2015, the Compensation Committee of the Board of Directors adopted both the 2014 Performance Award Agreement (“2014 PU Award Agreement”) under the Key Energy Services, Inc. 2014 Equity and Cash Incentive Plan (the “2014 Plan”) and the 2015 Performance Unit Plan (the “2015 PU Plan”). We believe that the 2015 PU Plan and 2014 PU Award Agreement will enable us to obtain and retain employees who will contribute to our long term success by aligning the interests of our executives with the interests of our stockholders by providing compensation that is linked directly to increases in share value.

In January 2015, we issued 2.1 million performance units to our executive officers under the 2014 Plan with such material terms as set forth in the 2014 PU Award Agreement. In February 2015, we issued 0.4 million performance units to certain other employees under the 2015 PU Plan. The performance units are measured based on one three-year performance period from January 1, 2015 to December 31, 2017. The number of performance units that may be earned by a participant is determined at the end of the performance period based on the relative placement of Key’s total stockholder return for that period within the peer group, as follows:



Company Placement for the Performance Period	Performance Units Earned as a Percentage of Target
First	200	%
Second	180	%
Third	160	%
Fourth	140	%
Fifth	120	%
Sixth	100	%
Seventh	0	%
Eighth	0	%
Ninth	0	%
Tenth	0	%
Eleventh	0	%
Twelfth	0	%

If any performance units vest for a given performance period, the award holder will be paid a cash amount equal to the vested percentage of the performance units multiplied by the closing stock price of our common stock on the last trading day of the performance period. We account for the performance units as a liability-type award as they are settled in cash. As of ~~June~~September 30, 2015, the fair value of outstanding performance units was ~~$6.2~~$0.8 million, and is being accreted to compensation

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expense over the vesting terms of the awards. As of ~~June~~September 30, 2015, the unrecognized compensation cost related to our unvested performance units is estimated to be ~~$4.8~~$0.6 million and is expected to be recognized over a weighted-average period of ~~2.4~~2.2 years.

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NOTE ~~13.~~14. TRANSACTIONS WITH RELATED PARTIES

Board of Director Relationships

A member of our board of directors is the Executive Vice President, General Counsel and Chief Administrative Officer of Anadarko Petroleum Corporation (“Anadarko”), which is one of our customers. Sales to Anadarko were approximately ~~$2.7~~$2.3 million and ~~$9.3~~$8.1 million for the three months ended ~~June~~September 30, 2015 and 2014, respectively, and ~~$7.8~~$10.1 million and ~~$18.1~~$26.2 million for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, respectively. Receivables outstanding from Anadarko were approximately ~~$1.0~~$0.9 million and $2.9 million as of ~~June~~September 30, 2015 and December 31, 2014, respectively. Transactions with Anadarko for our services are made on terms consistent with other customers.

NOTE ~~14.~~15. ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS

The following is a summary of the carrying amounts and estimated fair values of our financial instruments as of ~~June~~September 30, 2015 and December 31, 2014.

Cash, cash equivalents, accounts receivable, accounts payable and accrued liabilities. These carrying amounts approximate fair value because of the short maturity of the instruments or because the carrying value is equal to the fair value of those instruments on the balance sheet date.


	June 30, 2015				December 31, 2014				September 30, 2015				December 31, 2014
	Carrying Value		Fair Value		Carrying Value		Fair Value		Carrying Value		Fair Value		Carrying Value		Fair Value
	(in thousands)								(in thousands)
Financial assets:
Notes receivable - Argentina operations sale	$	3,755	$	3,755	$	8,300	$	8,300	$	—	$	—	$	8,300	$	8,300
Financial liabilities:
6.75% Senior Notes due 2021	$	675,000	$	399,938	$	675,000	$	413,438	$	675,000	$	236,250	$	675,000	$	413,438
Term Loan Facility due 2020	315,000		315,000		—		—		314,212		314,212		—		—
Credit Facility revolving loans	—		—		70,000		70,000		—		—		70,000		70,000

Notes receivable — Argentina operations sale. The fair value of these notes receivable are based upon the quoted market Treasury rates as of the dates indicated. The carrying values of these items approximate their fair values due to the maturity dates rapidly approaching, thus giving way to discount rates that are similar. The carrying value and fair value are net of aA $4.0 million valuation allowance for collectibility of the notes ~~receivable.~~receivable was recorded in the first quarter of 2015. An additional $3.8 million reserve was recorded in the third quarter of 2015.

6.75% Senior Notes due 2021. The fair value of these notes are based upon the quoted market prices for those securities as of the dates indicated. The carrying value of these notes as of ~~June~~September 30, 2015 was $675.0 million, and the fair value was ~~$399.9~~$236.3 million ~~(59.3%~~(35.0% of carrying value).

Term Loan Facility due 2020. Because the variable interest rates of these loans approximate current market rates, the fair values of the loans borrowed under this facility approximate their carrying values.

Credit Facility Revolving Loans. In connection with entering into the ABL Facility and the Term Loan Facility, we terminated our 2011 Credit Facility on June 1, 2015.

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NOTE ~~15.~~16. SEGMENT INFORMATION

We revised our reportable business segments as of the fourth quarter of 2014. The revised reportable segments are U.S. Rig Services, Fluid Management Services, Coiled Tubing Services, Fishing and Rental Services and International. We also have a “Functional Support” segment associated with overhead and other costs in support of our reportable segments. Segment disclosures as of and for the the three and ~~six~~nine months ended ~~June~~September 30, 2014 have been revised to reflect the change in reportable segments. We revised our segments to reflect changes in management’s resource allocation and performance assessment in making decisions regarding our business. Our U.S. Rig Services, Fluid Management Services, Coiled Tubing Services, Fishing and Rental Services operate geographically within the United States. The International reportable segment includes our operations in Mexico, Colombia, Ecuador, Russia, Bahrain and Oman. Our Canadian subsidiary is also reflected in our International reportable segment. We evaluate the performance of our segments based on gross margin measures. All inter-segment sales pricing is based on current market conditions.

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U.S. Rig Services

Our U.S. Rig Services include the completion of newly drilled wells, workover and recompletion of existing oil and natural gas wells, well maintenance, and the plugging and abandonment of wells at the end of their useful lives. We also provide specialty drilling services to oil and natural gas producers with certain of our larger rigs that are capable of providing conventional and horizontal drilling services. Our rigs encompass various sizes and capabilities, allowing us to service all types of wells with depths up to 20,000 feet. Many of our rigs are outfitted with our proprietary KeyView® technology, which captures and reports well site operating data and provides safety control systems. We believe that this technology allows our customers and our crews to better monitor well site operations, improves efficiency and safety, and adds value to the services that we offer.

The completion and recompletion services provided by our rigs prepare wells for production, whether newly drilled, or recently extended through a workover operation. The completion process may involve selectively perforating the well casing to access production zones, stimulating and testing these zones, and installing tubular and downhole equipment. We typically provide a well service rig and may also provide other equipment to assist in the completion process. Completion services vary by well and our work may take a few days to several weeks to perform, depending on the nature of the completion.

The workover services that we provide are designed to enhance the production of existing wells and generally are more complex and time consuming than normal maintenance services. Workover services can include deepening or extending wellbores into new formations by drilling horizontal or lateral wellbores, sealing off depleted production zones and accessing previously bypassed production zones, converting former production wells into injection wells for enhanced recovery operations and conducting major subsurface repairs due to equipment failures. Workover services may last from a few days to several weeks, depending on the complexity of the workover.

Maintenance services provided with our rig fleet are generally required throughout the life cycle of an oil or natural gas well. Examples of these maintenance services include routine mechanical repairs to the pumps, tubing and other equipment, removing debris and formation material from wellbores, and pulling rods and other downhole equipment from wellbores to identify and resolve production problems. Maintenance services are generally less complicated than completion and workover related services and require less time to perform.

Our rig fleet is also used in the process of permanently shutting-in oil or natural gas wells that are at the end of their productive lives. These plugging and abandonment services generally require auxiliary equipment in addition to a well servicing rig. The demand for plugging and abandonment services is not significantly impacted by the demand for oil and natural gas because well operators are required by state regulations to plug wells that are no longer productive.

Fluid Management Services

We provide transportation and well-site storage services for various fluids utilized in connection with drilling, completions, workover and maintenance activities. We also provide disposal services for fluids produced subsequent to well completion. These fluids are removed from the well site and transported for disposal in saltwater disposal wells owned by us or a third party. In addition, we operate a fleet of hot oilers capable of pumping heated fluids used to clear soluble restrictions in a wellbore. Demand and pricing for these services generally correspond to demand for our well service rigs.

Coiled Tubing Services

Coiled Tubing Services involve the use of a continuous metal pipe spooled onto a large reel which is then deployed into oil and natural gas wells to perform various applications, such as wellbore clean-outs, nitrogen jet lifts, through-tubing fishing, and formation stimulations utilizing acid and chemical treatments. Coiled tubing is also used for a number of horizontal well applications such as milling temporary isolation plugs that separate frac zones, and various other pre- and post-hydraulic fracturing well preparation services.

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Fishing and Rental Services

We offer a full line of fishing services and rental equipment designed for use in providing both onshore and offshore drilling and workover services. Fishing services involve recovering lost or stuck equipment in the wellbore utilizing a broad array of “fishing tools.” Our rental tool inventory consists of drill pipe, tubulars, handling tools (including our patented Hydra-Walk^® pipe-handling units and services), pressure-control equipment, pumps, power swivels, reversing units, foam air units, frac stack equipment used to support hydraulic fracturing operations and the associated flowback of frac fluids, proppants, oil and natural gas. We also provide well testing services.

Demand for our fishing and rental services is closely related to capital spending by oil and natural gas producers, which is generally a function of oil and natural gas prices.

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International

Our International segment includes operations in Mexico, Colombia, Ecuador, the Middle East and Russia. We provide rig-based services such as the maintenance, workover, recompletion of existing oil wells, completion of newly-drilled wells and plugging and abandonment of wells at the end of their useful lives in each of our international markets. In addition, we have a technology development and control systems business based in Canada.

In addition, in Mexico we provide drilling, coiled tubing, wireline and project management and consulting services. Our work in Mexico also requires us to provide third-party services, which vary in scope by project.

Our technology development and control systems business based in Canada is focused on the development of hardware and software related to oilfield service equipment controls, data acquisition and digital information flow.

In April 2015, we announced our decision to exit markets in which we participate outside of North America. Our strategy is to sell or relocate the assets of the businesses operating in these markets. We are in negotiations to sell our subsidiary in Bahrain and certain assets in Oman. We expect these sales to occur before the end of 2015. In the third quarter, we transferred four rigs from Ecuador to the U.S. and sold the remaining operating assets of our Ecuadorian business unit at auction. Additionally, in Colombia, we relocated one rig to the U.S. in the third quarter and plan to sell or relocate thirteen rigs to the U.S. in the fourth quarter. We plan to sell the remaining property and equipment, net, and inventories of our Colombian business unit in the fourth quarter of 2015.

Functional Support

Our Functional Support segment includes unallocated overhead costs associated with administrative support for our U.S. and International reporting segments.

Financial Summary

The following tables set forth our unaudited segment information as of and for the three and ~~six~~nine months ended ~~June~~September 30, 2015 and 2014 (in thousands):


As of and for the three months ended June 30, 2015
As of and for the three months ended September 30, 2015																									As of and for the three months ended September 30, 2015
	U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Functional Support(2)			Reconciling Eliminations			Total			U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	93,253		$	39,178		$	21,609		$	28,142		$	15,314		$	—		$	—		$	197,496		$	85,200		$	35,519		$	20,820		$	27,629		$	7,689		$	—		$	—		$	176,857
Intersegment revenues	196			421			—			1,447			798			542			(3,404		)	—			84			417			2			1,552			763			542			(3,360		)	—
Depreciation and amortization	14,975			6,525			5,841			8,982			6,507			3,066			—			45,896			14,876			6,618			5,671			8,561			6,236			3,308			—			45,270
Impairment expense	—			—			—			—			21,352			—			—			21,352			297,719			24,479			105,995			180,974			40,777			—			—			649,944
Other operating expenses	82,410			32,712			19,851			25,734			16,326			32,518			—			209,551			77,939			32,758			25,726			24,172			32,844			26,380			—			219,819
Operating loss	(4,132		)	(59		)	(4,083		)	(6,574		)	(28,871		)	(35,584		)	—			(79,303		)	(305,334		)	(28,336		)	(116,572		)	(186,078		)	(72,168		)	(29,688		)	—			(738,176		)
Interest expense, net of amounts capitalized	—			—			—			—			—			17,058			—			17,058			—			—			—			—			16			21,688			—			21,704
Loss before income taxes	(4,067		)	(41		)	(4,074		)	(6,574		)	(28,919		)	(52,438		)	—			(96,113		)	(305,373		)	(28,321		)	(116,570		)	(185,784		)	(74,408		)	(55,339		)	—			(765,795		)
Long-lived assets(1)	796,551			171,058			166,931			319,480			221,832			245,188			(152,640		)	1,768,400			495,278			152,610			60,871			141,349			150,897			198,340			(145,984		)	1,053,361
Total assets	1,609,569			299,670			251,201			658,464			371,152			(481,597		)	(418,681		)	2,289,778			1,333,275			279,377			143,892			474,416			250,438			(579,969		)	(407,405		)	1,494,024
Capital expenditures, excluding acquisitions	3,201			2,506			2,007			2,124			1,509			2,333			—			13,680
Capital expenditures																									779			2,200			434			2,586			4			229			—			6,232

2021

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As of and for the three months ended June 30, 2014
As of and for the three months ended September 30, 2014																						As of and for the three months ended September 30, 2014
	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services		International			Functional Support(2)			Reconciling Eliminations			Total			U.S. Rig Services		Fluid Management Services			Coiled Tubing Services		Fishing and Rental Services			International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	169,980	$	62,087	$	43,108		$	49,340	$	26,080		$	—		$	—		$	350,595		$	178,219	$	63,818		$	42,309	$	55,502		$	25,950		$	—		$	—		$	365,798
Intersegment revenues	167		32		—			—		2,547			543			(3,289		)	—			278		368			—		(1,045		)	2,343			361			(2,305		)	—
Depreciation and amortization	14,630		8,255		5,968			12,088		7,795			3,448			—			52,184			15,375		8,101			5,850		11,031			7,689			2,878			—			50,924
Impairment expense	—		—		—			—		28,687			—			—			28,687			—		—			—		60,792			—			—			—			60,792
Other operating expenses	132,389		52,874		37,722			36,449		26,444			34,886			—			320,764			134,707		55,859			36,443		39,094			27,517			43,716			—			337,336
Operating income (loss)	22,961		958		(582		)	803		(36,846		)	(38,334		)	—			(51,040		)	28,137		(142		)	16		(55,415		)	(9,256		)	(46,594		)	—			(83,254		)
Interest expense, net of amounts capitalized	—		—		(1		)	—		26			13,401			—			13,426			—		—			—		—			1			13,416			—			13,417
Income (loss) before income taxes	23,520		1,183		(392		)	981		(35,289		)	(51,736		)	—			(61,733		)	28,214		(104		)	240		(55,397		)	(10,274		)	(59,698		)	—			(97,019		)
Long-lived assets(1)	774,613		208,563		232,228			412,033		269,153			256,298			(160,271		)	1,992,617			782,392		201,985			217,122		347,144			260,706			274,946			(160,014		)	1,924,281
Total assets	1,565,553		285,746		255,615			649,739		436,067			(358,680		)	(388,932		)	2,445,108			1,593,832		288,597			254,701		657,890			415,678			(430,217		)	(373,835		)	2,406,646
Capital expenditures, excluding acquisitions	25,759		896		2,000			7,691		1,796			2,762			—			40,904
Capital expenditures																						22,884		583			3,071		9,618			831			1,704			—			38,691


As of and for the six months ended June 30, 2015
As of and for the nine months ended September 30, 2015																							As of and for the nine months ended September 30, 2015
	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services			International			Functional Support(2)			Reconciling Eliminations			Total			U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	214,075	$	89,933	$	52,626		$	70,832		$	37,829		$	—		$	—		$	465,295		$	299,275		$	125,452		$	73,446		$	98,461		$	45,518		$	—		$	—		$	642,152
Intersegment revenues	459		729		—			3,249			2,165			1,084			(7,686		)	—			543			1,146			2			4,801			2,928			1,626			(11,046		)	—
Depreciation and amortization	29,685		14,247		11,608			17,946			13,336			6,285			—			93,107			44,561			20,865			17,279			26,507			19,572			9,593			—			138,377
Impairment expense	—		—		21,700			—			21,352			—			—			43,052			297,719			24,479			127,695			180,974			62,129			—			—			692,996
Other operating expenses	180,522		74,269		47,223			59,516			41,623			78,572			—			481,725			258,461			107,027			72,949			83,688			74,467			104,952			—			701,544
Operating income (loss)	3,868		1,417		(27,905		)	(6,630		)	(38,482		)	(84,857		)	—			(152,589		)
Operating loss																							(301,466		)	(26,919		)	(144,477		)	(192,708		)	(110,650		)	(114,545		)	—			(890,765		)
Interest expense, net of amounts capitalized	—		—		—			—			—			30,400			—			30,400			—			—			—			—			16			52,088			—			52,104
Income (loss) before income taxes	3,965		1,483		(27,894		)	(6,800		)	(39,550		)	(118,377		)	—			(187,173		)
Loss before income taxes																							(301,408		)	(26,838		)	(144,464		)	(192,584		)	(113,958		)	(173,716		)	—			(952,968		)
Long-lived assets(1)	796,551		171,058		166,931			319,480			221,832			245,188			(152,640		)	1,768,400			495,278			152,610			60,871			141,349			150,897			198,340			(145,984		)	1,053,361
Total assets	1,609,569		299,670		251,201			658,464			371,152			(481,597		)	(418,681		)	2,289,778			1,333,275			279,377			143,892			474,416			250,438			(579,969		)	(407,405		)	1,494,024
Capital expenditures, excluding acquisitions	12,862		3,800		4,121			5,619			2,875			3,398			—			32,675
Capital expenditures																							13,641			6,000			4,555			8,205			2,879			3,627			—			38,907

2122

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As of and for the six months ended June 30, 2014
As of and for the nine months ended September 30, 2014																							As of and for the nine months ended September 30, 2014
	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services		International			Functional Support(2)			��	Reconciling Eliminations			Total			U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services			International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	334,731	$	123,675	$	87,603		$	102,550	$	58,177		$	—			$	—		$	706,736		$	512,950	$	187,493	$	129,912		$	158,052		$	84,127		$	—		$	—		$	1,072,534
Intersegment revenues	290		144		—			—		4,768			1,085				(6,287		)	—			568		512		—			(1,045		)	7,111			1,446			(8,592		)	—
Depreciation and amortization	28,791		16,433		11,805			24,615		15,699			5,936				—			103,279			44,166		24,534		17,655			35,646			23,388			8,814			—			154,203
Impairment expense	—		—		—			—		28,687			—				—			28,687			—		—		—			60,792			28,687			—			—			89,479
Other operating expenses	258,637		103,937		70,242			74,302		61,128			63,686				—			631,932			393,344		159,796		106,685			113,396			88,645			107,402			—			969,268
Operating income (loss)	47,303		3,305		5,556			3,633		(47,337		)	(69,622		)		—			(57,162		)	75,440		3,163		5,572			(51,782		)	(56,593		)	(116,216		)	—			(140,416		)
Interest expense, net of amounts capitalized	—		—		(1		)	—		28			26,953				—			26,980			—		—		(1		)	—			29			40,369			—			40,397
Income (loss) before income taxes	48,244		3,698		5,843			3,929		(47,237		)	(95,817		)		—			(81,340		)	76,458		3,594		6,083			(51,468		)	(57,511		)	(155,515		)	—			(178,359		)
Long-lived assets(1)	774,613		208,563		232,228			412,033		269,153			256,298				(160,271		)	1,992,617			782,392		201,985		217,122			347,144			260,706			274,946			(160,014		)	1,924,281
Total assets	1,565,553		285,746		255,615			649,739		436,067			(358,680		)		(388,932		)	2,445,108			1,593,832		288,597		254,701			657,890			415,678			(430,217		)	(373,835		)	2,406,646
Capital expenditures, excluding acquisitions	43,896		1,758		3,497			11,155		3,670			5,453				—			69,429
Capital expenditures																							66,780		2,341		6,568			20,773			4,501			7,157			—			108,120


(1)	Long-lived assets include fixed assets, goodwill, intangibles and other non-current assets.


(2)	Functional Support is geographically located in the United States.

2223

Table of Contents

NOTE ~~16.~~17. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

Our 2021 Notes, ABL Facility and Term Loan Facility are guaranteed by virtually all our domestic subsidiaries, all of which are wholly owned. The guarantees are joint and several, full, complete and unconditional. There are no restrictions on the ability of subsidiary guarantors to transfer funds to the parent company.

As a result of these guarantee arrangements, we are required to present the following condensed consolidating financial information pursuant to SEC Regulation S-X Rule 3-10, “Financial Statements of Guarantors and Issuers of Guaranteed Securities Registered or Being Registered.”

																										CONDENSED CONSOLIDATING UNAUDITED BALANCE SHEETS
	June 30, 2015												September 30, 2015
	Parent Company		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Consolidated		Parent Company		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)												(in thousands)
Assets:
Current assets	$	213,786	$	262,473	$	45,119		$	—		$	521,378	$	194,876	$	218,717		$	27,070		$	—		$	440,663
Property and equipment, net	—		1,059,966		77,568			—			1,137,534		—		979,808			26,018			—			1,005,826
Goodwill	—		556,658		4,381			—			561,039		—		—			—			—			—
Intercompany notes and accounts receivable and investment in subsidiaries	3,047,124		1,228,949		49,976			(4,326,049		)	—		2,277,824		1,248,558			59,222			(3,585,604		)	—
Other assets	—		51,928		17,899			—			69,827		—		41,831			5,704			—			47,535
TOTAL ASSETS	$	3,260,910	$	3,159,974	$	194,943		$	(4,326,049	)	$	2,289,778	$	2,472,700	$	2,488,914		$	118,014		$	(3,585,604	)	$	1,494,024
Liabilities and equity:
Current liabilities	$	21,018	$	115,315	$	21,606		$	—		$	157,939	$	4,791	$	114,406		$	19,109		$	—		$	138,306
Long-term debt	961,080		—		—			—			961,080		961,566		—			—			—			961,566
Intercompany notes and accounts payable	1,162,648		2,710,438		131,150			(4,004,236		)	—		1,162,648		2,724,959			130,048			(4,017,655		)	—
Deferred tax liabilities	178,008		398		(143		)	—			178,263		44,149		344			(4,449		)	—			40,044
Other long-term liabilities	1,276		54,186		136			—			55,598		6,882		54,578			(33		)	—			61,427
Equity	936,880		279,637		42,194			(321,813		)	936,898		292,664		(405,373		)	(26,661		)	432,051			292,681
TOTAL LIABILITIES AND EQUITY	$	3,260,910	$	3,159,974	$	194,943		$	(4,326,049	)	$	2,289,778	$	2,472,700	$	2,488,914		$	118,014		$	(3,585,604	)	$	1,494,024

2324

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CONDENSED CONSOLIDATING BALANCE SHEETS

	December 31, 2014
	Parent Company		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Assets:
Current assets	$	39,020	$	341,188	$	53,587		$	—		$	433,795
Property and equipment, net	—		1,128,776		106,482			—			1,235,258
Goodwill	—		578,358		4,381			—			582,739
Intercompany notes and accounts receivable and investment in subsidiaries	3,170,874		1,426,160		42,352			(4,639,386		)	—
Other assets	—		56,664		14,307			—			70,971
TOTAL ASSETS	$	3,209,894	$	3,531,146	$	221,109		$	(4,639,386	)	$	2,322,763
Liabilities and equity:
Current liabilities	$	22,046	$	192,079	$	27,733		$	—		$	241,858
Long-term debt	737,691		—		—			—			737,691
Intercompany notes and accounts payable	1,162,648		2,696,051		123,810			(3,982,509		)	—
Deferred tax liabilities	228,199		398		(134		)	(69		)	228,394
Other long-term liabilities	1,264		55,182		311			—			56,757
Equity	1,058,046		587,436		69,389			(656,808		)	1,058,063
TOTAL LIABILITIES AND EQUITY	$	3,209,894	$	3,531,146	$	221,109		$	(4,639,386	)	$	2,322,763

CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
Three Months Ended June 30, 2015

Parent
Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries
Eliminations Consolidated
(in thousands)
Revenues $ —
$ 185,061
$ 15,118
$ (2,683 ) $ 197,496
Direct operating expense —
148,714
11,325
(1,198 ) 158,841
Depreciation and amortization expense —
43,085
2,811
—
45,896
General and administrative expense 186
48,159
3,842
(1,477 ) 50,710
Impairment expense —
—
21,352
—
21,352
Operating loss (186 ) (54,897 ) (24,212 ) (8 ) (79,303 )
Interest expense, net of amounts capitalized 17,058
—
—
—
17,058
Other (income) loss, net (582 ) 445
(126 ) 15
(248 )
Loss before income taxes (16,662 ) (55,342 ) (24,086 ) (23 ) (96,113 )
Income tax (expense) benefit 30,756
(74 ) 52
—
30,734
Net income (loss) $ 14,094
$ (55,416 ) $ (24,034 ) $ (23 ) $ (65,379 )

~~Table of Contents~~

CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
Three Months Ended June 30, 2014

Parent
Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries
Eliminations Consolidated
(in thousands)
Revenues $ —
$ 326,835
$ 30,272
$ (6,512 ) $ 350,595
Direct operating expense —
245,267
20,632
(3,016 ) 262,883
Depreciation and amortization expense —
48,702
3,482
—
52,184
General and administrative expense 242
55,459
5,623
(3,443 ) 57,881
Impairment expense —
—
28,687
—
28,687
Operating loss (242 ) (22,593 ) (28,152 ) (53 ) (51,040 )
Interest expense, net of amounts capitalized 13,402
(1 ) 25
—
13,426
Other income, net (618 ) (572 ) (1,564 ) 21
(2,733 )
Loss before income taxes (13,026 ) (22,020 ) (26,613 ) (74 ) (61,733 )
Income tax (expense) benefit 7,977
2,094
(534 ) —
9,537
Net loss $ (5,049 ) $ (19,926 ) $ (27,147 ) $ (74 ) $ (52,196 )

																															CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Six Months Ended June 30, 2015															Three Months Ended September 30, 2015
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated			Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)															(in thousands)
Revenues	$	—		$	434,468		$	38,069		$	(7,242	)	$	465,295		$	—		$	170,913		$	8,876		$	(2,932	)	$	176,857
Direct operating expense	—			338,340			28,620			(3,589		)	363,371			—			166,503			9,487			(1,485		)	174,505
Depreciation and amortization expense	—			87,524			5,583			—			93,107			—			43,001			2,269			—			45,270
General and administrative expense	407			113,794			7,793			(3,640		)	118,354			200			42,664			3,891			(1,441		)	45,314
Impairment expense	—			21,700			21,352			—			43,052			—			610,384			39,560			—			649,944
Operating loss	(407		)	(126,890		)	(25,279		)	(13		)	(152,589		)	(200		)	(691,639		)	(46,331		)	(6		)	(738,176		)
Interest expense, net of amounts capitalized	30,400			—			—			—			30,400			21,689			—			15			—			21,704
Other (income) loss, net	(900		)	4,486			583			15			4,184			(756		)	5,164			1,462			45			5,915
Loss before income taxes	(29,907		)	(131,376		)	(25,862		)	(28		)	(187,173		)	(21,133		)	(696,803		)	(47,808		)	(51		)	(765,795		)
Income tax benefit	61,618			3			497			—			62,118
Income tax (expense) benefit																146,571			(21,259		)	322			—			125,634
Net income (loss)	$	31,711		$	(131,373	)	$	(25,365	)	$	(28	)	$	(125,055	)	$	125,438		$	(718,062	)	$	(47,486	)	$	(51	)	$	(640,161	)

Table of Contents

																															CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Six Months Ended June 30, 2014															Three Months Ended September 30, 2014
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated			Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)															(in thousands)
Revenues	$	—		$	657,310		$	63,553		$	(14,127	)	$	706,736		$	—		$	340,496		$	30,163		$	(4,861	)	$	365,798
Direct operating expense	—			481,925			45,684			(6,424		)	521,185			—			252,747			21,115			(1,750		)	272,112
Depreciation and amortization expense	—			96,465			6,814			—			103,279			—			47,451			3,473			—			50,924
General and administrative expense	478			105,007			12,957			(7,695		)	110,747			231			62,660			5,391			(3,058		)	65,224
Impairment expense	—			—			28,687			—			28,687			—			60,792			—			—			60,792
Operating loss	(478		)	(26,087		)	(30,589		)	(8		)	(57,162		)
Operating income (loss)																(231		)	(83,154		)	184			(53		)	(83,254		)
Interest expense, net of amounts capitalized	26,954			(1		)	27			—			26,980			13,415			—			2			—			13,417
Other income, net	(1,289		)	(1,296		)	(248		)	31			(2,802		)
Other (income) loss, net																(430		)	(18		)	798			(2		)	348
Loss before income taxes	(26,143		)	(24,790		)	(30,368		)	(39		)	(81,340		)	(13,216		)	(83,136		)	(616		)	(51		)	(97,019		)
Income tax benefit	10,983			5,843			419			—			17,245			32,158			2,301			331			—			34,790
Net loss	$	(15,160	)	$	(18,947	)	$	(29,949	)	$	(39	)	$	(64,095	)
Net income (loss)																$	18,942		$	(80,835	)	$	(285	)	$	(51	)	$	(62,229	)

CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS
Six Months Ended June 30, 2015

Parent
Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries
Eliminations Consolidated
(in thousands)
Net cash provided by (used in) operating activities $ —
$ (6,317 ) $ 5,119
$ —
$ (1,198 )
Cash flows from investing activities:

Capital expenditures —
(31,435 ) (1,240 ) —
(32,675 )
Intercompany notes and accounts —
41,993
—
(41,993 ) —
Other investing activities, net —
10,545
—
—
10,545
Net cash provided by (used in) investing activities —
21,103
(1,240 ) (41,993 ) (22,130 )
Cash flows from financing activities:

Proceeds from long-term debt 305,550
—
—
—
305,550
Proceeds from borrowings on revolving credit facility 130,000
—
—
—
130,000
Repayments on revolving credit facility (200,000 ) —
—
—
(200,000 )
Payment of deferred financing costs (11,072 ) —
—
—
(11,072 )
Repurchases of common stock (312 ) —
—
—
(312 )
Intercompany notes and accounts (41,993 ) —
—
41,993
—
Other financing activities, net (2,950 ) —
—
—
(2,950 )
Net cash provided by financing activities 179,223
—
—
41,993
221,216
Effect of changes in exchange rates on cash —
—
289
—
289
Net increase in cash and cash equivalents 179,223
14,786
4,168
—
198,177
Cash and cash equivalents at beginning of period 19,949
450
6,905
—
27,304
Cash and cash equivalents at end of period $ 199,172
$ 15,236
$ 11,073
$ —
$ 225,481



CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Nine Months Ended September 30, 2015
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	605,381		$	46,945		$	(10,174	)	$	642,152
Direct operating expense	—			504,843			38,107			(5,074		)	537,876
Depreciation and amortization expense	—			130,525			7,852			—			138,377
General and administrative expense	607			156,458			11,684			(5,081		)	163,668
Impairment expense	—			632,084			60,912			—			692,996
Operating loss	(607		)	(818,529		)	(71,610		)	(19		)	(890,765		)
Interest expense, net of amounts capitalized	52,089			—			15			—			52,104
Other (income) loss, net	(1,656		)	9,650			2,045			60			10,099
Loss before income taxes	(51,040		)	(828,179		)	(73,670		)	(79		)	(952,968		)
Income tax (expense) benefit	208,189			(21,256		)	819			—			187,752
Net income (loss)	$	157,149		$	(849,435	)	$	(72,851	)	$	(79	)	$	(765,216	)

Table of Contents

CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS
Six Months Ended June 30, 2014

Parent
Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries
Eliminations Consolidated
(in thousands)
Net cash provided by operating activities $ —
$ 100,170
$ 7,098
$ —
$ 107,268
Cash flows from investing activities:

Capital expenditures —
(66,280 ) (3,149 ) —
(69,429 )
Intercompany notes and accounts —
(41,350 ) —
41,350
—
Other investing activities, net —
9,389
—
—
9,389
Net cash used in investing activities —
(98,241 ) (3,149 ) 41,350
(60,040 )
Cash flows from financing activities:

Repayments of long-term debt (3,573 ) —
—
—
(3,573 )
Proceeds from borrowings on revolving credit facility 115,000
—
—
—
115,000
Repayments on revolving credit facility (160,000 ) —
—
—
(160,000 )
Repurchases of common stock (2,211 ) —
—
—
(2,211 )
Intercompany notes and accounts 41,350
—
—
(41,350 ) —
Other financing activities, net (1,221 ) —
—
—
(1,221 )
Net cash used in financing activities (10,655 ) —
—
(41,350 ) (52,005 )
Effect of changes in exchange rates on cash —
—
(81 ) —
(81 )
Net increase (decrease) in cash and cash equivalents (10,655 ) 1,929
3,868
—
(4,858 )
Cash and cash equivalents at beginning of period 23,115
788
4,403
—
28,306
Cash and cash equivalents at end of period $ 12,460
$ 2,717
$ 8,271
$ —
$ 23,448



CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Nine Months Ended September 30, 2014
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	997,806		$	93,716		$	(18,988	)	$	1,072,534
Direct operating expense	—			734,672			66,798			(8,173		)	793,297
Depreciation and amortization expense	—			143,916			10,287			—			154,203
General and administrative expense	709			167,714			18,347			(10,799		)	175,971
Impairment expense	—			60,792			28,687			—			89,479
Operating loss	(709		)	(109,288		)	(30,403		)	(16		)	(140,416		)
Interest expense, net of amounts capitalized	40,369			(1		)	29			—			40,397
Other (income) loss, net	(1,719		)	(1,314		)	550			29			(2,454		)
Loss before income taxes	(39,359		)	(107,973		)	(30,982		)	(45		)	(178,359		)
Income tax benefit	43,141			8,144			750			—			52,035
Net income (loss)	$	3,782		$	(99,829	)	$	(30,232	)	$	(45	)	$	(126,324	)



CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS
	Nine Months Ended September 30, 2015
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Net cash provided by (used in) operating activities	$	—		$	(25,358	)	$	4,520		$	—		$	(20,838	)
Cash flows from investing activities:
Capital expenditures	—			(37,667		)	(1,240		)	—			(38,907		)
Intercompany notes and accounts	—			57,401			—			(57,401		)	—
Other investing activities, net	—			12,095			—			—			12,095
Net cash provided by (used in) investing activities	—			31,829			(1,240		)	(57,401		)	(26,812		)
Cash flows from financing activities:
Repayments of long-term debt	(788		)	—			—			—			(788		)
Proceeds from long-term debt	305,550			—			—			—			305,550
Proceeds from borrowings on revolving credit facility	130,000			—			—			—			130,000
Repayments on revolving credit facility	(200,000		)	—			—			—			(200,000		)
Payment of deferred financing costs	(11,072		)	—			—			—			(11,072		)
Repurchases of common stock	(313		)	—			—			—			(313		)
Intercompany notes and accounts	(57,401		)	—			—			57,401			—
Other financing activities, net	(3,301		)	—			—			—			(3,301		)
Net cash provided by financing activities	162,675			—			—			57,401			220,076
Effect of changes in exchange rates on cash	—			—			(613		)	—			(613		)
Net increase in cash and cash equivalents	162,675			6,471			2,667			—			171,813
Cash and cash equivalents at beginning of period	19,949			450			6,905			—			27,304
Cash and cash equivalents at end of period	$	182,624		$	6,921		$	9,572		$	—		$	199,117

Table of Contents



CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS
	Nine Months Ended September 30, 2014
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Net cash provided by operating activities	$	—		$	122,697		$	3,387		$	—		$	126,084
Cash flows from investing activities:
Capital expenditures	—			(104,336		)	(3,784		)	—			(108,120		)
Intercompany notes and accounts	—			(33,381		)	—			33,381			—
Other investing activities, net				16,278			—			—			16,278
Net cash used in investing activities	—			(121,439		)	(3,784		)	33,381			(91,842		)
Cash flows from financing activities:
Repayments of long-term debt	(3,573		)	—			—			—			(3,573		)
Proceeds from borrowings on revolving credit facility	220,000			—			—			—			220,000
Repayments on revolving credit facility	(225,000		)	—			—			—			(225,000		)
Repurchases of common stock	(2,239		)	—			—			—			(2,239		)
Intercompany notes and accounts	33,381			—			—			(33,381		)	—
Other financing activities, net	(1,240		)	—			—			—			(1,240		)
Net cash provided by (used in) financing activities	21,329			—			—			(33,381		)	(12,052		)
Effect of changes in exchange rates on cash	—			—			6,896			—			6,896
Net increase in cash and cash equivalents	21,329			1,258			6,499			—			29,086
Cash and cash equivalents at beginning of period	23,115			788			4,403			—			28,306
Cash and cash equivalents at end of period	$	44,444		$	2,046		$	10,902		$	—		$	57,392

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

OVERVIEW

Key Energy Services, Inc., and its wholly owned subsidiaries (collectively, “Key,” the “Company,” “we,” “us,” “its,” and “our”) provide a full range of well services to major oil companies, foreign national oil companies and independent oil and natural gas production companies. Our services include rig-based and coiled tubing-based well maintenance and workover services, well completion and recompletion services, fluid management services, fishing and rental services, and other ancillary oilfield services. Additionally, certain rigs are capable of specialty drilling applications. We operate in most major oil and natural gas producing regions of the continental United States and have operations in Mexico, Colombia, Ecuador, the Middle East and Russia. In addition, we have a technology development and control systems business based in Canada.

The following discussion and analysis should be read in conjunction with the accompanying unaudited condensed consolidated financial statements and related notes as of and for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, included elsewhere herein, and the audited consolidated financial statements and notes thereto included in our 2014 Form 10-K.

We operate in five business segments; U.S. Rig Services, Fluid Management Services, Coiled Tubing Services, Fishing and Rental Services and International. We also have a “Functional Support” segment associated with managing our U.S. and International business segments. See “Note ~~15.~~16. Segment Information” in “Item 1. Financial Statements” of Part I of this report for a summary of our business segments.

PERFORMANCE MEASURES

The Baker Hughes U.S. rig count data, which is publicly available on a weekly basis, is often used as an indicator of overall Exploration and Production (“E&P”) company spending and broader oilfield activity. In assessing overall activity in the U.S. onshore oilfield service industry in which we operate, we believe that the Baker Hughes U.S. land drilling rig count is the best available barometer of E&P companies’ capital spending and resulting activity levels. Historically, our activity levels have been highly correlated to U.S. onshore capital spending by our E&P company customers as a group.


	WTI Cushing Oil(1)		NYMEX Henry Hub Natural Gas(1)		Average Baker Hughes U.S. Land Drilling Rigs(2)	WTI Cushing Oil(1)		NYMEX Henry Hub Natural Gas(1)		Average Baker Hughes U.S. Land Drilling Rigs(2)
2015:
First Quarter	$	48.49	$	2.90	1,353	$	48.49	$	2.90	1,353
Second Quarter	$	57.85	$	2.75	876	$	57.85	$	2.75	876
Third Quarter						$	46.49	$	2.76	833

2014:
First Quarter	$	98.68	$	5.18	1,779	$	98.68	$	5.18	1,779
Second Quarter	$	103.35	$	4.61	1,796	$	103.35	$	4.61	1,796
Third Quarter	$	97.87	$	3.96	1,842	$	97.87	$	3.96	1,842
Fourth Quarter	$	73.21	$	3.78	1,856	$	73.21	$	3.78	1,856


(1)	Represents the average of the monthly average prices for each of the periods presented. Source: EIA and Bloomberg


(2)	Source: www.bakerhughes.com

Internally, we measure activity levels for our well servicing operations primarily through our rig and trucking hours. Generally, as capital spending by E&P companies increases, demand for our services also rises, resulting in increased rig and trucking services and more hours worked. Conversely, when activity levels decline due to lower spending by E&P companies, we generally provide fewer rig and trucking services, which results in lower hours worked.

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In the U.S., our rig activity occurs primarily on weekdays during daylight hours. Accordingly, we track U.S. rig activity on a “per U.S. working day” basis. Key's U.S. working days per quarter, which exclude national holidays, are indicated in the table below. Our international rig activity and domestic trucking activity tend to occur on a 24/7 basis. Accordingly, we track our international rig activity and our domestic trucking activity on a “per calendar day” basis. The following table presents our quarterly rig and trucking hours from 2014 through the ~~second~~third quarter of 2015:


	Rig Hours			Trucking Hours	Key’s U.S. Working Days(1)	Rig Hours			Trucking Hours	Key’s U.S. Working Days(1)
2015:	U.S.	International	Total			U.S.	International	Total
First Quarter	271,005	36,950	307,955	418,032	62	271,005	36,950	307,955	418,032	62
Second Quarter	232,169	25,555	257,724	342,271	63	232,169	25,555	257,724	342,271	63
Third Quarter						226,953	13,330	240,283	309,601	64
Total 2015	503,174	62,505	565,679	760,303	125	730,127	75,835	805,962	1,069,904	189

2014:
First Quarter	347,047	46,090	393,137	481,353	63	347,047	46,090	393,137	481,353	63
Second Quarter	355,219	33,758	388,977	493,494	63	355,219	33,758	388,977	493,494	63
Third Quarter	365,891	34,603	400,494	506,486	64	365,891	34,603	400,494	506,486	64
Fourth Quarter	341,313	41,156	382,469	481,653	61	341,313	41,156	382,469	481,653	61
Total 2014	1,409,470	155,607	1,565,077	1,962,986	251	1,409,470	155,607	1,565,077	1,962,986	251


(1)	Key's U.S. working days are the number of weekdays during the quarter minus national holidays.

MARKET CONDITIONS AND OUTLOOK

Market Conditions — Quarter Ended ~~June~~September 30, 2015

Our core businesses depend on our customers’ willingness to make expenditures to produce, develop and explore for ~~oil and natural gas based on the economics of these activities as determined by industry conditions and the prices of~~ oil and natural gas. Industry conditions are influenced by numerous factors, such as the supply of and demand for oil and natural gas, domestic and worldwide economic conditions, and political instability in oil producing countries.

The ~~second~~third quarter continued to present significant challenges for the domestic oil & gas complex as persistent depressed oil prices continued to strain E&P cash flows and associated capital spending. The oilfield services industry activity fellwitness deterioration in the ~~second quarter of 2015~~oil and gas industry as ~~evidenced by the 35% sequential decline of the average Baker Hughes~~persistently low commodity prices caused oilfield service activity to continue to decline. The drilling rig count ~~touching~~dropped to a level ~~that hasn’t been~~not seen in ~~over a decade. The~~nearly two decades. As energy and production companies continued ~~decline in~~to operate with caution, spending on most oilfield services ~~activity has left an overflow~~continued to slip due to a lack of ~~oilfield service capacity~~confidence in ~~the market. As such, fierce competitive pressures~~future commodity prices and a desire to avoid uneconomic projects. We continued ~~in the second quarter of 2015 as service providers lower the price for their services~~ to ~~keep assets working. The Company was not immune to these dynamics, as~~face activity and pricing ~~both declined materially during the quarter,~~declines in each of our business lines, though ~~our activity in~~ our core production services business continues to perform somewhat better than ~~the decline in the Baker Hughes average rig count.~~broader market indicators.

Outside of the U.S., ~~the Company progressed in its’ efforts in~~we moved closer to exiting the markets in which ~~it participates~~we participate outside of North America. In Oman, we have ~~identified a buyer for~~ceased operations and have neared finalization of the sale of assets in this country. In Bahrain, we also are finalizing the sale of our ~~assets and are currently negotiating an agreement to exit the~~ business. In Colombia and Ecuador, operations have ceased and we ~~are in~~have begun the process of ~~relocating~~bringing back rigs ~~and some ancillary equipment back~~ to the U.S. ~~In Bahrain,~~; to date we ~~will be ceasing operations under our contract~~have returned ten rigs to the U.S. and are ~~talking to parties for a~~evaluating the sale or relocation of the ~~assets or business.~~remaining nine rigs in Colombia. In Russia, we are ~~talking~~engaged in discussion with several interested parties about a sale of the ~~assets. The exit of certain international markets may require that some assets will be sold at a loss in the future and that severance costs may be incurred in future periods.~~business. We ~~believe we will~~are seeking to have this effort substantially completed by the end of ~~2015.~~2015, though a sale of our business in Russia could slip into the first quarter of 2016.

Market Outlook

~~Persistent low oil prices driven by robust global oil production and a decelerating global demand base has created structural obstacles for the U.S.~~The domestic oil and gas complex ~~lowering~~is now facing the challenge of how to achieve return-accretive cash ~~flows~~flow in the face of low commodity prices. We believe that due to deferred maintenance by energy producers, a backlog of well maintenance is building, though we cannot predict what factors will drive our customers to resume normal production maintenance activity levels. However, we do know that our customers must work on these wells to maintain the production base, and the ~~amount available to be spend on services~~economics associated with this work make sense at a much lower oil price than drilling and completion. As such, we ~~provide. The Company’s exposure and~~believe that Key’s commitment to ~~servicing the needs of existing~~ production ~~is an integral piece to navigating these challenges as the Company believes customers~~enhancement activities will continue to spend, albeit at lower levels funds to maintain existing production. As the economics supporting drilling and completion activities become uneconomic at current oil prices, we believe this enhances the potentialeventually provide a meaningful opportunity for a greater shift in spending by our customers toward production maintenance activities. Further, we continue to diversify our U.S. revenue base as a result of focusing on the mix of customers and markets where we add the most value. us.

~~Table of Contents~~

As we look ~~beyond~~into the ~~second~~fourth quarter, the outlook for the U.S. oilfield services landscape remains ~~challenged with low activity and continued pressure on the price of~~challenged. We expect that there will be a greater seasonal downturn than in prior years, as our services. Given the refinancing of our revolving credit facility during the quarter, we enhanced our balance sheet with new, long-dated capital. Further, we plan to further reduce our capital expenditures for the yearcustomers exhaust their budgets and take ~~further actions~~longer work vacations around the holidays. We expect this exaggerated downturn to ~~adjust our business and organizational structure to~~impact activity levels at a level approximately double the downturn typically seen in the fourth quarter. In light of the current ~~environment. As a result~~challenging environment, we intend to continue to

Table of ~~these actions,~~Contents

identify ways to streamline our cost structure and to explore ways to enhance the liquidity position of the company ~~may incur losses on disposal of assets or properties~~both internally and severance costs. Therefore, we believe our new credit facilities due in 2020 with limited capital needs coupled with additional steps to reduce costs and preserve liquidity are necessary given current market conditions.externally.

RESULTS OF OPERATIONS

The following table shows our consolidated results of operations for the three and ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, respectively (in thousands):


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
REVENUES	$	197,496		$	350,595		$	465,295		$	706,736		$	176,857		$	365,798		$	642,152		$	1,072,534
COSTS AND EXPENSES:
Direct operating expenses	158,841			262,883			363,371			521,185			174,505			272,112			537,876			793,297
Depreciation and amortization expense	45,896			52,184			93,107			103,279			45,270			50,924			138,377			154,203
General and administrative expenses	50,710			57,881			118,354			110,747			45,314			65,224			163,668			175,971
Impairment expense	21,352			28,687			43,052			28,687			649,944			60,792			692,996			89,479
Operating loss	(79,303		)	(51,040		)	(152,589		)	(57,162		)	(738,176		)	(83,254		)	(890,765		)	(140,416		)
Interest expense, net of amounts capitalized	17,058			13,426			30,400			26,980			21,704			13,417			52,104			40,397
Other (income) loss, net	(248		)	(2,733		)	4,184			(2,802		)	5,915			348			10,099			(2,454		)
Loss before income taxes	(96,113		)	(61,733		)	(187,173		)	(81,340		)	(765,795		)	(97,019		)	(952,968		)	(178,359		)
Income tax benefit	30,734			9,537			62,118			17,245			125,634			34,790			187,752			52,035
NET LOSS	$	(65,379	)	$	(52,196	)	$	(125,055	)	$	(64,095	)	$	(640,161	)	$	(62,229	)	$	(765,216	)	$	(126,324	)

Consolidated Results of Operations — Three Months Ended ~~June~~September 30, 2015 and 2014

Revenues

Our revenues for the three months ended ~~June~~September 30, 2015 decreased $~~153.1~~188.9 million, or ~~43.7%~~51.7%, to $~~197.5~~176.9 million from $~~350.6~~365.8 million for the three months ended ~~June~~September 30, 2014, due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services. Internationally, we had lower revenue as a result of reduced customer activity in ~~Mexico, Russia~~Colombia and ~~Colombia.~~the exit of operations in the Middle East and South America. See “Segment Operating Results — Three Months Ended ~~June~~September 30, 2015 and 2014” below for a more detailed discussion of the change in our revenues.

Direct Operating Expenses

Our direct operating expenses decreased $~~104.0~~97.6 million, to $~~158.8~~174.5 million (~~80.4%~~98.7% of revenues), for the three months ended ~~June~~September 30, 2015, compared to $~~262.9~~272.1 million (~~75.0%~~74.4% of revenues) for the three months ended ~~June~~September 30, 2014. The decrease is primarily related to a decrease in employee compensation costs, fuel expense and repair and maintenance expense as we sought to reduce our cost structure and as a result of lower activity levels.

Depreciation and Amortization Expense

Depreciation and amortization expense decreased $~~6.3~~5.7 million, or ~~12.0%~~11.1%, to $~~45.9~~45.3 million during the three months ended ~~June~~September 30, 2015, compared to $~~52.2~~50.9 million for the three months ended ~~June~~September 30, 2014. The decrease is primarily attributable to the impairment of certain fixed assets and decreases in capital expenditures and lower amortization expense due to the impairment of certain intangible assets.

General and Administrative Expenses

General and administrative expenses decreased $~~7.2~~19.9 million, to $~~50.7~~45.3 million (~~25.7%~~25.6% of revenues), for the three months ended ~~June~~September 30, 2015, compared to $~~57.9~~65.2 million (~~16.5%~~17.8% of revenues) for the three months ended ~~June~~September 30, 2014. The decrease is primarily due to a decrease in expenses related to FCPA investigations and lower employee compensation costs as a result of reduced staffing ~~levels and reduction in wages partially offset by increase in expenses related to FCPA investigations.~~levels.

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Impairment Expense

During the three months ended ~~June~~September 30, 2015, we recorded a ~~$21.4~~$561.0 million impairment of goodwill, a $45.0 million impairment of fixed assets, ~~in our Oman business unit which is included in our International reporting segment.~~a $4.9 million impairment of other intangible assets that are no longer being used, and a $42.4 million impairment of fixed assets to reduce the carrying value of assets held for sale to fair market value. During the three months ended ~~June~~September 30, 2014, we recorded a ~~$28.7~~$60.8 million impairment of goodwill and ~~tradenames in~~fixed assets at our ~~Russian business unit which is included in our International reporting~~Fishing and Rental Services segment.

Interest Expense, Net of Amounts Capitalized

Interest expense increased $~~3.6~~8.3 million, or ~~27.1%~~61.8%, to $~~17.1~~21.7 million for the three months ended ~~June~~September 30, 2015, compared to $13.4 million for the same period in 2014. The increase is primarily related to increased borrowings and interest rate under the new Term Loan Facility for the three months ended ~~June~~September 30, 2015 compared to the same period in 2014 and the ~~write off~~write-off of the remaining $0.8 million of unamortized deferred financing costs related to the 2011 Credit Facility in the second quarter of 2015.

Other ~~Income,~~Loss, Net

During the quarter ended ~~June~~September 30, 2015, we recognized other ~~income,~~loss, net, of $~~0.2~~5.9 million, compared to other ~~income,~~loss, net, of $~~2.7~~0.3 million for the quarter ended ~~June~~September 30, 2014. During the quarter ended March 31, 2015, we recorded an allowance for the collectibility of our notes receivable related to the sale of our operations in Argentina. An additional $3.8 million reserve was recorded in the third quarter of 2015. Our foreign exchange ~~(gain)~~ loss relates to U.S. dollar-denominated transactions in our foreign businesses and fluctuations in exchange rates between local currencies and the U.S. dollar.

The following table summarizes the components of other ~~income,~~loss, net for the periods indicated:


	Three Months Ended June 30,						Three Months Ended September 30,
	2015			2014			2015			2014
	(in thousands)						(in thousands)
Interest income	$	(25	)	$	(30	)	$	(61	)	$	(12	)
Foreign exchange (gain) loss	333			(1,377		)
Foreign exchange loss							2,472			1,118
Allowance for collectibility of notes receivable							3,755			—
Other, net	(556		)	(1,326		)	(251		)	(758		)
Total	$	(248	)	$	(2,733	)	$	5,915		$	348

Income Tax Benefit

We recorded an income tax benefit of ~~$30.7~~$125.6 million on a pre-tax loss of ~~$96.1~~$765.8 million in the three months ended ~~June~~September 30, 2015, compared to an income tax benefit of ~~$9.5~~$34.8 million on a pre-tax loss of ~~$61.7~~$97.0 million in the three months ended ~~June~~September 30, 2014. Our effective tax rate was ~~32.0%~~16.4% for the three months ended ~~June~~September 30, 2015, compared to ~~15.4%~~35.9% for the three months ended ~~June~~September 30, 2014. Excluding the impact of non-deductible goodwill impairment expense and valuation allowances recorded against deferred tax assets in the third quarter, our effective tax rate for the three months ended September 30, 2015 was 31.7%. Our effective tax rates for such periods differ from the U.S. statutory rate of 35% due to a number of factors, including the mix of profit and loss between domestic and international taxing jurisdictions and the impact of permanent items, ~~mainly non-deductible expenses such as fines and penalties,~~including goodwill impairment expense and expenses subject to statutorily imposed limitations such as meals and entertainment expenses, that affect book income but do not affect taxable ~~income.~~income and discrete tax adjustments, such as valuation allowances against deferred tax assets and tax expense or benefit recognized for uncertain tax positions.

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Segment Operating Results — Three Months Ended ~~June~~September 30, 2015 and 2014

The following table shows operating results for each of our segments for the three months ended ~~June~~September 30, 2015 and 2014 (in thousands):


For the three months ended June 30, 2015
For the three months ended September 30, 2015																						For the three months ended September 30, 2015
	U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Functional Support			Total				U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Functional Support			Total
Revenues from external customers	$	93,253		$	39,178		$	21,609		$	28,142		$	15,314		$	—		$	197,496			$	85,200		$	35,519		$	20,820		$	27,629		$	7,689		$	—		$	176,857
Operating expenses	97,385			39,237			25,692			34,716			44,185			35,584			276,799				390,534			63,855			137,392			213,707			79,857			29,688			915,033
Operating loss	(4,132		)	(59		)	(4,083		)	(6,574		)	(28,871		)	(35,584		)	(79,303		)		(305,334		)	(28,336		)	(116,572		)	(186,078		)	(72,168		)	(29,688		)	(738,176		)


For the three months ended June 30, 2014
For the three months ended September 30, 2014																			For the three months ended September 30, 2014
	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services		International			Functional Support			Total				U.S. Rig Services		Fluid Management Services			Coiled Tubing Services		Fishing and Rental Services			International			Functional Support			Total
Revenues from external customers	$	169,980	$	62,087	$	43,108		$	49,340	$	26,080		$	—		$	350,595			$	178,219	$	63,818		$	42,309	$	55,502		$	25,950		$	—		$	365,798
Operating expenses	147,019		61,129		43,690			48,537		62,926			38,334			401,635				150,082		63,960			42,293		110,917			35,206			46,594			449,052
Operating income (loss)	22,961		958		(582		)	803		(36,846		)	(38,334		)	(51,040		)		28,137		(142		)	16		(55,415		)	(9,256		)	(46,594		)	(83,254		)

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U.S. Rig Services

Revenues for our U.S. Rig Services segment decreased ~~$76.7~~$93.0 million, or ~~45.1%~~52.2%, to ~~$93.3~~$85.2 million for the three months ended ~~June~~September 30, 2015, compared to ~~$170.0~~$178.2 million for the three months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our U.S. Rig Services segment were ~~$97.4~~$390.5 million during the three months ended ~~June~~September 30, 2015, which represented ~~a decrease~~an increase of ~~$49.6~~$240.5 million, or ~~33.8%~~160.2%, compared to ~~$147.0~~$150.1 million for the same period in 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs and equipment expense as we sought to reduce our cost structure and as a result of lower activity levels.

Fluid Management Services

Revenues for our Fluid Management Services segment decreased ~~$22.9~~$28.3 million, or ~~36.9%~~44.3%, to ~~$39.2~~$35.5 million for the three months ended ~~June~~September 30, 2015, compared to ~~$62.1~~$63.8 million for the three months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our Fluid Management Services segment were ~~$39.2~~$63.9 million during the three months ended ~~June~~September 30, 2015, which represented a decrease of ~~$21.9~~$0.1 million, or ~~35.8%~~0.2%, compared to ~~$61.1~~$64.0 million for the same period in 2014. These expenses decreased primarily as a result of a decrease in equipment expense and employee compensation costs as we sought to reduce our cost structure and as a result of lower activity levels. This decrease was partially offset by impairment expense recorded in 2015.

Coiled Tubing Services

Revenues for our Coiled Tubing Services segment decreased $21.5 million, or ~~49.9%~~50.8%, to ~~$21.6~~$20.8 million for the three months ended ~~June~~September 30, 2015, compared to ~~$43.1~~$42.3 million for the three months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our Coiled Tubing Services segment were ~~$25.7~~$137.4 million during the three months ended ~~June~~September 30, 2015, which represented ~~a decrease~~an increase of ~~$18.0~~$95.1 million, or ~~41.2%~~224.9%, compared to ~~$43.7~~$42.3 million for the same period in 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs, repair and maintenance expense and fuel costs as we sought to reduce our cost structure and as a result of lower activity levels.

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Fishing and Rental Services

Revenues for our Fishing and Rental Services segment decreased ~~$21.2~~$27.9 million, or ~~43.0%~~50.2%, to ~~$28.1~~$27.6 million for the three months ended ~~June~~September 30, 2015, compared to ~~$49.3~~$55.5 million for the three months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our Fishing and Rental Services segment were ~~$34.7~~$213.7 million during the three months ended ~~June~~September 30, 2015, which represented ~~a decrease~~an increase of ~~$13.8~~$102.8 million, or ~~28.5%~~92.7%, compared to ~~$48.5~~$110.9 million for the same period in 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs, repair and maintenance expense and fuel costs as we sought to reduce our cost structure and as a result of lower activity levels.

International

Revenues for our International segment decreased ~~$10.8~~$18.3 million, or ~~41.3%~~70.4%, to ~~$15.3~~$7.7 million for the three months ended ~~June~~September 30, 2015, compared to ~~$26.1~~$26.0 million for the three months ended ~~June~~September 30, 2014. The decrease was primarily attributable to lower customer activity in ~~Mexico, Russia~~Colombia and ~~Colombia.~~the exit of operations in the Middle East and South America.

Operating expenses for our International segment ~~decreased $18.7~~increased $44.7 million, or ~~29.8%~~126.8%, to ~~$44.2~~$79.9 million for the three months ended ~~June~~September 30, 2015, compared to ~~$62.9~~$35.2 million for the three months ended ~~June~~September 30, 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs and equipment expense, primarily due to lower ~~activity, and a decrease in impairment expense.~~activity.

Functional Support

Operating expenses for Functional Support, which represent expenses associated with managing our U.S. and International reporting segments, decreased ~~$2.8~~$16.9 million, or ~~7.2%~~36.3%, to ~~$35.6~~$29.7 million ~~(18.0%~~(16.8% of consolidated revenues) for the three months ended ~~June~~September 30, 2015 compared to ~~$38.3~~$46.6 million ~~(10.9%~~(12.7% of consolidated revenues) for the same period in 2014. ~~The~~These expenses decreased primarily as a result of a decrease ~~is primarily due~~in expenses related to FCPA investigations and lower employee compensation costs as a result of reduced staffing ~~levels partially offset by increase in expenses related to FCPA investigations.~~levels.

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Consolidated Results of Operations — ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014

Revenues

Our revenues for the ~~six~~nine months ended ~~June~~September 30, 2015 decreased $~~241.4~~430.4 million, or ~~34.2%~~40.1%, to $~~465.3~~642.2 million from $~~706.7~~1,072.5 million for the ~~six~~nine months ended ~~June~~September 30, 2014, due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services. Internationally, we had lower revenue as a result of reduced customer activity in ~~Mexico,~~ Russia and ~~Colombia.~~Colombia and the exit of operations in the Middle East and South America. See “Segment Operating Results — ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014” below for a more detailed discussion of the change in our revenues.

Direct Operating Expenses

Our direct operating expenses decreased $~~157.8~~255.4 million, to $~~363.4~~537.9 million (~~78.1%~~83.8% of revenues), for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to $~~521.2~~793.3 million (~~73.7%~~74.0% of revenues) for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease is primarily related to a decrease in employee compensation costs, fuel expense and repair and maintenance expense as we sought to reduce our cost structure and as a result of lower activity levels.

Depreciation and Amortization Expense

Depreciation and amortization expense decreased $~~10.2~~15.8 million, or ~~9.8%~~10.3%, to $~~93.1~~138.4 million during the ~~six~~nine months ended ~~June~~September 30, 2015, compared to $~~103.3~~154.2 million for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease is primarily attributable to the impairment of certain fixed assets and decreases in capital expenditures and lower amortization expense due to the impairment of certain intangible assets.

General and Administrative Expenses

General and administrative expenses ~~increased~~decreased $~~7.6~~12.3 million, to $~~118.4~~163.7 million (~~25.4%~~25.5% of revenues), for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to $~~110.7~~176.0 million (~~15.7%~~16.4% of revenues) for the ~~six~~nine months ended ~~June~~September 30, 2014. The ~~increase~~decrease is primarily due to ~~higher expenses related to FCPA investigations partially offset by~~ lower employee compensation costs due to reduced staffing levels and reduction in ~~wages.~~wages partially offset by higher expenses related to FCPA investigations.

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Impairment Expense

During the ~~six~~nine months ended ~~June~~September 30, 2015, we recorded a ~~$21.4~~$582.7 million impairment of goodwill, a $45.0 million impairment of fixed assets, ~~in our Oman business unit which is included in our International reporting segment and~~ a ~~$21.7~~$4.9 million impairment of ~~goodwill in our Coiled Tubing Services segment related~~other intangible assets that are no longer being used, and a $63.8 million impairment of fixed assets to reduce the ~~finalization~~carrying value of ~~our 2014 goodwill impairment testing.~~assets held for sale to fair market value. During the ~~six~~nine months ended ~~June~~September 30, 2014, we recorded a $28.7 million impairment of goodwill and tradenames in our Russian business unit which is included in our International reporting segment and a $60.8 million impairment of goodwill and fixed assets at our Fishing and Rental Services segment.

Interest Expense, Net of Amounts Capitalized

Interest expense increased $~~3.4~~11.7 million, or ~~12.7%~~29.0%, to $~~30.4~~52.1 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to $~~27.0~~40.4 million for the same period in 2014. The increase is primarily related to increased borrowings and interest rate under the new Term Loan Facility for the ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same period in 2014 and the ~~write off~~write-off of the remaining $0.8 million of unamortized deferred financing costs related to the 2011 Credit Facility in the second quarter of 2015.

Other (Income) Loss, Net

During the ~~six~~nine months ended ~~June~~September 30, 2015, we recognized other loss, net, of $~~4.2~~10.1 million, compared to other income, net, of $~~2.8~~2.5 million for the ~~six~~nine months ended ~~June~~September 30, 2014. ~~During the quarter ended March 31, 2015, we recorded an~~A $4.0 million allowance for the collectibility of our notes receivable related to the sale of our operations in ~~Argentina.~~Argentina was recorded in the first quarter of 2015. An additional $3.8 million reserve was recorded in the third quarter of 2015. Our foreign exchange (gain) loss relates to U.S. dollar-denominated transactions in our foreign locations and fluctuations in exchange rates between local currencies and the U.S. dollar.

The following table summarizes the components of other (income) loss, net for the periods indicated:


	Six Months Ended June 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
	(in thousands)						(in thousands)
Interest income	$	(40	)	$	(48	)	$	(99	)	$	(60	)
Foreign exchange (gain) loss	1,593			(11		)
Foreign exchange loss							4,065			1,107
Allowance for collectibility of notes receivable	3,950			—			7,705			—
Other, net	(1,319		)	(2,743		)	(1,572		)	(3,501		)
Total	$	4,184		$	(2,802	)	$	10,099		$	(2,454	)

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Income Tax Benefit

We recorded an income tax benefit of ~~$62.1~~$187.8 million on a pre-tax loss of ~~$187.2~~$953.0 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to an income tax benefit of ~~$17.2~~$52.0 million on a pre-tax loss of ~~$81.3~~$178.4 million for the same period in 2014. Our effective tax rate was ~~33.2%~~19.7% for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~21.2%~~29.2% for the ~~six~~nine months ended ~~June~~September 30, 2014. Excluding the impact of non-deductible goodwill impairment expense and valuation allowances recorded against deferred tax assets in the third quarter, our effective tax rate for the nine months ended September 30, 2015 was 32.1%. Our effective tax rates for such periods differ from the U.S. statutory rate of 35% due to a number of factors, including the mix of profit and loss between domestic and international taxing jurisdictions and the impact of permanent items, ~~mainly non-deductible expenses such as fines and penalties,~~including goodwill impairment expense and expenses subject to statutorily imposed limitations such as meals and entertainment expenses, that affect book income but do not affect taxable ~~income.~~income and discrete tax adjustments, such as valuation allowances against deferred tax assets and tax expense or benefit recognized for uncertain tax positions.

Segment Operating Results — ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014

The following table shows operating results for each of our segments for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014 (in thousands):


For the six months ended June 30, 2015
For the nine months ended September 30, 2015																				For the nine months ended September 30, 2015
	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services			Fishing and Rental Services			International			Functional Support			Total				U.S. Rig Services			Fluid Management Services			Coiled Tubing Services			Fishing and Rental Services			International			Functional Support			Total
Revenues from external customers	$	214,075	$	89,933	$	52,626		$	70,832		$	37,829		$	—		$	465,295			$	299,275		$	125,452		$	73,446		$	98,461		$	45,518		$	—		$	642,152
Operating expenses	210,207		88,516		80,531			77,462			76,311			84,857			617,884				600,741			152,371			217,923			291,169			156,168			114,545			1,532,917
Operating income (loss)	3,868		1,417		(27,905		)	(6,630		)	(38,482		)	(84,857		)	(152,589		)		(301,466		)	(26,919		)	(144,477		)	(192,708		)	(110,650		)	(114,545		)	(890,765		)

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For the six months ended June 30, 2014
For the nine months ended September 30, 2014																		For the nine months ended September 30, 2014
	U.S. Rig Services		Fluid Management Services		Coiled Tubing Services		Fishing and Rental Services		International			Functional Support			Total				U.S. Rig Services		Fluid Management Services		Coiled Tubing Services		Fishing and Rental Services			International			Functional Support			Total
Revenues from external customers	$	334,731	$	123,675	$	87,603	$	102,550	$	58,177		$	—		$	706,736			$	512,950	$	187,493	$	129,912	$	158,052		$	84,127		$	—		$	1,072,534
Operating expenses	287,428		120,370		82,047		98,917		105,514			69,622			763,898				437,510		184,330		124,340		209,834			140,720			116,216			1,212,950
Operating loss	47,303		3,305		5,556		3,633		(47,337		)	(69,622		)	(57,162		)		75,440		3,163		5,572		(51,782		)	(56,593		)	(116,216		)	(140,416		)

U.S. Rig Services

Revenues for our U.S. Rig Services segment decreased ~~$120.7~~$213.7 million, or ~~36.0%~~41.7%, to ~~$214.1~~$299.3 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~$334.7~~$513.0 million for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our U.S. Rig Services segment were ~~$210.2~~$600.7 million for the ~~six~~nine months ended ~~June~~September 30, 2015, which represented an ~~decrease~~increase of ~~$77.2~~$163.2 million, or ~~26.9%~~37.3%, compared to ~~$287.4~~$437.5 million for the same period in 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs and equipment expense as we sought to reduce our cost structure and as a result of lower activity levels.

Fluid Management Services

Revenues for our Fluid Management Services segment decreased ~~$33.7~~$62.0 million, or ~~27.3%~~33.1%, to ~~$89.9~~$125.5 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~$123.7~~$187.5 million for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our Fluid Management Services segment were ~~$88.5~~$152.4 million for the ~~six~~nine months ended ~~June~~September 30, 2015, which represented a decrease of ~~$31.9~~$32.0 million, or ~~26.5%~~17.3%, compared to ~~$120.4~~$184.3 million for the same period in 2014. These expenses decreased primarily as a result of a decrease in equipment expense and employee compensation costs as we sought to reduce our cost structure and as a result of lower activity levels. This decrease was partially offset by an impairment expense recorded in 2015.

Coiled Tubing Services

Revenues for our Coiled Tubing Services segment decreased ~~$35.0~~$56.5 million, or ~~39.9%~~43.5%, to ~~$52.6~~$73.4 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~$87.6~~$129.9 million for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our Coiled Tubing Services segment were ~~$80.5~~$217.9 million for the ~~six~~nine months ended ~~June~~September 30, 2015, which represented an ~~decrease~~increase of ~~$1.5~~$93.6 million, or ~~1.8%~~75.3%, compared to ~~$82.0~~$124.3 million for the same period in 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs, repair and maintenance expense and

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fuel costs as we sought to reduce our cost structure and as a result of lower activity levels. ~~These reductions in expenses were largely offset by the $21.7 million impairment of goodwill in the first quarter of 2015.~~

Fishing and Rental Services

Revenues for our Fishing and Rental Services segment decreased ~~$31.7~~$59.6 million, or ~~30.9%~~37.7%, to ~~$70.8~~$98.5 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~$102.6~~$158.1 million for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease for this segment is primarily due to lower spending from our customers as a result of lower oil prices. These market conditions ~~result~~resulted in reduced customer activity and a reduction in the price received for our ~~services and reduced customer activity.~~services.

Operating expenses for our Fishing and Rental Services segment were ~~$77.5~~$291.2 million for the ~~six~~nine months ended ~~June~~September 30, 2015, which represented ~~a decrease~~an increase of ~~$21.5~~$81.3 million, or ~~21.7%~~38.8%, compared to ~~$98.9~~$209.8 million for the same period in 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs, repair and maintenance expense and fuel costs as we sought to reduce our cost structure and as a result of lower activity levels.

International

Revenues for our International segment decreased ~~$20.3~~$38.6 million, or ~~35.0%~~45.9%, to ~~$37.8~~$45.5 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~$58.2~~$84.1 million for the ~~six~~nine months ended ~~June~~September 30, 2014. The decrease was primarily attributable to lower customer activity in ~~Mexico,~~ Russia and ~~Colombia.~~Colombia and the exit of operations in the Middle East and South America.

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Operating expenses for our International segment ~~decreased $29.2~~increased $15.4 million, or ~~27.7%~~11.0%, to ~~$76.3~~$156.2 million for the ~~six~~nine months ended ~~June~~September 30, 2015, compared to ~~$105.5~~$140.7 million for the ~~six~~nine months ended ~~June~~September 30, 2014. These expenses ~~decreased~~increased primarily as a result of impairment expense in 2015, partially offset by a decrease in employee compensation costs and equipment expense, primarily due to lower ~~activity, and a decrease in impairment expense.~~activity.

Functional Support

Operating expenses for Functional Support, which represent expenses associated with managing our U.S. and International reporting segments, ~~increased $15.2~~decreased $1.7 million, or ~~21.9%~~1.4%, to ~~$84.9~~$114.5 million ~~(18.2%~~(17.8% of consolidated revenues) for the ~~six~~nine months ended ~~June~~September 30, 2015 compared to ~~$69.6~~$116.2 million ~~(9.9%~~(10.8% of consolidated revenues) for the same period in 2014. The ~~increase~~decrease is primarily due to ~~increased legal expense related to the FCPA investigations partially offset by~~ lower employee compensation costs due to reduced staffing ~~levels.~~levels partially offset by increased legal expense related to the FCPA investigations.

LIQUIDITY AND CAPITAL RESOURCES

Current Financial Condition and Liquidity

As of ~~June~~September 30, 2015, we had cash and cash equivalents of $~~225.5~~199.1 million. Our working capital was $~~363.4~~302.4 million as of ~~June~~September 30, 2015, compared to $191.9 million as of December 31, 2014. Our working capital increased from the prior year end primarily as a result of an increase in cash and cash equivalents related to proceeds of long-term debt. Our total outstanding debt was $~~964.2~~964.7 million, and we have no significant debt maturities until 2020. As of ~~June~~September 30, 2015, we have no borrowings outstanding and $48.2 million in committed letters of credit outstanding with borrowing capacity of ~~$44.4~~$30.5 million available subject to covenant constraints under our ABL Facility (defined below).

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Cash Flows

The following table summarizes our cash flows for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014:


	Six Months Ended June 30,						Nine Months Ended September 30,
	2015			2014			2015			2014
	(in thousands)						(in thousands)
Net cash provided by (used in) operating activities	$	(1,198	)	$	107,268		$	(20,838	)	$	126,084
Cash paid for capital expenditures	(32,675		)	(69,429		)	(38,907		)	(108,120		)
Proceeds received from sale of fixed assets	9,950			7,239			11,500			12,288
Proceeds from notes receivable	595			2,150			595			3,990
Repayments of long-term debt	—			(3,573		)	(788		)	(3,573		)
Proceeds from long-term debt	305,550			—			305,550			—
Proceeds from borrowings on revolving credit facility	130,000			115,000			130,000			220,000
Repayments on revolving credit facility	(200,000		)	(160,000		)	(200,000		)	(225,000		)
Payment of deferred financing costs	(11,072		)	—			(11,072		)	—
Other financing activities, net	(3,262		)	(3,432		)	(3,614		)	(3,479		)
Effect of exchange rates on cash	289			(81		)	(613		)	6,896
Net increase (decrease) in cash and cash equivalents	$	198,177		$	(4,858	)
Net increase in cash and cash equivalents							$	171,813		$	29,086

Cash used in operating activities was $~~1.2~~20.8 million for the ~~six~~nine months ended ~~June~~September 30, 2015 compared to cash provided by operating activities of $~~107.3~~126.1 million for the ~~six~~nine months ended ~~June~~September 30, 2014.

Cash used in investing activities was $~~22.1~~26.8 million and $~~60.0~~91.8 million for ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, respectively. Investing cash outflows during these periods consisted primarily of capital expenditures. Our capital expenditures through ~~June~~September 30, 2015 primarily relate to ~~our~~ replacement assets for our existing fleet and equipment.

Cash provided by financing activities was $~~221.2~~220.1 million for the ~~six~~nine months ended ~~June~~September 30, 2015 compared to cash used in financing activities of $~~52.0~~12.1 million for the ~~six~~nine months ended ~~June~~September 30, 2014. Overall financing cash inflows for 2015 primarily relate to proceeds from long-term debt partially offset by net payments on the revolving credit facility and repayments of long-term debt. Overall financing cash outflows for 2014 primarily relate to net payments on the revolving credit facility.

Sources of Liquidity and Capital Resources

Our sources of liquidity include our current cash and cash equivalents, availability under our ABL Facility, and internally generated cash flows from operations.

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Debt Service

We have no significant maturities of debt until 2020. Interest on our ABL Facility and Term Loan Facility is due each quarter. ~~Interest to be paid~~There are no interest payments for the remainder of 2015 ~~is approximately $23.0 million~~ related to our 2021 Notes. Principal to be paid for the remainder of 2015 is approximately ~~$1.6~~$0.8 million related to our Term Loan Facility. We expect to fund these payments from cash on hand or generated by operations. At ~~June~~September 30, 2015, our annual debt maturities for our 2021 Notes and Term Loan Facility were as follows:


Year	Principal Payments		Principal Payments
	(in thousands)		(in thousands)
2015	$	1,575	$	787
2016	3,150		3,150
2017	3,150		3,150
2018	3,150		3,150
2019 and thereafter	978,975		978,975
Total principal payments	$	990,000	$	989,212

At ~~June~~September 30, 2015, we were in compliance with all the covenants under the ABL Facility and the Term Loan Facility and the indenture governing the 2021 Notes.

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6.75% Senior Notes due 2021



Year	Percentage
2016	103.375	%
2017	102.250	%
2018	101.125	%
2019 and thereafter	100.000	%

At any time and from time to time prior to March 1, 2016, we may, at our option, redeem all or a portion of the 2021 Notes at a redemption price equal to 100% of the principal amount plus a premium with respect to the 2021 Notes plus accrued and unpaid interest to the redemption date. The premium is the excess of (i) the present value of the redemption price of 103.375 of the principal amount, plus all remaining scheduled interest payments due through March 1, 2016 discounted at the treasury rate plus 0.50% over (ii) the principal amount of the note. If we experience a change of control, subject to certain exceptions, we must give holders of the 2021 Notes the opportunity to sell to us their 2021 Notes, in whole or in part, at a purchase price equal to 101% of the aggregate principal amount, plus accrued and unpaid interest to the date of purchase.

We are subject to certain negative covenants under the Indenture. The Indenture limits our ability to, among other things:

incur additional indebtedness and issue preferred equity interests;

pay dividends or make other distributions or repurchase or redeem equity interests;

make loans and investments;

enter into sale and leaseback transactions;

sell, transfer or otherwise convey assets;

create liens;

enter into transactions with affiliates;

enter into agreements restricting subsidiaries’ ability to pay dividends;

designate future subsidiaries as unrestricted subsidiaries; and

consolidate, merge or sell all or substantially all of the applicable entities’ assets.

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These covenants are subject to certain exceptions and qualifications, and contain cross-default provisions relating to the covenants of our Facilities discussed below. Substantially all of the covenants will terminate before the 2021 Notes mature if one of two specified ratings agencies assigns the 2021 Notes an investment grade rating in the future and no events of default exist under the Indenture. As of ~~June~~September 30, 2015, the 2021 Notes were rated below investment grade. Any covenants that cease to apply to us as a result of achieving an investment grade rating will not be restored, even if the investment rating assigned to the 2021 Notes later falls below investment grade. We were in compliance with these covenants as of ~~June~~September 30, 2015.

Credit Facilities due 2020

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dividends and the sale of assets. The Facilities also contain financial covenants requiring that we maintain an asset coverage ratio of at least 1.5 to 1.0 and that liquidity, as defined in the Facilities agreements, must not be less than $100.0 million. The ABL also includes a fixed charge coverage ratio of at least 1.0 to 1.0, which is tested only if excess availability under the ABL falls below a specified threshold or upon the occurrence of certain other events. Additionally, in certain situations, we may be required to offer to prepay some principal amounts under the Term Loan Facility including 50% of our fiscal excess cash flow, as defined in the Term Loan Facility agreement. In the event of a change in control, as defined in the Term Loan Facility agreement, the Company must offer to prepay all term loans (i) at a price of 101% of the amount outstanding if, after giving effect to such change of control, the asset coverage ratio is at least 1.5 to 1.0 or (ii) at a price equal to the greater of 101% of the amount outstanding and the applicable prepayment premium provided for in the Term Loan Facility if, after giving effect to such change of control, the asset coverage ratio is less than 1.5 to 1.0.

We were in compliance with covenants of the Facilities as of ~~June~~September 30, 2015. As of ~~June~~September 30, 2015, we have no borrowings outstanding and $48.2 million of letters of credit outstanding with borrowing capacity of ~~$44.4~~$30.5 million available subject to covenant constraints under our ABL Facility.



	~~June 30, 2015~~
	~~(in thousands)~~
~~ABL Facility~~	—	%
~~Term Loan Facility~~	~~10.38~~	%



	Three Months Ended		Nine Months Ended
	September 30, 2015		September 30, 2015
	(in thousands)
ABL Facility	—	%	—	%
Term Loan Facility	10.25	%	10.28	%

Senior Secured Credit Facility

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were ~~3.14%~~zero and ~~2.88%~~3.01% for the three-month periods ended ~~June~~September 30, 2015 and ~~June~~September 30, 2014, respectively, and the weighted average interest rates on the outstanding borrowings under the 2011 Credit Facility were ~~3.15%~~3.14% and ~~2.88%~~2.92% for ~~six~~the nine months ended ~~June~~September 30, 2015 and ~~June~~September 30, 2014, respectively.

Letter of Credit Facility

Off-Balance Sheet Arrangements

At ~~June~~September 30, 2015 we did not, and we currently do not, have any off-balance sheet arrangements that have or are reasonably likely to have a material current or future effect on our financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

Liquidity Outlook and Future Capital Requirements

As of ~~June~~September 30, 2015,, we had cash and cash equivalents of ~~$225.5~~$199.1 million,, borrowing capacity of ~~$44.4~~$30.5 million, subject to covenant constraints under the ABL Facility, and no significant debt maturities until 2020. During the third quarter, we utilized existing cash balances to fund the Company’s operations as our cash flow from operations was negative. We believe that ~~our internally generated~~current sources of liquidity, including cash ~~flows from operations~~on hand and current ~~reserves of cash and cash equivalents~~availability under the ABL Facility, will be sufficient tofinance the majority of our cash requirements for operations, budgeted capital expenditures, and debt service for the next twelve ~~months.~~ months, however, given worsening conditions in the markets we participate in, the company may need to take other actions to address its liquidity. It should be noted that liquidity, as defined under our Facilities Agreements, must not be less than $100.0 million at any given time.Also, as we have historically done, we may, from time to time, access available funds under our ABL Facility to supplement our liquidity to meet cash requirements for day-to-day operations and times of peak needs throughout the year. Our planned capital expenditures, as well as any acquisitions we choose to pursue, could be financed through a combination of cash on hand, borrowings under our ABL Credit Facility and, in the case of acquisitions, equity.

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Capital Expenditures

During the ~~six~~nine months ended ~~June~~September 30, 2015, our capital expenditures totaled ~~$32.7~~$38.9 million, primarily related to the ongoing replacement to our rig service fleet, coiled tubing units, fluid transportation equipment and rental equipment. Our capital expenditure plan for 2015 contemplates spending approximately ~~$50.0~~$45.0 million, subject to market conditions. This is primarily related to equipment replacement needs, including ongoing replacement to our rig services fleet. Our capital expenditure program for 2015 is subject to market conditions, including activity levels, commodity prices, industry capacity and specific customer needs. Our focus for 2015 has been and continues to be the maximization of our current equipment fleet, but we may choose to increase our capital expenditures in 2015 to increase market share or expand our presence into a new market. We may also incur capital expenditures for strategic investments and acquisitions. We currently anticipate funding our 2015 capital expenditures through a combination of cash on hand, operating cash flow, and borrowings under our ABL Facility. Should our operating cash flows or activity levels prove to be insufficient to fund our currently planned capital spending levels, management expects it will adjust our capital spending plans accordingly. We may also incur capital expenditures for strategic investments and acquisitions.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There have been no material changes in our quantitative and qualitative disclosures about market risk from those disclosed in our 2014 Form 10-K. More detailed information concerning market risk can be found in “Item 7A. Quantitative and Qualitative Disclosures about Market Risk” in our 2014 Form 10-K.

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

As of the end of the period covered by this Quarterly Report on Form 10-Q, management performed, with the participation of our Chief Executive Officer and our Chief Financial Officer, an evaluation of the effectiveness of our disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Our disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports 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. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information is accumulated and communicated to our management, including our Chief Executive Officer and our Chief Financial Officer, to allow timely decisions regarding required disclosures. Based on this evaluation, management concluded that our disclosure controls and procedures are effective as of the end of the period covered by this report.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting during the ~~second~~third quarter of 2015 that materially affected, or were reasonably likely to materially affect, our internal control over financial reporting.

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PART II — OTHER INFORMATION


ITEM 1.	LEGAL PROCEEDINGS

We are subject to various suits and claims that have arisen in the ordinary course of business. We do not believe that the disposition of any of our ordinary course litigation will result in a material adverse effect on our consolidated financial position, results of operations or cash flows. For additional information on legal proceedings, see “Note 11. Commitments and Contingencies” in “Item 1. Financial Statements” of Part I of this report, which is incorporated herein by reference.

Between May of 2013 and June of 2014, five lawsuits (four class actions and one enforcement action) were filed in California involving alleged violations of California's wage and hour laws. In general, the lawsuits allege failure to pay wages, including overtime and minimum wages, failure to pay final wages upon employment terminations in a timely manner, failure to reimburse reasonable and necessary business expenses, failure to provide wage statements consistent with California law, and violations of the California meal and break period laws, among other claims. Two of the five cases have been consolidated in United States District Court for the Central District of California. A hearing on the class certification motion ~~is scheduled for~~was held August 10, 2015. As of October 30, 2015, no decision has been made by the court. One of the remaining cases has been stayed pending outcome of the class certification motion. The fourth case is waiting for a decision regarding whether it will move forward in California state court or in federal court. The fifth case is an enforcement action for civil penalties based on California’s Private Attorneys General Act, which is pending in California state court. We have investigated the claims in all five lawsuits, and intend to vigorously defend them. At this time, we cannot estimate any possible loss or range of loss.

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unspecified amount allegedly sustained by the Company. The Board of Directors referred the demand letter to the Special Committee. We cannot predict the outcome of this matter.

In May 2015, a class and collective action lawsuit was filed in the Southern District of Texas, Houston Division, individually and on behalf of all others similarly situated, alleging violations of the FLSA and the New Mexico Minimum Wage Act. We have answered the lawsuit and asserted affirmative defenses. Because the case is in the early stages, we cannot predict the outcome at this time. Accordingly, we cannot estimate any possible loss or range of loss of this case.


ITEM 1A.	RISK FACTORS

Reference is made to Part I, Item 1A. Risk Factors of the 2014 Form 10-K, as updated by Part II, Item 1A. Risk Factors of the Form 10-Q for the quarter ended March 31, 2015 for information concerning risk factors.

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

Issuer Purchases of Equity Securities

During the three months ended ~~June~~September 30, 2015, we repurchased the shares shown in the table below to satisfy tax withholding obligations upon the vesting of restricted stock awarded to certain of our employees:

Period
Number of
Shares Purchased

Average Price
Paid per Share(1)
April 1, 2015 to April 30, 2015 221
$ 1.86
May 1, 2015 to May 31, 2015 38,330
2.59
June 1, 2015 to June 30, 2015 768
1.74
Total 39,319
$ 2.57



Period	Number of Shares Purchased	Average Price Paid per Share(1)
July 1, 2015 to July 31, 2015	794	$	0.91
August 1, 2015 to August 31, 2015	—	—
September 1, 2015 to September 30, 2015	1,004	0.57
Total	1,798	$	0.72


(1)	The price paid per share with respect to the tax withholding repurchases was determined using the closing prices on the applicable vesting date, as quoted on the NYSE.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.


ITEM 4.	MINE SAFETY DISCLOSURES

Not applicable.


ITEM 5.	OTHER INFORMATION

None.


ITEM 6.	EXHIBITS

The Exhibit Index, which follows the signature pages to this report and is incorporated by reference herein, sets forth a list of exhibits to this report.

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SIGNATURE

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.



		KEY ENERGY SERVICES, INC. (Registrant)

Date:	~~August 3,~~November 6, 2015	By:	/s/ J. MARSHALL DODSON
			J. Marshall Dodson
			Senior Vice President and Chief Financial Officer (As duly authorized officer and Principal Financial Officer)

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EXHIBIT INDEX



Exhibit No.		Description

3.1		Articles of Restatement of Key Energy Services, Inc. (Incorporated by reference to Exhibit 3.1 of our Annual Report on Form 10-K for the fiscal year ended December 31, 2006, File No. 001-08038.)

3.2		Unanimous consent of the Board of Directors of Key Energy Services, Inc. dated January 11, 2000, limiting the designation of the additional authorized shares to common stock. (Incorporated by reference to Exhibit 3.2 of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2000, File No. 001-08038.)

3.3		~~Eighth~~Ninth Amended and Restated By-laws of Key Energy Services, Inc. as amended through ~~March 16,~~August 21, 2015. (Incorporated by reference to Exhibit 3.1 of our Current Report on Form 8-K filed on ~~March 17,~~August 24, 2015, File No. 001-08038.)

10.1†*		Letter Agreement Regarding Continued Employment Terms, effective as of August 21, 2015, between Key Energy ~~Services,~~Service, Inc. ~~2014 Equity and Cash Incentive Plan Performance Unit Award Agreement dated January 30th by and between Richard J. Alario and Key Energy Services, Inc. as revised June 13, 2015.~~

~~10.2~~†		~~Employment Agreement dated June 22, 2015 by and between Robert Drummond, Key Energy Services, Inc. and~~, Key Energy Services, LLC and Richard J. Alario (Incorporated by reference to Exhibit 10.1 ofto our Current Report on Form 8-K filed on ~~June 22,~~August 24, 2015, File No. 001-08038.)

~~10.3~~ 10.2†*		~~Loan and Security~~Transition Agreement ~~dated as of June 1, 2015, among~~between Key Energy Services, Inc. and Key Energy Services, LLC, as the borrowers, certain subsidiaries of the borrowers named as guarantors therein, the financial institutions party thereto from time to time as lenders, Bank of America, N.A., as administrative agent for the lenders, and Bank of America, N.A. and Wells Fargo Bank, National Association, as co-collateral agents for the lenders. (Incorporated by reference to Exhibit 10.1 of our Current Report on Form 8-K filed on June 2, 2015, File No. 001-08038.)

~~10.4~~		~~Term Loan and Security Agreement,~~Kim B. Clarke dated as of June 1, 2015, among Key Energy Services, Inc., as borrower, certain subsidiaries of the borrower named as guarantors therein, the financial institutions party thereto from time to time as lenders, Cortland Capital Market Services LLC, as agent for the lenders, and Merrill Lynch, Pierce, Fenner & Smith Incorporated, as sole lead arranger and sole bookrunner.(Incorporated by reference to Exhibit 10.1 of our Current Report on Form 8-K filed on June 2, 2015, File No. 001-08038.)September 30, 2015.

31.1*		Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32*		Certification of Chief Executive Officer and Chief Financial Officer pursuant to Section 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101*		Interactive Data File.



†	Indicates a management contract or compensatory plan, contract or arrangement in which any Director or any Executive Officer participates.

*	Filed herewith

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CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Three Months Ended June 30, 2015
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	185,061		$	15,118		$	(2,683	)	$	197,496
Direct operating expense	—			148,714			11,325			(1,198		)	158,841
Depreciation and amortization expense	—			43,085			2,811			—			45,896
General and administrative expense	186			48,159			3,842			(1,477		)	50,710
Impairment expense	—			—			21,352			—			21,352
Operating loss	(186		)	(54,897		)	(24,212		)	(8		)	(79,303		)
Interest expense, net of amounts capitalized	17,058			—			—			—			17,058
Other (income) loss, net	(582		)	445			(126		)	15			(248		)
Loss before income taxes	(16,662		)	(55,342		)	(24,086		)	(23		)	(96,113		)
Income tax (expense) benefit	30,756			(74		)	52			—			30,734
Net income (loss)	$	14,094		$	(55,416	)	$	(24,034	)	$	(23	)	$	(65,379	)



CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Three Months Ended June 30, 2014
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	326,835		$	30,272		$	(6,512	)	$	350,595
Direct operating expense	—			245,267			20,632			(3,016		)	262,883
Depreciation and amortization expense	—			48,702			3,482			—			52,184
General and administrative expense	242			55,459			5,623			(3,443		)	57,881
Impairment expense	—			—			28,687			—			28,687
Operating loss	(242		)	(22,593		)	(28,152		)	(53		)	(51,040		)
Interest expense, net of amounts capitalized	13,402			(1		)	25			—			13,426
Other income, net	(618		)	(572		)	(1,564		)	21			(2,733		)
Loss before income taxes	(13,026		)	(22,020		)	(26,613		)	(74		)	(61,733		)
Income tax (expense) benefit	7,977			2,094			(534		)	—			9,537
Net loss	$	(5,049	)	$	(19,926	)	$	(27,147	)	$	(74	)	$	(52,196	)

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