KEY ENERGY SERVICES INC - Quarter Report: 2014 September (Form 10-Q)

Large accelerated filer

Accelerated filer

Non-accelerated filer

¨ (Do not check if a smaller reporting company)

Smaller reporting company

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 September 30, 2014



¨	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 October 28, 2014, the number of outstanding shares of common stock of the registrant was 153,474,453.

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KEY ENERGY SERVICES, INC.

QUARTERLY REPORT ON FORM 10-Q

For the Quarter Ended September 30, 2014



Part I — Financial Information

Item 1.	Financial Statements	3

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	37

Item 4.	Controls and Procedures	37

Part II — Other Information

Item 1.	Legal Proceedings	38

Item 1A.	Risk Factors	38

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	39

Item 3.	Defaults Upon Senior Securities	39

Item 4.	Mine Safety Disclosures	39

Item 5.	Other Information	39

Item 6.	Exhibits	39

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 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 this report, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2013 and “Part II - Item 1A. Risk Factors” in our Quarterly Reports Form 10-Q for the quarters ended March 31, 2014 and June 30, 2014.

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)



	September 30, 2014			December 31, 2013
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	57,392		$	28,306
Accounts receivable, net of allowance for doubtful accounts of $2,101 and $766, respectively	294,828			348,966
Inventories	42,363			32,335
Other current assets	87,782			96,546
Total current assets	482,365			506,153
Property and equipment	2,546,087			2,606,738
Accumulated depreciation	(1,299,543		)	(1,241,092		)
Property and equipment, net	1,246,544			1,365,646
Goodwill	601,839			624,875
Other intangible assets, net	27,456			41,146
Deferred financing costs, net	11,798			13,897
Other assets	36,644			35,753
TOTAL ASSETS	$	2,406,646		$	2,587,470
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	61,145		$	58,826
Other current liabilities	156,556			169,945
Current portion of long-term debt	—			3,573
Total current liabilities	217,701			232,344
Long-term debt	758,565			763,981
Workers' compensation, vehicular and health insurance liabilities	30,972			29,944
Deferred tax liabilities	250,843			284,453
Other non-current liabilities	27,009			25,655
Commitments and contingencies
Equity:
Common stock, $0.10 par value; 200,000,000 shares authorized, 153,558,770 and 152,331,006 shares issued and outstanding	15,356			15,233
Additional paid-in capital	958,981			953,306
Accumulated other comprehensive loss	(24,425		)	(15,414		)
Retained earnings	171,644			297,968
Total equity	1,121,556			1,251,093
TOTAL LIABILITIES AND EQUITY	$	2,406,646		$	2,587,470

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						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
REVENUES	$	365,798		$	389,673		$	1,072,534		$	1,229,512
COSTS AND EXPENSES:
Direct operating expenses	272,112			268,297			793,297			854,581
Depreciation and amortization expense	50,924			56,962			154,203			169,363
General and administrative expenses	65,224			52,665			175,971			173,646
Impairment expense	60,792			—			89,479			—
Operating income (loss)	(83,254		)	11,749			(140,416		)	31,922
Interest expense, net of amounts capitalized	13,417			13,814			40,397			41,602
Other (income) loss, net	348			(85		)	(2,454		)	(878		)
Loss before income taxes	(97,019		)	(1,980		)	(178,359		)	(8,802		)
Income tax benefit (expense)	34,790			(2,717		)	52,035			147
Net loss	(62,229		)	(4,697		)	(126,324		)	(8,655		)
Income attributable to noncontrolling interest	—			151			—			595
LOSS ATTRIBUTABLE TO KEY	$	(62,229	)	$	(4,848	)	$	(126,324	)	$	(9,250	)
Loss per share attributable to Key:
Basic and diluted	$	(0.41	)	$	(0.03	)	$	(0.82	)	$	(0.06	)
Weighted average shares outstanding:
Basic and diluted	153,550			152,394			153,327			152,249

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						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
NET LOSS	$	(62,229	)	$	(4,697	)	$	(126,324	)	$	(8,655	)
Other comprehensive income (loss):
Foreign currency translation income (loss)	(7,010		)	1,018			(9,011		)	(4,348		)
COMPREHENSIVE LOSS	(69,239		)	(3,679		)	(135,335		)	(13,003		)
Comprehensive (income) loss attributable to noncontrolling interest	—			(127		)	—			96
COMPREHENSIVE LOSS ATTRIBUTABLE TO KEY	$	(69,239	)	$	(3,806	)	$	(135,335	)	$	(12,907	)

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)



	Nine Months Ended
	September 30,
	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(126,324	)	$	(8,655	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization expense	154,203			169,363
Impairment expense	89,479			—
Bad debt expense	1,484			960
Accretion of asset retirement obligations	447			454
Loss from equity method investments	221			348
Amortization of deferred financing costs and premium	1,682			2,044
Deferred income tax benefit	(30,066		)	(10,402		)
Capitalized interest	—			(469		)
(Gain) loss on disposal of assets, net	3,760			(1,445		)
Share-based compensation	9,277			11,666
Excess tax expense from share-based compensation	1,240			1,846
Changes in working capital:
Accounts receivable	51,585			20,225
Other current assets	(3,410		)	8,592
Accounts payable, accrued interest and accrued expenses	(12,050		)	(61,924		)
Share-based compensation liability awards	(578		)	1,262
Other assets and liabilities	(14,866		)	23,153
Net cash provided by operating activities	126,084			157,018
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(108,120		)	(111,021		)
Proceeds from sale of fixed assets	12,288			7,530
Proceeds from notes receivable	3,990			—
Acquisition of the 50% noncontrolling interest in Geostream	—			(14,600		)
Net cash used in investing activities	(91,842		)	(118,091		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments of long-term debt	(3,573		)	—
Repayments of capital lease obligations	—			(392		)
Proceeds from borrowings on revolving credit facility	220,000			195,000
Repayments on revolving credit facility	(225,000		)	(210,000		)
Payment of deferred financing costs	—			(69		)
Repurchases of common stock	(2,239		)	(3,169		)
Excess tax expense from share-based compensation	(1,240		)	(1,846		)
Net cash used in financing activities	(12,052		)	(20,476		)
Effect of changes in exchange rates on cash	6,896			212
Net increase in cash and cash equivalents	29,086			18,663
Cash and cash equivalents, beginning of period	28,306			45,949
Cash and cash equivalents, end of period	$	57,392		$	64,612

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 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, 2013 balance sheet was prepared from audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2013 (the “2013 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 2013 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 nine months ended September 30, 2014 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 2013 Form 10-K.

Accounting Standards Adopted or Not Yet Adopted in this Report

There are no new accounting standards that have been adopted in this report.

ASU 2014-09. In May 2014, the FASB issued ASU 2014-09, Revenue from Contract 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 is effective for interim and annual reporting periods beginning after December 15, 2016 and must be adopted using either a full retrospective method or a modified retrospective method. We are currently evaluating the standard to determine the impact of its adoption on the consolidated financial statements.

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NOTE 3. ACQUISITION OF NONCONTROLLING INTERESTS

Geostream. On October 31, 2008, we acquired a 26% interest in OOO Geostream Services Group (“Geostream”) for $17.4 million. Geostream is a limited liability company incorporated in the Russian Federation that provides a wide range of drilling, workover and reservoir engineering services. On September 1, 2009, we acquired an additional 24% interest for $16.4 million, which brought our total investment in Geostream to 50% and provided us a controlling interest with representation on Geostream's board of directors. We accounted for the second investment as a business combination achieved in stages. The results of Geostream have been included in our consolidated financial statements since the initial acquisition date, with the portion outside of our control forming a noncontrolling interest. On April 9, 2013, we completed the acquisition of the 50% noncontrolling interest in Geostream for $14.6 million. Geostream is now our wholly owned subsidiary. This acquisition of the 50% noncontrolling interest in Geostream was accounted for as an equity transaction. Therefore, our acquisition of the non-controlling interest in Geostream in the second quarter of 2013 did not result in a gain or loss.

AlMansoori Key Energy Services, LLC. On March 7, 2010, we entered into an agreement with AlMansoori Petroleum Services, LLC (“AlMansoori”) to form the joint venture AlMansoori Key Energy Services, LLC, a joint venture under the laws of Abu Dhabi, UAE. The purpose of the joint venture was to engage in conventional workover and drilling services, coiled tubing services, fishing and rental services, rig monitoring services, pipe handling services and fluids, waste treatment and handling services. Although AlMansoori held a 51% interest in the joint venture and we held a 49% interest, we held three of the five board of directors seats and a controlling financial interest. In addition, profits and losses of the joint venture were shared on equal terms and in equal amounts with AlMansoori. Because the joint venture did not have sufficient resources to carry on its activities without our financial support, we determined it to be a variable interest entity of which we were the primary beneficiary. We consolidated the entity in our financial statements. On August 5, 2013, we agreed to the dissolution of AlMansoori Key Energy Services, LLC and the acquisition of the underlying business for $5.1 million. The $5.1 million is expected to be paid in 2014 and is recorded in “Other current liabilities” in our consolidated balance sheet. The acquisition of the 51% noncontrolling interest in AlMansoori Key Energy Services, LLC was accounted for as an equity transaction and therefore did not result in a gain or loss.

NOTE 4. EQUITY

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



	COMMON STOCKHOLDERS
	Common Stock					Additional Paid-in Capital			Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interest		Total
	Number of Shares		Amount at Par			Additional Paid-in Capital			Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interest		Total
	(in thousands)
Balance at December 31, 2013	152,331		$	15,233		$	953,306		$	(15,414	)	$	297,968		$	—	$	1,251,093
Foreign currency translation	—		—			—			(9,011		)	—			—		(9,011		)
Common stock purchases	(288	)	(29		)	(2,210		)	—			—			—		(2,239		)
Share-based compensation	1,516		152			9,125			—			—			—		9,277
Excess tax expense from share-based compensation	—		—			(1,240		)	—			—			—		(1,240		)
Net loss	—		—			—			—			(126,324		)	—		(126,324		)
Balance at September 30, 2014	153,559		$	15,356		$	958,981		$	(24,425	)	$	171,644		$	—	$	1,121,556

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A reconciliation of the total carrying amount of our equity accounts for nine months ended September 30, 2013 is as follows:



	COMMON STOCKHOLDERS
	Common Stock					Additional Paid-in Capital			Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interest			Total
	Number of Shares		Amount at Par			Additional Paid-in Capital			Accumulated Other Comprehensive Loss			Retained Earnings			Noncontrolling Interest			Total
	(in thousands)
Balance at December 31, 2012	151,070		$	15,108		$	925,132		$	(6,148	)	$	319,736		$	33,504		$	1,287,332
Foreign currency translation	—		—			—			(3,657		)	—			(691		)	(4,348		)
Common stock purchases	(415	)	(42		)	(3,127		)	—			—			—			(3,169		)
Share-based compensation	1,702		170			11,496			—			—			—			11,666
Excess tax expense from share-based compensation	—		—			(1,846		)	—			—			—			(1,846		)
Acquisition of the 50% noncontrolling interest in Geostream (Note 3)	—		—			22,432			(4,350		)	—			(31,196		)	(13,114		)
Acquisition of the 51% noncontrolling interest in AlMansoori Key Energy Services, LLC (Note 3)	—		—			(2,888		)	—			—			(2,212		)	(5,100		)
Net income (loss)	—		—			—			—			(9,250		)	595			(8,655		)
Balance at September 30, 2013	152,357		$	15,236		$	951,199		$	(14,155	)	$	310,486		$	—		$	1,262,766

NOTE 5. OTHER BALANCE SHEET INFORMATION

The table below presents comparative detailed information about other current assets at September 30, 2014 and December 31, 2013:



	September 30, 2014		December 31, 2013
	(in thousands)
Other current assets:
Deferred tax assets	$	20,860	$	11,707
Prepaid current assets	21,009		28,435
Reinsurance receivable	9,548		9,113
VAT asset	20,789		21,683
Other	15,576		25,608
Total	$	87,782	$	96,546

The table below presents comparative detailed information about other non-current assets at September 30, 2014 and December 31, 2013:



	September 30, 2014		December 31, 2013
	(in thousands)
Other non-current assets:
Deferred tax assets	$	23,660	$	22,313
Reinsurance receivable	9,923		9,397
Deposits	1,449		1,533
Equity method investments	971		962
Other	641		1,548
Total	$	36,644	$	35,753

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The table below presents comparative detailed information about other current liabilities at September 30, 2014 and December 31, 2013:



	September 30, 2014		December 31, 2013
	(in thousands)
Other current liabilities:
Accrued payroll, taxes and employee benefits	$	43,750	$	34,956
Accrued operating expenditures	39,812		36,573
Income, sales, use and other taxes	30,387		37,064
Self-insurance reserve	32,105		32,129
Accrued interest	3,876		15,285
Accrued insurance premiums	1,163		8,049
Share-based compensation and other liabilities	5,463		5,889
Total	$	156,556	$	169,945

The table below presents comparative detailed information about other non-current liabilities at September 30, 2014 and December 31, 2013:



	September 30, 2014		December 31, 2013
	(in thousands)
Other non-current liabilities:
Asset retirement obligations	$	12,369	$	11,999
Environmental liabilities	5,860		6,176
Accrued rent	412		853
Accrued sales, use and other taxes	5,360		5,552
Other	3,008		1,075
Total	$	27,009	$	25,655

NOTE 6. GOODWILL AND OTHER INTANGIBLE ASSETS

The changes in the carrying amount of goodwill for the nine months ended September 30, 2014 are as follows:



	U.S.		International			Total
	(in thousands)
December 31, 2013	$	597,456	$	27,419		$	624,875
Goodwill impairment	—		(22,437		)	(22,437		)
Impact of foreign currency translation	—		(599		)	(599		)
September 30, 2014	$	597,456	$	4,383		$	601,839

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The components of our other intangible assets as of September 30, 2014 and December 31, 2013 are as follows:



	September 30, 2014			December 31, 2013
	(in thousands)
Noncompete agreements:
Gross carrying value	$	5,110		$	9,332
Accumulated amortization	(4,444		)	(7,104		)
Net carrying value	666			2,228
Patents, trademarks and tradenames:
Gross carrying value	12,612			14,039
Accumulated amortization and impairment	(5,598		)	(223		)
Net carrying value	7,014			13,816
Customer relationships and contracts:
Gross carrying value	99,750			100,271
Accumulated amortization	(84,422		)	(78,926		)
Net carrying value	15,328			21,345
Developed technology:
Gross carrying value	8,485			7,583
Accumulated amortization	(4,037		)	(3,826		)
Net carrying value	4,448			3,757
Customer Backlog:
Gross carrying value	779			779
Accumulated amortization	(779		)	(779		)
Net carrying value	—			—
Total:
Gross carrying value	126,736			132,004
Accumulated amortization and impairment	(99,280		)	(90,858		)
Net carrying value	$	27,456		$	41,146

Of our intangible assets at September 30, 2014, $6.9 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)	Remainder of 2014		2015		2016		2017		2018		2019
		(in thousands)
Noncompete agreements	2.0	$	116	$	305	$	245	$	—	$	—	$	—
Trademarks	3.7	10		40		40		40		17		—
Customer relationships and contracts	5.2	1,967		5,031		3,408		2,414		1,120		820
Developed technology	16.3	100		401		401		401		401		311
Total expected intangible asset amortization expense		$	2,193	$	5,777	$	4,094	$	2,855	$	1,538	$	1,131

Certain of our goodwill and 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 $2.6 million and $4.8 million for the three months ended September 30, 2014 and 2013, respectively, and $7.8 million and $14.5 million for the nine months ended September 30, 2014 and 2013, respectively.

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We perform an analysis of goodwill impairment on an annual basis unless an event occurs that triggers additional interim testing. Deterioration in the capital investment climate in Russia as a result of geopolitical events occurring during the second quarter of 2014 was determined to be a triggering event. This triggering event required us to perform testing for possible goodwill impairment of our Russian business reporting unit which is included in our International reporting segment. Our analysis concluded that Russia's $22.4 million of goodwill is fully impaired, and that $6.3 million of Russia's tradename intangible assets is impaired as well. We concluded that there is no impairment to Russia's other long-lived assets.

In addition, the decline in market value of our common stock in comparison to the carrying value of our assets during the third quarter of 2014 was determined to be a triggering event. This triggering event required us to perform testing for possible goodwill impairment in our U.S. Segment, and our step one testing indicated there may be an impairment in our U.S. fishing and rental business reporting unit. No impairment was indicated in our other U.S. business reporting units. Step two of the goodwill impairment testing for the fishing and rental business reporting unit was performed preliminarily during the third quarter of 2014 and, while our preliminary analysis concluded that that there was no impairment of goodwill, it did indicate that there was an impairment of fixed assets. Step two testing will be completed in the fourth quarter of 2014 and any adjustment to the amount recorded, which could differ materially, will be recorded in the fourth quarter of 2014. 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 2014 was determined to be a triggering event. This triggering event required us to perform step one of the goodwill impairment test to identify potential impairment. Our step one testing indicated potential impairment in our fishing and rental services business reporting unit 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 2014, using a discounted cash flow model to determine fair value, concluded that certain assets, primarily frac stack and well testing assets, were impaired. As a result, we recorded an estimated pre-tax charge of $60.8 million in the third quarter of 2014. Our preliminary step two testing also indicated no impairment of goodwill in our fishing and rental services business reporting unit. Step two testing will be completed in the fourth quarter of 2014 and any adjustment to the amount recorded, which may be material, will be recorded in the fourth quarter of 2014.

NOTE 8. LONG-TERM DEBT

As of September 30, 2014 and December 31, 2013, the components of our long-term debt were as follows:



	September 30, 2014		December 31, 2013
	(in thousands)
6.75% Senior Notes due 2021	$	675,000	$	675,000
8.375% Senior Notes due 2014	—		3,573
Senior Secured Credit Facility revolving loans due 2016	80,000		85,000
Net unamortized premium on debt	3,565		3,981
Total debt	758,565		767,554
Less current portion	—		(3,573		)
Long-term debt	$	758,565	$	763,981

8.375% Senior Notes due 2014

On February 25, 2014, we redeemed the $3.6 million aggregate principal amount and paid $0.1 million accrued interest of 8.375% Senior Notes due 2014 (the “2014 Notes”) pursuant to the indenture dated as of November 29, 2007 (as supplemented, the “Indenture”). The 2014 Notes were general unsecured senior obligations and were subordinate to all of our existing and future secured indebtedness. The 2014 Notes were jointly and severally guaranteed on a senior unsecured basis by certain of our existing and future domestic subsidiaries. Interest on the 2014 Notes was payable on June 1 and December 1 of each year.

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6.75% Senior Notes due 2021

We issued $475.0 million aggregate principal amount of 6.75% Senior Notes due 2021 (the “Initial 2021 Notes”) on March 4, 2011 and issued an additional $200.0 million aggregate principal amount of the 2021 Notes (the “Additional 2021 Notes” and together with the Initial 2021 Notes, the “2021 Notes”) in a private placement on March 8, 2012 under an indenture dated March 4, 2011 (the “Base Indenture”), as supplemented by a first supplemental indenture dated March 4, 2011 and amended by a further supplemental indenture dated March 8, 2012 (the “Supplemental Indenture” and, together with the Base Indenture, the “Indenture”). We used the net proceeds to repay senior secured indebtedness under our revolving bank credit facility. We capitalized $4.6 million of financing costs associated with the issuance of the 2021 Notes that will be amortized over the term of the notes.

On March 5, 2013, we completed an offer to exchange the $200.0 million in aggregate principal amount of unregistered Additional 2021 Notes for an equal principal amount of such notes registered under the Securities Act of 1933. All of the 2021 Notes are treated as a single class under the Indenture and as of the closing of the exchange offers bear the same CUSIP and ISIN numbers.

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;


•	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.

These covenants are subject to certain exceptions and qualifications, and contain cross-default provisions relating to the covenants of our 2011 Credit Facility 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 September 30, 2014, 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 September 30, 2014.

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Senior Secured Credit Facility

We are party to a $550.0 million senior secured revolving bank credit facility with JPMorgan Chase Bank, N.A., as Administrative Agent, Bank of America, N.A., as Syndication Agent, and Capital One, N.A., Wells Fargo Bank, N.A., Credit Agricole Corporate and Investment Bank and DnB NOR Bank ASA, as Co-Documentation Agent (as amended, the “2011 Credit Facility”), which is an important source of liquidity for us. The 2011 Credit Facility consists of a revolving credit facility, letter of credit sub-facility and swing line facility, all of which will mature no later than March 31, 2016.

The maximum amount that we may borrow under the facility may be subject to limitation due to the operation of the covenants contained in the facility. The 2011 Credit Facility allows us to request increases in the total commitments under the facility by up to $100.0 million in the aggregate in part or in full anytime during the term of the 2011 Credit Facility, with any such increases being subject to compliance with the restrictive covenants in the 2011 Credit Facility and in the Indenture governing our 2021 Senior Notes, as well as lender approval.

We capitalized $4.9 million of financing costs in connection with the execution of the 2011 Credit Facility and an additional $1.4 million related to a subsequent amendment that will be amortized over the term of the debt.

The interest rate per annum applicable to the 2011 Credit Facility is, 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 ranges from 225 to 300 basis points, and the applicable margin for all other loans ranges 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 equal 0.5%.

The 2011 Credit Facility contains certain financial covenants, which, among other things, limit our annual capital expenditures, restrict our ability to repurchase shares and require us to maintain certain financial ratios. The financial ratios require that:


•	our ratio of consolidated funded indebtedness to total capitalization be no greater than 45%;


•	our senior secured leverage ratio of senior secured funded debt to trailing four quarters of earnings before interest, taxes, depreciation and amortization (as calculated pursuant to the terms of the 2011 Credit Facility, “EBITDA”) be no greater than 2.00 to 1.00;


•	we maintain a collateral coverage ratio, the ratio of the aggregate book value of the collateral to the amount of the total commitments, as of the last day of any fiscal quarter of at least 2:00 to 1:00;


•	we maintain a consolidated interest coverage ratio of trailing four quarters EBITDA to interest expense of at least 3.00 to 1.00; and


•	we limit our capital expenditures and investments in foreign subsidiaries to $250.0 million per fiscal year, if the consolidated total leverage ratio exceeds 3.00 to 1.00.

We were in compliance with covenants of the 2011 Credit Facility as of September 30, 2014. We may prepay the 2011 Credit Facility in whole or in part at any time without premium or penalty, subject to certain reimbursements to the lenders for breakage and redeployment costs. As of September 30, 2014, we had borrowings of $80.0 million outstanding under the revolving credit facility, $49.1 million of letters of credit outstanding with borrowing capacity of $162.2 million available considering covenant constraints under our 2011 Credit Facility. The weighted average interest rates on the outstanding borrowings under the 2011 Credit Facility were 3.01% and 2.81% for the three-month periods ended September 30, 2014 and September 30, 2013, respectively, and the weighted average interest rates on the outstanding borrowings under the 2011 Credit Facility were 2.92% and 2.72% for nine months ended September 30, 2014 and September 30, 2013, 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 September 30, 2014, $3.0 million of letters of credit were outstanding under the facility.

NOTE 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 September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
	(in thousands)
Interest income	$	(12	)	$	(34	)	$	(60	)	$	(129	)
Foreign exchange (gain) loss	1,118			(60		)	1,107			413
Other, net	(758		)	9			(3,501		)	(1,162		)
Total	$	348		$	(85	)	$	(2,454	)	$	(878	)

NOTE 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 September 30, 2014 and 2013 were 35.9% and 137.2%, respectively, and 29.2% and 1.7% for the nine months ended September 30, 2014 and 2013, respectively. Excluding the impact of non-deductible goodwill and tradename impairment expense, our effective tax rates for the three month and nine month periods ended September 30, 2014, were 35.9% and 34.8%, 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 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, and expenses subject to statutorily imposed limitations such as meals and entertainment expenses, plus the impact of state income taxes.

As of September 30, 2014 and December 31, 2013, we had $0.9 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 and a tax benefit of $0.1 million for the three months ended September 30, 2014 and 2013, respectively, related to these items. We have substantially concluded all U.S. federal and state tax matters through the year ended December 31, 2009.

We record interest and penalties related to unrecognized tax benefits as income tax expense. We have accrued a liability of $0.1 million and $0.4 million for the payment of interest and penalties as of September 30, 2014 and December 31, 2013, respectively. We believe that it is reasonably possible that $0.4 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 nine months ended September 30, 2014 and 2013.

NOTE 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 $0.1 million of other liabilities related to litigation that is deemed probable and reasonably estimated as of September 30, 2014. 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.

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

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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. We intend to vigorously investigate and defend these actions. Because these cases are in relatively early stages, and we have not yet briefed class certification issues, we cannot predict the outcome of these lawsuits at this time. Accordingly, we cannot estimate any possible loss or range of loss.

As previously disclosed, a special committee of our Board of Directors is investigating possible violations of the U.S. Foreign Corrupt Practices Act (“FCPA”) involving business activities of our operations in Russia and 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. The special committee’s investigations, which also include a review of certain aspects of the Company’s operations in Colombia, as well as our other international locations, are ongoing. We are fully cooperating with investigations by the SEC and the Department of Justice (“DOJ”). At this time we are unable to predict the ultimate resolution of these matters with these agencies and, accordingly, cannot 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 Exchange Act. The lawsuits are 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. Both lawsuits allege that, during the period July 25, 2013 to July 17, 2014, the defendants failed to disclose (1) that the Company’s production for Petróleos Mexicanos (“Pemex”) was in decline; (2) that the Company engaged in improper conduct related to its operations in Russia; and (3) that the Company’s business practices in Russia were in violation of the FCPA. Because these cases are in early stages, we cannot predict the outcome of these lawsuits 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 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 is reviewing the demand letter. We cannot predict the outcome of this matter.

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 September 30, 2014 and December 31, 2013, we have recorded $63.1 million and $62.1 million, respectively, of self-insurance reserves related to workers’ compensation, vehicular liabilities and general liability claims. Partially offsetting these liabilities, we had $19.5 million and $18.5 million of insurance receivables as of September 30, 2014 and December 31, 2013, 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 September 30, 2014 and December 31, 2013, we have recorded $5.9 million and $6.2 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.

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NOTE 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						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
	(in thousands, except per share amounts)
Basic and Diluted EPS Calculation:
Numerator
Loss attributable to Key	$	(62,229	)	$	(4,848	)	$	(126,324	)	$	(9,250	)
Denominator
Weighted average shares outstanding	$	153,550		$	152,394		$	153,327		152,249
Basic and diluted loss per share attributable to Key	$	(0.41	)	$	(0.03	)	$	(0.82	)	$	(0.06	)

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 months ended September 30, 2014 exclude the potential exercise of 1.3 million stock options and 0.3 million SARs and for the nine months ended September 30, 2014 exclude the potential exercise of 1.4 million stock options and 0.3 million SARs as they would be anti-dilutive given the net loss attributable to Key. The diluted earnings per share calculations for the three months ended September 30, 2013 exclude the potential exercise of 1.6 million stock options and 0.3 million SARs and for the nine months ended September 30, 2013 exclude the potential exercise of 1.7 million stock options and 0.3 million SARs as they would be anti-dilutive given the net loss attributable to Key. No events occurred after September 30, 2014 that would materially affect the number of weighted average shares outstanding.

NOTE 13. SHARE-BASED COMPENSATION

We recognized employee share-based compensation expense of less than $0.1 million and $3.0 million during the three months ended September 30, 2014 and 2013, respectively, and the related income tax expense recognized was less than $0.1 million and $1.1 million for the same periods. We recognized employee share-based compensation expense of $7.1 million and $11.2 million during the nine months ended September 30, 2014 and 2013, respectively, and the related income tax expense recognized was $2.3 million and $4.1 million, respectively, for the same period. We did not capitalize any share-based compensation during the three and nine months ended September 30, 2014 and 2013.

The unrecognized compensation cost related to our unvested restricted stock as of September 30, 2014 is estimated to be $11.0 million and is expected to be recognized over a weighted-average period of 1.1 years. We do not have unrecognized cost related to our unvested stock options as of September 30, 2014. No phantom stock was outstanding as of September 30, 2014.

During May 2014, we issued 197,865 shares of common stock 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 shares vested immediately and we recognized $1.6 million of expense related to these awards. Additionally, during May 2013, we recognized $1.8 million of expense related to similar awards.

On January 30, 2014, the Compensation Committee of the Board of Directors adopted the 2014 Performance Unit Plan (the “2014 PU Plan”) and granted performance units pursuant to the Performance Award Agreement (“2012 PU Award Agreement”) under the Key Energy Services, Inc. 2012 Equity and Cash Incentive Plan (the “2012 Plan”). We believe that the 2014 PU Plan and 2012 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 2014, we issued 0.5 million performance units to our executive officers under the 2012 Plan with such material terms as set forth in the 2012 PU Award Agreement. In February 2014, we issued 0.1 million performance units to certain other employees under the 2014 PU Plan. The performance units are measured based on two performance periods from January 1, 2014 to December 31, 2014 and from January 1, 2015 to December 31, 2015. One half of the performance units are

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measured based on the first performance period, and the other half are measured based on the second performance period. The number of performance units that may be earned by a participant is determined at the end of each 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	Percentile Ranking in Peer Group		Performance Units Earned as a Percentage of Target
First	100	%	200	%
Second	91	%	180	%
Third	82	%	160	%
Fourth	73	%	140	%
Fifth	64	%	120	%
Sixth	55	%	100	%
Seventh	45	%	75	%
Eighth	36	%	50	%
Ninth	27	%	25	%
Tenth	18	%	0	%
Eleventh	9	%	0	%
Twelfth	0	%	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 September 30, 2014, the fair value of outstanding performance units was $1.4 million, and is being accreted to compensation expense over the vesting terms of the awards. As of September 30, 2014, the unrecognized compensation cost related to our unvested performance units is estimated to be $0.9 million and is expected to be recognized over a weighted-average period of 1.2 years.

NOTE 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 $8.1 million and $12.0 million for the three months ended September 30, 2014 and 2013, respectively, and $26.2 million for each of the nine months ended September 30, 2014 and 2013. Receivables outstanding from Anadarko were approximately $3.5 million and $4.9 million as of September 30, 2014 and December 31, 2013, respectively. Transactions with Anadarko for our services are made on terms consistent with other customers.

NOTE 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 September 30, 2014 and December 31, 2013.

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.



	September 30, 2014				December 31, 2013
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(in thousands)
Financial assets:
Notes receivable - Argentina operations sale	$	8,365	$	8,365	$	12,355	$	12,355
Financial liabilities:
6.75% Senior Notes	$	675,000	$	658,058	$	675,000	$	690,390
8.375% Senior Notes	—		—		3,573		3,627
Credit Facility revolving loans	80,000		80,000		85,000		85,000

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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.

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 September 30, 2014 was $675.0 million, and the fair value was $658.1 million (97.5% of carrying value).

8.375% Senior Notes due 2014. At December 31, 2013 the fair value of our 2014 Notes was based upon the quoted market prices for those securities as of the dates indicated. These notes were redeemed in February 2014.

Credit Facility Revolving Loans. Because of their variable interest rates, the fair values of the revolving loans borrowed under our 2011 Credit Facility approximate their carrying values. The carrying and fair values of these loans as of September 30, 2014 were $80.0 million.

NOTE 16. SEGMENT INFORMATION

Our operating segments are U.S. and International. We also have a “Functional Support” segment associated with managing each of our reportable operating segments. Our domestic rig services, fluid management services, fishing and rental services, and coiled tubing services are aggregated within our U.S. reportable segment. Our international rig services business and our Canadian technology development group are aggregated within our International reportable segment. We evaluate the performance of our operating segments based on revenue and income measures. All inter-segment sales pricing is based on current market conditions. The following is a description of the segments:

U.S. Segment

Rig-Based Services

Our rig-based 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.

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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.

Fishing and Rental Services

We offer a full line of 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.

International Segment

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, project management and consulting services. Our work in Mexico also requires us to provide third party services that vary in scope by project.

In the Middle East, we operate in the Kingdom of Bahrain and Oman. On August 5, 2013, we agreed to the dissolution of AlMansoori Key Energy Services, LLC, a joint venture formed under the laws of Abu Dhabi, UAE, and the acquisition of the underlying business for $5.1 million. See “Note 3. Acquisition of Noncontrolling Interests” for further discussion.

Our Russian operations provide drilling, workover, and reservoir engineering services. On April 9, 2013, we completed the acquisition of the 50% noncontrolling interest in Geostream, a limited liability company incorporated in the Russian Federation, for $14.6 million. We now own 100% of Geostream. See “Note 3. Acquisition of Noncontrolling Interests” for further discussion.

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.

Functional Support Segment

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

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Financial Summary

The following tables set forth our unaudited segment information as of and for the three and nine months ended September 30, 2014 and 2013 (in thousands):



As of and for the three months ended September 30, 2014
	U.S.			International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	339,848		$	25,950		$	—		$	—		$	365,798
Intersegment revenues	(396		)	2,343			361			(2,308		)	—
Depreciation and amortization	40,357			7,689			2,878			—			50,924
Impairment expense	60,792			—			—			—			60,792
Other operating expenses	266,103			27,517			43,716			—			337,336
Operating loss	(27,404		)	(9,256		)	(46,594		)	—			(83,254		)
Interest expense, net of amounts capitalized	—			1			13,416			—			13,417
Income (loss) before income taxes	(27,047		)	(10,274		)	(59,698		)	—			(97,019		)
Long-lived assets(1)	1,551,120			260,706			274,946			(162,491		)	1,924,281
Total assets	2,924,255			415,678			(430,217		)	(503,070		)	2,406,646
Capital expenditures, excluding acquisitions	36,156			831			1,704			—			38,691



As of and for the three months ended September 30, 2013
	U.S.		International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	345,115	$	44,558		$	—		$	—		$	389,673
Intersegment revenues	272		1,788			1,439			(3,499		)	—
Depreciation and amortization	45,551		8,440			2,971			—			56,962
Other operating expenses	247,567		43,430			29,965			—			320,962
Operating income (loss)	51,997		(7,312		)	(32,936		)	—			11,749
Interest expense, net of amounts capitalized	—		—			13,814			—			13,814
Income (loss) before income taxes	52,042		(7,336		)	(46,686		)	—			(1,980		)
Long-lived assets(1)	1,646,396		327,328			302,825			(193,919		)	2,082,630
Total assets	2,740,094		525,472			(72,943		)	(508,576		)	2,684,047
Capital expenditures, excluding acquisitions	29,443		2,290			6,711			—			38,444



As of and for the nine months ended September 30, 2014
	U.S.			International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	988,407		$	84,127		$	—		$	—		$	1,072,534
Intersegment revenues	38			7,111			1,446			(8,595		)	—
Depreciation and amortization	122,001			23,388			8,814			—			154,203
Impairment expense	60,792			28,687			—			—			89,479
Other operating expenses	773,221			88,645			107,402			—			969,268
Operating income (loss)	32,393			(56,593		)	(116,216		)	—			(140,416		)
Interest expense, net of amounts capitalized	(1		)	29			40,369			—			40,397
Income (loss) before income taxes	34,667			(57,511		)	(155,515		)	—			(178,359		)
Long-lived assets(1)	1,551,120			260,706			274,946			(162,491		)	1,924,281
Total assets	2,924,255			415,678			(430,217		)	(503,070		)	2,406,646
Capital expenditures, excluding acquisitions	96,462			4,501			7,157			—			108,120

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As of and for the nine months ended September 30, 2013
	U.S.		International			Functional Support(2)			Reconciling Eliminations			Total
Revenues from external customers	$	1,052,885	$	176,627		$	—		$	—		$	1,229,512
Intersegment revenues	8,734		5,983			1,586			(16,303		)	—
Depreciation and amortization	137,825		22,403			9,135			—			169,363
Other operating expenses	769,695		160,668			97,864			—			1,028,227
Operating income (loss)	145,365		(6,444		)	(106,999		)	—			31,922
Interest expense, net of amounts capitalized	1		64			41,537			—			41,602
Income (loss) before income taxes	145,461		(6,042		)	(148,221		)	—			(8,802		)
Long-lived assets(1)	1,646,396		327,328			302,825			(193,919		)	2,082,630
Total assets	2,740,094		525,472			(72,943		)	(508,576		)	2,684,047
Capital expenditures, excluding acquisitions	79,412		15,453			16,156			—			111,021


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


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

NOTE 17. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

Our 2021 Notes 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
	September 30, 2014
	Parent Company		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Assets:
Current assets	$	64,414	$	356,406	$	61,545		$	—		$	482,365
Property and equipment, net	—		1,136,242		110,302			—			1,246,544
Goodwill	—		597,458		4,381			—			601,839
Deferred financing costs, net	11,798		—		—			—			11,798
Intercompany notes and accounts receivable and investment in subsidiaries	3,227,598		1,420,405		38,537			(4,686,540		)	—
Other assets	—		51,635		12,465			—			64,100
TOTAL ASSETS	$	3,303,810	$	3,562,146	$	227,230		$	(4,686,540	)	$	2,406,646
Liabilities and equity:
Current liabilities	$	11,456	$	179,813	$	26,432		$	—		$	217,701
Long-term debt and capital leases, less current portion	758,565		—		—			—			758,565
Intercompany notes and accounts payable	1,162,648		2,690,370		123,954			(3,976,972		)	—
Deferred tax liabilities	248,414		4,570		(2,141		)	—			250,843
Other long-term liabilities	1,188		56,612		181			—			57,981
Equity	1,121,539		630,781		78,804			(709,568		)	1,121,556
TOTAL LIABILITIES AND EQUITY	$	3,303,810	$	3,562,146	$	227,230		$	(4,686,540	)	$	2,406,646

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CONDENSED CONSOLIDATING BALANCE SHEETS

	December 31, 2013
	Parent Company		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Assets:
Current assets	$	50,321	$	398,188	$	57,644		$	—		$	506,153
Property and equipment, net	—		1,244,216		121,430			—			1,365,646
Goodwill	—		597,457		27,418			—			624,875
Deferred financing costs, net	13,897		—		—			—			13,897
Intercompany notes and accounts receivable and investment in subsidiaries	3,421,607		1,364,174		12,939			(4,798,720		)	—
Other assets	—		34,278		42,621			—			76,899
TOTAL ASSETS	$	3,485,825	$	3,638,313	$	262,052		$	(4,798,720	)	$	2,587,470
Liabilities and equity:
Current liabilities	$	26,097	$	182,497	$	23,750		$	—		$	232,344
Long-term debt and capital leases, less current portion	763,981		—		—			—			763,981
Intercompany notes and accounts payable	1,162,648		2,667,943		97,050			(3,927,641		)	—
Deferred tax liabilities	280,828		4,643		(1,819		)	801			284,453
Other long-term liabilities	1,195		54,486		(82		)	—			55,599
Equity	1,251,076		728,744		143,153			(871,880		)	1,251,093
TOTAL LIABILITIES AND EQUITY	$	3,485,825	$	3,638,313	$	262,052		$	(4,798,720	)	$	2,587,470



CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Three Months Ended September 30, 2014
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	340,496		$	30,163		$	(4,861	)	$	365,798
Direct operating expense	—			252,747			21,115			(1,750		)	272,112
Depreciation and amortization expense	—			47,451			3,473			—			50,924
General and administrative expense	231			62,660			5,391			(3,058		)	65,224
Impairment expense	—			60,792			—			—			60,792
Operating income (loss)	(231		)	(83,154		)	184			(53		)	(83,254		)
Interest expense, net of amounts capitalized	13,415			—			2			—			13,417
Other (income) loss, net	(430		)	(18		)	798			(2		)	348
Loss before income taxes	(13,216		)	(83,136		)	(616		)	(51		)	(97,019		)
Income tax benefit	32,158			2,301			331			—			34,790
Net income (loss)	18,942			(80,835		)	(285		)	(51		)	(62,229		)
Income attributable to noncontrolling interest	—			—			—			—			—
INCOME (LOSS) ATTRIBUTABLE TO KEY	$	18,942		$	(80,835	)	$	(285	)	$	(51	)	$	(62,229	)

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CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Three Months Ended September 30, 2013
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	362,733		$	36,264		$	(9,324	)	$	389,673
Direct operating expense	—			248,712			26,121			(6,536		)	268,297
Depreciation and amortization expense	—			53,758			3,204			—			56,962
General and administrative expense	282			48,437			6,906			(2,960		)	52,665
Operating income (loss)	(282		)	11,826			33			172			11,749
Interest expense, net of amounts capitalized	13,992			(177		)	(1		)	—			13,814
Other (income) loss, net	(936		)	255			(351		)	947			(85		)
Income (loss) before income taxes	(13,338		)	11,748			385			(775		)	(1,980		)
Income tax (expense) benefit	(5,973		)	2,961			295			—			(2,717		)
Net income (loss)	(19,311		)	14,709			680			(775		)	(4,697		)
Income attributable to noncontrolling interest	—			—			151			—			151
INCOME (LOSS) ATTRIBUTABLE TO KEY	$	(19,311	)	$	14,709		$	529		$	(775	)	$	(4,848	)



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		)
Income attributable to noncontrolling interest	—			—			—			—			—
INCOME (LOSS) ATTRIBUTABLE TO KEY	$	3,782		$	(99,829	)	$	(30,232	)	$	(45	)	$	(126,324	)

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CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
	Nine Months Ended September 30, 2013
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries		Eliminations			Consolidated
	(in thousands)
Revenues	$	—		$	1,157,964		$	124,561	$	(53,013	)	$	1,229,512
Direct operating expense	—			807,942			89,241		(42,602		)	854,581
Depreciation and amortization expense	—			161,348			8,015		—			169,363
General and administrative expense	798			158,801			25,207		(11,160		)	173,646
Operating income (loss)	(798		)	29,873			2,098		749			31,922
Interest expense, net of amounts capitalized	42,007			(468		)	63		—			41,602
Other (income) loss, net	(2,745		)	(991		)	387		2,471			(878		)
Income (loss) before income taxes	(40,060		)	31,332			1,648		(1,722		)	(8,802		)
Income tax (expense) benefit	(8,356		)	8,232			271		—			147
Net income (loss)	(48,416		)	39,564			1,919		(1,722		)	(8,655		)
Income attributable to noncontrolling interest	—			—			595		—			595
INCOME (LOSS) ATTRIBUTABLE TO KEY	$	(48,416	)	$	39,564		$	1,324	$	(1,722	)	$	(9,250	)



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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CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS
	Nine Months Ended September 30, 2013
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
Net cash provided by operating activities	$	—		$	153,757		$	3,261		$	—		$	157,018
Cash flows from investing activities:
Capital expenditures	—			(106,800		)	(4,221		)	—			(111,021		)
Acquisition of the 50% noncontrolling interest in Geostream	—			(14,600		)	—			—			(14,600		)
Intercompany notes and accounts	—			(40,620		)	—			40,620			—
Other investing activities, net	—			7,530			—			—			7,530
Net cash used in investing activities	—			(154,490		)	(4,221		)	40,620			(118,091		)
Cash flows from financing activities:
Repayment of capital lease obligations	—			(392		)	—			—			(392		)
Proceeds from borrowings on revolving credit facility	195,000			—			—			—			195,000
Repayments on revolving credit facility	(210,000		)	—			—			—			(210,000		)
Payment of deferred financing costs	(69		)	—			—			—			(69		)
Repurchases of common stock	(3,169		)	—			—			—			(3,169		)
Intercompany notes and accounts	40,620			—			—			(40,620		)	—
Other financing activities, net	(1,846		)	—			—			—			(1,846		)
Net cash provided by (used in) financing activities	20,536			(392		)	—			(40,620		)	(20,476		)
Effect of changes in exchange rates on cash	—			—			212			—			212
Net increase (decrease) in cash and cash equivalents	20,536			(1,125		)	(748		)	—			18,663
Cash and cash equivalents at beginning of period	39,617			1,601			4,731			—			45,949
Cash and cash equivalents at end of period	$	60,153		$	476		$	3,983		$	—		$	64,612

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

OVERVIEW

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 three and nine months ended September 30, 2014 and 2013, included elsewhere herein, and the audited consolidated financial statements and notes thereto included in our 2013 Form 10-K.

We operate in two business segments; U.S. and International. We also have a “Functional Support” segment associated with managing our U.S. and International business segments. See “Note 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)
2014:
First Quarter	$	98.68	$	5.18	1,779
Second Quarter	$	103.35	$	4.61	1,796
Third Quarter	$	97.87	$	3.96	1,842

2013:
First Quarter	$	94.33	$	3.49	1,706
Second Quarter	$	94.05	$	4.02	1,710
Third Quarter	$	105.83	$	3.55	1,709
Fourth Quarter	$	97.50	$	3.84	1,697


(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 2013 through the third quarter of 2014:



	Rig Hours			Trucking Hours	Key’s U.S. Working Days(1)
2014:	U.S.	International	Total
First Quarter	347,047	46,090	393,137	481,353	63
Second Quarter	355,219	33,758	388,977	493,494	63
Third Quarter	365,891	34,603	400,494	506,486	64
Total 2014	1,068,157	114,451	1,182,608	1,481,333	190

2013:
First Quarter	337,714	114,103	451,817	580,862	62
Second Quarter	365,956	65,280	431,236	559,584	64
Third Quarter	360,112	55,105	415,217	524,513	64
Fourth Quarter	343,626	46,553	390,179	507,636	62
Total 2013	1,407,408	281,041	1,688,449	2,172,595	252


(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 September 30, 2014

Our core businesses depend on our customers' willingness to make expenditures to produce, develop and explore for 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.

Third quarter 2014 U.S. revenues increased approximately 5% compared to the second quarter of 2014 primarily related to increased rig hours compared to the prior quarter. While activity in California continued to decline due to customer spending decisions, increased activity in our other markets helped offset this decline. Operating income margins improved as the increase in rig activity helped overall U.S. margins, though this segment continued to be burdened by costs associated with rig mobilization, primarily from Mexico to the U.S., and expenses incurred in connection with the FCPA investigations.

Internationally, third quarter revenues were effectively flat compared to the second of quarter 2014. Excluding second quarter impairment of goodwill and other assets, operating income margins were also flat for the same periods.

Market Outlook

We continue to position Key to benefit from improving activity in many of our core markets through balanced service offerings across the wells’ life, giving Key exposure to unconventional horizontal well and legacy vertical well activities. We believe that the high value service we provide across the well life cycle yields many opportunities for Key.

We expect our U.S. businesses to experience normal levels of seasonality, consistent with what we have experienced in the past, which will likely result in a decrease in revenue in the fourth quarter. Extended holiday slowdowns, fewer daylight hours and inclement weather will have a negative impact on our activity levels, particularly in our production-driven businesses. We continue to focus on our completion-driven businesses to enact changes and drive improvements, though we will likely see end-of-year slowdowns in these businesses as well.

Internationally, we have now begun work under the new well services contract with Pemex. Work under the contract commenced during October 2014 and has an initial value of approximately $48 million over a two year period with a potential extension of one year and a maximum increase of 25% of contract value. The contract scope includes rigs, coil, nitrogen, wireline and additional third party services. We are encouraged by this development and are focused on execution under this contract and pursuing additional opportunities in Mexico.

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RESULTS OF OPERATIONS

The following table shows our consolidated results of operations for the three and nine months ended September 30, 2014 and 2013, respectively (in thousands):



	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2014			2013			2014			2013
REVENUES	$	365,798		$	389,673		$	1,072,534		$	1,229,512
COSTS AND EXPENSES:
Direct operating expenses	272,112			268,297			793,297			854,581
Depreciation and amortization expense	50,924			56,962			154,203			169,363
General and administrative expenses	65,224			52,665			175,971			173,646
Impairment expense	60,792			—			89,479			—
Operating income (loss)	(83,254		)	11,749			(140,416		)	31,922
Interest expense, net of amounts capitalized	13,417			13,814			40,397			41,602
Other (income) loss, net	348			(85		)	(2,454		)	(878		)
Loss before income taxes	(97,019		)	(1,980		)	(178,359		)	(8,802		)
Income tax benefit (expense)	34,790			(2,717		)	52,035			147
Net loss	(62,229		)	(4,697		)	(126,324		)	(8,655		)
Income attributable to noncontrolling interest	—			151			—			595
LOSS ATTRIBUTABLE TO KEY	$	(62,229	)	$	(4,848	)	$	(126,324	)	$	(9,250	)

Consolidated Results of Operations — Three Months Ended September 30, 2014 and 2013

Revenues

Our revenues for the three months ended September 30, 2014 decreased $23.9 million, or 6.1%, to $365.8 million from $389.7 million for the three months ended September 30, 2013, due to overall lower activity in the U.S. as a result of competitive pressure and reduced customer activity. Internationally, we had lower revenue as a result of reduced customer activity in Mexico. See “Segment Operating Results — Three Months Ended September 30, 2014 and 2013” below for a more detailed discussion of the change in our revenues.

Direct Operating Expenses

Our direct operating expenses increased $3.8 million, to $272.1 million (74.4% of revenues), for the three months ended September 30, 2014, compared to $268.3 million (68.9% of revenues) for the three months ended September 30, 2013. The increase is primarily related an increase in employee benefit costs and repair and maintenance expense.

Depreciation and Amortization Expense

Depreciation and amortization expense decreased $6.0 million, or 10.6%, to $50.9 million during the three months ended September 30, 2014, compared to $57.0 million for the three months ended September 30, 2013. The decrease is primarily attributable to decreases in capital expenditures and amortization of intangible assets.

General and Administrative Expenses

General and administrative expenses increased $12.6 million, to $65.2 million (17.8% of revenues), for the three months ended September 30, 2014, compared to $52.7 million (13.5% of revenues) for the three months ended September 30, 2013. The increase is primarily due to higher legal expense related to FCPA investigations, which totaled $16.1 million for the quarter. We expect costs to continue over the course of the investigations. The FCPA investigation expense was partially offset by lower employee compensation costs due to reduced staffing levels.

Impairment Expense

During the three months ended September 30, 2014, we recorded a $60.8 million impairment of fixed assets at our fishing and rental services business reporting unit which is included in our U.S. reporting segment. No impairments were recorded in 2013.

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Interest Expense, Net of Amounts Capitalized

Interest expense decreased $0.4 million, or 2.9%, to $13.4 million for the three months ended September 30, 2014, compared to $13.8 million for the same period in 2013. The decrease is primarily related to reduced borrowings under the revolving credit facility for the three months ended September 30, 2014 compared to the same period in 2013.

Other (Income) Loss, Net

During the quarter ended September 30, 2014, we recognized other loss, net, of $0.3 million, compared to other income, net, of $0.1 million for the quarter ended September 30, 2013. 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 September 30,
	2014			2013
	(in thousands)
Interest income	$	(12	)	$	(34	)
Foreign exchange (gain) loss	1,118			(60		)
Other, net	(758		)	9
Total	$	348		$	(85	)

Income Tax Benefit (Expense)

We recorded an income tax benefit of $34.8 million on a pre-tax loss of $97.0 million in the three months ended September 30, 2014, compared to an income tax expense of $2.7 million on a pre-tax loss of $2.0 million in the three months ended September 30, 2013. Our effective tax rate was 35.9% for the three months ended September 30, 2014, compared to 137.2% for the three months ended September 30, 2013. 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, such as goodwill impairment expense, that affect book income but do not affect taxable income.

Noncontrolling Interests

We have no noncontrolling interest holders in 2014. For the three months ended September 30, 2013, we allocated $0.2 million associated with the income incurred by our joint ventures to the noncontrolling interests holders of these ventures.

Segment Operating Results — Three Months Ended September 30, 2014 and 2013

The following table shows operating results for each of our segments for the three months ended September 30, 2014 and 2013 (in thousands):



For the three months ended September 30, 2014
	U.S.			International			Functional Support			Total
Revenues from external customers	$	339,848		$	25,950		$	—		$	365,798
Operating expenses	367,252			35,206			46,594			449,052
Operating income (loss)	(27,404		)	(9,256		)	(46,594		)	(83,254		)



For the three months ended September 30, 2013
	U.S.		International			Functional Support			Total
Revenues from external customers	$	345,115	$	44,558		$	—		$	389,673
Operating expenses	293,118		51,870			32,936			377,924
Operating income (loss)	51,997		(7,312		)	(32,936		)	11,749

U.S.

Revenues for our U.S. segment decreased $5.3 million, or 1.5%, to $339.8 million for the three months ended September 30, 2014, compared to $345.1 million for the three months ended September 30, 2013. The decrease for this segment is primarily due to competitive pressures impacting our coiled tubing, fluid management and fishing and rental services and reduced customer activity in our California rig-based services.

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Operating expenses for our U.S. segment were $367.3 million during the three months ended September 30, 2014, which represented a increase of $74.1 million, or 25.3%, compared to $293.1 million for the same period in 2013. These expenses increased primarily as a result of the impairment of fixed assets in our fishing and rental services business reporting unit and an increase in employee compensation and benefit costs and repair and maintenance expense.

International

Revenues for our International segment decreased $18.6 million, or 41.8%, to $26.0 million for the three months ended September 30, 2014, compared to $44.6 million for the three months ended September 30, 2013. The decrease was primarily attributable to lower customer activity in Mexico.

Operating expenses for our International segment decreased $16.7 million, or 32.1%, to $35.2 million for the three months ended September 30, 2014, compared to $51.9 million for the three months ended September 30, 2013. These expenses decreased as a direct result of lower customer activity in Mexico.

Functional Support

Operating expenses for Functional Support, which represent expenses associated with managing our U.S. and International reporting segments, increased $13.7 million, or 41.5%, to $46.6 million (12.7% of consolidated revenues) for the three months ended September 30, 2014 compared to $32.9 million (8.5% of consolidated revenues) for the same period in 2013. The increase is primarily due to increased legal expense related to the FCPA investigations, partially offset by lower employee compensation and benefit costs.

Consolidated Results of Operations — Nine Months Ended September 30, 2014 and 2013

Revenues

Our revenues for the nine months ended September 30, 2014 decreased $157.0 million, or 12.8%, to $1.1 billion from $1.2 billion for the nine months ended September 30, 2013, primarily due to overall lower activity in the U.S. as a result of competitive pressure and reduced customer activity. Reduced customer activity in Mexico resulted in reduced revenue in our International segment. See “Segment Operating Results — Nine Months Ended September 30, 2014 and 2013” below for a more detailed discussion of the change in our revenues.

Direct Operating Expenses

Our direct operating expenses decreased $61.3 million, to $793.3 million (74.0% of revenues), for the nine months ended September 30, 2014, compared to $854.6 million (69.5% of revenues) for the nine months ended September 30, 2013 as a result of lower variable costs such as cost attributable to direct labor and fuel due to reduced activity levels.

Depreciation and Amortization Expense

Depreciation and amortization expense decreased $15.2 million, or 9.0%, to $154.2 million during the nine months ended September 30, 2014, compared to $169.4 million for the nine months ended September 30, 2013. The decrease is primarily attributable to decreases in capital expenditures and amortization of intangible assets.

General and Administrative Expenses

General and administrative expenses increased $2.3 million, to $176.0 million (16.4% of revenues), for the nine months ended September 30, 2014, compared to $173.6 million (14.1% of revenues) for the nine months ended September 30, 2013. The increase is primarily due to higher legal expense related to FCPA investigations, which totaled $21.5 million year to date. We expect costs to continue over the course of the investigations. The FCPA investigation expense was largely offset by lower compensation costs due to reduced staffing levels.

Impairment Expense

During the nine months ended 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 fixed assets at our fishing and rental services business reporting unit which is included in our U.S. reporting segment. No impairments were recorded in 2013.

Interest Expense, Net of Amounts Capitalized

Interest expense decreased $1.2 million, or 2.9%, to $40.4 million for the nine months ended September 30, 2014, compared to $41.6 million for the same period in 2013. The decrease is primarily related to reduced borrowings under the revolving credit facility for the nine months ended September 30, 2014 compared to the same period in 2013.

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Other Income, Net

During the nine months ended September 30, 2014, we recognized other income, net, of $2.5 million, compared to other income, net, of $0.9 million for the nine months ended September 30, 2013. Our foreign exchange 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, net for the periods indicated:



	Nine Months Ended September 30,
	2014			2013
	(in thousands)
Interest income	$	(60	)	$	(129	)
Foreign exchange loss	1,107			413
Other, net	(3,501		)	(1,162		)
Total	$	(2,454	)	$	(878	)

Income Tax Benefit

We recorded an income tax benefit of $52.0 million on a pre-tax loss of $178.4 million for the nine months ended September 30, 2014, compared to an income tax benefit of $0.1 million on a pre-tax loss of $8.8 million for the same period in 2013. Our effective tax rate was 29.2% for the nine months ended September 30, 2014, compared to 1.7% for the nine months ended September 30, 2013. Excluding the impact of non-deductible goodwill and tradename impairment expense, our effective tax rate for the nine months ended September 30, 2014, was 34.8%. 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, such as goodwill impairment expense, that affect book income but do not affect taxable income.

Noncontrolling Interest

We have no noncontrolling interest holders in 2014. For the nine months ended September 30, 2013, we allocated $0.6 million associated with the income incurred by our joint ventures to the noncontrolling interest holders of these ventures.

Segment Operating Results — Nine Months Ended September 30, 2014 and 2013

The following table shows operating results for each of our segments for the nine months ended September 30, 2014 and 2013 (in thousands):



For the nine months ended September 30, 2014
	U.S.		International			Functional Support			Total
Revenues from external customers	$	988,407	$	84,127		$	—		$	1,072,534
Operating expenses	956,014		140,720			116,216			1,212,950
Operating income (loss)	32,393		(56,593		)	(116,216		)	(140,416		)



For the nine months ended September 30, 2013
	U.S.		International			Functional Support			Total
Revenues from external customers	$	1,052,885	$	176,627		$	—		$	1,229,512
Operating expenses	907,520		183,071			106,999			1,197,590
Operating income (loss)	145,365		(6,444		)	(106,999		)	31,922

U.S.

Revenues for our U.S. segment decreased $64.5 million, or 6.1%, to $988.4 million for the nine months ended September 30, 2014, compared to $1.1 billion for the nine months ended September 30, 2013. The decrease for this segment was due to lower activity in our fishing and rental, coiled tubing and fluid management services due to competitive pressure and reduced customer activity in our California rig-based services.

Operating expenses for our U.S. segment were $956.0 million for the nine months ended September 30, 2014, which represented an increase of $48.5 million, or 5.3%, compared to $907.5 million for the same period in 2013. These expenses

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increased primarily as a result of the impairment of fixed assets in our fishing and rental services business reporting unit partially offset by reduced labor cost as a result of lower activity.

International

Revenues for our International segment decreased $92.5 million, or 52.4%, to $84.1 million for the nine months ended September 30, 2014, compared to $176.6 million for the nine months ended September 30, 2013. The decrease was primarily attributable to lower customer activity in Mexico.

Operating expenses for our International segment decreased $42.4 million, or 23.1%, to $140.7 million for the nine months ended September 30, 2014, compared to $183.1 million for the nine months ended September 30, 2013. These expenses decreased as a direct result of lower customer activity and severance costs in Mexico, partially offset by impairment of goodwill and tradenames in our Russian business reporting unit.

Functional Support

Operating expenses for Functional Support, which represent expenses associated with managing our U.S. and International reporting segments, increased $9.2 million, or 8.6%, to $116.2 million (10.8% of consolidated revenues) for the nine months ended September 30, 2014 compared to $107.0 million (8.7% of consolidated revenues) for the same period in 2013. The increase is primarily due to increased legal expense related to the FCPA investigations, partially offset by lower employee compensation and benefit costs.

LIQUIDITY AND CAPITAL RESOURCES

Current Financial Condition and Liquidity

As of September 30, 2014, we had cash and cash equivalents of $57.4 million. Our adjusted working capital (working capital excluding the current portion of long-term debt) was $264.7 million as of September 30, 2014, compared to $277.4 million as of December 31, 2013. Our adjusted working capital decreased from the prior year end primarily as a result of a decrease in accounts receivable partially offset by an increase in cash and cash equivalents and inventories. We incurred $21.5 million of costs associated with FCPA investigations and expect costs to continue in future periods until the investigation is complete. Our total outstanding debt was $758.6 million, and we have no significant debt maturities until 2016. As of September 30, 2014, we have $80.0 million in borrowings, $49.1 million in committed letters of credit outstanding with borrowing capacity of $162.2 million available considering covenant constraints under our 2011 Credit Facility (defined below).

Cash Flows

The following table summarizes our cash flows for the nine month ended September 30, 2014 and 2013:



	Nine Months Ended September 30,
	2014			2013
	(in thousands)
Net cash provided by operating activities	$	126,084		$	157,018
Cash paid for capital expenditures	(108,120		)	(111,021		)
Proceeds received from sale of fixed assets	12,288			7,530
Proceeds from notes receivable	3,990			—
Acquisition of the 50% noncontrolling interest in Geostream	—			(14,600		)
Repayments of capital lease obligations	—			(392		)
Repayments of long-term debt	(3,573		)	—
Proceeds from borrowings on revolving credit facility	220,000			195,000
Repayments on revolving credit facility	(225,000		)	(210,000		)
Repurchases of common stock	(2,239		)	(3,169		)
Other financing activities, net	(1,240		)	(1,915		)
Effect of exchange rates on cash	6,896			212
Net increase in cash and cash equivalents	$	29,086		$	18,663

Cash provided by operating activities was $126.1 million and $157.0 million for the nine months ended September 30, 2014 and 2013, respectively.

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Cash used in investing activities was $91.8 million and $118.1 million for nine months ended September 30, 2014 and 2013, respectively. Investing cash outflows during these periods consisted primarily of capital expenditures. Our capital expenditures through September 30, 2014 primarily relate to our replacement assets for our existing fleet and equipment. Additionally, during the first quarter of 2013, as previously disclosed, we funded into escrow $14.6 million for the acquisition of the 50% noncontrolling interest in Geostream, our joint venture in Russia.

Cash used in financing activities was $12.1 million and $20.5 million for the nine months ended September 30, 2014 and 2013, respectively. Overall financing cash outflows for 2014 primarily relate to net payments on the revolving credit facility and repayments of long-term debt. Overall financing cash outflows for 2013 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 2011 Credit Facility, and internally generated cash flows from operations.

Debt Service

We do not have any maturities of debt until 2016. Interest on our 2011 Credit Facility is due each quarter. There are no interest payments for the remainder of 2014 related to our 2021 Notes (defined below). We expect to fund interest payments from cash generated by operations. At September 30, 2014, our annual debt maturities for our 2021 Notes and borrowings under our 2011 Credit Facility were as follows:



Year	Principal Payments
	(in thousands)
2014	$	—
2015	—
2016	80,000
2017	—
2018 and thereafter	675,000
Total principal payments	$	755,000

At September 30, 2014, we were in compliance with all the covenants under the 2011 Credit Facility and the indenture governing the 2021 Notes.

8.375% Senior Notes due 2014

On February 25, 2014, we redeemed the $3.6 million aggregate principal amount and paid $0.1 million accrued interest of 8.375% Senior Notes due 2014 (the “2014 Notes”) pursuant to the indenture dated as of November 29, 2007 (as supplemented, the “Indenture”). The 2014 Notes were general unsecured senior obligations were subordinate to all of our existing and future secured indebtedness. The 2014 Notes were jointly and severally guaranteed on a senior unsecured basis by certain of our existing and future domestic subsidiaries. Interest on the 2014 Notes was payable on June 1 and December 1 of each year.

6.75% Senior Notes due 2021

We issued $475.0 million aggregate principal amount of 6.75% Senior Notes due 2021 (the “Initial 2021 Notes”) on March 4, 2011 and issued an additional $200.0 million aggregate principal amount of the 2021 Notes (the “Additional 2021 Notes” and, together with the Initial 2021 Notes, the “2021 Notes”) in a private placement on March 8, 2012 under an indenture dated March 4, 2011 (the “Base Indenture”), as supplemented by a first supplemental indenture dated March 4, 2011 and amended by a further supplemental indenture dated March 8, 2012 (the “Supplemental Indenture” and, together with the Base Indenture, the “Indenture”). We used the net proceeds to repay senior secured indebtedness under our revolving bank credit facility. We capitalized $4.6 million of financing costs associated with the issuance of the 2021 Notes that will be amortized over the term of the notes.

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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.



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.

Senior Secured Credit Facility

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adjusted LIBOR plus 1.0%, plus in each case the applicable margin for all other loans. The applicable margin for LIBOR loans ranges from 225 to 300 basis points, and the applicable margin for all other loans ranges 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 equal 0.50%.


•	our ratio of consolidated funded indebtedness to total capitalization be no greater than 45%;


•	our senior secured leverage ratio of senior secured funded debt to trailing four quarters of earnings before interest, taxes, depreciation and amortization (as calculated pursuant to the terms of the 2011 Credit Facility, “EBITDA”) be no greater than 2.00 to 1.00;


•	we maintain a collateral coverage ratio, the ratio of the aggregate book value of the collateral to the amount of the total commitments, as of the last day of any fiscal quarter of at least 2:00 to 1:00;


•	we maintain a consolidated interest coverage ratio of trailing four quarters EBITDA to interest expense of at least 3.00 to 1.00; and


•	we limit our capital expenditures and investments in foreign subsidiaries to $250.0 million per fiscal year, if the consolidated total leverage ratio exceeds 3.00 to 1.00.

In addition, the 2011 Credit Facility contains certain affirmative and negative covenants, including, without limitation, restrictions on (i) liens; (ii) debt, guarantees and other contingent obligations; (iii) mergers and consolidations; (iv) sales, transfers and other dispositions of property or assets; (v) loans, acquisitions, joint ventures and other investments (with acquisitions permitted so long as, after giving pro forma effect thereto, no default or event of default exists under the 2011 Credit Facility, the pro forma consolidated total leverage ratio does not exceed 4.00 to 1.00, we are in compliance with other financial covenants and we have at least $25.0 million of availability under the 2011 Credit Facility); (vi) dividends and other distributions to, and redemptions and repurchases from, equity holders; (vii) making investments, loans or advances; (viii) selling properties; (ix) prepaying, redeeming or repurchasing subordinated (contractually or structurally) debt; (x) engaging in transactions with affiliates; (xi) entering into hedging arrangements; (xii) entering into sale and leaseback transactions; (xiii) granting negative pledges other than to the lenders; (xiv) changes in the nature of business; (xv) amending organizational documents; and (xvi) changes in accounting policies or reporting practices; in each of the foregoing cases, with certain exceptions. We were in compliance with these covenants at September 30, 2014. We may prepay the 2011 Credit Facility in whole or in part at any time without premium or penalty, subject to certain reimbursements to the lenders for breakage and redeployment costs. As of September 30, 2014, we had borrowings of $80.0 million outstanding under the revolving credit facility, $49.1 million of letters of credit outstanding with borrowing capacity of $162.2 million available considering covenant constraints under our 2011 Credit Facility. The weighted average interest rates on the outstanding borrowings under the 2011 Credit Facility were 3.01% and 2.81% for the three-month periods ended September 30, 2014 and September 30, 2013, respectively, and the weighted average interest rates on the outstanding borrowing under the 2011 Credit Facility were 2.92% and 2.72% for nine months ended September 30, 2014 and September 30, 2013, respectively.

Letter of Credit Facility

Off-Balance Sheet Arrangements

At September 30, 2014 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 September 30, 2014, we had cash and cash equivalents of $57.4 million, borrowing capacity of $162.2 million, available considering covenant constraints under the 2011 Credit Facility, and no significant debt maturities until 2016. We believe that our internally generated cash flows from operations and current reserves of cash and cash equivalents will be sufficient to finance the majority of our cash requirements for operations, budgeted capital expenditures, and debt service for the next twelve months. Also, as we have historically done, we may, from time to time, access available funds under our 2011 Credit 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 2011 Credit Facility and, in the case of acquisitions, equity.

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Capital Expenditures

During the nine months ended September 30, 2014, our capital expenditures totaled $108.1 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 2014 of approximately $150 million to $160 million is primarily related to equipment replacement needs, including ongoing replacement to our rig services fleet. Our capital expenditure program for 2014 is subject to market conditions, including activity levels, commodity prices, industry capacity and specific customer needs. Our focus for 2014 has been and continues to be the maximization of our current equipment fleet, but we may choose to increase our capital expenditures in 2014 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 2014 capital expenditures through a combination of cash on hand, operating cash flow, and borrowings under our 2011 Credit 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 2013 Form 10-K. More detailed information concerning market risk can be found in “Item 7A. Quantitative and Qualitative Disclosures about Market Risk“ in our 2013 Form 10-K.

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 third quarter of 2014 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 10. Commitments and Contingencies” in “Item 1. Financial Statements” of Part I of this report, which is incorporated herein by reference.

As previously disclosed, a special committee of our Board of Directors is investigating possible violations of the FCPA involving business activities of our operations in Russia and 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. The special committee’s investigations, which also include a review of certain aspects of the Company’s operations in Colombia, as well as our other international locations, are ongoing. We are fully cooperating with 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 estimate any possible loss or range of loss. See Part II, Item 1. Legal Proceedings of the Form 10-Q for the quarter ended June 30, 2014 for more information regarding these investigations.

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 Exchange Act. The lawsuits are 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. Both lawsuits allege that, during the period July 25, 2013 to July 17, 2014, the defendants failed to disclose (1) that the Company’s production for Pemex was in decline; (2) that the Company engaged in improper conduct related to its operations in Russia; and (3) that the Company’s business practices in Russia were in violation of the FCPA. Because these cases are in early stages, we cannot predict the outcome of these lawsuits at this time. Accordingly, we cannot estimate any possible loss or range of loss.


ITEM 1A.	RISK FACTORS

Reference is made to Part I, Item 1A. Risk Factors of the 2013 Form 10-K, as updated by Part II, Item 1A. Risk Factors of the Form 10-Q for the quarter ended March 31, 2014, and Part II, Item 1A. Risk Factors of the Form 10-Q for the quarter ended June 30, 2014 for information concerning risk factors.

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

Issuer Purchases of Equity Securities

During the three months ended September 30, 2014, 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)
July 1, 2014 to July 31, 2014	2,360	$	6.55
August 1, 2014 to August 31, 2014	1,092	6.15
September 1, 2014 to September 30, 2014	989	5.34
Total	4,441	$	6.18


(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:	November 3, 2014	By:	/s/ J. MARSHALL DODSON
			J. Marshall Dodson
			Senior Vice President and Chief Financial Officer (As duly authorized officer and Principal Financial Officer)

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		Seventh Amended and Restated By-laws of Key Energy Services, Inc. as amended through February 26, 2014. (Incorporated by reference to Exhibit 3.1 of our Current Report on Form 8-K filed on February 26, 2014, File No. 001-08038.)

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.



*	Filed herewith