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KEY ENERGY SERVICES INC - Quarter Report: 2013 March (Form 10-Q)

Table of Contents

 
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 March 31, 2013
or
¨
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.
Large accelerated filer
 
ý
  
Accelerated filer
 
¨
 
 
 
 
Non-accelerated filer
 
¨ (Do not check if a smaller reporting company)
  
Smaller reporting company
 
¨
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 April 26, 2013, the number of outstanding shares of common stock of the registrant was 152,309,996.
 


Table of Contents

KEY ENERGY SERVICES, INC.
QUARTERLY REPORT ON FORM 10-Q
For the Quarter Ended March 31, 2013
 
 
 
 
 
Item 1.
 
 
 
Item 2.
 
 
 
Item 3.
 
 
 
Item 4.
 
 
 
 
 
 
Item 1.
 
 
 
Item 1A.
 
 
 
Item 2.
 
 
 
Item 3.
 
 
 
Item 4.
 
 
 
Item 5.
 
 
 
Item 6.
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 “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2012.
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)
 
March 31,
2013
 
December 31,
2012
 
(unaudited)
 
 
ASSETS
 
 
 
Current assets:
 
 
 
Cash and cash equivalents
$
39,900

 
$
45,949

Restricted funds held in escrow
14,615

 

Accounts receivable, net of allowance for doubtful accounts of $4,001and $2,860, respectively
405,946

 
404,390

Inventories
42,072

 
38,622

Other current assets
113,585

 
100,833

Total current assets
616,118

 
589,794

Property and equipment
2,558,004

 
2,528,578

Accumulated depreciation
(1,138,354
)
 
(1,091,904
)
Property and equipment, net
1,419,650

 
1,436,674

Goodwill
626,047

 
626,481

Other intangible assets, net
55,873

 
60,905

Deferred financing costs, net
15,996

 
16,628

Deposits
7,940

 
7,339

Equity method investments
951

 
966

Other assets
18,726

 
22,801

TOTAL ASSETS
$
2,761,301

 
$
2,761,588

LIABILITIES AND EQUITY

 

Current liabilities:

 

Accounts payable
$
94,745

 
$
104,073

Other current liabilities
172,429

 
200,630

Current portion of capital leases
129

 
393

Total current liabilities
267,303

 
305,096

Long-term debt
877,971

 
848,110

Workers' compensation, vehicular and health insurance liabilities
33,234

 
33,676

Deferred tax liabilities
267,644

 
259,453

Other non-current liabilities
29,812

 
27,921

Commitments and contingencies

 

Equity:

 

Common stock, $0.10 par value; 200,000,000 shares authorized, 152,351,327 and 151,069,609 shares issued and outstanding
15,235

 
15,108

Additional paid-in capital
924,714

 
925,132

Accumulated other comprehensive loss
(6,988
)
 
(6,148
)
Retained earnings
319,462

 
319,736

Total equity attributable to Key
1,252,423

 
1,253,828

Noncontrolling interest
32,914

 
33,504

Total equity
1,285,337

 
1,287,332

TOTAL LIABILITIES AND EQUITY
$
2,761,301

 
$
2,761,588

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
 
March 31,
 
2013
 
2012
REVENUES
$
428,449

 
$
486,751

COSTS AND EXPENSES:
 
 
 
Direct operating expenses
299,182

 
311,497

Depreciation and amortization expense
54,193

 
51,189

General and administrative expenses
63,245

 
60,918

Operating income
11,829

 
63,147

Interest expense, net of amounts capitalized
13,804

 
11,882

Other income, net
(1,223
)
 
(1,029
)
Income (loss) from continuing operations before tax
(752
)
 
52,294

Income tax benefit (expense)
566

 
(18,813
)
Income (loss) from continuing operations
(186
)
 
33,481

Loss from discontinued operations, net of tax benefit of $- and $16,354, respectively

 
(30,905
)
Net income (loss)
(186
)
 
2,576

Income (loss) attributable to noncontrolling interest
88

 
(614
)
INCOME (LOSS) ATTRIBUTABLE TO KEY
$
(274
)
 
$
3,190

Income (loss) from continuing operations attributable to Key:
 
 
 
Income (loss) from continuing operations
$
(186
)
 
$
33,481

Income (loss) attributable to noncontrolling interest
88

 
(614
)
Income (loss) from continuing operations attributable to Key
$
(274
)
 
$
34,095

Earnings per share from continuing operations attributable to Key:
 
 
 
Basic and diluted
$

 
$
0.23

Loss per share from discontinued operations:
 
 
 
Basic and diluted
$

 
$
(0.21
)
Earnings per share attributable to Key:
 
 
 
Basic and diluted
$

 
$
0.02

Weighted average shares outstanding:
 
 
 
Basic
151,967

 
151,132

Diluted
151,967

 
151,506

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
 
March 31,
 
2013
 
2012
INCOME (LOSS) FROM CONTINUING OPERATIONS
$
(186
)
 
$
33,481

Other comprehensive income (loss), net of tax:
 
 
 
Foreign currency translation gain (loss)
(1,518
)
 
7,052

Total other comprehensive income (loss), net of tax
(1,518
)
 
7,052

COMPREHENSIVE INCOME (LOSS) FROM CONTINUING OPERATIONS, NET OF TAX
(1,704
)
 
40,533

Comprehensive loss from discontinued operations

 
(30,905
)
COMPREHENSIVE INCOME (LOSS)
(1,704
)
 
9,628

Comprehensive (income) loss attributable to noncontrolling interest
590

 
(2,414
)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO KEY
$
(1,114
)
 
$
7,214

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)
 
Three Months Ended
 
March 31,
 
2013
 
2012
CASH FLOWS FROM OPERATING ACTIVITIES:
 
 
 
Net income (loss)
$
(186
)
 
$
2,576

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

 

Depreciation and amortization expense
54,193

 
51,332

Asset retirements and impairments

 
41,457

Bad debt expense
1,203

 
418

Accretion of asset retirement obligations
159

 
150

Loss from equity method investments
128

 
132

Amortization of deferred financing costs and premium
659

 
634

Deferred income tax expense
(377
)
 
(6,008
)
Capitalized interest
(137
)
 
(285
)
Gain on disposal of assets, net

 
(2
)
Share-based compensation
4,947

 
4,207

Excess tax expense (benefit) from share-based compensation
1,402

 
(4,047
)
Changes in working capital:

 

Accounts receivable
(2,959
)
 
(4,262
)
Other current assets
(5,308
)
 
(24,293
)
Accounts payable, accrued interest and accrued expenses
(39,926
)
 
(15,615
)
Share-based compensation liability awards
1,017

 
1,877

Other assets and liabilities
4,747

 
26,049

Net cash provided by operating activities
19,562

 
74,320

CASH FLOWS FROM INVESTING ACTIVITIES:

 

Capital expenditures
(37,144
)
 
(169,438
)
Proceeds from sale of fixed assets
374

 
6,966

Restricted funds held in escrow
(14,615
)
 

Net cash used in investing activities
(51,385
)
 
(162,472
)
CASH FLOWS FROM FINANCING ACTIVITIES:
 
 
 
Proceeds from long-term debt

 
205,000

Repayments of capital lease obligations
(264
)
 
(556
)
Proceeds from borrowings on revolving credit facility
95,000

 
130,000

Repayments on revolving credit facility
(65,000
)
 
(245,000
)
Payment of deferred financing costs
(46
)
 
(4,421
)
Repurchases of common stock
(2,462
)
 
(6,936
)
Proceeds from exercise of stock options

 
812

Excess tax (expense) benefit from share-based compensation
(1,402
)
 
4,047

Other financing activities

 
7,123

Net cash provided by financing activities
25,826

 
90,069

Effect of changes in exchange rates on cash
(52
)
 
(5,425
)
Net decrease in cash and cash equivalents
(6,049
)
 
(3,508
)
Cash and cash equivalents, beginning of period
45,949

 
35,443

Cash and cash equivalents, end of period
$
39,900

 
$
31,935


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., its wholly owned subsidiaries and its controlled 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, 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, 2012 balance sheet was prepared from audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2012 (the “2012 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 2012 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 three months ended March 31, 2013 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. Accordingly, we have included information on the purchase of the remaining 50% of the noncontrolling interest in our Russian joint venture, OOO Geostream Services Group, a limited liability company incorporated in the Russian Federation ("Geostream"), in Note 17. Subsequent Events.
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 2012 Form 10-K.

Accounting Standards Adopted or Not Yet Adopted in this Report
There are no new accounting standards that have been adopted or not yet adopted in this report.


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NOTE 3. DISCONTINUED OPERATIONS
In September 2012, we completed the sale of our Argentina operations for approximately $12.5 million, net of transaction costs. In connection with the sale, we recognized a total loss of $85.8 million, which includes the noncash impairment charge of $41.5 million recorded in the first quarter of 2012, and a write-off of $51.9 million cumulative translation adjustment previously recorded in accumulated other comprehensive loss during the third quarter of 2012.
The following table presents the results of operations for the Argentina business sold in this transaction for the three months ended March 31, 2012.

 
 
Three Months Ended
 
 
March 31, 2012
 
 
(in thousands)
REVENUES
 
$
25,639

COSTS AND EXPENSES:
 


Direct operating expenses
 
26,305

Depreciation and amortization expense
 
143

General and administrative expenses
 
4,110

Impairment and other charges
 
41,457

Operating loss
 
(46,376
)
Interest expense, net of amounts capitalized
 
51

Other expense, net
 
832

Loss before tax
 
(47,259
)
Income tax benefit
 
16,354

Loss from discontinued operations
 
$
(30,905
)
NOTE 4. OTHER BALANCE SHEET INFORMATION
During the first quarter of 2013, Key funded into escrow $14.6 million for the acquisition of the remaining 50% of the noncontrolling interest in Geostream. See “Note 17. Subsequent Events” for further discussion. The table below presents comparative detailed information about restricted funds held in escrow at March 31, 2013 and December 31, 2012:
 
March 31,
2013
 
December 31,
2012
 
(in thousands)
Restricted funds held in escrow
$
14,615

 
$


The table below presents comparative detailed information about other current assets at March 31, 2013 and December 31, 2012:
 
March 31,
2013
 
December 31,
2012
 
(in thousands)
Other current assets:
 
 
 
Deferred tax assets
$
21,039

 
$
20,026

Prepaid current assets
29,755

 
27,736

Reinsurance receivable
10,013

 
10,217

VAT asset
30,264

 
32,762

Other
22,514

 
10,092

Total
$
113,585

 
$
100,833


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The table below presents comparative detailed information about other current liabilities at March 31, 2013 and December 31, 2012:
 
March 31,
2013
 
December 31,
2012
 
(in thousands)
Other current liabilities:
 
 
 
Accrued payroll, taxes and employee benefits
$
45,818

 
$
31,708

Accrued operating expenditures
37,990

 
42,137

Income, sales, use and other taxes
36,918

 
62,709

Self-insurance reserve
34,833

 
35,742

Accrued interest
4,774

 
15,301

Insurance premium financing
5,271

 
8,021

Share-based compensation and other liabilities
6,825

 
5,012

Total
$
172,429

 
$
200,630

The table below presents comparative detailed information about other non-current liabilities at March 31, 2013 and December 31, 2012:
 
March 31,
2013
 
December 31,
2012
 
(in thousands)
Other non-current liabilities:
 
 
 
Asset retirement obligations
$
11,790

 
$
11,659

Environmental liabilities
6,652

 
4,539

Accrued rent
1,283

 
1,424

Accrued sales, use and other taxes
7,145

 
6,952

Other
2,942

 
3,347

Total
$
29,812

 
$
27,921


NOTE 5. GOODWILL AND OTHER INTANGIBLE ASSETS
The changes in the carrying amount of goodwill for the three months ended March 31, 2013 are as follows:
 
U.S.
 
International
 
Total
 
(in thousands)
December 31, 2012
$
597,456

 
$
29,025

 
$
626,481

Impact of foreign currency translation

 
(434
)
 
(434
)
March 31, 2013
$
597,456

 
$
28,591

 
$
626,047


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The components of our other intangible assets as of March 31, 2013 and December 31, 2012 are as follows:
 
March 31, 2013
 
December 31, 2012
 
(in thousands)
Noncompete agreements:
 
 
 
Gross carrying value
$
7,134

 
$
9,332

Accumulated amortization
(4,492
)
 
(5,022
)
Net carrying value
$
2,642

 
$
4,310

Patents, trademarks and tradename:

 

Gross carrying value
$
14,528

 
$
14,689

Accumulated amortization
(458
)
 
(410
)
Net carrying value
$
14,070

 
$
14,279

Customer relationships and contracts:

 

Gross carrying value
$
100,419

 
$
100,481

Accumulated amortization
(66,328
)
 
(62,143
)
Net carrying value
$
34,091

 
$
38,338

Developed technology:

 

Gross carrying value
$
9,780

 
$
7,583

Accumulated amortization
(4,710
)
 
(3,605
)
Net carrying value
$
5,070

 
$
3,978

Customer Backlog:
 
 
 
Gross carrying value
$
776


$
779

Accumulated amortization
(776
)

(779
)
Net carrying value
$

 
$


Of our intangible assets at March 31, 2013, $13.7 million is an indefinite-lived tradename and 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
 
Remainder
of 2013
 
2014
 
2015
 
2016
 
2017
 
2018
 
 
 
(in thousands)
Noncompete agreements
1.6
 
$
1,304

 
$
1,338

 
$

 
$

 
$

 
$

Patents and trademarks
5.3
 
166

 
125

 
125

 
54

 
40

 
17

Customer relationships and contracts
6.9
 
12,764

 
7,963

 
5,100

 
3,454

 
2,431

 
1,120

Developed technology
17.8
 
42

 
233

 
221

 
221

 
221

 
221

Total expected intangible asset amortization expense
 
 
$
14,276

 
$
9,659

 
$
5,446

 
$
3,729

 
$
2,692

 
$
1,358

Certain of our goodwill and other intangible assets are denominated in currencies other than U.S. dollars 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 $4.8 million and $5.9 million for the three months ended March 31, 2013 and 2012, respectively.


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NOTE 6. LONG-TERM DEBT
As of March 31, 2013 and December 31, 2012, the components of our long-term debt were as follows:
 
March 31, 2013
 
December 31, 2012
 
(in thousands)
6.75% Senior Notes due 2021
$
675,000

 
$
675,000

8.375% Senior Notes due 2014
3,573

 
3,573

Senior Secured Credit Facility revolving loans due 2016
195,000

 
165,000

Net unamortized premium on debt
4,398

 
4,537

Capital lease obligations
129

 
393

Total debt
878,100

 
848,503

Less current portion
(129
)
 
(393
)
Long-term debt and capital leases
$
877,971

 
$
848,110

8.375% Senior Notes due 2014
We have outstanding $3.6 million aggregate principal amount of 8.375% Senior Notes due 2014 (the “2014 Notes”). The 2014 Notes are general unsecured senior obligations and are subordinate to all of our existing and future secured indebtedness. The 2014 Notes are jointly and severally guaranteed on a senior unsecured basis by certain of our existing and future domestic subsidiaries. Interest on the 2014 Notes is payable on June 1 and December 1 of each year.

The indenture governing the 2014 Notes contains various covenants. These covenants are subject to certain exceptions and qualifications, and contain cross-default provisions tied to the covenants of our 2011 Credit Facility (defined below). We were in compliance with these covenants at March 31, 2013.
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”) in a private placement on March 8, 2012 (collectively, the “2021 Notes”) 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 January 29, 2013, we commenced 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. The exchange offer was completed on March 5, 2013. 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.

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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 before March 1, 2014, we may on any one or more occasions redeem up to 35% of the aggregate principal amount of the outstanding 2021 Notes at a redemption price of 106.75% of the principal amount, plus accrued and unpaid interest to the redemption date, with the net cash proceeds from any one or more equity offerings provided that (i) at least 65% of the aggregate principal amount of the 2021 Notes remains outstanding immediately after each such redemption and (ii) each such redemption shall occur within 180 days of the date of the closing of such equity offering.
In addition, 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. 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 March 31, 2013, the 2021 Notes were 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 credit rating assigned to the 2021 Notes later falls below investment grade. We were in compliance with these covenants as of March 31, 2013.

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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 0.50%.
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.

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 as of March 31, 2013. 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 March 31, 2013, we had borrowings of $195.0 million outstanding under the revolving credit facility and $54.1 million of letters of credit outstanding, leaving $300.9 million of available borrowing capacity subject to compliance with the debt to capitalization limitation under the terms of the 2011 Credit Facility. The weighted average interest rate on the outstanding borrowings under the 2011 Credit Facility was 2.68% and 2.71% for the three-month periods ended March 31, 2013 and March 31, 2012, respectively.

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NOTE 7. OTHER INCOME, NET
The table below presents comparative detailed information about our other income and expense, shown on the condensed consolidated statements of operations as “Other income, net” for the periods indicated:
 
Three Months Ended March 31,
 
2013
 
2012
 
(in thousands)
Interest income
$
(11
)
 
$
(7
)
Foreign exchange gain
(925
)
 
(939
)
Other income, net
(287
)
 
(83
)
Total
$
(1,223
)
 
$
(1,029
)
NOTE 8. 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 on continuing operations for the three months ended March 31, 2013 and 2012 were 75.3% and 36.0%, 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, permanent differences impacting mainly the U.S. effective rate, 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 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 March 31, 2013 and December 31, 2012, we had $1.2 million of unrecognized tax benefits, net of federal tax benefit, which, if recognized, would impact our effective tax rate. We recognized tax expense of less than $0.1 million for each of the three-month periods ended March 31, 2013 and 2012 related to these items. We have substantially concluded all U.S. federal and state tax matters through the year ended December 31, 2006.
We record interest and penalties related to unrecognized tax benefits as income tax expense. We have accrued a liability of $0.3 million for the payment of interest and penalties as of March 31, 2013 and December 31, 2012. We believe that it is reasonably possible that $0.9 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 months ended March 31, 2013 and 2012.


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NOTE 9. 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. 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 $2.2 million of other liabilities related to litigation that is deemed probable and reasonably estimable as of March 31, 2013. 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.
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 March 31, 2013 and December 31, 2012, we have recorded $68.1 million and $69.4 million, respectively, of self-insurance reserves related to workers’ compensation, vehicular liabilities and general liability claims. Partially offsetting these liabilities, we had $20.3 million and $20.6 million of insurance receivables as of March 31, 2013 and December 31, 2012, 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. While our litigation reserves reflect the application of our insurance coverage, our environmental reserves do not reflect management’s assessment of the insurance coverage that may apply to the matters at issue. As of March 31, 2013 and December 31, 2012, we have recorded $6.7 million and $4.5 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 10. EARNINGS PER SHARE
Basic earnings per share is determined by dividing net earnings attributable to Key by the weighted average number of common shares actually outstanding during the period. Diluted earnings 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 earnings per share are as follows:
 
Three Months Ended
 
March 31,
 
2013
 
2012
 
(in thousands, except per share amounts)
Basic EPS Calculation:
 
 
 
Numerator
 
 
 
Income (loss) from continuing operations attributable to Key
$
(274
)
 
$
34,095

Loss from discontinued operations, net of tax

 
(30,905
)
Income (loss) attributable to Key
$
(274
)
 
$
3,190

Denominator
 
 

Weighted average shares outstanding
151,967

 
151,132

Basic earnings per share from continuing operations attributable to Key
$

 
$
0.23

Basic loss per share from discontinued operations

 
(0.21
)
Basic earnings per share attributable to Key
$

 
$
0.02

Diluted EPS Calculation:
 
 

Numerator
 
 

Income (loss) from continuing operations attributable to Key
$
(274
)
 
$
34,095

Loss from discontinued operations, net of tax

 
(30,905
)
Income (loss) attributable to Key
$
(274
)
 
$
3,190

Denominator
 
 

Weighted average shares outstanding
151,967

 
151,132

Stock options

 
304

Warrants

 

Stock appreciation rights

 
70

Total
151,967

 
151,506

Diluted earnings per share from continuing operations attributable to Key
$

 
$
0.23

Diluted loss per share from discontinued operations

 
(0.21
)
Diluted earnings per share attributable to Key
$

 
$
0.02

Stock options, warrants and stock appreciation rights (“SARs”) are included in the computation of diluted earnings per share using the treasury stock methods. 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 March 31, 2013 exclude the potential exercise of 1.8 million stock options and 0.4 million SARs, because of our net loss from continuing operations in the first quarter of 2013. The diluted earnings per share calculation for the three months ended March 31, 2012 excluded the potential exercise of 0.1 million stock options because their exercise prices exceeded the average price of our stock during the first quarter of 2012. None of our SARs were anti-dilutive for the three months ended March 31, 2012. There were no events occurring after March 31, 2013 that would materially affect the number of weighted average shares outstanding.


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NOTE 11. SHARE-BASED COMPENSATION
We recognized employee share-based compensation expense of $6.0 million and $6.1 million during the three months ended March 31, 2013 and 2012, respectively, and the related income tax benefit recognized was $2.2 million for the same periods. We did not capitalize any share-based compensation during the three months ended March 31, 2013 and 2012.
On January 16, January 21, February 4, March 25 and March 26, 2013, we issued less than 0.1 million, 0.9 million, 0.6 million, 0.1 million and less than 0.1 million shares of restricted common stock, respectively, to certain of our employees and officers, which vest in equal installments over the next three years. These shares had an issuance price of $7.44, $7.70, $7.98, $7.95 and $8.02 per share, respectively. The unrecognized compensation cost related to our unvested restricted stock as of March 31, 2013 is estimated to be $19.4 million and is expected to be recognized over a weighted- average period of 1.6 years. We do not have unrecognized cost related to our unvested stock options as of March 31, 2013. No phantom stock is outstanding as of March 31, 2013.
On January 21, 2013, the Compensation Committee of the Board of Directors adopted the Performance Unit Award Agreement (the “2012 PU Award Agreement”) under the Key Energy Services, Inc. 2012 Equity and Cash Incentive Plan (the“2012 Plan”) and the 2013 Performance Unit Plan (the “2013 PU Plan”). We believe that the 2013 PU Plan and 2012 PU Award Agreement will enable us to obtain and retain employees who will contribute to our long term success by providing compensation that is linked directly to increases in share value.
In January 2013, we issued 0.4 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 2013, we issued 0.2 million performance units to certain other employees under the 2013 PU Plan. The performance units are measured based on two performance periods from January 1, 2013 to December 31, 2013 and from January 1, 2014 to December 31, 2014. One half of the performance units are 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 March 31, 2013, the fair value of outstanding performance units was $5.6 million, and is being accreted to compensation expense over the vesting terms of the awards. As of March 31, 2013, the unrecognized compensation cost related to our unvested performance units is estimated to be $4.2 million and is expected to be recognized over a weighted-average period of 1.3 years.


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NOTE 12. TRANSACTIONS WITH RELATED PARTIES
Employee Loans and Advances
From time to time, we have made certain retention loans and relocation loans to employees other than executive officers. The retention loans are forgiven over various time periods, so long as the employees continue their employment with us. The relocation loans are repaid upon the employees selling their prior residence. As of March 31, 2013 and December 31, 2012, we did not have any employee loans or advances outstanding.
Transactions with Affiliates
In October 2010, we acquired certain subsidiaries, together with associated assets, from OFS, an oilfield services company owned by ArcLight Capital Partners, LLC. At the time of the acquisition, OFS conducted business with companies owned by a former owner and employee of an OFS subsidiary that we purchased. Subsequent to the acquisition, we
continued to provide services to these companies. The prices charged to these companies for our services are at rates that are equivalent to the prices charged to our other customers in the U.S. market. As of March 31, 2013 and December 31, 2012, our receivables from these related parties totaled less than $0.1 million and $0.2 million, respectively. Revenues from these customers for the three-month periods ended March 31, 2013 and 2012 totaled less than $0.1 million and $0.7 million, respectively.
Board of Director Relationships
A member of our board of directors is the Senior Vice President, General Counsel and Chief Administrative Officer of Anadarko Petroleum Corporation (“Anadarko”), which is one of our customers. Sales to Anadarko were approximately $6.6 million and $11.4 million for the three-month periods ended March 31, 2013 and 2012, respectively. Receivables outstanding from Anadarko were approximately $4.0 million and $3.5 million as of March 31, 2013 and December 31, 2012, respectively. Transactions with Anadarko for our services are made on terms consistent with other customers.
A member of our board of directors serves on the United States Advisory Board of the Alexander Proudfoot practice of Management Consulting Group PLC (“Proudfoot”), which provided consulting services to us related to our general and administrative cost restructuring initiative. Payments to Proudfoot were zero and $1.9 million for the three months ended March 31, 2013 and 2012, respectively.


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NOTE 13. 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 March 31, 2013 and December 31, 2012.
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.
 
 
March 31, 2013
 
December 31, 2012
 
 
Carrying Value
 
Fair Value
 
Carrying Value
 
Fair Value
 
 
(in thousands)
Financial assets:
 
 
 
 
 
 
 
 
Notes and accounts receivable - related parties
 
$
99


$
99

 
$
440


$
440

Notes receivable - Argentina operations sale
 
12,955


12,955

 
12,955


12,955

Financial liabilities:
 



 



6.75% Senior Notes
 
$
675,000


$
705,173

 
$
675,000


$
680,510

8.375% Senior Notes
 
3,573


3,658

 
3,573


3,656

Credit Facility revolving loans
 
195,000


195,000

 
165,000


165,000

Notes and accounts receivable — related parties. The amounts reported relate to certain trade accounts receivable with affiliates. The carrying values of these items approximate their fair values due to their short-term nature as of the applicable balance sheet dates.
Notes receivable — Argentina operations sale. The fair value of these notes receivable is based upon the quoted market Treasury rates as of the twelve, eighteen and twenty-four month maturity dates indicated. The carrying values of these items approximate their fair values due to the nature of the rates used to discount each note.
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 March 31, 2013 was $675.0 million, and the fair value was $705.2 million (104.5% of carrying value).
8.375% Senior Notes due 2014. The fair value of our 2014 Notes is based upon the quoted market prices for those securities as of the dates indicated. The carrying value of these notes as of March 31, 2013 was $3.6 million, and the fair value was $3.7 million (102.4% of carrying value).
Credit Facility Revolving Loans. Because of their variable interest rates, the fair values of the revolving loans borrowed under our 2012 Credit Facility approximate their carrying values. The carrying and fair values of these loans as of March 31, 2013 were $195.0 million.


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NOTE 14. 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.
Fluid Management Services
We provide transportation and well-site storage services for various fluids utilized in connection with drilling, completions, workover and maintenance activities. We also provide disposal services for fluids produced subsequent to well completion.  These fluids are removed from the well site and transported for disposal in saltwater disposal wells owned by us or a third party. In addition, we operate a fleet of hot oilers capable of pumping heated fluids used to clear soluble restrictions in a wellbore. Demand and pricing for these services generally correspond to demand for our well service rigs.
Coiled Tubing Services
Coiled tubing services involve the use of a continuous metal pipe spooled onto a large reel which is then deployed into oil and natural gas wells to perform various applications, such as wellbore clean-outs, nitrogen jet lifts, through-tubing fishing, and formation stimulations utilizing acid and chemical treatments. Coiled tubing is also used for a number of horizontal well applications such as milling temporary isolation plugs that separate frac zones, and various other pre- and post- hydraulic fracturing well preparation services.


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Table of Contents

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 also 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, the Middle East and Russia. In addition, we have a technology development and control systems business based in Canada. Also, prior to the sale of our Argentina business in the third quarter of 2012, we operated in Argentina. We are reporting the results of our Argentina business as discontinued operations for all periods presented. 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, 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, during the third quarter of 2012, we began operations in Oman. Our business in Bahrain is currently conducted through a joint venture in which we have a controlling interest.
Our Russian operations provide drilling, workover, and reservoir engineering services.
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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Table of Contents

The following tables set forth our unaudited segment information as of and for the three month periods ended March 31, 2013 and March 31, 2012 (in thousands):
As of and for the three months ended March 31, 2013
 
 
 
 
 
 
 
 
 
 
 
 
U.S.
 
International
 
Functional
Support(2)
 
Reconciling
Eliminations
 
Total
Revenues from external customers
 
$
346,072

 
$
82,377

 
$

 
$

 
$
428,449

Intersegment revenues
 
8,601

 
1,519

 
124

 
(10,244
)
 

Depreciation and amortization
 
44,790

 
6,500

 
2,903

 

 
54,193

Other operating expenses
 
263,007

 
64,003

 
35,417

 

 
362,427

Operating income (loss)
 
38,275

 
11,874

 
(38,320
)
 

 
11,829

Interest expense, net of amounts capitalized
 
1

 
49

 
13,754

 

 
13,804

Income (loss) from continuing operations before tax
 
38,209

 
13,056

 
(52,017
)
 

 
(752
)
Long-lived assets(1)
 
1,701,593

 
339,485

 
272,990

 
(168,885
)
 
2,145,183

Total assets
 
2,593,050

 
544,236

 
85,141

 
(461,126
)
 
2,761,301

Capital expenditures, excluding acquisitions
 
23,310

 
10,967

 
2,867

 


37,144

 
As of and for the three months ended March 31, 2012
 
 
 
 
 
 
 
 
 
 
 
 
U.S.
 
International
 
Functional
Support(2)
 
Reconciling
Eliminations
 
Total
Revenues from external customers
 
$
424,973

 
$
61,778

 
$

 
$

 
$
486,751

Intersegment revenues
 

 
957

 
15

 
(972
)
 

Depreciation and amortization
 
44,351

 
3,947

 
2,891

 

 
51,189

Other operating expenses
 
289,164

 
47,463

 
35,788

 

 
372,415

Operating income (loss)
 
91,458

 
10,368

 
(38,679
)
 

 
63,147

Interest expense, net of amounts capitalized
 
8

 
13

 
11,861

 

 
11,882

Income (loss) from continuing operations before tax
 
91,552

 
11,227

 
(50,485
)
 

 
52,294

Long-lived assets(1)
 
1,870,574

 
285,938

 
238,708

 
(294,818
)
 
2,100,402

Total assets
 
2,468,459

 
490,924

 
382,238

 
(637,491
)
 
2,704,130

Capital expenditures, excluding acquisitions
 
79,410

 
85,456

 
4,572

 

 
169,438

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

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


22

Table of Contents

NOTE 15. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS
Our 2021 Notes are guaranteed by 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 BALANCE SHEETS
 
 
March 31, 2013
 
 
Parent
Company
 
Guarantor
Subsidiaries
 
Non-Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(in thousands)
(unaudited)
Assets:
 
 
 
 
 
 
 
 
 
 
Current assets
 
$
71,712


$
495,501


$
48,905


$


$
616,118

Property and equipment, net
 


1,309,150


110,500




1,419,650

Goodwill
 


597,458


28,589




626,047

Deferred financing costs, net
 
15,996








15,996

Intercompany notes and accounts receivable and investment in subsidiaries
 
3,383,757


1,129,882


(15,468
)

(4,498,171
)


Other assets
 
4,082


35,576


43,832




83,490

TOTAL ASSETS
 
$
3,475,547

 
$
3,567,567

 
$
216,358

 
$
(4,498,171
)
 
$
2,761,301

Liabilities and equity:
 








 
Current liabilities
 
$
12,496


$
219,719


$
35,088


$


$
267,303

Long-term debt and capital leases, less current portion
 
877,971








877,971

Intercompany notes and accounts payable
 
1,036,538


2,605,633


12,994


(3,655,165
)


Deferred tax liabilities
 
261,686


6,781


(823
)



267,644

Other long-term liabilities
 
1,538


61,383


125




63,046

Equity
 
1,285,318


674,051


168,974


(843,006
)

1,285,337

TOTAL LIABILITIES AND EQUITY
 
$
3,475,547

 
$
3,567,567

 
$
216,358

 
$
(4,498,171
)
 
$
2,761,301



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Table of Contents

CONDENSED CONSOLIDATING BALANCE SHEETS
 
 
December 31, 2012
 
 
Parent
Company
 
Guarantor
Subsidiaries
 
Non-Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(in thousands)
Assets:
 
 
 
 
 
 
 
 
 
 
Current assets
 
$
66,435



$
469,049


$
54,310


$


$
589,794

Property and equipment, net
 



1,329,379


107,295




1,436,674

Goodwill
 



597,458


29,023




626,481

Deferred financing costs, net
 
16,628









16,628

Intercompany notes and accounts receivable and investment in subsidiaries
 
3,298,679



1,108,231


(20,371
)

(4,386,539
)


Other assets
 
8,068



39,696


44,247




92,011

TOTAL ASSETS
 
$
3,389,810


$
3,543,813

 
$
214,504

 
$
(4,386,539
)
 
$
2,761,588

Liabilities and equity:
 








 
Current liabilities
 
$
46,632



$
226,773


$
31,691


$


$
305,096

Long-term debt and capital leases, less current portion
 
848,110









848,110

Intercompany notes and accounts payable
 
947,700



2,590,398


14,138


(3,552,236
)


Deferred tax liabilities
 
258,528



6,781


(746
)

(5,110
)

259,453

Other long-term liabilities
 
1,528



60,068


1




61,597

Equity
 
1,287,312



659,793


169,420


(829,193
)

1,287,332

TOTAL LIABILITIES AND EQUITY
 
$
3,389,810

 
$
3,543,813

 
$
214,504

 
$
(4,386,539
)

$
2,761,588


CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS
 
 
Three Months Ended March 31, 2013
 
 
Parent
Company
 
Guarantor
Subsidiaries
 
Non-Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(in thousands)
Revenues
 
$
124


$
405,384


$
43,490


$
(20,549
)

$
428,449

Direct operating expense
 


286,042


30,483


(17,343
)

299,182

Depreciation and amortization expense
 


52,057


2,136




54,193

General and administrative expense
 
254


57,821


8,852


(3,682
)

63,245

Operating (loss) income
 
(130
)
 
9,464

 
2,019

 
476


11,829

Interest expense (income), net of amounts capitalized
 
13,891


(136
)

49




13,804

Other expense (income), net
 
(898
)

(1,169
)

37


807


(1,223
)
Income (loss) from continuing operations before taxes
 
(13,123
)
 
10,769

 
1,933

 
(331
)
 
(752
)
Income tax benefit (expense)
 
1,248


(883
)

201




566

Income (loss) from continuing operations
 
(11,875
)
 
9,886

 
2,134

 
(331
)
 
(186
)
Discontinued operations
 









Net income (loss)
 
(11,875
)
 
9,886

 
2,134

 
(331
)
 
(186
)
Income attributable to noncontrolling interest
 




88




88

INCOME (LOSS) ATTRIBUTABLE TO KEY
 
$
(11,875
)
 
$
9,886

 
$
2,046

 
$
(331
)
 
$
(274
)

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Table of Contents

 
 
Three Months Ended March 31, 2012
 
 
Parent
Company
 
Guarantor
Subsidiaries
 
Non-Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(in thousands)
Revenues
 
$
15


$
465,270


$
32,986


$
(11,520
)

$
486,751

Direct operating expense
 


295,637


24,783


(8,923
)

311,497

Depreciation and amortization expense
 


49,667


1,522




51,189

General and administrative expense
 
270


57,720


5,523


(2,595
)

60,918

Operating income (loss)
 
(255
)
 
62,246

 
1,158

 
(2
)
 
63,147

Interest expense, net of amounts capitalized
 
12,147


(273
)

9


(1
)

11,882

Other expense (income), net
 
(611
)

582


(1,077
)

77


(1,029
)
Income (loss) from continuing operations before taxes
 
(11,791
)
 
61,937

 
2,226

 
(78
)
 
52,294

Income tax expense
 
(17,962
)

(205
)

(646
)



(18,813
)
Income (loss) from continuing operations
 
(29,753
)
 
61,732

 
1,580

 
(78
)

33,481

Discontinued operations
 




(30,905
)



(30,905
)
Net income (loss)
 
(29,753
)
 
61,732

 
(29,325
)
 
(78
)

2,576

Loss attributable to noncontrolling interest
 




(614
)



(614
)
INCOME (LOSS) ATTRIBUTABLE TO KEY
 
$
(29,753
)
 
$
61,732

 
$
(28,711
)
 
$
(78
)

$
3,190


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Table of Contents


CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS
 
 
Three Months Ended March 31, 2013
 
 
Parent
Company
 
Guarantor
Subsidiaries
 
Non-Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(in thousands)
Net cash provided by operating activities
 
$


$
17,509


$
2,053


$


$
19,562

Cash flows from investing activities:
 








 
Capital expenditures
 


(33,410
)

(3,734
)



(37,144
)
Intercompany notes and accounts
 


29,505




(29,505
)


Other investing activities, net
 



(14,241
)





(14,241
)
Net cash used in investing activities
 

 
(18,146
)
 
(3,734
)
 
(29,505
)

(51,385
)
Cash flows from financing activities:
 








 
Repayment of capital lease obligations
 


(264
)





(264
)
Proceeds from borrowings on revolving credit facility
 
95,000








95,000

Repayments on revolving credit facility
 
(65,000
)







(65,000
)
Payment of deferred financing costs
 
(46
)







(46
)
Repurchases of common stock
 
(2,462
)







(2,462
)
Intercompany notes and accounts
 
(29,505
)





29,505



Other financing activities, net
 
(1,402
)







(1,402
)
Net cash provided by (used in) financing activities
 
(3,415
)
 
(264
)
 

 
29,505


25,826

Effect of changes in exchange rates on cash
 




(52
)



(52
)
Net decrease in cash and cash equivalents
 
(3,415
)
 
(901
)
 
(1,733
)
 

 
(6,049
)
Cash and cash equivalents at beginning of period
 
39,617


1,601


4,731




45,949

Cash and cash equivalents at end of period
 
$
36,202

 
$
700

 
$
2,998

 
$

 
$
39,900


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Table of Contents

 
 
Three Months Ended March 31, 2012
 
 
Parent
Company
 
Guarantor
Subsidiaries
 
Non-Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(in thousands)
Net cash provided by (used in) operating activities
 
$
(21,673
)
 
$
88,384

 
$
7,609

 
$

 
$
74,320

Cash flows from investing activities:
 
 
 
 
 
 
 
 
 


Capital expenditures
 

 
(166,557
)
 
(2,881
)
 

 
(169,438
)
Intercompany notes and accounts
 

 
58,363

 

 
(58,363
)
 

Other investing activities, net
 

 
6,966

 

 

 
6,966

Net cash used in investing activities
 

 
(101,228
)
 
(2,881
)
 
(58,363
)
 
(162,472
)
Cash flows from financing activities:
 
 
 
 
 
 
 

 
 
Proceeds from long-term debt
 
205,000

 

 

 

 
205,000

Repayment of capital lease obligations
 

 
(556
)
 

 

 
(556
)
Proceeds from borrowings on revolving credit facility
 
130,000

 

 

 

 
130,000

Repayments on revolving credit facility
 
(245,000
)
 

 

 

 
(245,000
)
Payment of deferred financing costs
 
(4,421
)
 

 

 

 
(4,421
)
Repurchases of common stock
 
(6,936
)
 

 

 

 
(6,936
)
Intercompany notes and accounts
 
(58,363
)
 

 

 
58,363

 

Other financing activities, net
 
4,859

 
6,190

 
933

 

 
11,982

Net cash provided by financing activities
 
25,139

 
5,634

 
933

 
58,363

 
90,069

Effect of changes in exchange rates on cash
 

 

 
(5,425
)
 

 
(5,425
)
Net increase (decrease) in cash and cash equivalents
 
3,466

 
(7,210
)
 
236

 

 
(3,508
)
Cash and cash equivalents at beginning of period
 
21,673

 
7,985

 
5,785

 

 
35,443

Cash and cash equivalents at end of period
 
$
25,139

 
$
775

 
$
6,021

 
$


$
31,935



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Table of Contents

NOTE 16. VARIABLE INTEREST ENTITIES
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 under the laws of Abu Dhabi, UAE. The purpose of the joint venture is to engage in conventional workover and drilling services, coiled tubing services, fishing and rental tools and services, rig monitoring services, pipe handling services and fluids, waste treatment and handling services. AlMansoori holds a 51% interest in the joint venture while we hold a 49% interest. However, we hold three of the five board of directors seats and a controlling financial interest. Future capital contributions to the joint venture will be made on equal terms and in equal amounts, and any future share capital increases will be issued in proportion to the initial share capital percentages but paid for by AlMansoori and Key in equal amounts. Also, we share the profits and losses of the joint venture on equal terms and in equal amounts with AlMansoori. The joint venture does not have sufficient resources to carry on its activities without our financial support; accordingly, we have determined it to be a variable interest entity of which we are the primary beneficiary. We consolidate the entity in our financial statements.
For the three months ended March 31, 2013 and 2012, we recognized $4.0 million and $3.3 million of revenue, respectively, and $0.9 million and $0.2 million of net income, respectively, associated with this joint venture. Also, we have guaranteed the performance of the joint venture under its sole services contract valued at $2.0 million. At March 31, 2013, there were approximately $16.0 million of assets and $13.6 million of liabilities in the joint venture. At December 31, 2012, there were approximately $16.2 million of assets and $14.7 million of liabilities in the joint venture. There are no restrictions on the use of assets and liabilities associated with the joint venture. Also, creditors of the joint venture have no recourse against us other than the $2.0 million performance guarantee previously mentioned.
NOTE 17. SUBSEQUENT EVENTS
On April 9, 2013 the Company completed the acquisition of the remaining 50% of the noncontrolling interest in Geostream for $14.6 million. Key now owns 100% of Geostream, which provides a wide range of drilling, workover and reservoir engineering services.



28

Table of Contents

ITEM 2.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
OVERVIEW    
Key Energy Services, Inc., its wholly owned subsidiaries and its controlled 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, the Middle East, and Russia. In addition, we have a technology development and control systems business based in Canada.
The following discussion and analysis should be read in conjunction with the accompanying unaudited condensed consolidated financial statements and related notes as of and for the three months ended March 31, 2013 and 2012, included elsewhere herein, and the audited consolidated financial statements and notes thereto included in our 2012 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 operating segments. See “Note 14. 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)
2013:
 
 
 
 
 
 
First Quarter
 
$
94.33

 
$
3.49

 
1,706

2012:
 
 
 
 
 
 
First Quarter
 
$
102.98

 
$
2.50

 
1,947

Second Quarter
 
$
93.06

 
$
2.35

 
1,924

Third Quarter
 
$
92.17

 
$
2.89

 
1,855

Fourth Quarter
 
$
88.01

 
$
3.40

 
1,759

 
(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.


29

Table of Contents

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 2012 through the first quarter of 2013:
 
 
 
Rig Hours
 
Trucking Hours
 
Key’s U.S. Working
Days (3)
2013:
 
U.S.
 
International Continuing Operations (1)
 
Total Continuing Operations (2)
 
 
 
 
First Quarter
 
337,714

 
114,103

 
451,817

 
580,862

 
62

Total 2013:
 
337,714

 
114,103

 
451,817

 
580,862

 
62

2012:
 
 
 
 
 
 
 
 
 
 
First Quarter
 
435,280

 
84,469

 
519,749

 
722,718

 
64

Second Quarter
 
428,864

 
104,656

 
533,520

 
685,587

 
63

Third Quarter
 
412,998

 
103,448

 
516,446

 
607,480

 
63

Fourth Quarter
 
357,628

 
113,246

 
470,874

 
594,770

 
62

Total 2012:
 
1,634,770

 
405,819

 
2,040,589

 
2,610,555

 
252

(1)
International continuing operations rig hours exclude rig hours generated in Argentina, as our Argentina operations were sold in the third quarter of 2012 and are reported as discontinued operations. Argentina rig hours were 54,625 and 55,972 for the first and second quarters of 2012, respectively.
(2)    Total continuing operations rig hours include U.S. rig hours and international continuing operations rig hours
(3)    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 March 31, 2013
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.
In our U.S. segment, our overall activity levels for our services were lower than anticipated for the first quarter of 2013 due to lower customer demand, adverse weather conditions, and the typical seasonal impact of shorter daylight hours. These factors resulted in reduced equipment utilization and slightly lower pricing for our services.
One of our larger customers meaningfully reduced its activity in California and the Permian Basin, which contributed to the decline in activity of our Rig Services business. Meanwhile, our Fluid Management Services business remains challenged due to chronic oversupply of equipment relative to customer activity, which has led us to commence a restructuring of this business. Conversely, our Coiled Tubing Services and Fishing and Rental Services benefitted from improved operating efficiencies during the quarter.
Internationally, our revenue declined in the first quarter of 2013 compared to the fourth quarter of 2012, as our principal customer in Mexico reduced activity in the North Region of the country, which negatively impacted our results. Additionally, during the quarter we expanded into the South Region of Mexico and grew our presence in Colombia and the Middle East.
Market Outlook    
We believe that macroeconomic fundamentals remain supportive of domestic and international oil and natural gas related drilling, workover and production maintenance activity. Thus far in 2013, U.S. activity has followed seasonal trends, which typically generate 3% to 5% activity improvement in the second quarter from first quarter levels, and we anticipate only a gradual activity increase for the year.
Subsequent to the first quarter, our customer in Mexico initiated material spending reductions. As a result, our activity in the North Region of Mexico has been reduced by approximately 50% from first quarter levels, and we believe our activity there will remain at this lower level through the third quarter of 2013. Meanwhile, we expect to redeploy idle rigs from the North Region to the South Region and to other countries, including the U.S., where we believe there are opportunities for these rigs.


30

Table of Contents

RESULTS OF OPERATIONS
The following table shows our consolidated results of operations for the three months ended March 31, 2013 and 2012, respectively (in thousands):
 
Three Months Ended
 
 
March 31,
 
 
2013
 
2012
 
REVENUES
$
428,449

 
$
486,751

 
COSTS AND EXPENSES:
 
 
 
 
Direct operating expenses
299,182

 
311,497

 
Depreciation and amortization expense
54,193

 
51,189

 
General and administrative expenses
63,245

 
60,918

 
Operating income
11,829

 
63,147

 
Interest expense, net of amounts capitalized
13,804

 
11,882

 
Other income, net
(1,223
)
 
(1,029
)
 
Income (loss) from continuing operations before tax
(752
)
 
52,294

 
Income tax benefit (expense)
566

 
(18,813
)
 
Income (loss) from continuing operations
(186
)
 
33,481

 
Loss from discontinued operations, net of tax benefit of $- and $16,354, respectively

 
(30,905
)
 
Net income (loss)
(186
)
 
2,576

 
Income (loss) attributable to noncontrolling interest
88

 
(614
)
 
INCOME (LOSS) ATTRIBUTABLE TO KEY
$
(274
)
 
$
3,190

 
Consolidated Results of Operations — Three Months Ended March 31, 2013 and 2012
Revenues
Our revenues for the three months ended March 31, 2013 decreased $58.3 million, or 12.0%, to $428.4 million from $486.8 million for the three months ended March 31, 2012, mostly due to lower demand for our rig-based services in oil markets and overall weaker economic conditions affecting both our domestic and international operations. See “Segment Operating Results — Three Months Ended March 31, 2013 and 2012 below for a more detailed discussion of the change in our revenues.
Direct Operating Expenses
Our direct operating expenses decreased $12.3 million, to $299.2 million (69.8% of revenues), for the three months ended March 31, 2013, compared to $311.5 million (64.0% of revenues) for the three months ended March 31, 2012. The decrease was a direct result of activity decreases in our business and better operating efficiencies in our coiled tubing and frac stack and flow back operations, partially offset by labor cost inefficiencies due to weather related work delays and the impact of higher employment taxes.
Depreciation and Amortization Expense
Depreciation and amortization expense increased $3.0 million, or 5.9%, to $54.2 million during the first quarter of 2013, compared to $51.2 million for the first quarter of 2012. The increase is primarily attributable to increased capital expenditures during 2012.
General and Administrative Expenses
General and administrative expenses increased $2.3 million, to $63.2 million (14.8% of revenues), for the three months ended March 31, 2013, compared to $60.9 million (12.5% of revenues) for the three months ended March 31, 2012. The increase is primarily related to a one-time $2.2 million charge associated with the retirement of an executive.

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Table of Contents

Interest Expense, Net of Amounts Capitalized
Interest expense increased $1.9 million, or 16.2%, to $13.8 million for the three months ended March 31, 2013, compared to $11.9 million for the same period in 2012. Interest expense for the three months ended March 31, 2013 increased due to the issuance of the additional $200 million aggregate principal amount of 2021 Notes during March 2012.
Other Income, Net
The following table summarizes the components of other income, net for the periods indicated:
 
Three Months Ended March 31,
 
2013
 
2012
 
(in thousands)
Interest income
$
(11
)
 
$
(7
)
Foreign exchange gain
(925
)
 
(939
)
Other income, net
(287
)
 
(83
)
Total
$
(1,223
)
 
$
(1,029
)
Income Tax Expense
We recorded income tax benefit of $0.6 million on pre-tax loss from continuing operations of $0.8 million in the first quarter of 2013, compared to income tax expense of $18.8 million on pre-tax income from continuing operations of $52.3 million in the first quarter of 2012. Our effective tax rate on continuing operations was 75.3% for the three months ended March 31, 2013, compared to 36.0% for the three months ended March 31, 2012. 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 various domestic and international taxing jurisdictions and the impact of permanent items that affect book income but do not affect taxable income.
Discontinued Operations
Our discontinued operations in 2012 related to the sale of our Argentina business, which was completed during the third quarter of 2012. Our net loss from discontinued operations for the three months ended March 31, 2013, was zero compared to a net loss from discontinued operations of $30.9 million for the three months ended March 31, 2012.
Noncontrolling Interest
For the three months ended March 31, 2013, we allocated $0.1 million associated with the income incurred by our joint ventures to the noncontrolling interest holders of these ventures compared to a loss of $0.6 million for the three months ended March 31, 2012.


32

Table of Contents

Segment Operating Results — Three Months Ended March 31, 2013 and 2012
The following table shows operating results for each of our segments for the three months ended March 31, 2013 and 2012 (in thousands):

For the three months ended March 31, 2013
 
 
 
 
 
 
 
 
 
 
U.S.
 
International
 
Functional
Support
 
Total
Revenues from external customers
 
$
346,072

 
$
82,377

 
$

 
$
428,449

Operating expenses
 
307,797

 
70,503

 
38,320

 
416,620

Operating income (loss)
 
38,275

 
11,874

 
(38,320
)
 
11,829


For the three months ended March 31, 2012
 
 
 
 
 
 
 
 
 
 
U.S.
 
International
 
Functional
Support
 
Total
Revenues from external customers
 
$
424,973

 
$
61,778

 
$

 
$
486,751

Operating expenses
 
333,515

 
51,410

 
38,679

 
423,604

Operating income (loss)
 
91,458

 
10,368

 
(38,679
)
 
63,147


U.S.
Revenues for our U.S. segment decreased $78.9 million, or 18.6%, to $346.1 million for the three months ended March 31, 2013, compared to $425.0 million for the three months ended March 31, 2012. The decrease for this segment was due to less customer spending, adverse weather conditions and lower activity in natural gas markets as well as increased competition.
Operating expenses for our U.S. segment were $307.8 million during the three months ended March 31, 2013, which represented a decrease of $25.7 million, or 7.7%, compared to $333.5 million for the same period in 2012. The decrease was directly attributable to lower activity in oil markets during the period and better operating efficiencies in Key's coiled tubing and frac stack and flow back operations, partially offset by labor cost inefficiencies due to weather related work delays and the impact of higher employment taxes.
International
Revenues for our International segment increased $20.6 million, or 33.3%, to $82.4 million for the three months ended March 31, 2013, compared to $61.8 million for the three months ended March 31, 2012. The increase was primarily attributable to increased activity in Mexico.
Operating expenses for our International segment increased $19.1 million, or 37.1%, to $70.5 million for the three months ended March 31, 2013, compared to $51.4 million for the three months ended March 31, 2012. These expenses increased as a direct result of additional activity during the period.
Functional Support
Operating expenses for Functional Support, which represent expenses associated with managing our U.S. and International reporting segments, decreased $0.4 million, or 0.9%, to $38.3 million (8.9% of consolidated revenues) for the three months ended March 31, 2013 compared to $38.7 million (7.9% of consolidated revenues) for the same period in 2012.



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LIQUIDITY AND CAPITAL RESOURCES
Current Financial Condition and Liquidity
As of March 31, 2013, we had cash and cash equivalents of $39.9 million. Our adjusted working capital (working capital excluding the current portion of capital lease obligations) was $348.9 million as of March 31, 2013, compared to $285.1 million as of December 31, 2012. Our adjusted working capital increased from the prior year end primarily as a result of lower accrued liabilities due to estimated federal tax payments and interest payments on our debt during the first quarter 2013. Our total outstanding debt (including capital leases) was $878.1 million, and we have no significant debt maturities until 2016. As of March 31, 2013, we have $195.0 million in borrowings and $54.1 million in committed letters of credit outstanding under our 2011 Credit Facility (defined below), leaving $300.9 million of available borrowing capacity subject to compliance with the terms of our senior secured credit facility.
Cash Flows
The following table summarizes our cash flows for the three-month periods ended March 31, 2013 and 2012:
 
 
Three Months Ended March 31,
 
 
2013
 
2012
 
 
(in thousands)
Net cash provided by operating activities
 
$
19,562

 
$
74,320

Cash paid for capital expenditures
 
(37,144
)
 
(169,438
)
Proceeds received from sale of fixed assets
 
374

 
6,966

Restricted funds held in escrow
 
(14,615
)
 

Repayments of capital lease obligations
 
(264
)
 
(556
)
Proceeds from long-term debt
 

 
205,000

Proceeds from borrowings on revolving credit facility
 
95,000

 
130,000

Repayments on revolving credit facility
 
(65,000
)
 
(245,000
)
Repurchases of common stock
 
(2,462
)
 
(6,936
)
Other financing activities, net
 
(1,448
)
 
7,561

Effect of exchange rates on cash
 
(52
)
 
(5,425
)
Net decrease in cash and cash equivalents
 
$
(6,049
)
 
$
(3,508
)

Cash provided by operating activities was $19.6 million and $74.3 million for the three months ended March 31, 2013 and 2012, respectively.
Cash used in investing activities was $51.4 million and $162.5 million for the three months ended March 31, 2013 and 2012, respectively. Investing cash outflows during these periods consisted primarily of capital expenditures. Our capital expenditures through March 31, 2013 primarily related to major maintenance of our existing fleet and equipment. Additionally, during the first quarter of 2013, as previously disclosed, Key funded into escrow the $14.6 million for the acquisition of the remaining 50% of the noncontrolling interest in Geostream, its joint venture in Russia, which closed on April 9, 2013.
Cash provided by financing activities was $25.8 million and $90.1 million during the three months ended March 31, 2013 and 2012, respectively. Overall financing cash inflows for 2013 related to net revolver borrowings on the revolving credit facility. Overall financing cash inflows for 2012 related to the proceeds from the issuance of the Additional 2021 Notes, partially offset by net payments on the revolving credit facility.

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Table of Contents

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 significant maturities of debt until 2016. Interest on our revolving credit facility is due each quarter. Interest to be paid for the remainder of 2013 is approximately $0.3 million and $2.3 million related to our 2014 Notes and 2021 Notes (each defined below), respectively. We expect to fund interest payments from cash generated by operations. At March 31, 2013, our annual debt maturities for our 2014 Notes and 2021 Notes and borrowings under our 2011 Credit Facility were as follows:
 
Year
Principal
Payments
 
(in thousands)
2013
$

2014
3,573

2015

2016
195,000

2017 and thereafter
675,000

Total principal payments
$
873,573

At March 31, 2013, we were in compliance with all the covenants under the 2011 Credit Facility and the indentures governing the 2014 Notes and 2021 Notes.
8.375% Senior Notes due 2014
We have outstanding $3.6 million aggregate principal amount of 8.375% Senior Notes due 2014 (the “2014 Notes”). The 2014 Notes are general unsecured senior obligations and are subordinate to all of our existing and future secured indebtedness. The 2014 Notes are jointly and severally guaranteed on a senior unsecured basis by certain of our existing and future domestic subsidiaries. Interest on the 2014 Notes is payable on June 1 and December 1 of each year.
The indenture governing the 2014 Notes contains various covenants. These covenants are subject to certain exceptions and qualifications, and contain cross-default provisions tied to the covenants of our 2011 Credit Facility. We were in compliance with these covenants at March 31, 2013.
6.75% Senior Notes due 2021
We issued $475.0 million aggregate principal amount of 6.75% Senior Notes due 2021 on March 4, 2011 and issued an additional $200.0 million aggregate principal amount of the 2021 Notes in a private placement on March 8, 2012 (collectively, the “2021 Notes”) 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 January 29, 2013, we commenced an offer to exchange the $200.0 million in aggregate principal amount of unregistered 2021 Notes on March 8, 2012 for an equal principal amount of such notes registered under the Securities Act of 1933. The exchange offer was completed on March 5, 2013. All of the 2021 Notes are treated as a single class under the Indenture and as of the closing of the exchange offer, 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.

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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 before March 1, 2014, we may on any one or more occasions redeem up to 35% of the aggregate principal amount of the outstanding 2021 Notes at a redemption price of 106.75% of the principal amount, plus accrued and unpaid interest to the redemption date, with the net cash proceeds from any one or more equity offerings provided that (i) at least 65% of the aggregate principal amount of the 2021 Notes remains outstanding immediately after each such redemption and (ii) each such redemption shall occur within 180 days of the date of the closing of such equity offering.
In addition, 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. 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 March 31, 2013, the 2021 Notes were 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 credit rating assigned to the 2021 Notes later falls below investment grade. We were in compliance with these covenants at March 31, 2013.

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Table of Contents

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 0.50%.
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.

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 March 31, 2013. 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 March 31, 2013, we had borrowings of $195.0 million outstanding under the revolving credit facility and $54.1 million of letters of credit outstanding, leaving $300.9 million of available borrowing capacity subject to compliance with the debt to capitalization limitation under the terms of the 2011 Credit Facility. The weighted average interest rate on the outstanding borrowings under the 2011 Credit Facility was 2.68% and 2.71% for the three-month periods ended March 31, 2013 and March 31, 2012, respectively.

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Table of Contents

Capital Lease Agreements
We lease equipment, such as vehicles, tractors, trailers, frac tanks and forklifts, from financial institutions under master lease agreements. As of March 31, 2013, there was $0.1 million outstanding under such equipment leases.
Off-Balance Sheet Arrangements
At March 31, 2013 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 March 31, 2013, we had cash and cash equivalents of $39.9 million, available borrowing capacity of $300.9 million subject to compliance with the terms of 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.
Capital Expenditures
During the three months ended March 31, 2013, our capital expenditures totaled $37.1 million, primarily related to major maintenance of our existing fleet and equipment. Our capital expenditure plan for 2013 is $210.0 million for equipment maintenance needs, including ongoing upgrades to our rig services fleet. Our capital expenditure program for 2013 is subject to market conditions, including activity levels, commodity prices, industry capacity and specific customer needs. Our focus for 2013 will be the maximization of our current equipment fleet, but we may choose to increase our capital expenditures in 2013 to increase market share or expand our presence into a new market. We currently anticipate funding our 2013 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 warrant 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.

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Table of Contents

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 2012 Form 10-K. More detailed information concerning market risk can be found in “Item 7A. Quantitative and Qualitative Disclosures about Market Risk“ in our 2012 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 first quarter of 2013 that materially affected, or were reasonably likely to materially affect, our internal control over financial reporting.
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 9. Commitments and Contingencies” in “Item 1. Financial Statements” of Part I of this report, which is incorporated herein by reference.
ITEM 1A.
RISK FACTORS
There have been no material changes in our risk factors disclosed in our 2012 Form 10-K. For a discussion of these risk factors, see “Item 1A. Risk Factors” in our 2012 Form 10-K.

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Table of Contents

ITEM 2.     UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
During the three months ended March 31, 2013, 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:
ISSUER PURCHASES OF EQUITY SECURITIES
Period
 
Number of
Shares Purchased (1)
 
Weighted
Average Price
Paid per Share (2)
 
Total Number of
Shares Purchased
as Part of Publicly
Announced Plans
or Programs
 
Approximate
Dollar Amount of
Shares that may
yet be Purchased
Under the Plans
or Programs
January 1, 2013 to January 31, 2013
 
2,719

 
$
8.44

 

 
$

February 1, 2013 to February 28, 2013
 
10,674

 
7.98

 

 

March 1, 2013 to March 31, 2013
 

 

 

 

Total
 
13,393

 
$
8.07

 

 
$

 
(1)
Represents shares repurchased to satisfy tax withholding obligations upon the vesting of restricted stock awards.
(2)
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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Table of Contents

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:
May 3, 2013
 
 
By:
/s/ J. MARSHALL DODSON
 
 
 
 
 
J. Marshall Dodson

 
 
 
 
 
Senior Vice President and Chief Financial Officer
(As duly authorized officer and Principal Financial Officer)

41


EXHIBIT INDEX

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
  
Fifth Amended and Restated By-laws of Key Energy Services, Inc. as amended through July 19, 2012. (Incorporated by reference to Exhibit 3.1 of our Current Report on Form 8-K filed on July 20, 2012, File No. 001-08038.)
 
 
4.1
 
Fifth Supplemental Indenture, dated as of January 17, 2013, to Indenture dated as of November 29, 2007, by and among Key Energy Services, Inc., the subsidiary guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee.  (Incorporated by reference to Exhibit 4.1.6 of our Annual Report on Form 10‑K for the year ended December 31, 2012, File No. 001-08038.)

 
 
 
4.2
 
Second Supplemental Indenture, dated as of January 17, 2013, to Indenture dated as of March 4, 2011, among Key Energy Services, Inc., the guarantors named therein and The Bank of New York Mellon Trust Company, N.A., as trustee.  (Incorporated by reference to Exhibit 4.2.4 of our Annual Report on Form 10‑K for the year ended December 31, 2012, File No. 001-08038.)
 
 
 
10.1
 
Form of Restricted Stock Award Agreement under 2012 Equity and Cash Incentive Plan.  (Incorporated by reference to Exhibit 10.1 of our Current Report on Form 8-K filed on January 25, 2013, File No. 001-08038.)
 
 
 
10.2
 
Form of Performance Unit Award Agreement under 2012 Equity and Cash Incentive Plan.  (Incorporated by reference to Exhibit 10.2 of our Current Report on Form 8-K filed on January 25, 2013, File No. 001-08038.)
 
 
 
10.3
 
Form of Restricted Stock Unit Award Agreement (Canadian) under 2012 Equity and Cash Incentive Plan.  (Incorporated by reference to Exhibit 10.4.5 of our Annual Report on Form 10‑K for the year ended December 31, 2012, File No. 001‑08038.)
 
 
 
10.4
 
Form of Restricted Stock Unit Award Agreement (Non-Canadian) under 2012 Equity and Cash Incentive Plan.  (Incorporated by reference to Exhibit 10.4.6 of our Annual Report on Form 10‑K for the year ended December 31, 2012, File No. 001‑08038.)
 
 
 
10.5
 
Key Energy Services, Inc. 2013 Performance Unit Plan.  (Incorporated by reference to Exhibit 10.5 of our Annual Report on Form 10‑K for the year ended December 31, 2012, File No. 001‑08038.)
 
 
 
10.6
 
Employment Agreement, dated as of March 25, 2013, by and between John Marshall Dodson and Key Energy Services, LLC (Incorporated by reference to Exhibit 10.1 of our Current Report on Form 8-K filed on March 28, 2013, 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


42