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KEY ENERGY SERVICES INC - Quarter Report: 2011 June (Form 10-Q)

Form 10-Q for quarterly period ended June 30, 2011
Table of Contents

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

Form 10-Q

 

 

(Mark One)

 

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

For the Quarterly Period Ended June 30, 2011

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   þ     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  þ     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   þ    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   þ

As of July 29, 2011, the number of outstanding shares of common stock of the registrant was 143,096,368.

 

 

 


Table of Contents

KEY ENERGY SERVICES, INC.

QUARTERLY REPORT ON FORM 10-Q

For the Quarter Ended June 30, 2011

 

Part I — Financial Information

 

Item 1.

 

Financial Statements

    3   

Item 2.

 

Management’s Discussion and Analysis of Financial Condition and Results of Operations

    33   

Item 3.

 

Quantitative and Qualitative Disclosures About Market Risk

    45   

Item 4.

 

Controls and Procedures

   
45
  

Part II — Other Information

 

Item 1.

 

Legal Proceedings

    46   

Item 1A.

 

Risk Factors

    46   

Item 2.

 

Unregistered Sales of Equity Securities and Use of Proceeds

    46   

Item 3.

 

Defaults Upon Senior Securities

    46   

Item 4.

 

(Removed and Reserved)

    46   

Item 5.

 

Other Information

    46   

Item 6.

 

Exhibits

    46   

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, 2010.

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

 

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PART I — FINANCIAL INFORMATION

 

ITEM 1. FINANCIAL STATEMENTS

Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(In thousands, except share amounts)

 

     June 30,
2011
    December  31,
2010
 
      
     (unaudited)        
ASSETS   

Current assets:

    

Cash and cash equivalents

   $ 14,641      $ 56,628   

Accounts receivable, net of allowance for doubtful accounts of $8,580 and $7,791, respectively

     376,809        261,818   

Inventories

     31,229        23,516   

Other current assets

     77,530        72,058   
  

 

 

   

 

 

 

Total current assets

     500,209        414,020   
  

 

 

   

 

 

 

Property and equipment

     1,987,042        1,832,443   

Accumulated depreciation

     (958,002     (895,699
  

 

 

   

 

 

 

Property and equipment, net

     1,029,040        936,744   
  

 

 

   

 

 

 

Goodwill

     466,414        447,609   

Other intangible assets, net

     47,694        58,151   

Deferred financing costs, net

     14,201        7,806   

Equity method investments

     1,024        5,940   

Other non-current assets

     25,496        22,666   
  

 

 

   

 

 

 

TOTAL ASSETS

   $ 2,084,078      $ 1,892,936   
  

 

 

   

 

 

 
LIABILITIES AND EQUITY   

Current liabilities:

    

Accounts payable

   $ 75,152      $ 56,310   

Other current liabilities

     201,158        221,346   

Current portion of capital leases and long-term debt

     2,881        3,979   
  

 

 

   

 

 

 

Total current liabilities

     279,191        281,635   
  

 

 

   

 

 

 

Capital leases and long-term debt

     569,672        427,121   

Other non-current liabilities

     221,107        202,377   

Commitments and contingencies

    

Equity:

    

Common stock, $0.10 par value; 200,000,000 shares authorized, 142,977,896 and 141,656,426 shares issued and outstanding

     14,298        14,166   

Additional paid-in capital

     788,717        775,601   

Accumulated other comprehensive loss

     (53,098     (51,334

Retained earnings

     228,598        210,653   
  

 

 

   

 

 

 

Total equity attributable to Key

     978,515        949,086   

Noncontrolling interest

     35,593        32,717   
  

 

 

   

 

 

 

Total equity

     1,014,108        981,803   
  

 

 

   

 

 

 

TOTAL LIABILITIES AND EQUITY

   $ 2,084,078      $ 1,892,936   
  

 

 

   

 

 

 

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
June 30,
    Six Months Ended
June 30,
 
     2011     2010     2011     2010  

REVENUES

   $ 445,369      $ 267,785      $ 836,353      $ 519,744   

Direct operating expenses

     290,620        196,171        562,420        385,373   

Depreciation and amortization expense

     39,852        32,478        79,775        65,802   

General and administrative expenses

     55,003        44,866        107,782        83,893   
  

 

 

   

 

 

   

 

 

   

 

 

 

Operating income (loss)

     59,894        (5,730     86,376        (15,324
  

 

 

   

 

 

   

 

 

   

 

 

 

Loss on early extinguishment of debt

                   46,451          

Interest expense, net of amounts capitalized

     10,041        10,729        20,352        20,988   

Other, net

     (7,319     467        (9,704     (776
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) from continuing operations before tax

     57,172        (16,926     29,277        (35,536

Income tax (expense) benefit

     (20,812     5,888        (11,629     13,596   
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) from continuing operations

     36,360        (11,038     17,648        (21,940

Income from discontinued operations, net of tax expense of $0, $(4,312), $0 and $(5,529), respectively

            8,182               10,077   
  

 

 

   

 

 

   

 

 

   

 

 

 

Net income (loss)

     36,360        (2,856     17,648        (11,863
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) attributable to noncontrolling interest

     280        (620     (297     (2,047
  

 

 

   

 

 

   

 

 

   

 

 

 

INCOME (LOSS) ATTRIBUTABLE TO KEY

   $ 36,080      $ (2,236   $ 17,945      $ (9,816
  

 

 

   

 

 

   

 

 

   

 

 

 

Earnings (loss) per share from continuing operations attributable to Key:

        

Basic

   $ 0.25      $ (0.08   $ 0.13      $ (0.16

Diluted

   $ 0.25      $ (0.08   $ 0.13      $ (0.16

Earnings per share from discontinued operations:

        

Basic

   $      $ 0.06      $      $ 0.08   

Diluted

   $      $ 0.06      $      $ 0.08   

Earnings (loss) per share attributable to Key:

        

Basic

   $ 0.25      $ (0.02   $ 0.13      $ (0.08

Diluted

   $ 0.25      $ (0.02   $ 0.13      $ (0.08

Income (loss) from continuing operations attributable to Key:

        

Income (loss) from continuing operations

   $ 36,360      $ (11,038   $ 17,648      $ (21,940

Income (loss) attributable to noncontrolling interest

     280        (620     (297     (2,047
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) from continuing operations attributable to Key

   $ 36,080      $ (10,418   $ 17,945      $ (19,893
  

 

 

   

 

 

   

 

 

   

 

 

 

Weighted average shares outstanding:

        

Basic

     142,833        125,412        142,521        125,183   

Diluted

     143,320        125,412        142,976        125,183   

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
June 30,
    Six Months Ended
June 30,
 
     2011     2010     2011     2010  

INCOME (LOSS) FROM CONTINUING OPERATIONS

   $ 36,360      $ (11,038   $ 17,648      $ (21,940

Other comprehensive (loss) income, net of tax:

        

Foreign currency translation (loss) gain

     (1,559     (429     348        (236

Gain on sale of equity method investment

     1,061               1,061          
  

 

 

   

 

 

   

 

 

   

 

 

 

Total other comprehensive (loss) income, net of tax

     (498     (429     1,409        (236
  

 

 

   

 

 

   

 

 

   

 

 

 

COMPREHENSIVE INCOME (LOSS) FROM CONTINUING OPERATIONS, NET OF TAX

     35,862        (11,467     19,057        (22,176

Comprehensive income from discontinued operations

            8,182               10,077   
  

 

 

   

 

 

   

 

 

   

 

 

 

COMPREHENSIVE INCOME (LOSS)

     35,862        (3,285     19,057        (12,099
  

 

 

   

 

 

   

 

 

   

 

 

 

Comprehensive (income) loss attributable to noncontrolling interest

     (871     715        (2,876     2,125   
  

 

 

   

 

 

   

 

 

   

 

 

 

COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO KEY

   $ 34,991      $ (2,570   $ 16,181      $ (9,974
  

 

 

   

 

 

   

 

 

   

 

 

 

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

 

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Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(In thousands)

(Unaudited)

 

     Six Months Ended
June 30,
 
     2011     2010  

CASH FLOWS FROM OPERATING ACTIVITIES:

    

Net income (loss)

   $ 17,648      $ (11,863

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

    

Depreciation and amortization expense

     79,775        72,560   

Bad debt expense

     1,618        (57

Accretion of asset retirement obligations

     292        259   

Income from equity method investments

     (757     (900

Gain on sale of equity method investment

     (4,783       

Loss on early extinguishment of debt

     46,451          

Amortization of deferred financing costs and discount

     816        1,319   

Deferred income tax expense (benefit)

     8,980        (5,246

Capitalized interest

     (1,076     (1,977

(Gain) loss on disposal of assets, net

     (507     645   

Share-based compensation

     9,086        6,438   

Excess tax benefits from share-based compensation

     (4,720     (2,172

Changes in working capital:

    

Accounts receivable

     (116,821     (70,261

Other current assets

     (10,595     55,220   

Accounts payable and accrued liabilities

     4,069        23,322   

Share-based compensation liability awards

     156        585   

Other assets and liabilities

     229        (3,177
  

 

 

   

 

 

 

Net cash provided by operating activities

     29,861        64,695   
  

 

 

   

 

 

 

CASH FLOWS FROM INVESTING ACTIVITIES:

    

Capital expenditures

     (178,077     (67,923

Proceeds from sale of fixed assets

     6,769        20,073   

Dividend from equity method investments

            165   

Proceeds from sale of equity method investments

     11,965          
  

 

 

   

 

 

 

Net cash used in investing activities

     (159,343     (47,685
  

 

 

   

 

 

 

CASH FLOWS FROM FINANCING ACTIVITIES:

    

Repayments of long-term debt

     (460,509     (6,970

Proceeds from long-term debt

     475,000          

Repayments of capital lease obligations

     (2,132     (3,992

Proceeds from borrowings on revolving credit facility

     143,000        30,000   

Repayments on revolving credit facility

     (53,000     (30,000

Payment of deferred financing costs

     (14,640       

Repurchases of common stock

     (5,399     (2,357

Proceeds from exercise of stock options

     4,841        2,083   

Excess tax benefits from share-based compensation

     4,720        2,172   
  

 

 

   

 

 

 

Net cash provided by (used in) financing activities

     91,881        (9,064
  

 

 

   

 

 

 

Effect of changes in exchange rates on cash

     (4,386     1,700   
  

 

 

   

 

 

 

Net (decrease) increase in cash and cash equivalents

     (41,987     9,646   
  

 

 

   

 

 

 

Cash and cash equivalents, beginning of period

     56,628        37,394   
  

 

 

   

 

 

 

Cash and cash equivalents, end of period

   $ 14,641      $ 47,040   
  

 

 

   

 

 

 

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. In addition, certain of our rigs are capable of specialty drilling applications. We operate in most major oil and natural gas producing regions of the continental United States and have operations based in Mexico, Colombia, the Middle East, Russia and Argentina. 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, 2010 balance sheet was prepared from audited financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2010 (the “2010 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 2010 Form 10-K.

Certain reclassifications have been made to prior period amounts to conform to current period financial statement classifications. We revised our reportable business segments effective in the first quarter of 2011, and in connection with the revision, have restated the corresponding items of segment information for all periods presented. The new operating segments are U.S. and International. We revised our segments to reflect changes in management’s resource allocation and performance assessment in making decisions regarding the Company. Our fluid management services, fishing and rental services, intervention services and domestic rig services businesses are aggregated within our U.S. segment. Our international rig services business and our Canadian technology development group are now aggregated within our International segment. These changes reflect our current operating focus in compliance with Accounting Standards Codification (“ASC”) No. 280, Segment Reporting (“ASC 280”). These presentation changes did not impact our consolidated net income, earnings per share, total current assets, total assets or total stockholders’ equity.

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- and six-month periods ended June 30, 2011 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 for possible disclosure as a subsequent event. Management monitored for subsequent events through the date these financial statements were available to be issued. Subsequent events that were identified by management as requiring disclosure are described in “Note 19. 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.

 

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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 2010 Form 10-K.

New Accounting Standards Adopted in this Report

ASU 2009-13. In October 2009, the FASB issued ASU 2009-13, Revenue Recognition (Topic 605) — Multiple-Deliverable Revenue Arrangements, a consensus of the FASB Emerging Issues Task Force (“ASU 2009-13”). ASU 2009-13 addresses the accounting for multiple-deliverable arrangements where products or services are accounted for separately rather than as a combined unit, and addresses how to separate deliverables and how to measure and allocate arrangement consideration to one or more units of accounting. As a result of ASU 2009-13, multiple-deliverable arrangements will be separated in more circumstances than under prior guidance. ASU 2009-13 establishes a selling price hierarchy for determining the selling price of a deliverable. The selling price will be based on vendor-specific objective evidence (“VSOE”) if it is available, on third-party evidence if VSOE is not available, or on an estimated selling price if neither VSOE nor third-party evidence is available. ASU 2009-13 also requires that an entity determine its best estimate of selling price in a manner that is consistent with that used to determine the selling price of the deliverable on a stand-alone basis, and increases the disclosure requirements related to an entity’s multiple-deliverable revenue arrangements. ASU 2009-13 must be prospectively applied to all revenue arrangements entered into or materially modified in fiscal years beginning on or after June 15, 2010. Entities may elect, but are not required, to adopt the amendments retrospectively for all periods presented. We adopted the provisions of ASU 2009-13 on January 1, 2011 and the adoption of this standard did not have a material impact on our financial position, results of operations, or cash flows.

ASU 2009-14. In October 2009, the FASB issued ASU 2009-14, Software (Topic 985) — Certain Revenue Arrangements That Include Software Elements — a consensus of the FASB Emerging Issues Task Force (“ASU 2009-14”). ASU 2009-14 was issued to address concerns relating to the accounting for revenue arrangements that contain tangible products and software that is “more than incidental” to the product as a whole. ASU 2009-14 changes the accounting model for revenue arrangements that include both tangible products and software elements to exclude those where the software components are essential to the tangible products’ core functionality. In addition, ASU 2009-14 also requires that hardware components of a tangible product containing software components always be excluded from the software revenue recognition guidance, and provides guidance on how to determine which software, if any, relating to tangible products is considered essential to the tangible products’ functionality and should be excluded from the scope of software revenue recognition guidance. ASU 2009-14 also provides guidance on how to allocate arrangement consideration to deliverables in an arrangement that contains tangible products and software that is not essential to the product’s functionality. ASU 2009-14 was issued concurrently with ASU 2009-13 and also requires entities to provide the disclosures required by ASU 2009-13 that are included within the scope of ASU 2009-14. ASU 2009-14 is effective prospectively for revenue arrangements entered into or materially modified in fiscal years beginning on or after June 15, 2010. Entities may also elect, but are not required, to adopt ASU 2009-14 retrospectively to prior periods, and must adopt ASU 2009-14 in the same period and using the same transition methods that it uses to adopt ASU 2009-13. We adopted the provisions of ASU 2009-14 on January 1, 2011 and the adoption of this standard did not have a material impact on our financial position, results of operations, or cash flows.

ASU 2010-13. In April 2010, the FASB issued ASU No. 2010-13, Compensation — Stock Compensation (Topic 718): Effect of Denominating the Exercise Price of a Share-Based Payment Award in the Currency of the Market in Which the Underlying Equity Security Trades. This ASU codifies the consensus reached in EITF Issue No. 09-J, “Effect of Denominating the Exercise Price of a Share-Based Payment Award in the Currency of the Market in Which the Underlying Equity Security Trades.” The amendments to the Codification clarify that an employee share-based payment award with an exercise price denominated in the currency of a market in which a substantial portion of the entity’s equity shares trades should not be considered to contain a condition that is not a market, performance, or service condition. Therefore, an entity would not classify such an award as a liability if it otherwise qualifies as equity. ASU 2010-13 is effective for fiscal years beginning on or after December 15, 2010. The amendments in this update should be applied by recording a cumulative-effect adjustment to the opening balance of retained earnings. The cumulative-effect adjustment should be calculated for all awards outstanding as of the beginning of the fiscal year in which the amendments are initially applied, as if the amendments had been applied consistently since the inception of the award. The cumulative-effect adjustment should be presented separately. We adopted the provisions of ASU 2010-13 on January 1, 2011 and the adoption of this standard did not have a material impact on our financial position, results of operations, or cash flows.

ASU 2010-28. In December 2010, the FASB issued ASU No. 2010-28, Intangibles — Goodwill and Other (Topic 350): When to Perform Step 2 of the Goodwill Impairment Test for Reporting Units with Zero or Negative Carrying Amounts. This ASU reflects the

 

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decision reached in EITF Issue No. 10-A. The amendments in this ASU modify Step 1 of the goodwill impairment test for reporting units with zero or negative carrying amounts. For those reporting units, an entity is required to perform Step 2 of the goodwill impairment test if it is more likely than not that a goodwill impairment exists. In determining whether it is more likely than not that goodwill impairment exists, an entity should consider whether there are any adverse qualitative factors indicating that impairment may exist. The qualitative factors are consistent with the existing guidance and examples, which require that goodwill of a reporting unit be tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. For public entities, the amendments in this ASU are effective for fiscal years, and interim periods within those years, beginning after December 15, 2010. We adopted the provisions of ASU 2010-28 on January 1, 2011 and the adoption of this standard did not have a material impact on our financial position, results of operations, or cash flows.

ASU 2010-29. In December 2010, the FASB issued ASU 2010-29, Business Combinations (Topic 805): Disclosure of Supplementary Pro Forma Information for Business Combinations. This ASU reflects the decision reached in EITF Issue No. 10-G. The amendments in this ASU affect any public entity as defined by Topic 805, Business Combinations, that enters into business combinations that are material on an individual or aggregate basis. The amendments in this ASU specify that if a public entity presents comparative financial statements, the entity should disclose revenue and earnings of the combined entity as though the business combination(s) that occurred during the current year had occurred as of the beginning of the comparable prior annual reporting period only. The amendments also expand the supplemental pro forma disclosures to include a description of the nature and amount of material, nonrecurring pro forma adjustments directly attributable to the business combination included in the reported pro forma revenue and earnings. ASU 2010-29 is effective prospectively for business combinations for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2010. We adopted the provisions of ASU 2010-29 on January 1, 2011 and the adoption of this standard may result in additional disclosures related to future acquisitions, but it will not have a material impact on our financial position, results of operations, or cash flows.

Accounting Standards Not Yet Adopted in this Report

ASU 2011-04. In May 2011, the FASB issued ASU 2011-04, Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRS. This ASU represents the converged guidance of the FASB and the IASB on measuring fair value and for disclosing information about fair value measurements. The amendments in this ASU clarify the Board’s intent about the application of existing fair value measurement and disclosure requirements and changes particular principles or requirements for measuring fair value and for disclosing information about fair value measurements. ASU 2011-04 is effective prospectively for interim and annual reporting periods beginning after December 15, 2011. We expect to adopt the provisions of ASU 2011-04 on January 1, 2012 and do not believe that the adoption of this standard will have a material impact on our financial position, results of operations, or cash flows.

ASU 2011-05. In June 2011, the FASB issued ASU 2011-05, Comprehensive Income (Topic 220): Presentation of Comprehensive Income. The amendments in this ASU allow an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. In both choices, an entity is required to present each component of net income along with total net income, each component of other comprehensive income along with a total for other comprehensive income, and a total amount for comprehensive income. This ASU eliminates the option to present the components of other comprehensive income as part of the statement of changes in stockholders’ equity. ASU 2011-05 should be applied retrospectively for interim and annual reporting periods beginning after December 15, 2011 with early adoption permitted. We expect to adopt the provisions of ASU 2011-05 on January 1, 2012 and do not believe that the adoption of this standard will have a material impact on our financial position, results of operations, or cash flows.

NOTE 3. ACQUISITIONS

2011 Acquisitions

Equity Energy Company (“EEC”). In January 2011, we acquired 10 saltwater disposal (“SWD”) wells from EEC for approximately $14.3 million. Most of these SWD wells are located in North Dakota. We accounted for this purchase as an asset acquisition.

 

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2010 Acquisitions

OFS Energy Services, LLC (“OFS”). In October 2010, we acquired certain subsidiaries, together with associated assets, owned by OFS, an oilfield services company of ArcLight Capital Partners, LLC. The total consideration for the acquisition was 15.8 million shares of our common stock and a cash payment of $75.8 million subject to certain working capital and other adjustments at closing. We accounted for this acquisition as a business combination. The results of operations for the acquired businesses have been included in our consolidated financial statements since the date of acquisition.

The following table summarizes the changes in the estimated fair values of the assets acquired and liabilities assumed between December 31, 2010 and June 30, 2011. We finalized the third-party valuations of the tangible and intangible assets during the second quarter and our acquisition accounting is final.

 

     June 30,
2011
     December 31,
2010
 
     (in thousands)  

At October 1, 2010:

     

Cash and cash equivalents

   $ 539       $ 539   

Acounts receivable

     23,335         23,384   

Other current assets

     1,372         1,372   

Property and equipment

     101,734         108,152   

Intangible assets

     17,696         20,988   

Deferred tax asset

     1,851         1,851   
  

 

 

    

 

 

 

Total identifiable assets acquired

     146,527         156,286   
  

 

 

    

 

 

 

Current liabilities

     18,881         18,498   

Other liabilities

     707         1,134   
  

 

 

    

 

 

 

Total liabilities assumed

     19,588         19,632   
  

 

 

    

 

 

 

Net identifiable assets acquired

     126,939         136,654   
  

 

 

    

 

 

 

Goodwill

     102,799         93,084   
  

 

 

    

 

 

 

Net assets acquired

   $ 229,738       $ 229,738   
  

 

 

    

 

 

 

Of the $17.7 million of acquired intangible assets, $16.7 million was assigned to customer relationships that will be amortized as the value of the relationships are realized using rates of 30.0%, 21.0%, 14.7%, 10.3%, 7.2%, 5.0% and 3.6% through 2017. The remaining $1.0 million of acquired intangible assets was assigned to non-compete agreements that will be amortized on a straight-line basis over 18 months. For the goodwill acquired, $101.7 million was assigned to intervention services, and $1.1 million was assigned to fluid management services, all of which are included in our U.S. reportable segment.

Five J.A.B., Inc. and Affiliates (“5 JAB”). In November 2010, we acquired 13 rigs and associated equipment from 5 JAB for cash consideration of approximately $14.6 million. We have accounted for this acquisition as a business combination. The goodwill acquired was assigned to rig-based services and is included in our U.S. reportable segment. The following table summarizes the changes in the estimated fair values of the assets acquired between December 31, 2010 and June 30, 2011. We completed the valuations of the property and equipment and intangible assets acquired during the second quarter and our acquisition accounting is final.

 

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     June 30,
2011
     December 31,
2010
 
     (in thousands)  

At November 15, 2010:

     

Property and equipment

   $ 9,560       $ 14,583   

Intangible assets

     2,512           
  

 

 

    

 

 

 

Total identifiable assets acquired

     12,072         14,583   
  

 

 

    

 

 

 

Total liabilities assumed

               
  

 

 

    

 

 

 

Net identifiable assets acquired

     12,072         14,583   
  

 

 

    

 

 

 

Goodwill

     2,511           
  

 

 

    

 

 

 

Net assets acquired

   $ 14,583       $ 14,583   
  

 

 

    

 

 

 

Enhanced Oilfield Technologies, LLC (“EOT”). In December 2010, we acquired 100% of the equity interests in EOT, a privately-held oilfield technology company, for a cash payment of $11.7 million and a performance earn-out equal to 8% of adjusted revenue over five years from the acquisition date. We have estimated our liability under the earn-out agreement to be $2.8 million. We accounted for this acquisition as a business combination. The acquired business was still in the developmental stage at the time of acquisition and continues to be in the developmental stage. The goodwill acquired of $10.1 million was assigned to fishing and rental services, which is included in our U.S. reportable segment. The acquired intangible asset of $4.4 million was assigned to developed technology and will be amortized on a straight line basis over a period of 20 years.

The following table summarizes the changes in the estimated fair values of the assets acquired between December 31, 2010 and June 30, 2011. We are in the process of finalizing third-party valuations of the intangible assets acquired; thus, the provisional measurements of intangible assets and goodwill are preliminary and subject to change.

 

     June 30,
2011
     December 31,
2010
 
     (in thousands)  

At December 15, 2010:

     

Intangible assets

   $ 4,420       $ 7,000   
  

 

 

    

 

 

 

Total identifiable assets acquired

     4,420         7,000   
  

 

 

    

 

 

 

Contingent consideration

     2,800           
  

 

 

    

 

 

 

Total liabilities assumed

     2,800           
  

 

 

    

 

 

 

Net identifiable assets acquired

     1,620         7,000   
  

 

 

    

 

 

 

Goodwill

     10,080         4,700   
  

 

 

    

 

 

 

Net assets acquired

   $ 11,700       $ 11,700   
  

 

 

    

 

 

 

NOTE 4. OTHER BALANCE SHEET INFORMATION

The table below presents comparative detailed information about other current assets at June 30, 2011 and December 31, 2010:

 

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     June 30,
2011
     December 31,
2010
 
     (in thousands)  

Other Current Assets:

     

Deferred tax assets

   $ 34,375       $ 32,046   

Prepaid current assets

     15,114         20,478   

Reinsurance receivable

     8,337         6,827   

VAT asset

     8,056         2,590   

Other

     11,648         10,117   
  

 

 

    

 

 

 

Total

   $ 77,530       $ 72,058   
  

 

 

    

 

 

 

The table below presents comparative detailed information about other current liabilities at June 30, 2011 and December 31, 2010:

 

     June 30,
2011
     December 31,
2010
 
     (in thousands)  

Other Current Liabilities:

     

Accrued payroll, taxes and employee benefits

   $ 71,702       $ 35,453   

Accrued operating expenditures

     36,027         39,399   

Income, sales, use and other taxes

     34,875         93,820   

Self-insurance reserve

     31,592         30,195   

Accrued interest

     10,492         4,097   

Insurance premium financing

     2,138         7,443   

Unsettled legal claims

     6,213         3,768   

Share-based compensation liabilities

     1,876         1,146   

Other

     6,243         6,025   
  

 

 

    

 

 

 

Total

   $ 201,158       $ 221,346   
  

 

 

    

 

 

 

The table below presents comparative detailed information about other noncurrent assets at June 30, 2011 and December 31, 2010:

 

     June 30,
2011
     December 31,
2010
 
     (in thousands)  

Other Noncurrent Assets:

     

Deposits

   $ 1,208       $ 1,478   

Reinsurance receivable

     8,394         7,650   

Deferred tax assets

     10,610         10,534   

Other

     5,284         3,004   
  

 

 

    

 

 

 

Total

   $ 25,496       $ 22,666   
  

 

 

    

 

 

 

The table below presents comparative detailed information about other noncurrent liabilities at June 30, 2011 and December 31, 2010:

 

 

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     June 30,
2011
     December 31,
2010
 
     (in thousands)  

Other Noncurrent Liabilities:

     

Deferred tax liabilities

   $ 159,099       $ 144,309   

Accrued insurance costs

     30,651         30,110   

Asset retirement obligations

     11,916         11,003   

Environmental liabilities

     5,691         4,011   

Income, sales, use and other taxes

     7,803         8,398   

Accrued rent

     1,780         1,998   

Share-based compensation liabilities

     76         1,106   

Other

     4,091         1,442   
  

 

 

    

 

 

 

Total

   $ 221,107       $ 202,377   
  

 

 

    

 

 

 

NOTE 5. GOODWILL AND OTHER INTANGIBLE ASSETS

We revised our reportable business segments effective in the first quarter of 2011, and accordingly, have restated goodwill by segment as of December 31, 2010. The changes in the carrying amount of goodwill for the six months ended June 30, 2011 are as follows:

 

     U.S.      International      Total  
            (in thousands)         

December 31, 2010

   $ 418,047       $ 29,562       $ 447,609   

Purchase price and other adjustments, net

     16,704                 16,704   

Impact of foreign currency translation

             2,101         2,101   
  

 

 

    

 

 

    

 

 

 

June 30, 2011

   $ 434,751       $ 31,663       $ 466,414   
  

 

 

    

 

 

    

 

 

 

The components of our other intangible assets as of June 30, 2011 and December 31, 2010 are as follows:

 

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     June 30,
2011
    December 31,
2010
 
     (in thousands)  

Noncompete agreements:

    

Gross carrying value

   $ 14,958      $ 15,058   

Accumulated amortization

     (9,963     (8,224
  

 

 

   

 

 

 

Net carrying value

   $ 4,995      $ 6,834   
  

 

 

   

 

 

 

Patents, trademarks and tradename:

    

Gross carrying value

   $ 11,141      $ 17,461   

Accumulated amortization

     (803     (927
  

 

 

   

 

 

 

Net carrying value

   $ 10,338      $ 16,534   
  

 

 

   

 

 

 

Customer relationships and contracts:

    

Gross carrying value

   $ 60,839      $ 60,057   

Accumulated amortization

     (33,117     (26,059
  

 

 

   

 

 

 

Net carrying value

   $ 27,722      $ 33,998   
  

 

 

   

 

 

 

Developed technology:

    

Gross carrying value

   $ 7,447      $ 3,106   

Accumulated amortization

     (2,847     (2,476
  

 

 

   

 

 

 

Net carrying value

   $ 4,600      $ 630   
  

 

 

   

 

 

 

Customer backlog:

    

Gross carrying value

   $ 742      $ 762   

Accumulated amortization

     (703     (607
  

 

 

   

 

 

 

Net carrying value

   $ 39      $ 155   
  

 

 

   

 

 

 

The changes in the carrying amount of other intangible assets are as follows (in thousands):

 

December 31, 2010

   $ 58,151   

Additions

       

Purchase price adjustments

     (3,360

Amortization expense

     (8,101

Impact of foreign currency translation

     1,004   
  

 

 

 

June 30, 2011

   $ 47,694   
  

 

 

 

The weighted average remaining amortization periods and expected amortization expense for the next five years for our intangible assets are as follows:

 

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Weighted

average
remaining

     Expected Amortization Expense  
     amortization
period (years)
     Remainder
of 2011
     2012      2013      2014      2015      2016  
                          (in thousands)                

Noncompete agreements

     1.9       $ 1,652       $ 2,597       $ 406       $ 340       $       $   

Patents, trademarks and tradename

     4.4         183         189         133         133         55         40   

Customer relationships and contracts

     6.7         5,622         6,822         4,910         3,492         2,491         1,871   

Developed technology

     19.0         402         221         221         221         221         221   

Customer backlog

     0.2         39                                           
     

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total intangible asset amortization expense

      $ 7,898       $ 9,829       $ 5,670       $ 4,186       $ 2,767       $ 2,132   
     

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

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. Additionally, certain of these assets are subject to purchase accounting adjustments. Purchase accounting adjustments in 2011 relate to reduction of fixed assets and intangibles acquired from OFS in 2010, and adjustments to the goodwill and intangibles related to the EOT and 5 JAB acquisitions. Amortization expense for our intangible assets was $3.9 million and $2.3 million for the three months ended June 30, 2011 and 2010, respectively, and $8.1 million and $5.1 million for the six months ended June 30, 2011 and 2010.

NOTE 6. EQUITY METHOD INVESTMENTS

IROC Energy Services Corp.

In April 2011, we sold our 8.7 million shares of IROC Energy Services Corp. (“IROC”), an Alberta-based oilfield services company, for $12.0 million, net of fees. We recorded a net gain on sale of $4.8 million (including the write-off of the cumulative translation adjustment of $1.1 million) during the second quarter of 2011, as the proceeds received exceeded the carrying value of our investment.

NOTE 7. LONG-TERM DEBT

As of June 30, 2011 and December 31, 2010, the components of our long-term debt were as follows:

 

     June 30,
2011
     December 31,
2010
 
     (in thousands)  

6.75% Senior Notes due 2021

   $ 475,000       $   

8.375% Senior Notes due 2014

     3,573         425,000   

Senior Secured Credit Facility revolving loans due 2016

     90,000           

Capital lease obligations

     3,980         6,100   
  

 

 

    

 

 

 

Total debt

     572,553         431,100   

Less current portion

     2,881         3,979   
  

 

 

    

 

 

 

Long-term debt and capital leases

   $ 569,672       $ 427,121   
  

 

 

    

 

 

 

 

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8.375% Senior Notes due 2014

On November 29, 2007, we issued $425.0 million aggregate principal amount of 8.375% Senior Notes due 2014 (the “2014 Notes”). On March 4, 2011, we repurchased $421.3 million aggregate principal amount of our 2014 Notes at a purchase price of $1,090 per $1,000 principal amount. On March 15, 2011, we repurchased an additional $0.1 million aggregate principal amount at a purchase price of $1,060 per $1,000 principal amount. In connection with the repurchase of the 2014 Notes, we incurred a loss of $44.3 million on the early extinguishment of debt related to the premium paid on the tender, the payment of related fees and the write-off of unamortized loan fees. Interest on the remaining $3.6 million aggregate principal amount of 2014 Notes outstanding is payable on June 1 and December 1 of each year.

6.75% Senior Notes due 2021

On March 4, 2011, we issued $475.0 million aggregate principal amount of 6.75% Senior Notes due 2021 (the “2021 Notes”). Net proceeds, after deducting underwriters’ fees and offering expenses, were $466.0 million. We used the net proceeds to repurchase the 2014 Notes as described above, including accrued and unpaid interest and fees and expenses. We capitalized $10.0 million of financing costs associated with the issuance of the 2021 Notes that will be amortized over the term of the notes.

The 2021 Notes are general unsecured senior obligations and are subordinate 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, beginning on September 1, 2011. The 2021 Notes mature on March 1, 2021.

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

 

Year

   Percentage  

2016

     103.375

2017

     102.250

2018

     101.125

2019 and thereafter

     100.000

At any time and from time to time 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 106.750% 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 governing the 2021 Notes (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;

 

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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 June 30, 2011, 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 June 30, 2011.

Senior Secured Credit Facility

On March 31, 2011, we simultaneously terminated (without pre-payment penalty) our $300 million credit agreement dated November 29, 2007, as amended, which was to mature no later than November 29, 2012, and entered into a new credit agreement with several lenders and JPMorgan Chase Bank, N.A., as Administrative Agent and Swing Line Lender, Bank of America, N.A., as Syndication Agent, and Capital One, N.A. and Wells Fargo Bank, N.A., as Co-Documentation Agents. In connection with the termination of our previous credit agreement, we incurred a loss of $2.2 million on early extinguishment of debt related to the write-off of the unamortized portion of deferred financing costs. The new 2011 credit agreement provides for a senior secured credit facility (the “2011 Credit Facility”) consisting of a revolving credit facility, letter of credit sub-facility and swing line facility of up to an aggregate principal amount of $400 million, all of which will mature no later than March 31, 2016. The 2011 Credit Facility and the obligations thereunder are secured by substantially all of our assets and those of our subsidiary guarantors and are guaranteed by certain of our existing and future domestic subsidiaries.

In connection with the execution of the 2011 Credit Facility, we capitalized $4.8 million of financing costs 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 consolidated funded indebtedness be no greater than 45% of our adjusted total capitalization;

 

   

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:

 

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Fiscal Quarter Ending

   Ratio  

June 30, 2011 through June 30, 2012

     1.85 to 1.00   

September 30, 2012 and thereafter

     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, up to 50% of which amount may be carried over for expenditure in the following fiscal year, if after giving pro forma effect thereto 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 million of availability under the 2011 Credit Facility); (vi) dividends and other distributions to, and redemptions and repurchases from, equityholders; (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. Furthermore, the 2011 Credit Facility provides that share repurchases in excess of $200 million can be made only if our debt to capitalization ratio is below 45%.

We were in compliance with these covenants at June 30, 2011. 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 June 30, 2011, we had borrowings of $90.0 million under the revolving credit facility and $59.5 million of letters of credit outstanding, leaving $250.5 million of available borrowing capacity under the 2011 Credit Facility. The weighted average interest rate on the outstanding borrowings under the 2011 Credit Facility was 2.76% for the three-month period ended June 30, 2011.

On July 27, 2011, we amended our 2011 Credit Facility. See “Note 19. Subsequent Events” for additional discussion.

NOTE 8. OTHER INCOME AND EXPENSE

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

 

     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2011     2010     2011     2010  
     (in thousands)     (in thousands)  

Loss (gain) on disposal of assets, net

   $ 162      $ 320      $ (507   $ 655   

Interest income

     (2     (21     (22     (36

Foreign exchange (gain) loss

     (2,717     855        (4,185     (509

Gain on sale of equity method investment

     (4,783            (4,783       

Other expense (income), net

     21        (687     (207     (886
  

 

 

   

 

 

   

 

 

   

 

 

 

Total

   $ (7,319   $ 467      $ (9,704   $ (776
  

 

 

   

 

 

   

 

 

   

 

 

 

 

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In April 2011 we sold our shares in IROC and recorded a gain on the sale of $4.8 million during the second quarter. Our foreign exchange gain relates to an increase in U.S. dollar-denominated transactions in our foreign locations and the strengthening of the U.S. dollar.

NOTE 9. INCOME TAXES

We are subject to U.S. federal income tax as well as income taxes in multiple state and foreign jurisdictions. Our effective tax rates for the three months ended June 30, 2011 and 2010 were 36.4% and 34.8%, respectively, and 39.7% and 38.3% for the six months ended June 30, 2011 and 2010, 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 June 30, 2011 and December 31, 2010, we had $2.3 million and $2.2 million, respectively, 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 and $0.1 million in each of the quarters ended June 30, 2011 and 2010 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 $0.9 million and $0.8 million for the payment of interest and penalties as of June 30, 2011 and December 31, 2010, respectively. We believe that it is reasonably possible that $0.9 million of our currently remaining unrecognized tax positions, each of which are 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 quarter ended June 30, 2011.

NOTE 10. COMMITMENTS AND CONTINGENCIES

Litigation

Various suits and claims arising in the ordinary course of business are pending against us. Due in part to the locations where we conduct business in the continental United States, we 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. As of June 30, 2011, the aggregate amount of our liabilities related to litigation that are deemed probable and reasonably estimable is $6.2 million. 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. During the second quarter of 2011, we recorded a net increase in our liability of $3.6 million related to new claims and the revision of our exposures for ongoing legal matters.

In June 2011, we agreed to accept $5.5 million in damages, related to the settlement of a KeyView® patent infringement lawsuit, which was paid in full in July 2011. We recognized related legal fees and other expenses of $1.3 million and $1.4 million during the three- and six-month periods ended June 30, 2011, respectively. The settlement amount has been recorded in general and administrative expenses on the condensed consolidated statement of operations.

Self-Insurance Reserves

We maintain reserves for workers’ compensation and vehicle liability on our balance sheet based on our judgment and estimates using an actuarial method based on claims incurred. We estimate general liability claims on a case-by-case basis. We maintain insurance policies for workers’ compensation, vehicle liability and general liability claims. These insurance policies carry self-insured retention limits or deductibles on a per occurrence basis. The retention limits or deductibles are accounted for in our accrual process for all workers’ compensation, vehicular liability and general liability claims. As of June 30, 2011 and December 31, 2010, we have recorded $62.2 million and $60.3 million, respectively, of self-insurance reserves related to workers’ compensation, vehicular liabilities and general liability claims. Partially offsetting these liabilities, we had $16.7 million and $15.4 million of insurance receivables as of June 30, 2011 and December 31, 2010, respectively. These insurance receivables are recorded as other assets as of June 30, 2011. 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.

 

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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 June 30, 2011 and December 31, 2010, we have recorded $5.7 million and $4.0 million, respectively, for our environmental remediation liabilities. We believe that the liabilities we have recorded are appropriate based on the known facts and circumstances and do not expect further losses materially in excess of the amounts already accrued.

NOTE 11. EARNINGS PER SHARE

Basic earnings per common 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
June 30,
    Six Months Ended
June 30,
 
     2011      2010     2011      2010  
    

(in thousands, except per share amounts)

 

Basic EPS Calculation:

          

Numerator

          

Income (loss) from continuing operations attributable to Key

   $ 36,080       $ (10,418   $ 17,945       $ (19,893

Income from discontinued operations, net of tax

             8,182                10,077   
  

 

 

    

 

 

   

 

 

    

 

 

 

Income (loss) attributable to Key

   $ 36,080       $ (2,236   $ 17,945       $ (9,816
  

 

 

    

 

 

   

 

 

    

 

 

 

Denominator

          

Weighted average shares outstanding

     142,833         125,412        142,521         125,183   

Basic earnings (loss) per share from continuing operations attributable to Key

   $ 0.25       $ (0.08   $ 0.13       $ (0.16

Basic earnings per share from discontinued operations

             0.06                0.08   
  

 

 

    

 

 

   

 

 

    

 

 

 

Basic earnings (loss) per share attributable to Key

   $ 0.25       $ (0.02   $ 0.13       $ (0.08
  

 

 

    

 

 

   

 

 

    

 

 

 

Diluted EPS Calculation:

          

Numerator

          

Income (loss) from continuing operations attributable to Key

   $ 36,080       $ (10,418   $ 17,945       $ (19,893

Income from discontinued operations, net of tax

             8,182                10,077   
  

 

 

    

 

 

   

 

 

    

 

 

 

Income (loss) attributable to Key

   $ 36,080       $ (2,236   $ 17,945       $ (9,816
  

 

 

    

 

 

   

 

 

    

 

 

 

Denominator

          

Weighted average shares outstanding

     142,833         125,412        142,521         125,183   

Stock options

     404                346           

Warrants

                    40           

Stock appreciation rights

     83                69           
  

 

 

    

 

 

   

 

 

    

 

 

 

Total

     143,320         125,412        142,976         125,183   

Diluted earnings (loss) per share from continuing operations attributable to Key

   $ 0.25       $ (0.08   $ 0.13       $ (0.16

Diluted earnings per share from discontinued operations

             0.06                0.08   
  

 

 

    

 

 

   

 

 

    

 

 

 

Diluted earnings (loss) per share attributable to Key

   $ 0.25       $ (0.02   $ 0.13       $ (0.08
  

 

 

    

 

 

   

 

 

    

 

 

 

The diluted earnings per share calculation for the three and six months ended June 30, 2011 exclude the potential exercise of less than 0.1 million and 0.1 million stock options, respectively. These options were considered anti-dilutive because the exercise prices exceeded the average price of our stock during those periods. None of our stock appreciation rights (“SARS”) were anti-dilutive for the three and six months ended June 30, 2011. Because of our loss from continuing operations for the three and six months ended June 30, 2010, 3.3 million stock options and 0.4 million SARS were excluded from the calculation of our diluted earnings per share, as the potential exercise of those securities would be anti-dilutive in those periods. See “Note 19. Subsequent Events” for events occurring after June 30, 2011 that would materially affect the number of weighted average shares outstanding.

 

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NOTE 12. SHARE-BASED COMPENSATION

We recognized employee share-based compensation expense of $3.9 million and $3.4 million during the three months ended June 30, 2011 and 2010, respectively, and the related income tax benefit recognized was $1.4 million and $1.2 million, respectively. We recognized employee share-based compensation expense of $7.9 million and $6.5 million during the six months ended June 30, 2011 and 2010, respectively, and the related income tax benefit recognized was $2.8 million and $2.6 million, respectively. We did not capitalize any share-based compensation during the three- or six-month periods ended June 30, 2011 and 2010.

The unrecognized compensation cost related to our unvested stock options, restricted shares and phantom shares as of June 30, 2011 is estimated to be less than $0.1 million, $19.4 million and $0.3 million, respectively and is expected to be recognized over a weighted-average period of 1.0 years, 1.3 years and 0.8 years, respectively.

During March 2011, approximately 0.2 million performance units subject to the performance period of March 2010 to March 2011 expired unvested. As of June 30, 2011, the fair value of the remaining performance units was $1.9 million, and is being accreted to compensation expense over the vesting terms of the awards. As of June 30, 2011, the unrecognized compensation cost related to our unvested performance units is estimated to be $0.6 million and is expected to be recognized over a weighted-average period of 0.7 years.

During May 2011, we issued 99,999 shares of common stock to our outside directors. These shares vested immediately and we recognized $1.6 million of expense related to these awards.

NOTE 13. 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 June 30, 2011 and December 31, 2010, these loans, in the aggregate, totaled less than $0.1 million, respectively.

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 June 30, 2011 and December 31, 2010, our receivables from these related parties totaled $0.6 million and $1.0 million, respectively. Revenues from these customers for the three-month periods ended June 30, 2011 and 2010 totaled $0.7 million and $0.5 million, respectively, and $2.1 million and $0.7 million for the six-month periods ended June 30, 2011 and 2010, respectively.

We provide services to an exploration and production company owned by one of our employees who had been the owner of the business we acquired. The prices charged to this company for these services are at rates that are an average of the prices charged to our other customers in the California market where the services are provided. As of June 30, 2011 and December 31, 2010, our receivables from this company totaled $0.5 million and $0.2 million, respectively. Revenues from this company totaled $1.0 million and $1.7 million for the three-month periods ended June 30, 2011 and 2010, respectively, and $1.6 million and $2.3 million for the six-month periods ended June 30, 2011 and 2010, respectively.

Board of Director Relationships with Customers

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 2% of our total revenues for each of the three- and six-month periods ended June 30, 2011 and 2010. Receivables outstanding from Anadarko were approximately 2% of our total accounts receivable as of June 30, 2011 and December 31, 2010, respectively. Transactions with Anadarko for our services are made on terms consistent with other customers.

 

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A former member of our board of directors who resigned in May 2011 is a member and managing director of the general partner of the indirect, majority owner of Element Petroleum, LP (“Element”), which is one of our customers. Sales to Element were less than 1% of our total revenues for the three and six months ended June 30, 2011 and 2010. Receivables outstanding from Element were less than 1% of our total accounts receivable as of June 30, 2011 and December 31, 2010. Transactions with Element for our services are made on terms consistent with other customers.

NOTE 14. ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS

The following is a summary of the carrying amounts and estimated fair values of our financial instruments as of June 30, 2011 and December 31, 2010.

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

 

     June 30, 2011      December 31, 2010  
     Carrying
Value
     Fair Value      Carrying
Value
     Fair Value  
    

(in thousands)

 

Financial assets:

           

Notes and accounts receivable — related parties

   $ 1,136       $ 1,136       $ 1,198       $ 1,198   

Financial liabilities:

           

6.75% Senior Notes

   $ 475,000       $ 475,000       $       $   

8.375% Senior Notes

     3,573         3,743         425,000         450,500   

Credit Facility revolving loans

     90,000         90,000                   

Notes and accounts receivable — related parties. The amounts reported relate to notes receivable from certain of our employees related to relocation and retention agreements and certain trade accounts receivable with affiliates. The carrying values of these items approximate their fair values as of the applicable balance sheet dates.

6.75% Senior Notes due 2021. The fair value of our 2021 Notes is based upon the quoted market prices for those securities as of the dates indicated. The carrying and fair values of these notes as of June 30, 2011 was $475.0 million.

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 June 30, 2011 was $3.6 million, and the fair value was $3.7 million (104.77% of carrying value).

Credit Facility Revolving Loans. Because of their variable interest rates, the fair values of the revolving loans borrowed under our 2011 Credit Facility approximate their carrying values. The carrying and fair values of these loans as of June 30, 2011 were $90.0 million.

NOTE 15. SEGMENT INFORMATION

We revised our reportable business segments as of the first quarter of 2011. The revised operating segments are U.S. and International. We also have a “Functional Support” segment associated with managing each of our reportable operating segments. Financial results as of and for the three and six months ended June 30, 2010 have been restated to reflect the change in operating segments. We revised our segments to reflect changes in management’s resource allocation and performance assessment in making decisions regarding our business. Our domestic rig services, fluid management services, fishing and rental services, and intervention services are now aggregated within our U.S. reportable segment. Our international rig services business and our Canadian technology development group are now aggregated within our International reportable segment. These changes reflect our current operating focus in compliance with ASC 280. We aggregate services that create our reportable segments in accordance with ASC 280, and the accounting policies for our segments are the same as those described in “Note 1. Organization and Summary of Significant Accounting Policies” of the notes to our consolidated financial statements included in Item 8 of our 2010 Form 10-K. We evaluate the

 

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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 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 well servicing rigs that are capable of providing conventional and horizontal drilling services. Our rigs consist of 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. 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 a newly drilled well, or a well that was recently extended through a workover, for production. 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. The completion process usually takes a few days to several weeks, 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.

The maintenance services that our rig fleet provides are generally required throughout the life cycle of an oil or natural gas well. Examples of the maintenance services that we provide as part of our rig-based services include routine mechanical repairs to the pumps, tubing and other equipment, removing debris and formation material from wellbores, and pulling the rods and other downhole equipment from wellbores to identify and resolve production problems. Maintenance services generally take less than 48 hours to complete.

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 fluid management services, including oilfield transportation and produced water disposal services, with our fleet of heavy and medium-duty trucks. The specific services offered include vacuum truck services, fluid transportation services and disposal services for operators whose wells produce saltwater or other non-hydrocarbon fluids. We also supply frac tanks used for temporary storage of fluids associated with fluid hauling operations. In addition, we provide equipment trucks that are used to move large pieces of equipment from one well site to the next, and we operate a fleet of hot oilers capable of pumping heated fluids used to clear soluble restrictions in a wellbore.

Fluid hauling trucks are utilized in connection with drilling and workover projects, which tend to use large amounts of various fluids. In connection with drilling, maintenance or workover activity at a well site, we transport fresh and brine water to the well site and provide temporary storage and disposal of produced saltwater and drilling or workover fluids. These fluids are removed from the well site and transported for disposal in a saltwater disposal well owned by us or a third party.

 

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Intervention Services

Our intervention services include our coiled tubing services business and our specialty pumping business. Coiled tubing services involve the use of a continuous metal pipe spooled on a large reel for oil and natural gas well applications, such as wellbore clean-outs, nitrogen jet lifts, and through-tubing fishing and formation stimulations utilizing acid, chemical treatments and fracturing. Coiled tubing is also used for a number of horizontal well applications such as milling temporary plugs between frac stages.

Fishing & 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, power swivels and foam air units.

International Segment

Our international operations include Mexico, Colombia, the Middle East, the Russian Federation and Argentina. Services in these locations include rig-based services such as the maintenance, workover, and recompletion of existing oil and natural gas wells, completion of newly-drilled wells, and plugging and abandonment of wells at the end of their useful lives. We also provide drilling services in the regions where we work and we provide engineering services for the development of reservoirs.

Our operations in Mexico consist mainly of drilling, workover, project management and consulting services. We generate significant revenue from our contract with the Mexican national oil company, Petróleos Mexicanos.

In Argentina and Colombia, our operations consist of drilling and workover services. Our operations in Colombia commenced in the third quarter of 2010.

In Russia, we provide drilling, workover, and reservoir engineering services. Our Russian operations are structured as a joint venture in which we have a controlling financial interest.

In the Middle East, we formed a joint venture in the first quarter of 2010 in which we have a controlling financial interest. We commenced operations in the Middle East in the fourth quarter of 2010. Our operations in the Middle East consist mainly of drilling and workover services.

Advanced Measurements, Inc. (“AMI”)

Also included in our International segment is AMI, our technology development and control systems business based in Canada. AMI is focused on oilfield service equipment controls, data acquisition and digital information flow.

Functional Support Segment

Our Functional Support segment manages our U.S. and International operating segments. Functional Support assets consist primarily of cash and cash equivalents, accounts and notes receivable and investments in subsidiaries, deferred financing costs, our equity-method investments and deferred income tax assets.

The following tables set forth our segment information as of and for the three- and six-month periods ended June 30, 2011 and 2010:

 

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As of and for the three months ended June 30, 2011

 

     U.S.      International      Functional
Support
    Reconciling
Eliminations
    Total  

Revenues from external customers

   $ 367,455       $ 77,914       $      $      $ 445,369   

Intersegment revenues

             2,147                (2,147       

Depreciation and amortization

     33,824         3,082         2,946               39,852   

Other operating expenses

     247,429         68,455         29,739               345,623   

Operating income (loss)

     86,202         6,377         (32,685            59,894   

Loss on early extinguishment of debt

                                     

Interest expense, net of amounts capitalized

     13         492         9,536               10,041   

Income (loss) from continuing operations before tax

     86,512         8,244         (37,584            57,172   

Long-lived assets1

     1,415,264         192,262         229,936        (253,593     1,583,869   

Total assets

     1,744,293         396,456         427,942        (484,613     2,084,078   

Capital expenditures, excluding acquisitions

     54,832         11,945         3,861               70,638   

As of and for the three months ended June 30, 2010

 

     U.S.     International     Functional
Support
    Reconciling
Eliminations
    Total  

Revenues from external customers

   $ 224,221      $ 43,564      $      $      $ 267,785   

Intersegment revenues

     2,257                      (2,257       

Depreciation and amortization

     26,235        3,921        2,322               32,478   

Other operating expenses

     163,270        51,498        26,269               241,037   

Operating income (loss)

     34,716        (11,855     (28,591            (5,730

Interest expense, net of amounts capitalized

     (207     (59     10,995               10,729   

Income (loss) from continuing operations before tax

     34,436        (12,582     (38,780            (16,926

Long-lived assets1

     1,040,088        90,458        132,344               1,262,890   

Total assets

     1,418,581        280,388        248,973        (266,106     1,681,836   

Capital expenditures, excluding acquisitions

     23,797        3,613        8,098               35,508   

As of and for the six months ended June 30, 2011

 

     U.S.      International      Functional
Support
    Reconciling
Eliminations
    Total  

Revenues from external customers

   $ 697,359       $ 138,994       $      $      $ 836,353   

Intersegment revenues

             4,010                (4,010       

Depreciation and amortization

     66,252         7,577         5,946               79,775   

Other operating expenses

     486,258         123,472         60,472               670,202   

Operating income (loss)

     144,849         7,945         (66,418            86,376   

Loss on early extinguishment of debt

                     46,451               46,451   

Interest (income) expense, net of amounts capitalized

     54         911         19,387               20,352   

Income (loss) from continuing operations before tax

     146,013         10,230         (126,966            29,277   

Long-lived assets1

     1,415,264         192,262         229,936        (253,593     1,583,869   

Total assets

     1,744,293         396,456         427,942        (484,613     2,084,078   

Capital expenditures, excluding acquisitions

     150,555         20,905         6,617               178,077   

 

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As of and for the six months ended June 30, 2010

 

     U.S.     International     Functional
Support
    Reconciling
Eliminations
    Total  

Revenues from external customers

   $ 420,529      $ 99,215      $      $      $ 519,744   

Intersegment revenues

     3,142                      (3,142       

Depreciation and amortization

     53,532        7,668        4,602               65,802   

Other operating expenses

     318,907        102,269        48,090               469,266   

Operating income (loss)

     48,090        (10,722     (52,692            (15,324

Interest (income) expense, net of amounts capitalized

     (674     (215     21,877               20,988   

Income (loss) from continuing operations before tax

     47,819        (9,799     (73,556            (35,536

Long-lived assets1

     1,040,088        90,458        132,344               1,262,890   

Total assets

     1,418,581        280,388        248,973        (266,106     1,681,836   

Capital expenditures, excluding acquisitions

     44,661        9,570        13,692               67,923   

 

1 

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

NOTE 16. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

During the first quarter of 2011, we issued the 2021 Notes, which are guaranteed by virtually all of our domestic subsidiaries, all of which are wholly-owned. These 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.” The information presented below for the year ended December 31, 2010 reflects our previous guarantee arrangements under the 2014 Notes, which were issued in the fourth quarter of 2007 and of which an aggregate principal amount of $3.6 million remains outstanding as of June 30, 2011.

 

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CONDENSED CONSOLIDATING BALANCE SHEETS

 

     June 30, 2011  
     Parent
Company
     Guarantor
Subsidiaries
     Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Assets:

            

Current assets

   $ 28,445       $ 377,611       $ 94,153      $      $ 500,209   

Property and equipment, net

             945,438         83,602               1,029,040   

Goodwill

             434,751         31,663               466,414   

Deferred financing costs, net

     14,201                               14,201   

Intercompany notes and accounts receivable and investment in subsidiaries

     2,325,766         787,504         (8,530     (3,104,740       

Other assets

     104         18,017         56,093               74,214   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

TOTAL ASSETS

   $ 2,368,516       $ 2,563,321       $ 256,981      $ (3,104,740   $ 2,084,078   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Liabilities and equity:

            

Current liabilities

   $ 78,341       $ 130,456       $ 70,394      $      $ 279,191   

Long-term debt and capital leases, less current portion

     568,573         1,099                       569,672   

Intercompany notes and accounts payable

     616,529         1,885,735         26,987        (2,529,251       

Deferred tax liabilities

     89,269         69,822         8               159,099   

Other long-term liabilities

     1,696         60,331         (19            62,008   

Equity

     1,014,108         415,878         159,611        (575,489     1,014,108   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

TOTAL LIABILITIES AND EQUITY

   $ 2,368,516       $ 2,563,321       $ 256,981      $ (3,104,740   $ 2,084,078   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 
     December 31, 2010  
     Parent
Company
     Guarantor
Subsidiaries
     Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  

Assets:

            

Current assets

   $ 20,287       $ 287,244       $ 106,489      $      $ 414,020   

Property and equipment, net

             861,041         75,703               936,744   

Goodwill

             418,047         29,562               447,609   

Deferred financing costs, net

     7,806                               7,806   

Intercompany notes and accounts receivable and investment in subsidiaries

     2,110,185         757,657         (6,226     (2,861,616       

Other assets

     5,234         56,954         24,569               86,757   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

TOTAL ASSETS

   $ 2,143,512       $ 2,380,943       $ 230,097      $ (2,861,616   $ 1,892,936   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Liabilities and equity:

            

Current liabilities

   $ 77,144       $ 142,962       $ 61,529      $      $ 281,635   

Long-term debt and capital leases, less current portion

     425,000         2,116         5               427,121   

Intercompany notes and accounts payable

     587,801         1,738,214         120,410        (2,446,425       

Deferred tax liabilities

     70,511         73,790         8               144,309   

Other long-term liabilities

     1,253         56,815                       58,068   

Equity

     981,803         367,046         48,145        (415,191     981,803   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

TOTAL LIABILITIES AND EQUITY

   $ 2,143,512       $ 2,380,943       $ 230,097      $ (2,861,616   $ 1,892,936   
  

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

 

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CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS

 

     Three Months Ended June 30, 2011  
     Parent
Company
    Guarantor
Subsidiaries
    Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Revenues

   $      $ 400,023      $ 54,927      $ (9,581   $ 445,369   

Direct operating expense

            251,548        47,440        (8,368     290,620   

Depreciation and amortization expense

            38,406        1,446               39,852   

General and administrative expense

     354        47,482        8,449        (1,282     55,003   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Operating (loss) income

     (354     62,587        (2,408     69        59,894   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Loss on early extinguishment of debt

                                   

Interest expense, net of amounts capitalized

     9,985        (437     492        1        10,041   

Other, net

     (4,359     (1,920     (1,180     140        (7,319
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations before taxes

     (5,980     64,944        (1,720     (72     57,172   

Income tax expense

     (19,967     (128     (717            (20,812
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations

     (25,947     64,816        (2,437     (72     36,360   

Discontinued operations

                                   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net (loss) income

     (25,947     64,816        (2,437     (72     36,360   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Income attributable to noncontrolling interest

                   280               280   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(LOSS) INCOME ATTRIBUTABLE TO KEY

   $ (25,947   $ 64,816      $ (2,717   $ (72   $ 36,080   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

     Three Months Ended June 30, 2010  
     Parent
Company
    Guarantor
Subsidiaries
    Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Revenues

   $      $ 236,978      $ 44,515      $ (13,708   $ 267,785   

Direct operating expense

            150,956        55,651        (10,436     196,171   

Depreciation and amortization expense

            30,134        2,344               32,478   

General and administrative expense

     65        39,428        6,065        (692     44,866   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Operating (loss) income

     (65     16,460        (19,545     (2,580     (5,730
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Interest expense, net of amounts capitalized

     11,486        (821     64               10,729   

Other, net

     (266     (130     3,442        (2,579     467   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations before taxes

     (11,285     17,411        (23,051     (1     (16,926

Income tax benefit

     5,186               702               5,888   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations

     (6,099     17,411        (22,349     (1     (11,038

Discontinued operations

            8,182                      8,182   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net (loss) income

     (6,099     25,593        (22,349     (1     (2,856
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Loss attributable to noncontrolling interest

                   (620            (620
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(LOSS) INCOME ATTRIBUTABLE TO KEY

   $ (6,099   $ 25,593      $ (21,729   $ (1   $ (2,236
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

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Table of Contents
     Six Months Ended June 30, 2011  
     Parent
Company
    Guarantor
Subsidiaries
    Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Revenues

   $      $ 751,836      $ 102,227      $ (17,710   $ 836,353   

Direct operating expense

            490,596        87,339        (15,515     562,420   

Depreciation and amortization expense

            75,778        3,997               79,775   

General and administrative expense

     667        93,773        15,631        (2,289     107,782   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Operating (loss) income

     (667     91,689        (4,740     94        86,376   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Loss on early extinguishment of debt

     46,451                             46,451   

Interest expense, net of amounts capitalized

     20,484        (1,043     911               20,352   

Other, net

     (5,108     (4,068     (737     209        (9,704
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations before taxes

     (62,494     96,800        (4,914     (115     29,277   

Income tax (expense) benefit

     (11,945     880        (564            (11,629
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations

     (74,439     97,680        (5,478     (115     17,648   

Discontinued operations

                                   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net (loss) income

     (74,439     97,680        (5,478     (115     17,648   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Loss attributable to noncontrolling interest

                   (297            (297
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(LOSS) INCOME ATTRIBUTABLE TO KEY

   $ (74,439   $ 97,680      $ (5,181   $ (115   $ 17,945   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

     Six Months Ended June 30, 2010  
     Parent
Company
    Guarantor
Subsidiaries
    Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Revenues

   $      $ 448,172      $ 100,526      $ (28,954   $ 519,744   

Direct operating expense

            296,303        110,787        (21,717     385,373   

Depreciation and amortization expense

            61,095        4,707               65,802   

General and administrative expense

     1,293        73,170        11,304        (1,874     83,893   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Operating (loss) income

     (1,293     17,604        (26,272     (5,363     (15,324
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Interest expense, net of amounts capitalized

     22,673        (1,710     25               20,988   

Other, net

     (963     556        5,924        (6,293     (776
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations before taxes

     (23,003     18,758        (32,221     930        (35,536

Income tax benefit

     12,492               1,104               13,596   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(Loss) income from continuing operations

     (10,511     18,758        (31,117     930        (21,940

Discontinued operations

            10,077                      10,077   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net (loss) income

     (10,511     28,835        (31,117     930        (11,863
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Loss attributable to noncontrolling interest

                   (2,047            (2,047
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

(LOSS) INCOME ATTRIBUTABLE TO KEY

   $ (10,511   $ 28,835      $ (29,070   $ 930      $ (9,816
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

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CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS

 

     Six Months Ended June 30, 2011  
     Parent
Company
    Guarantor
Subsidiaries
    Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Net cash provided by operating activities

   $      $ 26,184      $ 3,677      $      $ 29,861   

Cash flows from investing activities:

          

Capital expenditures

            (170,303     (7,774            (178,077

Intercompany notes and accounts

            108,653               (108,653       

Other investing activities, net

            18,734                      18,734   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net cash (used in) provided by investing activities

            (42,916     (7,774     (108,653     (159,343
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Cash flows from financing activities:

          

Repayments of long-term debt

     (460,509                          (460,509

Proceeds from long-term debt

     475,000                             475,000   

Repayment of capital lease obligations

            (2,132                   (2,132

Proceeds from borrowings on revolving credit facility

     143,000                             143,000   

Repayments on revolving credit facility

     (53,000                          (53,000

Payment of deferred financing costs

            (14,640                   (14,640

Repurchases of common stock

     (5,399                          (5,399

Intercompany notes and accounts

     (108,653                   108,653          

Other financing activities, net

     9,561                             9,561   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net cash provided by financing activities

            (16,772            108,653        91,881   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Effect of changes in exchange rates on cash

                   (4,386            (4,386
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net decrease in cash and cash equivalents

            (33,504     (8,483            (41,987
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Cash and cash equivalents at beginning of period

            42,973        13,655               56,628   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Cash and cash equivalents at end of period

   $      $ 9,469      $ 5,172      $      $ 14,641   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

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Table of Contents
     Six Months Ended June 30, 2010  
     Parent
Company
    Guarantor
Subsidiaries
    Non-Guarantor
Subsidiaries
    Eliminations     Consolidated  
     (in thousands)  
     (unaudited)  

Net cash provided by (used in) operating activities

   $      $ 66,432      $ (1,737   $      $ 64,695   

Cash flows from investing activities:

          

Capital expenditures

            (61,448     (6,475            (67,923

Intercompany notes and accounts

     (165     (2,094            2,259          

Other investing activities, net

     165        20,073                      20,238   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net cash (used in) provided by investing activities

            (43,469     (6,475     2,259        (47,685
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Cash flows from financing activities:

          

Repayments of long-term debt

            (6,970                   (6,970

Repurchases of common stock

     (2,357                          (2,357

Intercompany notes and accounts

     2,094        165               (2,259       

Other financing activities, net

     263                             263   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net cash used in financing activities

            (6,805            (2,259     (9,064
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Effect of changes in exchange rates on cash

                   1,700               1,700   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net increase (decrease) in cash and cash equivalents

            16,158        (6,512            9,646   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Cash and cash equivalents at beginning of period

            19,391        18,003               37,394   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Cash and cash equivalents at end of period

   $      $ 35,549      $ 11,491      $      $ 47,040   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

NOTE 17. DISCONTINUED OPERATIONS

On October 1, 2010, we completed the sale of our pressure pumping and wireline businesses to Patterson-UTI Energy, Inc. Management determined to sell these businesses because they were not aligned with our core business strategy of well intervention and international expansion. For the periods presented in this report, we show the results of operations related to these businesses as discontinued operations. The following table presents the results of discontinued operations for the businesses sold in connection with this transaction:

 

     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2011      2010     2011      2010  
     (in thousands)     (in thousands)  

REVENUES

   $       $ 71,244      $       $ 121,356   

COSTS AND EXPENSES:

          

Direct operating expenses

             53,540                95,258   

Depreciation and amortization

             3,379                6,758   

General and administrative expenses

             1,996                3,921   

Other, net

             (165             (187
  

 

 

    

 

 

   

 

 

    

 

 

 

Total costs and expenses, net

             58,750                105,750   
  

 

 

    

 

 

   

 

 

    

 

 

 

Income before taxes

             12,494                15,606   

Income tax expense

             (4,312             (5,529
  

 

 

    

 

 

   

 

 

    

 

 

 

Net income

   $       $ 8,182      $       $ 10,077   
  

 

 

    

 

 

   

 

 

    

 

 

 

 

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NOTE 18. VARIABLE INTEREST ENTITIES

On March 7, 2010, we entered into an agreement with AlMansoori Petroleum Services LLC to form the joint venture AlMansoori Key Energy Services LLC. We hold three of the five board of directors seats and a controlling financial interest in the joint venture; accordingly, we consolidate the entity in our financial statements.

For the three and six months ended June 30, 2011, we recognized $2.5 million and $4.2 million of revenue, respectively, and $0.3 million and $0.6 million of net income, respectively, associated with this joint venture. For the three and six months ended June 30, 2010, we recognized no revenue or net income associated with this joint venture. Also, we have guaranteed the timely performance of the joint venture under its sole contract valued at $2 million. At June 30, 2011, there were approximately $5.7 million of assets in the joint venture.

NOTE 19. SUBSEQUENT EVENTS

Proposed Acquisition

On July 13, 2011, we entered into an agreement and plan of merger with Edge Oilfield Services, L.L.C. and Summit Oilfield Services, L.L.C. (collectively, “Edge”). Edge primarily rents frac stack equipment used to support hydraulic fracturing operations and the associated flow back of frac fluids, proppants, oil and natural gas. It also provides well testing services, rental equipment such as pumps and power swivels, and oilfield fishing services. The total consideration for the acquisition is approximately $300 million consisting of approximately 7.5 million shares of our common stock and approximately $164 million in cash, which is subject to working capital and other adjustments at closing. In addition to the $300 million of consideration, we have also agreed to reimburse or fund up to $40 million of Edge’s pre-closing capital expenditures. The acquisition is subject to satisfaction of certain regulatory approvals and other customary closing conditions. We received notification that the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 terminated effective July 29, 2011. We expect the closing of the transaction to take place in the third quarter of 2011. We intend to account for this acquisition as a business combination. We plan to fund this acquisition with funds available under the amended 2011 Credit Facility and the issuance of equity.

Amendment of Credit Facility

On July 27, 2011, we entered into the First Amendment to the 2011 Credit Facility (the “Amendment”) with several lenders and 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 Agents. The Amendment, which is effective as of July 27, 2011, amends certain provisions of our 2011 Credit Facility, dated as of March 31, 2011, which provides for a senior secured credit facility consisting of a revolving credit facility, letter of credit sub-facility and swing line facility of up to an aggregate principal amount of $400.0 million, all of which will mature no later than March 31, 2016. The 2011 Credit Facility and the obligations thereunder are secured by substantially all of our assets and those of our subsidiary guarantors, and are guaranteed by certain of our existing and future domestic subsidiaries. Among other changes, the Amendment increased the total commitments by the lenders under the credit facility from $400.0 million to $550.0 million, effected by an increase in the commitments of certain existing lenders under the facility and the addition of certain new lenders. The Amendment also modifies the 2011 Credit Facility by, among other things: increasing, from $500.0 million to $650.0 million, the maximum aggregate amount of commitments permitted under the 2011 Credit Facility pursuant to our option to increase commitments by the lenders; and amending the requirement that we maintain a debt to capitalization ratio of consolidated total funded indebtedness to total capitalization of 45% or less by changing the maximum required ratio to 50% through March 31, 2012.

In connection with the execution of the Amendment to the 2011 Credit Facility, we anticipate capitalizing $1.5 million of financing costs that will be amortized over the term of the debt.

 

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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 of our rigs are capable of specialty drilling applications. We operate in most major oil and natural gas producing regions of the continental United States and have operations based in Mexico, Colombia, the Middle East, Russia and Argentina. 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 and six months ended June 30, 2011 and 2010, included elsewhere herein, and the audited consolidated financial statements and notes thereto included in our 2010 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 15. Segment Information” in “Item 1. Financial Statements” of Part I of this report for a summary of our business segments.

PERFORMANCE MEASURES

We believe that the Baker Hughes U.S. land drilling rig count is the best barometer of overall oilfield capital spending and activity levels in our primary U.S. onshore market, and this data is made publicly available on a weekly basis. Historically, our activity levels have been highly correlated to capital spending by oil and natural gas producers. Generally, when oil and natural gas prices rise, capital spending by our customers tends to increase. Conversely, if oil and natural gas prices fall, capital spending by our customers tends to decrease, and the Baker Hughes U.S. land drilling rig count tends to decline.

 

     WTI Cushing Oil     

NYMEX Henry

Hub Natural Gas

    

Average Baker

Hughes U.S. Land

 
     (1)      (1)      Drilling Rigs (2)  

2011:

        

First Quarter

   $ 94.07       $ 4.20         1,695   

Second Quarter

   $ 102.02       $ 4.38         1,803   

2010:

        

First Quarter

   $ 74.78       $ 5.14         1,354   

Second Quarter

   $ 74.79       $ 4.30         1,513   

Third Quarter

   $ 72.46       $ 4.30         1,626   

Fourth Quarter

   $ 85.16       $ 3.98         1,688   

 

(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 in our U.S. and International segments primarily through our rig and trucking hours. Generally, as capital spending by oil and natural gas producers 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 oil and natural gas producers, we generally provide fewer rig and trucking services, which results in lower hours worked.

 

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The following table presents our quarterly rig and trucking hours from 2010 through the second quarter of 2011:

 

     Rig Hours      Trucking Hours  

2011:

     

First Quarter

     525,460         711,701   

Second Quarter

     544,917         776,382   

2010:

     

First Quarter

     485,183         459,292   

Second Quarter

     489,168         518,483   

Third Quarter

     503,890         559,181   

Fourth Quarter

     493,945         707,616   
  

 

 

    

 

 

 

Total 2010

     1,972,186         2,244,572   

MARKET CONDITIONS AND OUTLOOK

Market Conditions — Quarter Ended June 30, 2011

Market conditions during the second quarter of 2011 continued to improve, especially in the oil markets we serve. Many of our major customers increased oil-directed activity during the quarter.

Demand for our services in the U.S. was strong in all our oil-driven markets. We saw improvement in pricing compared to previous quarters due largely to price increases implemented late in the first quarter of 2011. Overall, results for the majority of our U.S. operations improved due to increased demand, pricing and favorable work mix. We continue to deploy assets across all our domestic lines of business to more profitable regions to help offset our rising costs.

Our international segment continued to have profitable results in the second quarter of 2011. Our assets in Mexico were fully utilized and we saw significant improvements over the first quarter. These improvements were partially offset by negative results in Argentina as a result of general work strikes throughout the quarter. In Colombia, we placed additional rigs into service during the quarter, which improved our results in this region.

Market Outlook

We believe that we will continue to see growth in our U.S. and international markets during the remainder of 2011 due to increased activity and pricing relative to 2010. Driven by higher oil prices, we anticipate that our core businesses will continue to show improvement, as our customers increase capital expenditures in an effort to grow production.

In the U.S., with the largest fleet of onshore well servicing rigs, we believe we are well positioned to benefit from increasing demand for conventional well maintenance and repair. Given our recent and ongoing investments in larger, higher capability rigs and coiled tubing units, as well as fluid transportation, frac tanks, and fishing and rental equipment, we believe we are well positioned to benefit from increased horizontal well drilling activity, which is driving a higher level of revenue and margin intensity per well.

We also believe that our international operations will play an increasing role in the growth of our business. We intend to deploy additional assets internationally during 2011. We expect our activity in the Middle East and Russia to grow in 2011, and combined with full utilization of assets in Mexico and Colombia, this should result in positive contributions to our revenues and earnings for the remainder of 2011.

We also continue to explore opportunities for expanding our service footprint into new markets or new lines of business as those opportunities present themselves.

 

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RESULTS OF OPERATIONS

The following table shows our consolidated results of operations for the three and six months ended June 30, 2011 and 2010, respectively (in thousands):

 

     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2011     2010     2011     2010  

REVENUES

   $ 445,369      $ 267,785      $ 836,353      $ 519,744   

Direct operating expenses

     290,620        196,171        562,420        385,373   

Depreciation and amortization expense

     39,852        32,478        79,775        65,802   

General and administrative expenses

     55,003        44,866        107,782        83,893   
  

 

 

   

 

 

   

 

 

   

 

 

 

Operating income (loss)

     59,894        (5,730     86,376        (15,324
  

 

 

   

 

 

   

 

 

   

 

 

 

Loss on early extinguishment of debt

                   46,451          

Interest expense, net of amounts capitalized

     10,041        10,729        20,352        20,988   

Other, net

     (7,319     467        (9,704     (776
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) from continuing operations before tax

     57,172        (16,926     29,277        (35,536

Income tax (expense) benefit

     (20,812     5,888        (11,629     13,596   
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) from continuing operations

     36,360        (11,038     17,648        (21,940

Income from discontinued operations, net of tax expense of $0, $(4,312), $0 and $(5,529), respectively

            8,182               10,077   
  

 

 

   

 

 

   

 

 

   

 

 

 

Net income (loss)

     36,360        (2,856     17,648        (11,863
  

 

 

   

 

 

   

 

 

   

 

 

 

Income (loss) attributable to noncontrolling interest

     280        (620     (297     (2,047
  

 

 

   

 

 

   

 

 

   

 

 

 

INCOME (LOSS) ATTRIBUTABLE TO KEY

   $ 36,080      $ (2,236   $ 17,945      $ (9,816
  

 

 

   

 

 

   

 

 

   

 

 

 

Consolidated Results of Operations — Three Months Ended June 30, 2011 and 2010

Revenues

Our revenues for the three months ended June 30, 2011 increased $177.6 million, or 66.3%, to $445.4 million from $267.8 million for the three months ended June 30, 2010 mostly due to increased demand for our services from improved market and overall economic conditions as well as both domestic and international expansion. See “Segment Operating Results — Three Months Ended June 30, 2011 and 2010” below for a more detailed discussion of the change in our revenues.

Direct Operating Expenses

Our direct operating expenses increased $94.4 million, to $290.6 million (65.3% of revenues), for the three months ended June 30, 2011, compared to $196.2 million (73.3% of revenues) for the three months ended June 30, 2010. The increase was a direct result of activity increases in our business and inflation. Fuel and salary expenses have increased compared to the second quarter of the prior year due to rising prices. We have also reinstated employee benefits that were suspended since 2009.

Depreciation and Amortization Expense

Depreciation and amortization expense increased $7.4 million, or 22.7%, to $39.9 million during the second quarter of 2011, compared to $32.5 million for the second quarter of 2010. The increase is primarily attributable to the increase in our fixed asset base through our acquisitions during 2010, as well as increased capital expenditures in 2010 and the first six months of 2011.

General and Administrative Expenses

General and administrative expenses increased $10.1 million, to $55.0 million (12.3% of revenues), for the three months ended June 30, 2011, compared to $44.9 million (16.8% of revenues) for the three months ended June 30, 2010. The second quarter increase was primarily due to the rescission of temporary employee compensation and benefit reductions as well as increased headcount due to our growth.

 

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Interest Expense, net of Amounts Capitalized

Interest expense decreased $0.7 million, or 6.4%, to $10.0 million for the three months ended June 30, 2011, compared to $10.7 million for the same period in 2010. We repurchased 99.2%, or $421.4 million, in aggregate principal amount of our 8.375% Notes due 2014 during the first quarter pursuant to a tender offer for the notes and simultaneously issued $475.0 million aggregate principal amount of 6.75% Notes due 2021, therefore decreasing interest expense due to the lower interest rate.

Other, net

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

 

     Three Months
Ended June 30,
 
     2011     2010  
     (in thousands)  

Loss on disposal of assets, net

   $ 162      $ 320   

Interest income

     (2     (21

Foreign exchange (gain) loss

     (2,717     855   

Gain on sale of equity method investment

     (4,783       

Other expense (income), net

     21        (687
  

 

 

   

 

 

 

Total

   $ (7,319   $ 467   
  

 

 

   

 

 

 

In April 2011 we sold our shares in IROC Energy Services Corp. (“IROC”) and recorded a gain on the sale of $4.8 million during the second quarter. Our foreign exchange gain relates to an increase in U.S. dollar-denominated transactions in our foreign locations and the strengthening of the U.S. dollar.

Income Tax (Expense) Benefit

We recorded income tax expense of $20.8 million on pre-tax income of $57.2 million in the second quarter of 2011, compared to an income tax benefit of $5.9 million on a pre-tax loss of $16.9 million in the second quarter of 2010. Our effective tax rate was 36.4% for the three months ended June 30, 2011, compared to 34.8% for the three months ended June 30, 2010. Our effective tax rates for the 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 taxing jurisdictions and the impact of permanent items that affect book income but do not affect taxable income.

Discontinued Operations

We recorded no amounts from discontinued operations for the three months ended June 30, 2011, compared to net income from discontinued operations of $8.2 million for the three months ended June 30, 2010. Our discontinued operations in 2010 relate to the sale of our pressure pumping and wireline businesses during the fourth quarter of 2010.

Noncontrolling Interest

For the three months ended June 30, 2011, we allocated $0.3 million associated with the income incurred by our joint ventures to the noncontrolling interest holders of these ventures compared to a net loss of $0.6 million for the three months ended June 30, 2010.

Segment Operating Results — Three Months Ended June 30, 2011 and 2010

 

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The following table shows operating results for each of our segments for the three-month periods ended June 30, 2011 and 2010 (in thousands):

For the three months ended June 30, 2011

 

     U.S.      International      Functional
Support
    Total  

Revenues from external customers

   $ 367,455       $ 77,914       $      $ 445,369   

Operating expenses

     281,253         71,537         32,685        385,475   

Operating income (loss)

     86,202         6,377         (32,685     59,894   

For the three months ended June 30, 2010

 

     U.S.      International     Functional
Support
    Total  

Revenues from external customers

   $ 224,221       $ 43,564      $      $ 267,785   

Operating expenses

     189,505         55,419        28,591        273,515   

Operating income (loss)

     34,716         (11,855     (28,591     (5,730

U.S.

Revenues from external customers for our U.S. segment increased $143.2 million, or 63.9%, to $367.5 million for the three months ended June 30, 2011, compared to $224.2 million for the three months ended June 30, 2010. The increase for this segment was due to an increase in activity for our rig-based services and fluid management services along with improved pricing during the period, as well as a shift in our work mix to higher intensity horizontal well completion. Activity also increased in our intervention services business due to the acquisition of additional coiled tubing units during 2010. Demand for fishing and rental services also increased compared to the prior year, and pricing for these services improved as drilling and completion activity has increased.

Operating expenses for our U.S. segment were $281.3 million during the three months ended June 30, 2011, which represented an increase of $91.7 million, or 48.4%, compared to $189.5 million for the same period in 2010. The increase was directly attributable to increased activity during the period combined with the impact of inflationary pressure on fuel and wage expenses and the impact of the rescission in late 2010 of temporary cost reduction measures implemented in 2009.

International

Revenues for our international segment increased $34.4 million, or 78.8%, to $77.9 million for the three months ended June 30, 2011, compared to $43.6 million for the three months ended June 30, 2010. The increase for this segment is primarily attributable to our international expansion during 2010 to Colombia and the Middle East, in addition to increased activity in Mexico and Russia.

Operating expenses for our international segment increased $16.1 million, or 29.1%, to $71.5 million for the three months ended June 30, 2011, compared to $55.4 million for the three months ended June 30, 2010, and 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 operating segments, increased $4.1 million, or 14.3%, to $32.7 million (7.3% of consolidated revenues) for the three months ended June 30, 2011 compared to $28.6 million (10.7% of consolidated revenues) for the same period in 2010. The increase in costs relates to the reinstatement in late 2010 of certain employee compensation and benefits that had been suspended in 2009 as part of our cost savings effort.

 

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Consolidated Results of Operations — Six Months Ended June 30, 2011 and 2010

Revenues

Our revenues for the six months ended June 30, 2011 increased $316.6 million, or 60.9%, to $836.4 million from $519.7 million for the six months ended June 30, 2010. See “Segment Operating Results — Six Months Ended June 30, 2011 and 2010” below for a more detailed discussion of the change in our revenues.

Direct Operating Expenses

Our direct operating expenses increased $177.0 million, to $562.4 million (67.2% of revenues), for the six months ended June 30, 2011, compared to $385.4 million (74.1% of revenues) for the six months ended June 30, 2010. The increase was a direct result of activity increases in our business and inflation. Fuel and salary expenses have increased compared to the first six months of the prior year due to rising prices. We have also reinstated employee compensation and benefits that were suspended since 2009.

Depreciation and Amortization Expense

Depreciation and amortization expense increased $14.0 million, or 21.2%, to $79.8 million for the six months ended June 30, 2011, compared to $65.8 million for the six months ended June 30, 2010. The increase is primarily attributable to the increase in our fixed asset base through our acquisitions during 2010, as well as increased capital expenditures in 2010 and 2011.

General and Administrative Expenses

General and administrative expenses increased $23.9 million, to $107.8 million (12.9% of revenues), for the six months ended June 30, 2011, compared to $83.9 million (16.1% of revenues) for the six months ended June 30, 2010. The increase for the first six months of 2011 was primarily due to an increase in employee compensation resulting from the rescission of temporary employee compensation and benefit reductions as well as increased headcount due to our growth. We also incurred additional professional fees related to acquisition activity.

Interest Expense, net of Amounts Capitalized

Interest expense decreased $0.6 million, to $20.4 million for the six months ended June 30, 2011, compared to $21.0 million for the same period in 2010. The decrease relates to the first quarter repurchase of the majority of our 8.375% Notes due 2014 as well as lower interest rates on the 6.75% Notes due 2021.

Loss on Extinguishment of Debt

Loss on extinguishment of debt was $46.5 million for the six months ended June 30, 2011, compared to zero for the same period in 2010, due to our tender offer for the 2014 Notes and the termination of the 2007 Credit Facility during the first quarter of 2011. The loss consisted of the tender premium on the 2014 Notes, as well as transaction fees and the write-off of the unamortized portion of deferred financing costs.

Other, net

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

 

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     Six Months Ended
June 30,
 
     2011     2010  
     (in thousands)  

(Gain) loss on disposal of assets, net

   $ (507   $ 655   

Interest income

     (22     (36

Foreign exchange gain

     (4,185     (509

Gain on sale of equity method investment

     (4,783       

Other income, net

     (207     (886
  

 

 

   

 

 

 

Total

   $ (9,704   $ (776
  

 

 

   

 

 

 

In April 2011 we sold our shares in IROC Energy Services Corp. (“IROC”) and recorded a gain on the sale of $4.8 million during the second quarter. Our foreign exchange gain relates to an increase in U.S. dollar-denominated transactions in our foreign locations and the strengthening of the U.S. dollar.

Income Tax (Expense) Benefit

We recorded income tax expense of $11.6 million on pre-tax income of $29.3 million for the six months ended June 30, 2011, compared to an income tax benefit of $13.6 million on a pre-tax loss of $35.6 million for the six months ended June 30, 2010. Our effective tax rate was 39.7% for the six months ended June 30, 2011, compared to 38.3% for the six months ended June 30, 2010. Our effective tax rates for the periods differ from the U.S. statutory rate of 35% due to numerous factors, including the mix of profit and loss between various taxing jurisdictions, specifically the charge recorded in the U.S. on the early extinguishment of debt, and the impact of permanent items that affect book income but do not affect taxable income.

Discontinued Operations

We recorded no amounts from discontinued operations for the six months ended June 30, 2011, compared to net income from discontinued operations of $10.1 million for the six months ended June 30, 2010. Our discontinued operations in 2010 relate to the sale of our pressure pumping and wireline businesses during the fourth quarter of 2010.

Noncontrolling Interest

For the six months ended June 30, 2011, we allocated $0.3 million associated with the net loss incurred by our joint ventures to the noncontrolling interest holders of these ventures compared to $2.0 million for the six months ended June 30, 2010.

Segment Operating Results — Six Months Ended June 30, 2011 and 2010

The following table shows operating results for each of our segments for the six-month periods ended June 30, 2011 and 2010 (in thousands):

For the six months ended June 30, 2011

     U.S.      International      Functional
Support
    Total  

Revenues from external customers

   $ 697,359       $ 138,994       $      $ 836,353   

Operating expenses

     552,510         131,049         66,418        749,977   

Operating income (loss)

     144,849         7,945         (66,418     86,376   

 

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For the six months ended June 30, 2010

     U.S.      International     Functional
Support
    Total  

Revenues from external customers

   $ 420,529       $ 99,215      $      $ 519,744   

Operating expenses

     372,439         109,937        52,692        535,068   

Operating income (loss)

     48,090         (10,722     (52,692     (15,324

U.S.

Revenues from external customers for our U.S. segment increased $276.8 million, or 65.8%, to $697.4 million for the six months ended June 30, 2011, compared to $420.5 million for the six months ended June 30, 2010. The increase for this segment was due to an increase in activity for our services along with improved pricing. During the first quarter of 2011, we implemented price increases for all of our lines of business.

Operating expenses for our U.S. segment were $552.5 million during the six months ended June 30, 2011, which represented an increase of $180.1 million, or 48.3%, compared to $372.4 million for the same period in 2010. The increase was directly attributable to increased activity during the period combined with the impact of inflationary pressure on fuel and wage expenses and the impact of the rescission in late 2010 of temporary cost reduction measures implemented in 2009.

International

Revenues for our international segment increased $39.8 million, or 40.1%, to $139.0 million for the six months ended June 30, 2011, compared to $99.2 million for the six months ended June 30, 2010. The increase for this segment is primarily attributable to our international expansion during 2010 to Colombia and the Middle East, in addition to increased activity in Mexico and Russia.

Operating expenses for our international segment increased $21.1 million, or 19.2%, to $131.0 million for the six months ended June 30, 2011, compared to $109.9 million for the six months ended June 30, 2010, and increased as a direct result of additional activity during the period.

Functional Support

Operating expenses for Functional Support increased $13.7 million, or 26.0%, to $66.4 million (7.9% of consolidated revenues) for the six months ended June 30, 2011 compared to $52.7 million (10.1% of consolidated revenues) for the same period in 2010. The increase in costs relates to the reinstatement in late 2010 of certain employee compensation and benefits that had been suspended in 2009 as part of our cost savings effort.

LIQUIDITY AND CAPITAL RESOURCES

Current Financial Condition and Liquidity

As of June 30, 2011, we had cash and cash equivalents of $14.6 million. Our working capital (excluding the current portion of capital leases and long-term debt) was $223.9 million, compared to $136.4 million as of December 31, 2010. Our working capital increased from the prior year end primarily as a result of the payment of income taxes in March 2011 through borrowings on our long-term revolving credit facility and an increase in accounts receivable due to activity increases associated with improving market conditions during the six months ended June 30, 2011. Our total outstanding debt (including capital leases) was $572.6 million, and we have no significant debt maturities until 2016. As of June 30, 2011, we have $90.0 million in borrowings and $59.5 million in

 

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committed letters of credit outstanding under our 2011 Credit Facility (defined below), leaving $250.5 million of available borrowing capacity. We amended the 2011 Credit Facility effective July 27, 2011 which increased our available borrowing capacity by $150 million (as discussed further below under “Senior Secured Credit Facility”).

Cash Flows

The following table summarizes our cash flows for the six-month periods ended June 30, 2011 and 2010:

 

     Six Months Ended
June 30,
 
     2011     2010  
     (in thousands)  

Net cash provided by operating activities

   $ 29,861      $ 64,695   

Cash paid for capital expenditures

     (178,077     (67,923

Proceeds received from sale of fixed assets

     6,769        20,073   

Proceeds from sale of equity method investment

     11,965          

Other investing activities, net

            165   

Repayments of capital lease obligations

     (2,132     (3,992

Repayments of long-term debt

     (460,509     (6,970

Proceeds from long-term debt

     475,000          

Proceeds from borrowings on revolving credit facility

     143,000        30,000   

Repayments on revolving credit facility

     (53,000     (30,000

Repurchases of common stock

     (5,399     (2,357

Other financing activities, net

     (5,079     4,255   

Effect of exchange rates on cash

     (4,386     1,700   
  

 

 

   

 

 

 

Net (decrease) increase in cash and cash equivalents

   $ (41,987   $ 9,646   
  

 

 

   

 

 

 

Cash provided by operating activities was $29.9 million and $64.7 million for the six months ended June 30, 2011 and 2010, respectively. Operating cash inflows for 2011 relate to net income for the period, partially offset by the payment of our income tax obligations from 2010 and an increase in accounts receivable associated with increased activity.

Cash used in investing activities was $159.3 million and $47.7 million for the six months ended June 30, 2011 and 2010, respectively. Investing cash outflows during these periods consisted primarily of capital expenditures. Our capital expenditures through June 30, 2011 relate to the increased demand for our services and associated growth initiatives.

Cash provided by financing activities was $91.9 million during the six months ended June 30, 2011 compared to cash used in financing activities of $9.1 million for the six months ended June 30, 2010. Overall financing cash inflows for 2011 relate to borrowings on our revolving credit facility to fund a portion of our capital expenditure program and an income tax payment made in March 2011.

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 in 2011. Interest on our revolving credit facility is due each quarter. Interest on our 2021 Notes (as defined below) is estimated to be $16.4 million for the remainder of 2011. We expect to fund interest payments from cash generated by operations. At June 30, 2011, our annual debt maturities for our 2014 Notes and 2021 Notes and borrowings under our 2011 Credit Facility were as follows:

 

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     Principal
Payments
 
     (in thousands)  

2011

   $   

2012

       

2013

       

2014

     3,573   

2015 and thereafter

     565,000   
  

 

 

 

Total principal payments

   $ 568,573   

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

8.375% Senior Notes due 2014

On November 29, 2007, we issued $425.0 million aggregate principal amount of 8.375% Senior Notes due 2014 (the “2014 Notes”). On March 4, 2011, we repurchased $421.3 million aggregate principal amount of our 2014 Notes at a purchase price of $1,090 per $1,000 principal amount. On March 15, 2011, we repurchased an additional $0.1 million aggregate principal amount at a purchase price of $1,060 per $1,000 principal amount. In connection with the repurchase of the 2014 Notes, we incurred a loss of $44.3 million on the early extinguishment of debt related to the premium paid on the tender, the payment of related fees and the write-off of unamortized loan fees. Interest on the remaining $3.6 million aggregate principal amount of 2014 Notes outstanding is payable on June 1 and December 1 of each year. The 2014 Notes mature on December 1, 2014.

6.75% Senior Notes due 2021

On March 4, 2011, we issued $475.0 million aggregate principal amount of 6.75% Senior Notes due 2021 (the “2021 Notes”). Net proceeds, after deducting underwriters’ fees and offering expenses, were $466.0 million. We used the net proceeds to repurchase the 2014 Notes as described above, including accrued and unpaid interest and fees and expenses. We capitalized $10.0 million of financing costs associated with the issuance of this debt that will be amortized over the term of the notes.

The 2021 Notes are general unsecured senior obligations and are subordinate 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, beginning on September 1, 2011. The 2021 Notes mature on March 1, 2021.

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

 

Year

   Percentage  

2016

     103.375

2017

     102.250

2018

     101.125

2019 and thereafter

     100.000

At any time and from time to time 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 106.750% 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

 

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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 governing the 2021 Notes (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 June 30, 2011, 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 June 30, 2011.

Senior Secured Credit Facility

On March 31, 2011, we simultaneously terminated (without pre-payment penalty) our $300 million credit agreement dated November 29, 2007, as amended, which was to mature no later than November 29, 2012, and entered into a new credit agreement with several lenders and JPMorgan Chase Bank, N.A., as Administrative Agent and Swing Line Lender, Bank of America, N.A., as Syndication Agent, and Capital One, N.A. and Wells Fargo Bank, N.A., as Co-Documentation Agents. In connection with the termination of our previous credit agreement, we incurred a loss of $2.2 million on early extinguishment of debt related to the write-off of the unamortized portion of deferred financing costs. The new 2011 credit agreement provides for a senior secured credit facility (the “2011 Credit Facility”) consisting of a revolving credit facility, letter of credit sub-facility and swing line facility of up to an aggregate principal amount of $400 million, all of which will mature no later than March 31, 2016. The 2011 Credit Facility and the obligations thereunder are secured by substantially all of our assets and those of our subsidiary guarantors and are guaranteed by certain of our existing and future domestic subsidiaries.

In connection with the execution of the 2011 Credit Facility, we capitalized $4.8 million of financing costs 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 weighted average interest rate on the outstanding borrowings under the 2011 Credit Facility was 2.76% for the three-month period ended June 30, 2011.

 

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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 consolidated funded indebtedness be no greater than 45% of our adjusted total capitalization;

 

   

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:

 

Fiscal Quarter Ending

  

Ratio

June 30, 2011 through June 30, 2012

   1.85 to 1.00

September 30, 2012 and thereafter

   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, up to 50% of which amount may be carried over for expenditure in the following fiscal year, if after giving pro forma effect thereto 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 million of availability under the 2011 Credit Facility); (vi) dividends and other distributions to, and redemptions and repurchases from, equityholders; (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. Furthermore, the 2011 Credit Facility provides that share repurchases in excess of $200 million can be made only if our debt to capitalization ratio is below 45%.

On July 27, 2011, we entered into the First Amendment to the 2011 Credit Facility (the “Amendment”) with several lenders and 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 Agents. The Amendment, which is effective as of July 27, 2011, amends certain provisions of our 2011 Credit Facility. Among other changes, the Amendment increased the total commitments by the lenders under the credit facility from $400.0 million to $550.0 million, effected by an increase in the commitments of certain existing lenders under the facility and the addition of certain new lenders. The Amendment also modifies the 2011 Credit Facility by increasing, from $500.0 million to $650.0 million, the maximum aggregate amount of commitments permitted under the 2011 Credit Facility pursuant to our option to increase commitments by the lenders and amending the requirement that we maintain a debt to capitalization ratio of consolidated total funded indebtedness to total capitalization of 45% or less by changing the maximum required ratio to 50% through March 31, 2012.

Capital Lease Agreements

We lease equipment, such as vehicles, tractors, trailers, frac tanks and forklifts, from financial institutions under master lease agreements. As of June 30, 2011, there was $4.0 million outstanding under such equipment leases.

Off-Balance Sheet Arrangements

At June 30, 2011 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.

 

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Liquidity Outlook and Future Capital Requirements

As of June 30, 2011, we had cash and cash equivalents of $14.6 million, available borrowing capacity of $250.5 million under our 2011 Credit Facility, and no significant debt maturities until 2016. Also, with the amendment of our 2011 Credit Facility in July 2011, we increased our available borrowing capacity by $150 million. We believe that our internally generated cash flows from operations, availability under the 2011 Credit Facility and current reserves of cash and cash equivalents will be sufficient to finance the majority of our cash requirements for current and future 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, cash flow from operations, borrowings under our 2011 Credit Facility and, in the case of acquisitions, equity.

Capital Expenditures

During the six months ended June 30, 2011, our capital expenditures totaled $178.1 million, primarily related to fluid management expansion in the Bakken Shale, the deployment of heavy duty workover rigs, the purchase of premium drill pipe and major maintenance of our existing fleet and equipment. Our capital expenditures program is expected to total $365.0 million during 2011, focusing mainly on expansion to selected growth regions in the U.S. market. Our capital expenditure program for 2011 is subject to market conditions, including activity levels, commodity prices, and industry capacity. During the remainder of 2011, we plan to focus on maximizing our current equipment fleet, and we have increased our planned capital expenditures to increase market share and expand our presence into new markets. We currently anticipate funding our 2011 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 insufficient to warrant our currently planned capital spending levels, management expects it would adjust our capital spending plans accordingly. We may also incur capital expenditures for strategic investments and acquisitions.

Proposed Acquisition

On July 13, 2011, we entered into an agreement and plan of merger with Edge Oilfield Services, L.L.C. and Summit Oilfield Services, L.L.C. (collectively, “Edge”). Edge primarily rents frac stack equipment used to support hydraulic fracturing operations and the associated flow back of frac fluids, proppants, oil and natural gas. It also provides well testing services, rental equipment such as pumps and power swivels, and oilfield fishing services. The total consideration for the acquisition is approximately $300 million consisting of approximately 7.5 million shares of our common stock and approximately $164 million in cash, which is subject to working capital and other adjustments at closing. We received notification that the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 terminated effective July 29, 2011. In addition to the $300 million of consideration, we have also agreed to reimburse or fund up to $40 million of Edge’s pre-closing capital expenditures. The acquisition is subject to satisfaction of certain regulatory approvals and other customary closing conditions. We expect the closing of the transaction to take place in the third quarter of 2011. We intend to account for this acquisition as a business combination. We plan to fund this acquisition with available funds under the amended 2011 Credit Facility and the issuance of equity.

 

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 2010 Form 10-K. More detailed information concerning market risk can be found in “Item 7A. Quantitative and Qualitative Disclosures about Market Risk” in our 2010 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.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting during the second quarter of 2011 that materially affected, or were reasonably likely to materially affect, our internal control over financial reporting.

 

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PART II — OTHER INFORMATION

 

ITEM 1. LEGAL PROCEEDINGS

In June 2011, we agreed to accept $5.5 million in damages, related to the settlement of a KeyView® patent infringement lawsuit, which was paid in full in July 2011. We recognized related legal fees and other expenses of $1.3 million during the second quarter of 2011.

We are subject to various suits and claims that have arisen in the ordinary course of business. We do not believe that the disposition of any of our ordinary course litigation will result in a material adverse effect on our consolidated financial position, results of operations or cash flows. For additional information on legal proceedings, see “Note 10. Commitments and Contingencies” in “Item 1. Financial Statements” in Part I of this report.

 

ITEM 1A. RISK FACTORS

There have been no material changes in our risk factors disclosed in our 2010 Form 10-K. For a discussion of these risk factors, see “Item 1A. Risk Factors” in our 2010 Form 10-K.

 

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

During the three months ended June 30, 2011, 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
 

April 1, 2011 to April 30, 2011

     18,481       $ 15.31               $   

May 1, 2011 to May 31, 2011

     1,983         15.70                   

June 1, 2011 to June 30, 2011

     17,372         17.33                   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total

     37,836       $ 16.26               $   

 

(1) Represents shares repurchased to satisfy tax withholding obligations upon the vesting of restricted stock awards.
(2) The price paid per share on the vesting date with respect to the tax withholding repurchases was determined using the closing price as quoted on the NYSE on the vesting date for awards granted under the Key Energy Services, Inc. 2007 Equity and Cash Incentive Plan and the Key Energy Services, Inc. 2009 Equity and Cash Incentive Plan.

 

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

 

ITEM 4. (REMOVED AND RESERVED)

 

ITEM 5. OTHER INFORMATION

None.

 

ITEM 6. EXHIBITS

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

 

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SIGNATURE

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

    KEY ENERGY SERVICES, INC. (Registrant)
Date: August 5, 2011     By:   /s/    T.M. Whichard III        
      T.M. Whichard III
      Senior Vice President and Chief Financial Officer
      (As duly authorized officer and Principal
      Financial Officer)

 

 

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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    Third Restated By-laws of Key Energy Services, Inc. (reflecting the Second Amended and Restated By-laws of Key Energy Services, Inc. adopted on September 21, 2006, as amended on November 2, 2007, April 4, 2008 and June 4, 2009) (Incorporated by reference to Exhibit 3.1 of our Current Report on Form 8-K filed on July 15, 2011, 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

 

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