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

	For the Quarterly Period Ended ~~March 31,~~June 30, 2008
or
or

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

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

124,445,608.

KEY ENERGY SERVICES, INC.

INDEX TO FORM 10-Q
FOR THE QUARTERLY PERIOD ENDED ~~MARCH 31,~~JUNE 30, 2008

~~Part I - Financial Information~~	3
~~Item 1.~~ Part I—Financial Information			~~Financial Statements~~	3
Item 1.		Financial Statements		3
Item 2.	~~Management’s~~	Management's Discussion and Analysis of Financial Condition and Results of Operations	20	32
Item 3.	~~Quantiative~~	Quantitative and Qualitative Disclosures About Market Risk	29	54
Item 4.		Controls and Procedures	30	54
Part II—Other Information				58
~~Part II - Other Information~~ Item 1.	30	Legal Proceedings		58
Item 1. 1A.	~~Legal Proceedings~~	30 Risk Factors		60
~~Item 1A.~~	~~Risk Factors~~	32
Item 2.		Unregistered Sales of Equity Securities and Use of Proceeds	32	60
Item 3.		Defaults Upon Senior Securities	32	60
Item 4.		Submission of Matters to a Vote of Security Holders	32	60
Item 5.		Other Information	32	61
Item 6.	~~Exhibits~~	32 Exhibits		61

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”~~"forward-looking statements" are based on our current expectations, estimates and projections about Key Energy Services, Inc. (“its subsidiaries ("the ~~Company”~~Company"), our industry and ~~management’s~~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,” “predicts,” “projects,” “potential”~~"may," "will," "predicts," "projects," "potential" or ~~“continue”~~"continue" or the negative of such terms and other comparable terminology. These statements are only predictions and are subject to substantial risks and uncertainties. Actual performance or results may differ materially and adversely.

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.

PART ~~I —~~ I—FINANCIAL INFORMATION

Item 1. Financial Statements.

Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(In ~~thousands)~~thousands, except share amounts)

		June 30, 2008			December 31, 2007

		(unaudited)
*ASSETS*
Current assets:
	Cash and cash equivalents	$	45,459		$	58,503
	Short-term investments		8			276
	Accounts receivable, net of allowance for doubtful accounts of $12,615 and $13,501 at June 30, 2008 and December 31, 2007, respectively		395,079			343,408
	Inventories		28,478			22,849
	Prepaid expenses		9,906			12,997
	Deferred tax assets		28,645			27,676
	Income taxes receivable		947			15,796
	Other current assets		6,117			6,360

Total current assets			514,639			487,865

Property and equipment, gross			1,695,243			1,595,225
Accumulated depreciation			(748,338	)		(684,017	)

Property and equipment, net			946,905			911,208

Goodwill			395,213			378,550
Other intangible assets, net			48,531			45,894
Deferred financing costs, net			11,436			12,117
Notes and accounts receivable—related parties			187			173
Investment in IROC Energy Services Corp.			11,765			11,217
Other assets			9,085			12,053

TOTAL ASSETS		$	1,937,761		$	1,859,077

*LIABILITIES AND STOCKHOLDERS' EQUITY*
Current liabilities:
	Accounts payable	$	19,952		$	35,159
	Accrued liabilities		224,897			183,364
	Accrued interest		5,319			3,895
	Current portion of capital lease obligations		9,334			10,701
	Current notes payable—related parties, net of discount		1,749			1,678

Total current liabilities			261,251			234,797

Capital lease obligations, less current portion			13,840			16,114
Notes payable—related parties, less current portion			20,500			20,500
Long-term debt			525,000			475,000
Workers' compensation, vehicular, health and other insurance claims			44,067			43,818
Deferred tax liabilities			160,786			160,068
Other non-current accrued liabilities			20,640			19,531
Minority interest			—			251
Commitments and contingencies			—			—
Stockholders' equity:
	Common stock, $0.10 par value; 200,000,000 shares authorized, 125,205,458 and 131,142,905 shares issued and outstanding at June 30, 2008 and December 31, 2007, respectively		12,521			13,114
	Additional paid-in capital		627,192			704,644
	Accumulated other comprehensive loss		(35,753	)		(37,981	)
	Retained earnings		287,717			209,221

Total stockholders' equity			891,677			888,998

TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY		$	1,937,761		$	1,859,077

March 31,

December 31,

2008

2007

(unaudited)

ASSETS

Current assets:

Cash and cash equivalents

$
29,871

$
58,503

Short-term investments

270

276

Accounts receivable, net of allowance for doubtful accounts of $13,500 and $13,501 at March 31, 2008 and December 31, 2007, respectively

355,327

343,408

Inventories

25,310

22,849

Prepaid expenses

12,644

12,997

Deferred tax assets

27,687

27,676

Income taxes receivable

1,261

15,796

Other current assets

8,420

6,360

Total current assets

460,790

487,865

Property and equipment, gross

1,623,594

1,595,225

Accumulated depreciation

(714,776
)
(684,017
)

Property and equipment, net

908,818

911,208

Goodwill

378,593

378,550

Other intangible assets, net

43,673

45,894

Deferred financing costs, net

11,925

12,117

Notes and accounts receivable - related parties

168

173

Investment in IROC Energy Services Corp

10,617

11,217

Other assets

12,222

12,053

TOTAL ASSETS

$
1,826,806

$
1,859,077

LIABILITIES AND STOCKHOLDERS’ EQUITY

Current liabilities:

Accounts payable

$
20,594

$
35,159

Accrued liabilities

187,935

183,364

Accrued interest

13,117

3,895

Current portion of capital lease obligations

9,899

10,701

Current notes payable - related parties, net of discount

1,714

1,678

Total current liabilities

233,259

234,797

Capital lease obligations, less current portion

15,105

16,114

Notes payable - related party, less current portion

20,500

20,500

Long-term debt

475,000

475,000

Workers’ compensation, vehicular, health and other insurance claims

42,629

43,818

Deferred tax liabilities

159,909

160,068

Other non-current accrued liabilities

19,150

19,531

Minority interest

207

251

Commitments and contingencies

Stockholders’ equity:

Common stock, $0.10 par value; 200,000,000 shares authorized, 126,005,998 and 131,142,905 shares issued and outstanding at March 31, 2008 and December 31, 2007, respectively

12,601

13,114

Additional paid-in capital

643,277

704,644

Accumulated other comprehensive loss

(38,536
)
(37,981
)
Retained earnings

243,705

209,221

Total stockholders’ equity

861,047

888,998

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

$
1,826,806

$
1,859,077

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

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,

		2008			2007			2008			2007
*REVENUES:*
	Well servicing	$	379,959		$	308,825		$	728,837		$	619,985
	Pressure pumping		91,952			77,289			173,804			151,366
	Fishing and rental		30,092			24,397			55,761			48,079

Total revenues			502,003			410,511			958,402			819,430

*COSTS AND EXPENSES:*
	Well servicing		241,634			177,304			453,385			352,832
	Pressure pumping		62,837			47,410			116,616			93,943
	Fishing and rental		18,017			13,509			34,128			26,960
	Depreciation and amortization		42,271			30,684			82,247			60,298
	General and administrative		58,249			56,154			125,981			108,217
	Interest expense, net of amounts capitalized		10,079			8,968			20,119			18,317
	Gain on sale of assets, net		(360	)		(703	)		(626	)		(453	)
	Interest income		(182	)		(1,798	)		(690	)		(3,737	)
	Other (income) expense, net		(1,789	)		512			(912	)		(112	)

Total costs and expenses, net			430,756			332,040			830,248			656,265

Income before income taxes and minority interest			71,247			78,471			128,154			163,165
Income tax expense			(27,446	)		(30,335	)		(49,903	)		(62,838	)
Minority interest			211			—			245			—

*NET INCOME*		$	44,012		$	48,136		$	78,496		$	100,327

*EARNINGS PER SHARE:*
	Basic	$	0.35		$	0.37		$	0.62		$	0.76
	Diluted	$	0.35		$	0.36		$	0.61		$	0.75
*WEIGHTED AVERAGE SHARES OUTSTANDING:*
	Basic		124,448			131,627			126,207			131,628
	Diluted		126,521			134,140			127,914			134,028

Three Months Ended March 31,

2008

2007

REVENUES:

Well servicing

$
348,878

$
311,160

Pressure pumping

81,852

74,077

Fishing and rental

25,669

23,682

Total revenues

456,399

408,919

COSTS AND EXPENSES:

Well servicing

211,751

175,529

Pressure pumping

53,779

46,533

Fishing and rental

16,111

13,451

Depreciation and amortization

39,976

29,614

General and administrative

67,732

52,064

Interest expense, net of amounts capitalized

10,040

9,348

(Gain) loss on sale of assets

(266
)
250

Interest income

(508
)
(1,940
)
Other expense (income), net

877

(624
)

Total costs and expenses, net

399,492

324,225

Income before income taxes

56,907

84,694

Income tax expense

(22,457
)
(32,504
)
Minority interest

34

—

NET INCOME

$
34,484

$
52,190

EARNINGS PER SHARE:

Basic

$
0.27

$
0.40

Diluted

$
0.27

$
0.39

WEIGHED AVERAGE SHARES OUTSTANDING:

Basic

127,966

131,629

Diluted

129,307

133,915

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

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,

		2008		2007			2008		2007
*NET INCOME*		$	44,012	$	48,136		$	78,496	$	100,327
*OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX:*
	Foreign currency translation gain, net of tax of $0, $0 , $0, and $0, respectively		2,776		160			2,228		—
	Net deferred gain from cash flow hedges, net of tax of $0, $(106), $0, and $(40), respectively		—		198			—		75
	Deferred gain (loss) from available for sale investments, net of tax of $0, $4, $0, and $112, respectively		7		(8	)		—		(206	)

*COMPREHENSIVE INCOME, NET OF TAX*		$	46,795	$	48,486		$	80,724	$	100,196

~~(Unaudited)~~

Three Months Ended March 31,

2008

2007

NET INCOME

$
34,484

$
52,190

OTHER COMPREHENSIVE LOSS, NET OF TAX:

Foreign currency translation loss

(548
)
(169
)
Deferred loss from cash flow hedges

—

(123
)
Deferred loss from short-term investments

(7
)
(198
)

COMPREHENSIVE INCOME, NET OF TAX

$
33,929

$
51,700

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

Key Energy Services, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(In thousands)

(Unaudited)

					Six Months Ended June 30,

					2008			2007
*CASH FLOWS FROM OPERATING ACTIVITIES:*
	Net income				$	78,496		$	100,327
	Adjustments to reconcile net income to net cash provided by operating activities:
		Minority interest				(245	)		—
		Depreciation and amortization				82,247			60,298
		Accretion of asset retirement obligations				320			262
		Income from equity method investment in IROC Energy Services Corp.				(1,027	)		(243	)
		Amortization of deferred financing costs and discount				1,066			858
		Deferred income tax expense				886			5,720
		Capitalized interest				(3,174	)		(1,998	)
		Gain on sale of assets, net				(360	)		(453	)
		Share-based compensation				7,217			3,592
		Excess tax benefits from share-based compensation				(1,695	)		—
		Changes in working capital:
			Accounts receivable, net			(42,925	)		(15,745	)
			Share-based compensation liability awards			384			2,041
			Other current assets			(1,014	)		(5,156	)
			Accounts payable, accrued interest and accrued expenses			42,258			4,119
		Other assets and liabilities				(350	)		(4,982	)

				Net cash provided by operating activities		162,084			148,640

*CASH FLOWS FROM INVESTING ACTIVITIES:*
	Capital expenditures—Well Servicing					(54,453	)		(67,674	)
	Capital expenditures—Pressure Pumping					(8,496	)		(35,794	)
	Capital expenditures—Fishing and Rental					(5,902	)		(10,919	)
	Capital expenditures—Other					(2,520	)		(4,458	)
	Proceeds from sale of fixed assets					2,512			2,826
	Acquisitions, net of cash acquired of $2,017					(61,619	)		—
	Acquisition of intangible asset					(1,086	)		—
	Cash paid for short-term investments					—			(85,147	)
	Proceeds received from sale of short-term investments					268			31,900

				Net cash used in investing activities		(131,296	)		(169,266	)

*CASH FLOWS FROM FINANCING ACTIVITIES:*
	Borrowings on revolving credit facility					85,000			—
	Payments on revolving credit facility					(35,000	)		(2,000	)
	Repayments of capital lease obligations					(5,936	)		(5,357	)
	Repurchases of common stock					(95,879	)		—
	Proceeds from exercise of stock options					5,972			—
	Proceeds paid for debt issuance costs					(314	)		—
	Excess tax benefits from share-based compensation					1,695			—

				Net cash used in financing activities		(44,462	)		(7,357	)

	Effect of changes in exchange rates on cash					630			(305	)

	Net decrease in cash and cash equivalents					(13,044	)		(28,288	)

	Cash and cash equivalents, beginning of period					58,503			88,375

	Cash and cash equivalents, end of period				$	45,459		$	60,087

~~(Unaudited)~~

Three Months Ended March 31,

2008

2007

CASH FLOWS FROM OPERATING ACTIVITIES:

Net income

$
34,484

$
52,190

Adjustments to reconcile net income to net cash provided by operating activities:

Minority interest

(34
)
—

Depreciation and amortization

39,976

29,614

Accretion of asset retirement obligations

173

131

Income from equity method investment in IROC Energy Services Corp

(4
)
(556
)
Amortization of deferred financing costs and discount

542

428

Deferred income tax (benefit) expense

(110
)
3,292

Capitalized interest

(1,658
)
(844
)
(Gain) loss on sale of assets, net

(266
)
250

Stock-based compensation

2,913

2,391

Excess tax benefits from stock-based compensation

(108
)
—

Changes in working capital:

Accounts receivable, net

(13,040
)
(13,650
)
Stock-based compensation liability awards

(1,225
)
—

Other current assets

(4,179
)
(3,272
)
Accounts payable, accrued interest and accrued expenses

14,054

19,395

Other assets and liabilities

(1,207
)
(2,519
)

Net cash provided by operating activities

70,311

86,850

CASH FLOWS FROM INVESTING ACTIVITIES:

Capital expenditures - Well Servicing

(25,895
)
(26,791
)
Capital expenditures - Pressure Pumping

(1,857
)
(13,576
)
Capital expenditures - Fishing and Rental

(1,406
)
(4,006
)
Capital expenditures - Other

(1,217
)
(2,002
)
Proceeds from sale of fixed asssets

2,088

265

Acquisitions, net of cash acquired

(993
)
—

Acquisition of intangible asset

(1,086
)
—

Cash paid for short-term investments

—

(83,077
)
Proceeds received from sale of short-term investments

—

18,635

Net cash used in investing activities

(30,366
)
(110,552
)

CASH FLOWS FROM FINANCING ACTIVITIES:

Repayments of long-term debt

—

(1,000
)
Repayments of capital lease obligations

(3,006
)
(2,591
)
Repurchases of common stock

(65,376
)
—

Proceeds from exercise of stock options

353

—

Proceeds paid for debt issuance costs

(314
)
—

Excess tax benefits from stock-based compensation

108

—

Net cash used in financing activities

(68,235
)
(3,591
)

Effect of exchange rates on cash

(342
)
(370
)

Net decrease in cash and cash equivalents

(28,632
)
(27,663
)
Cash and cash equivalents, beginning of period

58,503

88,375

Cash and cash equivalents, end of period

$
29,871

$
60,712

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

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS

1. GENERAL

Key Energy Services, Inc. and its wholly owned subsidiaries (collectively, the ~~“Company,” “we,” “us,” “its,”~~"Company," "we," "us," "its," and ~~“our”~~"our") ~~provides~~provide a complete range of well services to major oil companies and independent oil and natural gas production companies, including rig-based well maintenance, workover, well completion and recompletion services, drilling, oilfield transportation services, pressure pumping services, fishing and rental services, and ancillary oilfield services. We believe that we are the leading onshore, rig-based well servicing contractor in the United States. We operate in most major oil and natural gas producing regions of the United States as well as internationally in Argentina and Mexico. We also have a technology development company based in Canada.

The accompanying unaudited condensed consolidated financial statements were prepared using generally accepted accounting principles in the United States of America ~~(“GAAP”~~("GAAP") for interim financial information and in accordance with the rules and regulations of the Securities and Exchange Commission ~~(“SEC”~~("SEC"). The condensed December 31, 2007 balance sheet was prepared from audited financial statements included in the ~~Company’s~~Company's Annual Report on Form 10-K for the year ended December 31, 2007. Certain information relating to the ~~Company’s~~Company's organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in this Quarterly Report on Form 10-Q. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the ~~Company’s~~Company's Annual Report on Form 10-K for the year ended December 31, 2007.

Certain reclassifications have been made to prior period amounts to conform to current period financial statement classifications. These reclassifications relate to the cash flow presentation of certain of our share-based payment arrangements that are accounted for as liabilities. In prior periods, these amounts were included in the caption titled "Stock-Based Compensation," a component of cash flows from operating activities. These amounts are now presented in a caption titled "Share-based compensation liability awards," which is also classified as a cash flow from operations. Total cash provided by operating activities remains unchanged from previously reported amounts.

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 statement of the financial position, results of operations and cash flows for the interim periods presented herein. The results of operations for the three ~~months~~and six month periods ended ~~March 31,~~June 30, 2008 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.

2. SIGNIFICANT ACCOUNTING POLICIES AND ESTIMATES

The preparation of these 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 also impact the nature and extent of our disclosure, if any, of our ~~contingent liabilities.~~commitments and contingencies. 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, and (vi) assess ~~workers’~~workers' compensation, vehicular liability, self-insured risk accruals and

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

2. SIGNIFICANT ACCOUNTING POLICIES AND ESTIMATES (Continued)

other insurance reserves. Our actual results may differ materially from these estimates. We believe that our estimates are reasonable.

We apply Financial Accounting Standards Board ("FASB") Interpretation ("FIN") No. 46, "Consolidation of Variable Interest Entities—an Interpretation of ARB No. 51 (Revised 2003)" ("FIN 46(R)") when determining whether or not to consolidate a Variable Interest Entity ("VIE"). FIN 46(R) requires that an equity investor in a VIE have significant equity at risk (generally a minimum of 10%) and hold a controlling interest, evidenced by voting rights, and absorb a majority of the entity's expected losses, receive a majority of the entity's expected returns, or both. If the equity investor is unable to evidence these characteristics, the entity that retains these ownership characteristics will be required to consolidate the VIE. We have determined that we do not have an interest in a VIE and as such we are not the primary beneficiary of a variable interest in a VIE and we are not the holder of a significant variable interest in a VIE.

The Company adopted Statement of Financial Accounting Standards ~~(“SFAS”~~("SFAS") No. 159, ~~“The~~"The Fair Value Option for Financial Assets and Liabilities, including an amendment of FASB Statement No. ~~115” (“~~115" ("SFAS ~~159”~~159"), on January 1, 2008. SFAS 159 permits companies to choose, at specified election dates, to measure eligible items at fair value (the ~~“Fair~~"Fair Value ~~Option”~~Option"). Companies choosing such an election report unrealized gains and losses on items for which the Fair Value Option has been elected in earnings at each subsequent reporting period. We did not elect to measure any of our financial assets or liabilities using the Fair Value Option. We will assess at each measurement date whether to use the Fair Value Option on any future financial assets or liabilities as permitted pursuant to the provisions of SFAS 159.

There have been no material changes or developments in the ~~Company’s~~Company's evaluation of accounting estimates and underlying assumptions or methodologies that the Company believes to be Critical Accounting Policies and Estimates as disclosed in our Annual Report on Form 10-K for the year ended December 31, 2007.

3. NEW ACCOUNTING STANDARDS

SFAS 157. In September 2006, the ~~Financial Accounting Standards Board (“FASB”)~~FASB issued SFAS No. 157, ~~“Fair~~"Fair Value ~~Measurements” (“~~Measurements" ("SFAS ~~157”~~157"), which is intended to increase consistency and comparability in fair value measurements by defining fair value, establishing a framework for measuring fair value, and expanding disclosures about fair value measurements. SFAS 157 applies to other accounting pronouncements that require or permit fair value measurements and is effective for financial statements issued for fiscal years beginning after November 15, 2007 and interim periods within those fiscal years.

In February 2008, the FASB issued FASB Staff Position FAS 157-2 (“("FSP FAS ~~157-2”~~157-2"). FSP FAS 157-2 delays the effective date of SFAS 157 to fiscal years beginning after November 15, 2008, and interim periods within those fiscal

years, for non-financial assets and liabilities, except for items that are recognized or disclosed at fair value in the ~~registrant’s~~

registrant's financial statements on a recurring basis. The adoption of SFAS 157, as modified by FSP FAS 157-2, did not have a material impact on our financial position, results of operations, or cash flows.

SFAS 141(R). In December 2007, the FASB issued SFAS No. 141 (Revised 2007), ~~“Business Combinations” (“~~"Business Combinations" ("SFAS 141(R)”"). SFAS 141(R) will significantly change the accounting for business combinations. Under SFAS 141(R), an acquiring entity will be required to recognize all the assets and

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

3. NEW ACCOUNTING STANDARDS (Continued)

liabilities assumed in a transaction at the acquisition-date fair value, with limited exceptions. Specific changes in SFAS 141(R) from previously issued guidance include:

•

Acquisition costs will generally be expensed as incurred;

•

Noncontrolling interests will be valued at fair value at the acquisition date;

•

Certain acquired contingent liabilities will be recorded at fair value at the acquisition date and subsequently remeasured at either the higher of such amount or the amount determined under existing guidance for non-acquired contingencies;

•

In-process research and development will be recorded at fair value as an indefinite-lived intangible asset at the acquisition date;

•

Restructuring costs associated with a business combination will generally be expensed subsequent to the acquisition date; and

•

Changes in deferred tax asset valuation allowances and income tax uncertainties after the acquisition date generally will affect income tax expense.

SFAS 141(R) also includes new disclosure requirements related to business combinations. This statement applies to all 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, 2008, and earlier adoption is prohibited. The impact of the adoption of this standard on the ~~Company’s~~Company's financial position, results of operations, and cash flows will not be known until the Company completes a business combination subsequent to the adoption date of this standard.

SFAS 160. In December 2007 the FASB issued SFAS No. 160, ~~“Noncontrolling~~"Noncontrolling Interests in Consolidated Financial Statements: an amendment of ARB No. ~~51” (“~~51" ("SFAS ~~160”~~160"). SFAS 160 establishes new accounting and reporting standards for the noncontrolling interest (formerly referred to as ~~“minority interests”~~"minority interests") in a subsidiary and for the deconsolidation of a subsidiary. Specifically, this statement requires the recognition of a noncontrolling interest as equity in the consolidated financial statements and separate from the ~~parent’s~~parent's equity. The amount of net income attributable to a noncontrolling interest will be included in consolidated net income on the face of the income statement. SFAS 160 clarifies that changes in a ~~parent’s~~parent's ownership interest in a subsidiary that do not result in deconsolidation are equity transactions if the parent retains its controlling financial interest. In addition, SFAS 160 requires that a parent recognize a gain or loss in net income when a subsidiary is deconsolidated. Such gains or loss will be measured using the fair value of the noncontrolling equity investment on the deconsolidation date. SFAS 160 also includes expanded disclosure requirements regarding the interests of the parent and its noncontrolling interest. SFAS 160 is effective for fiscal years and interim periods within those fiscal years, beginning on or after December 15, 2008, with early adoption prohibited. The Company is in the process of determining the impact the adoption of this standard will have on the ~~Company’s~~Company's financial position, results of operations and cash flows.

SFAS 161. In March 2008, the FASB issued SFAS No. 161, ~~“Disclosure~~"Disclosure about Derivative Instruments and Hedging ~~Activities –~~ Activities—An Amendment of FASB Statement No. ~~133” (“~~133" ("SFAS ~~161”~~161"). SFAS 161 requires more disclosures about an ~~entity’s~~entity's derivative and hedging activities in order to improve the transparency of financial reporting. SFAS 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged.

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

3. NEW ACCOUNTING STANDARDS (Continued)

This Statement encourages, but does not require, comparative disclosures for earlier periods at initial adoption. We will adopt the provisions of SFAS 161 on January 1, 2009. The Company currently has no financial instruments that qualify as derivatives, and we do not expect that the adoption of this standard will have a material impact on the ~~Company’s~~Company's financial position, results of operations, and cash flows.

4. ACQUISITIONS ~~ACQUISITIONS~~

~~The~~From time to time, the Company ~~has acquired~~acquires businesses that are consistent with its long-term growth strategy. Results of operations for acquisitions are included in the unaudited condensed consolidated statements of operations beginning from the date of acquisition. The ~~balances~~purchase price allocations included in the unaudited condensed consolidated balance sheets related to acquisitions made during the third and

fourth quarters of 2007 and the ~~first quarter of~~six months ended June 30, 2008 are based on preliminary information and are subject to change when final ~~asset valuations~~fair value determinations are ~~obtained~~made for the assets acquired and ~~the potential for~~ liabilities ~~has been evaluated.~~assumed. Acquisitions are accounted for using the purchase method of accounting and the purchase price is allocated to the net assets acquired and liabilities assumed based upon their estimated fair values at the date of acquisition. Final valuations of assets and liabilities are obtained and recorded as soon as practicable and within one year from the date of the acquisition.

Tri-Energy Services, LLC

On January 17, 2008, the Company, through a wholly-owned subsidiary, purchased the fishing and rental assets of Tri-Energy Services, LLC ~~(“Tri-Energy”~~("Tri-Energy"), for approximately $1.9 million in cash. These assets were integrated into our Fishing and Rental segment. The equity interests of Tri-Energy were owned by employees of the Company who joined the Company in October 2007 in connection with the acquisition of Moncla Well Service, Inc. and related entities. The purchase price was allocated to the tangible and intangible assets purchased and the acquisition of the Tri-Energy assets was accounted for as an asset purchase and did not result in the establishment of goodwill.

Western Drilling, LLC

On April 3, 2008, the Company, through a wholly-owned subsidiary, purchased all of the outstanding equity interests of Western Drilling, LLC ("Western"), a privately-owned company based in California that operated 22 working well service rigs, three stacked well service rigs, and equipment used in the workover and rig relocation process. We acquired Western to increase our service footprint in the California market.

The purchase price was $51.5 million in cash and was paid on April 3, 2008. The purchase price was subject to a working capital adjustment 45 days from the closing date of the acquisition and resulted in additional consideration paid of $0.1 million in May 2008. The Company also incurred direct transaction costs of approximately $0.4 million. The acquisition was funded from borrowings of $50.0 million under the Company's Senior Secured Credit Facility (see Note 8—"Long-Term Debt.") and cash on hand.

The total purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values. The excess of the purchase price over the fair value of net assets acquired was recorded as goodwill. The allocation of the purchase price was based upon preliminary valuations and estimates, and is subject to change as the valuations are finalized. The primary areas of the purchase

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

4. ACQUISITIONS (Continued)

price allocation that are not yet finalized relate to the fair values of identifiable intangible and tangible assets, and pre-merger contingencies related to environmental exposures. The final valuation of net assets is expected to be completed no later than the first quarter of 2009.

The following table summarizes the preliminary estimated fair values of the assets acquired and liabilities assumed on the date of the Western acquisition (in thousands):


Cash		$	687
Other current assets			6,839
Property and equipment			30,162
Goodwill			8,149
Intangible assets			9,000
Other assets			132

	Total assets acquired		54,969
Current liabilities			2,979

	Total liabilities assumed		2,979

Net assets acquired		$	51,990

The fair values of property and equipment were determined using a market approach. The fair values of identified intangible assets were determined using an income approach to measure the present worth of anticipated future economic benefits. The Company also performed an economic obsolescence analysis to confirm the values identified through the aforementioned methods. The allocation is still preliminary at this time, and may potentially change by a material amount once the purchase price allocation is finalized.

Goodwill was recognized as part of the acquisition of Western as the purchase price exceeded the fair value of the acquired assets and assumed liabilities. The Company believes the goodwill associated with the Western acquisition is related to the acquired workforce, potential future expansion of the Western service offerings, and the ability to expand our service offerings. Therefore, it was not allocated to the acquired assets and assumed liabilities.

The acquired identifiable intangible asset of $9.0 million is related to customer relationships and is subject to amortization under SFAS No. 142, "Goodwill and Other Intangible Assets" ("SFAS 142"). The customer relationship will be amortized as the value of the relationships are realized using rates of 17%, 19%, 15%, 12%, 9%, 7%, 6%, 5%, 4%, 3%, 2%, and 1% for years one through twelve, respectively. The $8.1 million of goodwill associated with the purchase of Western has been allocated to our Well Servicing segment, and the assets and results of operations subsequent to April 3, 2008 have also been incorporated into the Well Servicing segment.

Hydra-Walk, Inc.

On May 30, 2008, the Company, through a wholly-owned subsidiary, purchased all of the outstanding stock of Hydra-Walk, Inc. ("Hydra-Walk") for approximately $10.3 million in cash and a performance earn-out potential of up to $2.0 million over the next two years if certain financial performance measures are met. The purchase price is subject to a post-closing working capital adjustment that has not been finalized. The Company retained approximately $1.1 million of Hydra-

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

4. ACQUISITIONS (Continued)

Walk's net working capital as a result of the transaction and did not assume any of the debt of Hydra-Walk.

Hydra-Walk is a leading provider of pipe handling solutions for the oil and gas industry and operates over 80 automated pipe handling units in Oklahoma, Texas and Wyoming. The assets and results of operations for Hydra-Walk were integrated into our Fishing and Rental segment beginning on May 31, 2008. The acquisition is accounted for as a business combination and the purchase price was allocated to the tangible assets acquired and liabilities assumed based on their estimated fair values. The excess of the purchase price over the fair value of net assets acquired resulted in the establishment of $5.5 million of goodwill. The allocation of the purchase price was based upon preliminary estimates of the fair value of the tangible assets, and is subject to change as valuations are finalized. The primary areas of the purchase price allocation that are not yet finalized relate to the fair values of tangible assets and valuation of the intangible assets acquired, if any. The final valuation of net assets is expected to be completed no later than the second quarter of 2009.

Acquisitions made during 2007

On September 5, 2007, the Company acquired Advanced Measurements, Inc. ("AMI"), which operates in Canada and is a technology company focused on oilfield service equipment controls, data acquisition, and digital information flow. The purchase price was $6.6 million in cash and $2.9 million in assumed debt and was paid in September 2007. ~~The purchase price is subject~~During the six months ended June 30, 2008, the Company made additional payments to asettle its working capital adjustment ~~mechanism which was settled in February 2008~~with the former owners of AMI and ~~resulted in~~incurred additional ~~consideration paid of approximately $0.9 million. This also~~transaction costs directly related to the business combination. These payments totaled $1.3 million and resulted in additional goodwill of ~~$0.9~~$1.3 million.

On October 25, 2007, the Company acquired Moncla Well Service, Inc. and related entities ("Moncla") which ~~operate~~operated well service rigs, barges, and ancillary equipment in the southeastern United States. During the ~~three~~six months ended ~~March 31,~~June 30, 2008, the Company refined its fair value allocation of the ~~net~~assets acquired and liabilities assumed by decreasing the working capital accounts by $0.6 million, decreasing the fair value of the well service assets acquired by $3.6 million, increasing the deferred tax asset balance by $0.3 million, decreasing ~~working capital~~its deferred tax liability balance by ~~$0.7~~$0.4 million, and incurring additional fees related to the closing of the transaction of less than $0.1 million. These changes were offset with a corresponding net increase to goodwill for $3.6 million in the unaudited condensed consolidated balance sheet as of ~~March 31,~~June 30, 2008.

On December 7, 2007, the Company acquired the well service assets and related equipment of Kings Oil Tools, Inc. ("Kings"), a California-based well service company. During the ~~three~~six months ended ~~March 31,~~June 30, 2008, the Company revised its fair value allocation of the ~~net~~ assets acquired and liabilities assumed by increasing the fair value of the well service assets acquired by ~~$1.5~~$1.6 million, ~~decreased~~increasing the deferred tax assets by $0.4 million, decreasing the fair value of working capital accounts by $0.1 million, and ~~paid~~incurring additional fees related to the closing of the transaction of $0.1 million. These changes were offset with a corresponding net decrease to goodwill for $1.7 million in the unaudited condensed consolidated balance sheet as of ~~March 31,~~June 30, 2008.

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

5. SUPPLEMENTAL FINANCIAL INFORMATION

The table below presents the comparative detailed financial information of current accrued liabilities at ~~March 31,~~June 30, 2008 and December 31, ~~2007.~~

2007:


	March 31, 2008		December 31, 2007			June 30, 2008		December 31, 2007
	(in thousands)					(in thousands)
Current accrued liabilities:					Current accrued liabilities:
Accrued payroll, taxes, and employee benefits	$	55,408	$	56,744	Accrued payroll, taxes, and employee benefits	$	74,979	$	56,744
Accrued operating expenditures	53,826		52,180		Accrued operating expenditures		60,713		52,180
Income, sales, use and other taxes	42,198		35,310		Income, sales, use and other taxes		47,956		35,310
Self-insurance reserves	23,572		25,208		Self-insurance reserves		26,391		25,208
Unsettled legal claims	8,284		6,783		Unsettled legal claims		7,799		6,783
Phantom share liability	1,118		2,458		Phantom share liability		1,945		2,458
Deferred revenue	328		976		Deferred revenue		337		976
Other	3,201		3,705		Other		4,777		3,705
Total	$	187,935	$	183,364

					Total	$	224,897	$	183,364

		June 30, 2008		December 31, 2007

		(in thousands)
Non-current accrued liabilities:
Asset retirement obligations		$	9,632	$	9,298
Environmental liabilities			2,803		3,090
Accrued rent			2,663		2,829
Accrued income taxes			2,739		2,705
Phantom share liability			2,182		896
Other			621		713

	Total	$	20,640	$	19,531

March 31, 2008

December 31,
2007

(in thousands)

Non-current accrued liabilities:

Asset retirement obligations

$
9,235

$
9,298

Environmental liabilities

2,863

3,090

Accrued rent

2,746

2,829

Accrued income taxes

2,705

2,705

Phantom share liability

1,011

896

Other

590

713

Total

$
19,150

$
19,531

~~The table below presents the comparative supplemental cash flow information for the three months ended March 31, 2008 and 2007:~~

Three Months Ended March 31,

2008

2007

(in thousands)

Supplemental cash flow information:

Cash paid for interest

$
2,432

$
6,835

Cash paid for taxes

1,095

6,130

~~Cash paid for interest includes cash payments for interest on our long-term debt and capital lease obligations and commitment and agency fees paid.~~

6.GOODWILL AND OTHER INTANGIBLE ASSETS

The changes in the carrying amount of goodwill for the ~~three~~six months ended ~~March 31,~~June 30, 2008 are as follows:

		Well Servicing Segment			Pressure Pumping Segment		Fishing and Rental Services Segment		Total

		(in thousands)
December 31, 2007		$	311,744		$	47,905	$	18,901	$	378,550
	Goodwill acquired during period		8,149			—		5,481		13,630
	Purchase price allocation and other adjustments, net		3,113			—		—		3,113
	Impact of foreign currency translation		(80	)		—		—		(80	)

June 30, 2008		$	322,926		$	47,905	$	24,382	$	395,213

Well Servicing
Segment

Pressure
Pumping Segment

Fishing and
Rental Segment

Total

(in thousands)

December 31, 2007

$
311,744

$
47,905

$
18,901

$
378,550

Purchase price and other adjustments, net

221

—

—

221

Foreign currency translation

(178
)
—

—

(178
)
March 31, 2008

$
311,787

$
47,905

$
18,901

$
378,593

The components of our intangible assets are as follows:

March 31, 2008

December 31,
2007

(in thousands)

Noncompete agreements:

Gross carrying value

$
18,342

$
18,402

Accumulated amortization

(3,765
)
(2,772
)
Net carrying value

$
14,577

$
15,630

Patents and trademarks:

Gross carrying value

$
4,126

$
4,150

Accumulated amortization

(2,686
)
(2,526
)
Net carrying value

$
1,440

$
1,624

Customer relationships:

Gross carrying value

$
26,225

$
25,139

Accumulated amortization

(3,754
)
(1,649
)
Net carrying value

$
22,471

$
23,490

Customer backlog:

Gross carrying value

$
744

$
999

Accumulated amortization

(108
)
(214
)
Net carrying value

$
636

$
785

Developed technology:

Gross carrying value

$
5,644

$
4,762

Accumulated amortization

(1,095
)
(397
)
Net carrying value

$
4,549

$
4,365

			June 30, 2008			December 31, 2007

			(in thousands)
Noncompete agreements:
	Gross carrying value		$	18,345		$	18,402
	Accumulated amortization			(4,961	)		(2,772	)

		Net carrying value	$	13,384		$	15,630

Patents and trademarks:
	Gross carrying value		$	4,077		$	4,150
	Accumulated amortization			(2,818	)		(2,526	)

		Net carrying value	$	1,259		$	1,624

Customer relationships:
	Gross carrying value		$	35,225		$	25,139
	Accumulated amortization			(6,369	)		(1,649	)

		Net carrying value	$	28,856		$	23,490

Customer backlog:
	Gross carrying value		$	766		$	999
	Accumulated amortization			(223	)		(214	)

		Net carrying value	$	543		$	785

Developed technology:
	Gross carrying value		$	5,901		$	4,762
	Accumulated amortization			(1,412	)		(397	)

		Net carrying value	$	4,489		$	4,365

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

6. GOODWILL AND OTHER INTANGIBLE ASSETS (Continued)

Certain of our intangible assets are denominated in currencies other than U.S. Dollars and as such the values of those assets are subject to fluctuations associated with changes in exchange rates. Additionally, certain of these assets are also subject to purchase accounting adjustments. The estimated fair ~~value~~values of intangible assets obtained through acquisitions consummated in the preceding twelve months are based on preliminary information which is subject to change when final valuations are obtained. Amortization expense for our intangible assets was ~~$3.8~~$4.3 million and ~~$0.7~~$8.1 million for the three months and six months ended ~~March 31,~~June 30, 2008, respectively, and $0.5 million and $1.2 million for the three months and six months ended June 30, 2007, respectively.

7. INVESTMENT IN IROC ENERGY SERVICES CORP.

As of ~~March 31,~~June 30, 2008 and December 31, 2007, we owned 8,734,469 shares of IROC Energy Services Corp.~~, formerly known as IROC Systems Corp. (“IROC”~~ ("IROC"), an Alberta-based oilfield services company. This represented approximately 19.7% of ~~IROC’s~~IROC's outstanding common stock on ~~March 31,~~June 30, 2008 and December 31, 2007. IROC shares trade on the Toronto Venture Stock Exchange and had a closing price of ~~$0.80~~$1.35 CDN and $0.74 CDN per share on ~~March 31,~~June 30, 2008 and December 31, 2007, respectively. Mr. William Austin, our Chief Financial Officer, and Mr. Newton W. Wilson III, our Chief Operating Officer and former General Counsel, serve on the board of directors of IROC.

We have significant influence over the operations of IROC through our ownership interest and representation on ~~IROC’s~~IROC's board of directors, but we do not control it. We account for our investment in IROC using the equity method. Our investment in IROC totaled ~~$10.6~~$11.8 million and $11.2 million as of ~~March 31,~~June 30, 2008 and December 31, 2007, respectively. The pro-rata share of ~~IROC’s~~IROC's earnings and losses to which we are entitled is recorded in our unaudited condensed consolidated statements of operations as a component of other income and expense, with an offsetting increase or decrease to the value of our investment, as appropriate. Any earnings distributed back to us from IROC in the form of dividends would result in a decrease in the value of our equity investment. The value of our investment may also increase or decrease each period due to changes in the exchange rate between USD and CDN. Changes in the value of our investment due to fluctuations in exchange rates are offset by Accumulated Other Comprehensive Income.

We recorded ~~less than $0.1~~$1.0 million and ~~$0.6~~$1.0 million of income related to our investment in IROC for the three and six months ended ~~March 31,~~June 30, 2008, respectively, and $0.3 million of losses and $0.2 million of income for the three and six months ended June 30, 2007, respectively. During those time periods, no earnings were distributed back to us by IROC in the form of dividends.

An impairment review of our equity method investment in IROC is performed on a quarterly basis to determine if there has been a decline in fair value that is other than temporary. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, fair value is based on an estimate of discounted cash flows. In determining whether the decline is other than temporary, we consider the cyclicality of the industry in which the investment operates, its historical performance, its performance in relation to its peers and the current economic environment. Future conditions in the industry, operating performance and performance in relation to peers and the future economic environment may vary from our current assessment of recoverability. Such future conditions could therefore result in a determination that a decline in fair value is other than temporary. ~~IROC’s~~IROC's stock price is currently depressed and has historically been volatile, and as such the fair value of the ~~Company’s~~Company's investment is less than the amount reflected in the ~~Company’s~~Company's consolidated financial

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

7. INVESTMENT IN IROC ENERGY SERVICES CORP. (Continued)

statements. If we later determine that the decline is other than temporary, we ~~would~~will record a write-down in the carrying value of our asset to the then current fair market value.

8. LONG-TERM DEBT

The components of our long-term debt are as follows:

	June 30, 2008			December 31, 2007

	(in thousands)
8.375% Senior Notes due 2014	$	425,000		$	425,000
Senior Secured Credit Facility revolving loans due 2012		100,000			50,000
Notes payable—related parties, net of discount of $251 and $322		22,249			22,178
Capital lease obligations		23,174			26,815

		570,423			523,993

Less current portion		(11,083	)		(12,379	)

Total long-term debt and capital lease obligations, net of fair value discount	$	559,340		$	511,614

March 31, 2008

December 31,
2007

(in thousands)

8.375% Senior Notes due 2014

$
425,000

$
425,000

Senior Secured Credit Facility revolving loans due 2012

50,000

50,000

Notes payable - related party, net of discount of $286 and $322

22,214

22,178

Capital lease obligations

25,004

26,815

522,218

523,993

Less current portion

(11,613
)
(12,379
)
Total long-term debt and capital lease obligations, net of fair value discount

$
510,605

$
511,614

8.375% Senior Notes due 2014

On November 29, 2007, the Company issued $425.0 million aggregate principal amount of 8.375% Senior Notes due 2014 (the "Notes"), under an Indenture, dated as of November 29, 2007 (the "Indenture"), among us, the guarantors party thereto (the "Guarantors") and The Bank of New York Trust Company, N.A., as trustee. The Notes were priced at 100% of their face value to yield 8.375%. Net proceeds, after deducting initial purchasers' discounts and estimated offering expenses, were approximately $416.1 million. We used approximately $394.9 million of the net proceeds to retire then-existing term loans, including accrued and unpaid interest, with the balance used for general corporate purposes.

The Notes are general unsecured senior obligations of Key. Accordingly, they rank effectively subordinate to all of our existing and future secured indebtedness. The 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 Notes is payable on June 1 and December 1 of each year, beginning June 1, 2008. The Notes mature on December 1, 2014.

Senior Secured Credit Facility

The Company maintains a revolving credit agreement with a syndicate of banks of which Bank of America Securities LLC and Wells Fargo Bank, N.A. are the Administrative Agents (“("Senior Secured Credit ~~Facility”~~Facility"). The aggregate lending commitment of this facility is $400.0 million and allows for a combination of borrowings and issuances of letters of credit. There were borrowings of ~~$50.0~~$100.0 million and outstanding letters of credit ~~$61.1~~of $61.5 million under the Senior Secured Credit Facility at ~~March 31,~~June 30, 2008. The weighted-average interest rate on the outstanding borrowings of the Senior Secured Credit Facility was 4.17125% at ~~March 31,~~June 30, 2008. The Senior Secured Credit Facility requires the Company to

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

8. LONG-TERM DEBT (Continued)

maintain a consolidated interest coverage ratio of at least 3.0 to 1.0, maintain a consolidated leverage ratio of not more than 3.5 to 1.0, and to not exceed capital expenditures of $250.0 million in any fiscal year. The Company was in compliance with these covenants at ~~March 31,~~June 30, 2008.

All obligations under the Senior Secured Credit Facility are guaranteed by most of our subsidiaries and are secured by most of our assets, including our accounts receivable, inventory and equipment.

9. INCOME TAXES

The ~~Company’s~~Company's effective tax rate for the three months and six months ended ~~March 31,~~June 30, 2008 was 38.5% and ~~2007 was 39.5 %~~38.9%, respectively, and ~~38.4%,~~38.7% and 38.5% for the three months and six months ended June 30, 2007, respectively. The primary difference between the statutory rate of 35% and our effective tax rate relates to state and foreign taxes.

As of ~~March 31,~~June 30, 2008 and December 31, 2007, we had approximately ~~$6.9~~$7.0 million and $6.8 million, respectively, of unrecognized tax benefits, net of federal tax benefit, which, if recognized, would impact our effective tax rate. We are subject to U.S. Federal Income Tax as well as income taxes in multiple state and foreign jurisdictions. We have substantially concluded all U.S. federal and state tax matters through the year ended December 31, 2002.

Approximately $0.5 million of the Net Operating Loss deferred tax asset valuation allowance related to our Mexico operations has been released as a discrete tax benefit and recorded in the quarter ended June 30, 2008. The actual income from our Mexico operations for 2008 will affect the ultimate utilization of this deferred tax asset.

We recognize accrued interest expense and penalties related to unrecognized tax benefits as income tax expense. We have accrued approximately ~~$2.5~~$2.6 million and $2.3 million for the payment of interest and penalties as of ~~March 31,~~June 30, 2008 and December 31, 2007. We do not expect any substantial changes within the next 12 months related to uncertain tax positions.

During the first ~~quarter~~six months of 2008, the Company applied approximately ~~$14.5~~$17.0 million of the income tax refund receivable due as of December 31, 2007 against the ~~Company’s~~Company's current income taxes payable. No cash refund was received by the Company.

The Company is subject to the revised Texas Franchise tax. The revised Texas Franchise tax is an income tax equal to one percent of Texas-sourced revenue reduced by the greater of (a) cost of goods sold (as defined by Texas law), (b) compensation (as defined by Texas law) or (c) thirty percent of the Texas-sourced revenue. The Company accounts for the revised Texas Franchise tax in accordance with SFAS No. 109, "Accounting for Income Taxes," as the tax is derived from a taxable base that consists of income less deductible expenses.

10. COMMITMENTS AND CONTINGENCIES

Litigation.~~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 are often subject to jury verdicts and arbitration hearings that result in outcomes in favor of the plaintiffs. 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. In accordance with SFAS No. 5, "Accounting for Contingencies," we establish a provision for a contingent liability when it is

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

10. COMMITMENTS AND CONTINGENCIES (Continued)

probable that a liability has been incurred and the amount is estimable. As of June 30, 2008, the aggregate amount of our provisions for losses related to litigation that are deemed probable and estimable is approximately $7.8 million. We do not believe that the disposition of any of these matters will result in ~~a material adverse impact on our consolidated financial position, results~~an additional loss materially in excess of ~~operations or cash flows.~~amounts that have been recorded.

Gonzales Matter. In September 2005, a class action lawsuit,Gonzales v. Key Energy Services, Inc., was filed in Ventura County, California Superior Court, alleging that Key did not pay its hourly employees for travel time between the yard and the wellhead and that certain employees were denied meal and rest periods between shifts. We have recorded a liability for this matter and do not expect that the conclusion of this matter will result in an additional loss materially in excess of the amounts that have ~~a material impact on our financial position, results of operations, or cash flows.~~been recorded.

Litigation with Former Officers and Employees. We were named in a lawsuit by our former general counsel, Jack D. Loftis, Jr., filed in the U.S. District Court, District of New Jersey on April 21, 2006, in which he alleges a ~~“whistle-blower”~~"whistle-blower" claim under the Sarbanes-Oxley Act, breach of contract, breach of good faith and fair dealing, breach of fiduciary duty, and wrongful termination. On August 17, 2007, the Company filed counterclaims against Mr. Loftis alleging attorney malpractice, breach of contract, and breach of fiduciary duties. In its counterclaims, the Company seeks repayment of all severance paid to Mr. Loftis to date (approximately $0.8 million) plus benefits paid during the period July 8, 2004 to September 21, 2004, and damages relating to the allegations of malpractice and breach of fiduciary duties. The case was transferred to and is now pending in the U.S. District Court for the Eastern District of Pennsylvania. We have not recorded a liability for this matter and do not believe that the conclusion of this matter will have a material impact on our financial position, results of operations or cash flows.

On September 3, 2006, our former controller and assistant controller filed a joint complaint against the Company in the 133rd District Court, Harris County, Texas, alleging constructive termination and breach of contract. Additionally, on January 11, 2008, our former Chief Operating Officer, James Byerlotzer, filed a lawsuit in the 55th District Court, Harris County, Texas, alleging breach of contract based on his inability to exercise his stock options during the period that Key was not current in its SEC filings, and based on ~~Key’s~~Key's failure to provide him shares of restricted stock. We have not recorded a liability for these matters and do not believe that the conclusion of these matters will have a material impact on our financial position, results of operations or cash flows.

~~We are vigorously defending against these claims; however, we cannot predict the outcome of the lawsuits.~~

Shareholder Class Action Suits and Derivative Actions. Since June 2004, we and certain of our officers and directors were named as a defendant in six class action complaints for alleged violations of federal securities laws, which were filed in federal district court in Texas. These six actions were consolidated into one action. Four shareholder derivative actions were filed, purportedly on our behalf. On September 7, 2007, we reached agreements in principle to settle all pending securities class action and derivative lawsuits in consideration of payments totaling $16.6 million in exchange for full and complete releases for all defendants, of which Key will be required to pay approximately $1.1 million. We received final approval of the settlement of the shareholder class action claims by the court on March 6, 2008 and preliminary court approval on the derivative actions on April 18, 2008. ~~Final~~A hearing for final approval on the derivative ~~action is anticipated~~settlement was held on August 1, 2008. No objections were made by any party during the hearing. The Company anticipates that the final order dismissing the derivative actions will be signed in the third quarter. Following dismissal, all of the litigation in the shareholder and derivative matters will be concluded, and if there are no actions taken to ~~occur~~reconsider the order that

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

10. COMMITMENTS AND CONTINGENCIES (Continued)

has been signed by the court, the court-approved administrator in these matters will begin distribution of payments to eligible class members according to the terms of the settlement. We anticipate this will also be completed in the third quarter of 2008. ~~We have recorded an appropriate~~The liability for ~~this matter.~~the amount of the settlement was recorded in the first quarter of 2007.

Expired Option Holders.On In September ~~24,~~ 2007, Belinda Taylor, ~~on behalf of herself and all similarly situated residents of~~ Texas, filed a lawsuit in the 11^th Judicial District of Harris County, ~~Texas, alleging that the Company breached its contracts with~~on behalf of herself and all similarly situated current and former employees who held vested options that expired between April 28, 2004 and the date that the Company became current in its financial statements (the ~~“Expired~~"Expired Option ~~Holders”~~Holders"). The suit, ~~also~~as amended, alleges that the Company breached its contracts with the Expired Option Holders, and breached its fiduciary duties and duties of good faith and fair dealing in the pricing of stock options it granted to those Expired Option Holders, based upon the alleged overstatement of assets prior to the Company’s restatement. Ms. Taylor amended her lawsuit on September 25, 2007, to include all Expired Option Holders, regardless of residence.Holders. On March 6, 2008, the parties agreed to settle all pending claims with all Expired Option Holders, excluding those terminated for cause and those who have previously filed suits against Key, for approximately $1.0 million, which includes all taxes and legal fees, and in March 2008 we ~~have~~ recorded a liability in the amount of the settlement for this matter. ~~The~~On June 17, 2008, the settlement agreement was preliminarily approved by the Court. A hearing for final approval is ~~subject to court approval, which is expected~~scheduled to occur in the third quarter of 2008.

Automobile Accident Litigation. On August 22, 2007, one of our employees was involved in an automobile accident that resulted in a third party fatality. A lawsuit arising from this accident is currently pending in Jasper County, Texas. We are vigorously defending against the claims in the lawsuit; however, at this time we cannot predict the outcome of the lawsuit. Mediation ~~is expected~~has been rescheduled to occur ~~in June~~during the third quarter of 2008. ~~We have~~In first quarter of 2008, we recorded an appropriate liability for this ~~matter.~~matter and do not expect that the final conclusion of this matter will result in an additional loss materially in excess of the amount accrued.

Tax Audits. We are routinely the subject of audits by tax authorities, and in the past have received ~~some~~ material assessments from tax auditors. As of December 31, 2007 and ~~March 31,~~June 30, 2008, we have recorded reserves that management feels are appropriate for future potential liabilities as a result of these audits. While we believe we have fully reserved for these assessments, the ultimate amount of settlements can vary from our estimates. In connection with our former Egyptian operations, which terminated in 2005, we are undergoing income tax audits for all periods in which we had operations. As of ~~March 31,~~June 30, 2008, the Company had recorded a liability of approximately $0.4 million relating to open Egyptian tax audits. In the fourth quarter of 2007, the Company reached a preliminary settlement with the Egyptian tax authorities on the 2003 and 2004 tax years, recording a tax benefit of $0.7 million and reducing the tax liability accrued at December 31, 2007 to approximately $0.4 million. We do not expect that the ultimate resolution of the matter will result in a loss materially in excess of the amount already accrued.

Self-Insurance Reserves. We maintain reserves for ~~workers’~~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’~~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’~~workers' compensation, vehicular liability and general liability claims. As of ~~March 31,~~June 30, 2008 and December 31, 2007, we have recorded ~~$66.2~~

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

10. COMMITMENTS AND CONTINGENCIES (Continued)

$70.5 million and $69.0 million, respectively, of self-insurance reserves related to ~~workers’~~workers' compensation, vehicular liabilities and general liability claims. Partially offsetting these liabilities, we had approximately ~~$9.4~~$10.2 million and $8.1 million of insurance receivables as of ~~March 31,~~June 30, 2008 and December 31, 2007, respectively. We feel that the liabilities we have recorded are appropriate based on the known facts and circumstances and do not expect further losses materially in excess of the amounts already accrued for existing claims.

Environmental Remediation Liabilities. For environmental reserve matters, including remediation efforts for current locations and those relating to previously-disposed properties, we record liabilities when our remediation efforts are probable and the costs to conduct such remediation efforts ~~are~~can be reasonably estimated. ~~Environmental~~While our litigation reserves reflect the application of our insurance coverage, our environmental reserves do not reflect ~~management’s~~management's assessment of the insurance coverage that may apply to ~~these~~the matters at ~~issue, if such coverage is available, whereas our litigation reserves do reflect the application of our insurance coverage.~~issue. As of ~~March 31,~~June 30, 2008 and December 31, 2007, we have recorded ~~$2.9~~$2.8 million and $3.1 million, respectively, for our environmental remediation liabilities. We feel 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.

We provide performance bonds to provide financial surety assurances for the remediation and maintenance of our Salt Water Disposal ~~(“SWD”~~("SWD") properties to comply with environmental protection standards. Costs for SWD properties may be mandatory (to comply with applicable laws and regulations), in the future (required to divest or cease operations), or for optimization (to improve operations, but not for safety or regulatory compliance).

Registration Payment Arrangement. In January 1999 we issued 150,000 warrants (the "Warrants") in connection with a debt offering that were exercisable for an aggregate of approximately 2.2 million shares of the Company's stock at an exercise price of $4.88125 per share. As of June 30, 2008, 75,000 Warrants had been exercised, leaving 75,000 outstanding, which were convertible into approximately 1.1 million shares of our common stock. The Warrants expire in January 2009.

~~Argentina Payroll Matters.~~ ~~Our Argentinean subsidiary, Key Energy Services S.A., had previously underpaid social security contributions~~ Under the terms of the Warrants, we are required to maintain an effective registration statement covering the shares potentially issuable upon exercise of the Warrants. If we do not have an effective registration statement covering the shares, we are required to make liquidated damages payments to the ~~Administración Federal de Ingressos Públicos (“AFIP”) as a result~~holders of ~~applying~~the Warrants. We currently do not have an ~~incorrect rate in~~effective registration statement covering the ~~calculation~~shares issuable for the Warrants. The maximum undiscounted consideration that may be required to be paid under the terms of ~~our obligations. Additionally, we also underpaid AFIP as a result of our incorrect use of food stamp equivalents provided~~the Warrants from June 30, 2008 to employees as compensation. The correct amounts have been reflected in these financial statements. On May 31, 2007, we paid AFIP $3.5 million, representing the cumulative amount of underpayment and interest. As a result of our underpayment, AFIP imposed fines and penalties against us and began an audit of our filings made to them in prior years. In March 2008, we received notification from AFIP that the audit was complete with respect to this matter and that no additional monies were due.January 2009 is approximately $0.4 million.

11. SHARE REPURCHASE PROGRAM

On October 26, 2007, the ~~Company’s~~Company's Board of Directors authorized a share repurchase program, in which the Company may spend up to $300.0 million to repurchase shares of its common stock on the open market. The program expires at the end ofof the first quarter of 2009. At ~~March 31,~~June 30, 2008, the Company had ~~$202.6~~$175.5 million of availability under the share repurchase program to repurchase shares of its common stock on the open market. During the first ~~quarter~~six months of 2008, the Company repurchased an aggregate of approximately ~~5.2~~7.0 million shares at a total cost of approximately ~~$65.3~~$92.3 million, which represents the fair market value of the shares based on the price of the ~~Company’s~~Company's stock on the dates of purchase. Since the inception of the program in November 2007 through ~~March 31,~~June 30, 2008, we have repurchased an aggregate of approximately ~~7.5~~9.3 million shares for a total cost of ~~$97.4~~approximately

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

11. SHARE REPURCHASE PROGRAM (Continued)

$124.5 million. Under the terms of our Senior Secured Credit Facility, we are limited to stock repurchases of ~~$200~~$200.0 million if our consolidated debt to capitalization ratio, as defined in the Senior Secured Credit Facility, is in excess of 50%. As of ~~March 31,~~June 30, 2008, our consolidated debt to capitalization ratio was less than 50%.

12. EARNINGS PER SHARE

We present earnings per share information in accordance with the provisions of SFAS No. 128, ~~“Earnings~~"Earnings Per ~~Share” (“~~Share" ("SFAS ~~128”~~128"). Under SFAS 128, basic earnings per common share is determined by dividing net earnings applicable to common stock 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 dilutive outstanding convertible securities using the ~~“as~~treasury stock and "as if ~~converted” method.~~

converted" methods.

Three Months Ended March 31,

2008

2007

(in thousands, except per share data)

Basic Earnings per Share Computation:

Numerator

Net income

$
34,484

$
52,190

Denominator

Weighted average shares outstanding

127,966

131,629

Basic earnings per share

$
0.27

$
0.40

Diluted Earnings per Share Computation:

Numerator

Net income

$
34,484

$
52,190

Denominator

Weighted average shares outstanding

127,966

131,629

Dilutive effect from stock options

580

1,717

Dilutive effect from unvested restricted stock

269

—

Dilutive effect from warrants

492

569

129,307

133,915

Diluted earnings per share

$
0.27

$
0.39

		Three Months Ended June 30,				Six Months Ended June 30,

		2008		2007		2008		2007
		(in thousands, except per share data)
Basic EPS Computation:
Numerator
	Net income	$	44,012	$	48,136	$	78,496	$	100,327
Denominator
	Weighted average shares outstanding		124,448		131,627		126,207		131,628
Basic earnings per share		$	0.35	$	0.37	$	0.62	$	0.76
Diluted EPS Computation:
Numerator
	Net income	$	44,012	$	48,136	$	78,496	$	100,327
Denominator
	Weighted average shares outstanding		124,448		131,627		126,207		131,628
	Stock options		877		1,912		729		1,815
	Unvested restricted stock		401		—		335		—
	Warrants		795		601		643		585

			126,521		134,140		127,914		134,028

Diluted earnings per share		$	0.35	$	0.36	$	0.61	$	0.75

The diluted earnings per share calculation for the quarters ended ~~March 31,~~June 30, 2008 and 2007 exclude the potential exercise of ~~1.9~~2.3 million and ~~18,000~~less than 0.1 million stock options, ~~at weighted-average exercise prices of $14.63 and $16.25,~~ respectively, because the effects of such exercises on earnings per share in those periods would be anti-dilutive. ~~These~~The diluted earnings per share calculation for the six months ended June 30, 2008 and 2007 exclude the potential exercise of 2.1 million and less than 0.1 million stock options, respectively, because the effects of such exercises on earnings per share in those periods would be anti-dilutive. The diluted earnings per share calculation for the three and six months ended June 30, 2008 exclude the potential exercise of 0.6 million stock appreciation rights ("SARs") because the effects of such exercises on earnings per

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

12. EARNINGS PER SHARE (Continued)

share in those periods would be anti-dilutive. No SARs were issued or outstanding during the three and six months ended June 30, 2007. The options and SARs would be anti-dilutive because their exercise prices were higher than the average price of the ~~Company’s~~Company's common stock during the three and six month periods ended ~~March 31,~~June 30, 2008 and ~~2007, respectively.~~2007.

13. SHARE-BASED COMPENSATION

The Company recognized employee share-based compensation expense of ~~$3.7~~$5.1 million and ~~$2.3~~$3.1 million during the three months ended ~~March 31,~~June 30, 2008 and 2007, respectively, and $8.8 million and $5.5 million during the six months ended June 30, 2008 and 2007, respectively. In addition, during the second quarter of 2008 the Company issued 47,190 shares of common stock to our outside directors. These shares vest immediately and we recognized approximately $0.9 million of expense related to these awards. No common shares were issued to our outside directors for the three and six month periods ended June 30, 2007. The related income tax benefit recognized was $1.8 million and $0.9 million for the three months ended June 30, 2008 and 2007, respectively, and $2.8 million and $1.6 million during the six months ended June 30, 2008 and 2007, respectively. The related income tax benefit ~~recognized~~for common stock awards made to our outside directors was ~~$1.0 million and $0.7~~approximately $0.3 million for the three and six months ended ~~March 31, 2008 and 2007, respectively.~~June 30, 2008. The Company did not capitalize any share-based compensation during the three ~~months~~and six month periods ended ~~March 31,~~June 30, 2008 and 2007.

The unrecognized compensation cost related to the ~~Company’s~~Company's unvested stock options, restricted shares, stock appreciation rights, and phantom shares as of ~~March 31,~~June 30, 2008 was ~~$5.9~~$10.0 million, ~~$4.2~~$7.1 million, ~~$2.2~~$1.7 million, and ~~$2.8~~$8.5 million, respectively and ~~are~~is expected to be recognized over a weighted-average period of 1.7 years, 1.5 years, 1.1 years ~~0.5 years, 1.4 years~~ and ~~1.3~~1.9 years, respectively.

14. TRANSACTIONS WITH RELATED PARTIES

In connection with our acquisition of Western, the former owner of Western, Fred Holmes, became an employee of the Company. At the time of and subsequent to the acquisition, Mr. Holmes also owns an exploration and production company, Holmes Western Oil Corporation ("HWOC"), which was a customer of Western. Subsequent to the acquisition, the Company continued to provide services to HWOC. The prices charged for these services are at rates that are an average of the prices charged to Key's other customers in the California market. As of June 30, 2008, our receivables with HWOC totaled approximately $0.7 million and for the three and six months ended June 30, 2008, revenues from HWOC totaled approximately $2.0 million.

~~14.~~ Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

15. SEGMENT INFORMATION

The following table sets forth our segment information as of and for the three and six month periods ended ~~March 31,~~June 30, 2008 and 2007:

	Well Servicing			Pressure Pumping			Fishing and Rental			Corporate/ Other			Eliminations			Consolidated

	(in thousands)
As of and for the three months ended June 30, 2008:
Operating revenues	$	381,108		$	91,952		$	30,092		$	—		$	(1,149	)	$	502,003
Direct costs, other than depreciation expense		242,403			62,837			18,017			—			(769	)		322,488
Depreciation and amortization		31,964			4,761			2,553			2,993			—			42,271
Interest expense, net of amounts capitalized		(299	)		(334	)		(91	)		10,803			—			10,079
Net income (loss)		83,847			22,208			6,976			(68,658	)		(361	)		44,012
Property and equipment, net		726,966			133,451			54,030			32,458			—			946,905
Total assets		1,670,235			285,195			111,096			1,558,870			(1,687,635	)		1,937,761
Capital expenditures, excluding acquisitions		(28,558	)		(6,639	)		(4,496	)		(1,303	)		—			(40,996	)
	Well Servicing			Pressure Pumping			Fishing and Rental			Corporate/ Other			Eliminations			Consolidated
	(in thousands)
As of and for the three months ended June 30, 2007:
Operating revenues	$	308,825		$	77,289		$	24,397		$	—		$	—		$	410,511
Direct costs, other than depreciation expense		177,304			47,410			13,509			—			—			238,223
Depreciation and amortization		21,305			4,056			2,048			3,275			—			30,684
Interest expense, net of amounts capitalized		(270	)		(225	)		(108	)		9,571			—			8,968
Net income (loss)		93,601			23,503			6,899			(75,867	)		—			48,136
Property and equipment, net		550,045			125,787			43,120			39,303			—			758,255
Total assets		1,032,513			232,103			85,894			85,741			212,999			1,649,250
Capital expenditures, excluding acquisitions		(40,833	)		(22,218	)		(6,913	)		(2,456	)		—			(72,420	)

	Well Servicing			Pressure Pumping			Fishing and Rental			Corporate/ Other			Eliminations			Consolidated
	(in thousands)
As of and for the six months ended June 30, 2008:
Operating revenues	$	730,526		$	173,804		$	55,761		$	—		$	(1,689	)	$	958,402
Direct costs, other than depreciation expense		454,437			116,616			34,128			—			(1,052	)		604,129
Depreciation and amortization		61,495			9,573			5,154			6,025			—			82,247
Interest expense, net of amounts capitalized		(851	)		(725	)		(211	)		21,658			248			20,119
Net income (loss)		166,690			43,221			12,307			(143,103	)		(619	)		78,496
Property and equipment, net		726,966			133,451			54,030			32,458			—			946,905
Total assets		1,670,235			285,195			111,096			1,558,870			(1,687,635	)		1,937,761
Capital expenditures, excluding acquisitions		(54,453	)		(8,496	)		(5,902	)		(2,520	)		—			(71,371	)
	Well Servicing			Pressure Pumping			Fishing and Rental			Corporate/ Other			Eliminations			Consolidated
	(in thousands)
As of and for the six months ended June 30, 2007:
Operating revenues	$	619,985		$	151,366		$	48,079		$	—		$	—		$	819,430
Direct costs, other than depreciation expense		352,832			93,943			26,960			—			—			473,735
Depreciation and amortization		41,072			7,992			4,394			6,840			—			60,298
Interest expense, net of amounts capitalized		(435	)		(369	)		(179	)		19,300			—			18,317
Net income (loss)		191,636			44,521			12,332			(148,162	)		—			100,327
Property and equipment, net		550,045			125,787			43,120			39,303			—			758,255
Total assets		1,032,513			232,103			85,894			85,741			212,999			1,649,250
Capital expenditures, excluding acquisitions		(67,674	)		(35,794	)		(10,919	)		(4,458	)		—			(118,845	)

	Argentina		Mexico		Canada		Total

As of and for the three months ended June 30, 2008:
Operating revenues	$	29,740	$	9,760		1,613	$	41,113
Total assets		90,151		47,001		15,856		153,008
As of and for the three months ended June 30, 2007:
Operating revenues	$	19,517	$	62	$	—	$	19,579
Total assets		75,139		11,748		—		86,887
	Argentina		Mexico		Canada		Total
As of and for the six months ended June 30, 2008:
Operating revenues	$	56,606	$	15,461	$	5,503	$	77,570
Total assets		90,151		47,001		15,856		153,008
As of and for the six months ended June 30, 2007:
Operating revenues	$	39,944	$	62	$	—	$	40,006
Total assets		75,139		11,748		—		86,887

16. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATING BALANCE SHEETS

			June 30, 2008

			Parent Company		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Consolidated
			(in thousands)
			(unaudited)
Assets:
	Current assets		$	4	$	428,427	$	85,578		$	630		$	514,639
	Property and equipment, net			—		916,180		30,725			—			946,905
	Goodwill			—		388,754		6,459			—			395,213
	Deferred financing costs, net			11,436		—		—			—			11,436
	Intercompany notes and accounts receivable and investment in subsidiaries			1,796,784		305,742		1,815			(2,104,341	)		—
	Other assets			11,765		52,773		5,030			—			69,568

TOTAL ASSETS			$	1,819,989	$	2,091,876	$	129,607		$	(2,103,711	)	$	1,937,761

Liabilities and stockholders' equity:
	Current liabilities		$	31,659	$	202,430	$	27,729		$	(567	)	$	261,251
	Capital lease obligations, less current portion			—		13,674		166			—			13,840
	Notes payable—related parties,
		less current portion		—		20,500		—			—			20,500
	Long-term debt			525,000		—		—			—			525,000
	Intercompany notes and accounts payable			213,523		1,550,314		64,922			(1,828,759	)		—
	Deferred tax liabilities			158,130		—		2,656			—			160,786
	Other long-term liabilities			—		64,711		(4	)		—			64,707
	Stockholders' equity			891,677		240,247		34,138			(274,385	)		891,677

TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY			$	1,819,989	$	2,091,876	$	129,607		$	(2,103,711	)	$	1,937,761

Key Energy Services, Inc. and Subsidiaries

March 31, 2008

Parent Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries

Eliminations

Consolidated

(in thousands)

(unaudited)

Assets:

Current assets

$
—

$
386,908

$
73,882

$
—

$
460,790

Net property and equipment

—

879,261

29,557

—

908,818

Goodwill

—

372,594

5,999

—

378,593

Deferred financing costs, net

11,925

—

—

—

11,925

Intercompany receivables and investments in subsidiaries

1,605,437

218,954

541

(1,824,932
)
—

Other assets

10,617

50,781

5,282

—

66,680

TOTAL ASSETS

$
1,627,979

$
1,908,498

$
115,261

$
(1,824,932
)
$
1,826,806

Liabilities and equity:

Current liabilities

18,867

190,111

24,281

—

233,259

Long-term debt

475,000

—

—

—

475,000

Capital lease obligations

—

14,982

123

—

15,105

Long-term notes payable - related party

—

20,500

—

—

20,500

Intercompany payables

113,156

1,271,699

29,013

(1,413,868
)
—

Deferred tax liabilities

159,909

(1,807
)
1,807

—

159,909

Other long-term liabilities

—

61,779

207

—

61,986

Stockholders’ equity

861,047

351,234

59,830

(411,064
)
861,047

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

$
1,627,979

$
1,908,498

$
115,261

$
(1,824,932
)
$
1,826,806

December 31, 2007

Parent Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries

Eliminations

Consolidated

(in thousands)

Assets:

Current assets

$
39,501

$
378,865

$
69,499

$
—

$
487,865

Net property and equipment

—

880,907

30,301

—

911,208

Goodwill

—

373,283

5,267

—

378,550

Deferred financing costs, net

12,117

—

—

—

12,117

Intercompany receivables and investments in subsidiaries

1,557,993

175,461

—

(1,733,454
)
—

Other assets

11,217

52,074

6,046

—

69,337

TOTAL ASSETS

$
1,620,828

$
1,860,590

$
111,113

$
(1,733,454
)
$
1,859,077

Liabilities and equity:

Current liabilities

17,278

192,222

25,297

—

234,797

Long-term debt

475,000

—

—

—

475,000

Capital lease obligations

—

15,998

116

—

16,114

Long-term notes payable - related party

—

20,500

—

—

20,500

Intercompany payables

78,660

1,489,377

24,408

(1,592,445
)
—

Deferred tax liabilities

157,759

(79
)
2,388

—

160,068

Other long-term liabilities

3,133

60,216

251

—

63,600

Stockholders’ equity

888,998

82,356

58,653

(141,009
)
888,998

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

$
1,620,828

$
1,860,590

$
111,113

$
(1,733,454
)
$
1,859,077

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

1716. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

			December 31, 2007
			Parent Company		Guarantor Subsidiaries			Non-Guarantor Subsidiaries		Eliminations			Consolidated
			(in thousands)
Assets:
	Current assets		$	39,501	$	378,865		$	69,499	$	—		$	487,865
	Property and equipment, net			—		880,907			30,301		—			911,208
	Goodwill			—		373,283			5,267		—			378,550
	Deferred financing costs, net			12,117		—			—		—			12,117
	Intercompany notes and accounts receivable
		and investment in subsidiaries		1,557,993		175,461			—		(1,733,454	)		—
	Other assets			11,217		52,074			6,046		—			69,337

TOTAL ASSETS			$	1,620,828	$	1,860,590		$	111,113	$	(1,733,454	)	$	1,859,077

Liabilities and stockholders' equity:												��
	Current liabilities		$	17,278	$	192,222		$	25,297	$	—		$	234,797
	Capital lease obligations, less current portion			—		15,998			116		—			16,114
	Notes payable—related parties,
		less current portion		—		20,500			—		—			20,500
	Long-term debt			475,000		—			—		—			475,000
	Intercompany notes and accounts payable			78,660		1,489,377			24,408		(1,592,445	)		—
	Deferred tax liability			157,759		(79	)		2,388		—			160,068
	Other long-term liabilities and minority interest			3,133		60,216			251		—			63,600
	Stockholders' equity			888,998		82,356			58,653		(141,009	)		888,998

TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY			$	1,620,828	$	1,860,590		$	111,113	$	(1,733,454	)	$	1,859,077

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

16. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF OPERATIONS

		Three Months Ended June 30, 2008

		Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
		(in thousands)
Revenues		$	—		$	465,542		$	41,114		$	(4,653	)	$	502,003
Costs and expenses:
	Direct expenses		—			297,612			28,209			(3,333	)		322,488
	Depreciation and amortization		—			40,404			1,867			—			42,271
	General and administrative		1,036			52,459			4,859			(105	)		58,249
	Interest expense, net of amounts capitalized		11,061			(981	)		(1	)		—			10,079
	Other, net		(1,063	)		(428	)		13			(853	)		(2,331	)

Total costs and expenses, net			11,034			389,066			34,947			(4,291	)		430,756

(Loss) income before income taxes			(11,034	)		76,476			6,167			(362	)		71,247
Income tax expense			(24,395	)		(1,490	)		(1,561	)		—			(27,446	)
Minority interest			—			—			211			—			211

NET (LOSS) INCOME		$	(35,429	)	$	74,986		$	4,817		$	(362	)	$	44,012

		Three Months Ended June 30, 2007
		Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
		(in thousands)
Revenues		$	—		$	390,949		$	19,664		$	(102	)	$	410,511
Costs and expenses:
	Direct expenses		—			220,252			18,112			(141	)		238,223
	Depreciation and amortization		—			29,549			1,135			—			30,684
	General and administrative		166			53,426			2,523			39			56,154
	Interest expense, net of amounts capitalized		9,651			(701	)		18			—			8,968
	Other, net		239			(2,660	)		432			—			(1,989	)

Total costs and expenses, net			10,056			299,866			22,220			(102	)		332,040

(Loss) income before income taxes			(10,056	)		91,083			(2,556	)		—			78,471
Income tax expense			(31,129	)		(17	)		811			—			(30,335	)

NET (LOSS) INCOME		$	(41,185	)	$	91,066		$	(1,745	)	$	—		$	48,136

Key Energy Services, Inc. and Subsidiaries

Three Months Ended March 31, 2008

Parent Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries

Eliminations

Consolidated

(in thousands)

(unaudited)

Revenues

$
—

$
422,621

$
36,457

$
(2,679
)
$
456,399

Costs and expenses:

Direct expenses

—

257,771

25,666

(1,796
)
281,641

Depreciation and amortization

—

38,051

1,925

—

39,976

General and administrative

185

62,874

4,782

(109
)
67,732

Interest expense, net of amounts capitalized

10,756

(1,007
)
43

248

10,040

Other, net

35

(664
)
1,497

(765
)
103

Total costs and expenses, net

10,976

357,025

33,913

(2,422
)
399,492

(Loss) income before income taxes

(10,976
)
65,596

2,544

(257
)
56,907

Income tax expense

(20,484
)
(561
)
(1,412
)
—

(22,457
)
Minority interest

—

—

34

—

34

NET (LOSS) INCOME

$
(31,460
)
$
65,035

$
1,166

$
(257
)
$
34,484

Three Months Ended March 31, 2007

Parent Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries

Eliminations

Consolidated

(in thousands)

(unaudited)

Revenues

$
—

$
388,492

$
20,427

$
—

$
408,919

Costs and expenses:

Direct expenses

—

219,302

16,211

—

235,513

Depreciation and amortization

—

28,315

1,299

—

29,614

General and administrative

235

50,601

1,228

—

52,064

Interest expense, net of amounts capitalized

9,732

(355
)
(29
)
—

9,348

Other, net

(549
)
(2,056
)
291

—

(2,314
)
Total costs and expenses, net

9,418

295,807

19,000

—

324,225

(Loss) income before income taxes

(9,418
)
92,685

1,427

—

84,694

Income tax expense

(32,069
)
—

(435
)
—

(32,504
)
NET (LOSS) INCOME

$
(41,487
)
$
92,685

$
992

$
—

$
52,190

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

1816. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

		Six Months Ended June 30, 2008
		Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
		(in thousands)
Revenues		$	—		$	888,163		$	77,571		$	(7,332	)	$	958,402
Costs and expenses:
	Direct expenses		—			555,383			53,875			(5,129	)		604,129
	Depreciation and amortization		—			78,455			3,792			—			82,247
	General and administrative		1,221			115,333			9,641			(214	)		125,981
	Interest expense, net of amounts capitalized		21,817			(1,988	)		42			248			20,119
	Other, net		(1,028	)		(1,092	)		1,510			(1,618	)		(2,228	)

Total costs and expenses, net			22,010			746,091			68,860			(6,713	)		830,248

(Loss) income before income taxes			(22,010	)		142,072			8,711			(619	)		128,154
Income tax expense			(44,879	)		(2,051	)		(2,973	)		—			(49,903	)
Minority interest			—			—			245			—			245

NET (LOSS) INCOME		$	(66,889	)	$	140,021		$	5,983		$	(619	)	$	78,496

		Six Months Ended June 30, 2007
		Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
		(in thousands)
Revenues		$	—		$	779,441		$	40,091		$	(102	)	$	819,430
Costs and expenses:
	Direct expenses		—			439,553			34,323			(141	)		473,735
	Depreciation and amortization		—			57,864			2,434			—			60,298
	General and administrative		401			104,026			3,751			39			108,217
	Interest expense, net of amounts capitalized		19,383			(1,055	)		(11	)		—			18,317
	Other, net		(310	)		(4,715	)		723			—			(4,302	)

Total costs and expenses, net			19,474			595,673			41,220			(102	)		656,265

(Loss) income before income taxes			(19,474	)		183,768			(1,129	)		—			163,165
Income tax expense			(63,198	)		(16	)		376			—			(62,838	)

NET (LOSS) INCOME		$	(82,672	)	$	183,752		$	(753	)	$	—		$	100,327

Key Energy Services, Inc. and Subsidiaries

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

16. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

CONDENSED CONSOLIDATING UNAUDITED STATEMENTS OF CASH FLOWS

		Six Months Ended June 30, 2008

		Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
		(in thousands)
Net cash (used in) provided by operating activities		$	(1,695	)	$	151,179		$	12,600		$	—		$	162,084
Cash flows from investing activities:
	Capital expenditures		—			(70,376	)		(995	)		—			(71,371	)
	Acquisitions, net of cash acquired		—			(61,619	)		—			—			(61,619	)
	Intercompany notes and accounts		(90,972	)		(134,266	)		(1,815	)		227,053			—
	Other investing activities, net		—			1,694			—			—			1,694

Net cash (used in) provided by investing activities			(90,972	)		(264,567	)		(2,810	)		227,053			(131,296	)

Cash flows from financing activities:
	Borrowings on revolving credit facility		85,000			—			—			—			85,000
	Repayments on revolving credit facility		(35,000	)		—			—			—			(35,000	)
	Repurchases of common stock		(95,879	)		—			—			—			(95,879	)
	Intercompany notes and accounts		131,193			92,786			3,074			(227,053	)		—
	Other financing activities, net		7,353			(5,936	)		—			—			1,417

Net cash provided by (used in) financing activities			92,667			86,850			3,074			(227,053	)		(44,462	)

Effect of changes in exchange rates on cash			—			—			630			—			630

Net (decrease) increase in cash			—			(26,538	)		13,494			—			(13,044	)

Cash and cash equivalents at beginning of period			—			46,358			12,145			—			58,503

Cash and cash equivalents at end of period		$	—		$	19,820		$	25,639		$	—		$	45,459

Key Energy Services, Inc. and Subsidiaries

Three Months Ended March 31, 2008

Parent Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries

Eliminations

Consolidated

(in thousands)

(unaudited)

Net cash (used in) provided by operating activities

$
(108
)
$
67,550

$
2,869

$
—

$
70,311

Net cash used in investing activities

(1,644
)
(97,347
)
—

68,625

(30,366
)
Net cash provided by (used in) financing activities

1,752

(2,967
)
1,605

(68,625
)
(68,235
)
Effect of exchange rates on cash

—

—

(342
)
—

(342
)
Net (decrease) increase in cash

—

(32,764
)
4,132

—

(28,632
)
Cash at beginning of period

—

46,358

12,145

—

58,503

Cash at end of period

$
—

$
13,594

$
16,277

$
—

$
29,871

Three Months Ended March 31, 2007

Parent Company

Guarantor
Subsidiaries

Non-Guarantor
Subsidiaries

Eliminations

Consolidated

(in thousands)

(unaudited)

Net cash provided by operating activities

$
—

$
82,562

$
4,288

$
—

$
86,850

Net cash provided by (used in) investing activities

3,649

(105,424
)
(2,479
)
(6,298
)
(110,552
)
Net cash (used in) provided by financing activities

(3,649
)
(9,889
)
3,649

6,298

(3,591
)
Effect of exchange rates on cash

—

—

(370
)
—

(370
)
Net (decrease) increase in cash

—

(32,751
)
5,088

—

(27,663
)
Cash at beginning of period

—

84,633

3,742

—

88,375

Cash at end of period

$
—

$
51,882

$
8,830

$
—

$
60,712

NOTES TO CONDENSED CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS (Continued)

16. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS (Continued)

Six Months Ended June 30, 2007

Parent
Company Guarantor
Subsidiaries Non-Guarantor
Subsidiaries Eliminations Consolidated

(in thousands)

Net cash provided by (used in) operating activities
$ — $ 151,808 $ (3,168 ) $ — $ 148,640
Cash flows from investing activities:

Capital expenditures
— (114,245 ) (4,600 ) — (118,845 )

Investment in available for sale securities
— (85,147 ) — — (85,147 )

Proceeds from sale of available for sale securities
— 31,900 — — 31,900

Other investing activities, net
3,649 (525 ) — (298 ) 2,826

Net cash provided by (used in) investing activities
3,649 (168,017 ) (4,600 ) (298 ) (169,266 )

Net cash (used in) provided by financing activities
(3,649 ) (12,655 ) 8,649 298 (7,357 )

Effect of changes in exchange rates on cash

—
—
(305
)
—
(305
)

Net (decrease) increase in cash

—
(28,864
)
576
—
(28,288
)

Cash and cash equivalents at beginning of period
— 84,633 3,742 — 88,375

Cash and cash equivalents at end of period
$ — $ 55,769 $ 4,318 $ — $ 60,087

17. SUBSEQUENT EVENTS

On ~~April 3,~~July 22, 2008, the Company acquired ~~Western Drilling, LLC (“Western”~~all of the United States based assets of Leader Energy Services Ltd. and related entities ("Leader"), a Canadian company, for ~~approximately $51.5~~total consideration of $34.6 million in ~~cash. Western owned 22 working well service rigs, three stacked well service rigs,~~cash, which is subject to a purchase price adjustment that has not yet been finalized. We borrowed approximately $35.0 million under our revolving credit facility in order to finance this acquisition. The acquired assets include nine coiled tubing units, seven nitrogen trucks, twelve pumping trucks, and ~~rental equipment used in the workover and rig relocation process.~~other ancillary equipment. We acquired these assets to increase our service footprint, specifically in the ~~California market,~~Marcellus and Bakken shale formations, and the acquisition will be included in the ~~Company’s Well Servicing~~Company's Pressure Pumping Services segment. The purchase price is subject to a working capital adjustment 45 days from the closing date. The acquisition was funded using $1.5 million of cash on hand and borrowings of $50.0 million under our Senior Secured Credit Facility. We have analyzed this transaction under the guidance provided by SFAS No. 141, ~~“Accounting~~"Accounting for Business ~~Combinations” (“~~Combinations" ("SFAS ~~141”~~141") and ~~have determined that~~based on our preliminary evaluation expect the transaction will be accounted for as ~~a business combination. At this time, we are unable to make a determination of the allocation of the purchase price to the assets acquired and the liabilities assumed.~~an asset purchase.

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

Overview

~~Overview~~

Key Energy Services, Inc. and its wholly owned subsidiaries (collectively, the ~~“Company,” “we,” “us,” “its,”~~"Company," "we," "us," "its," and ~~“our”~~"our") ~~provides~~provide a complete range of well services to major oil companies and independent oil and natural gas production companies, including rig-based well maintenance, workover, well completion, and recompletion services, oilfield transportation services, pressure pumping services, fishing and rental services, and ancillary oilfield services. We believe that we are the leading onshore, rig-based well servicing contractor in the United States. We operate in most major oil and natural gas producing regions of the United States as well as internationally in Argentina and Mexico. We also have a technology development company based in Canada.

The following discussion and analysis should be read in conjunction with the accompanying unaudited consolidated financial statements and related notes as of June 30, 2008 and for the three and six months ended June 30, 2008 and 2007, included elsewhere herein, and the audited consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2007.

We operate in three business segments:

Well Servicing

~~We provide~~Our Well Servicing segment provides a broad range of ~~well~~ services, including rig-based services, oilfield transportation services, cased-hole electric wireline services and ancillary oilfield services. Our well service rig fleet ~~is used to perform four major categories of rig services for our customers: (i)~~provides well maintenance, ~~(ii)~~ workover, ~~(iii)~~ completion, and ~~(iv)~~ plugging and abandonment ~~services.~~services to our customers. Certain of our larger well service rigs are suitable for and used in certain drilling applications, including horizontal drilling. Our oilfield transportation fleet provides vacuum truck services, fluid transportation services, ~~include: (i) vacuum truck services, (ii) fluid transportation services,~~ and ~~(iii)~~ disposal services for operators whose ~~oil or natural gas~~ wells produce saltwater or other fluids and ~~other fluids. In addition, we are~~is also a supplier of frac tanks, which are used for temporary storage of fluids used in conjunction with fluid hauling operations. We conduct our well servicing operations in virtually every major onshore oil and gas producing region of the continental United States, as well as internationally in Argentina and Mexico. In addition to our onshore operations, we also ~~provide cased-hole electric wireline services.~~operate a number of barge-based rigs that serve customers along the Gulf Coast that can conduct operations in shallow water.

Pressure Pumping

Our Pressure Pumping ~~Services~~

~~We provide~~segment provides a broad range of well stimulation and completion services, ~~also~~collectively known as ~~pressure~~"pressure pumping services." Our primary ~~services~~service offerings include well stimulation and cementing services. Well stimulation includes fracturing, nitrogen and acidizing services. These services (which may be used in completion and workover services) are used to enhance the production of oil and natural gas wells from formations ~~which~~that exhibit a restricted flow of oil and natural gas. In the fracturing process, we typically pump fluid and sized sand, or proppants, into a well at high pressure in order to fracture the formation and thereby increase the flow of oil and natural gas. With our cementing services, we pump cement into a well between the casing and the wellbore. We provide a full range of pressure pumping services in the Permian Basin ~~of Texas, the~~and Barnett Shale ~~of North~~in Texas, ~~the Mid-Continent region of Oklahoma and in~~ the San Juan ~~Basin. In addition, we~~Basin in Colorado and New Mexico and the Oswego, Mississippi and Anadarko Basins in Oklahoma, and provide cementing services in the Elk Hills and Kern River Basins of California.

Fishing and Rental ~~Services~~

We provide fishing and rental services in the Gulf Coast, ~~Mid-Continent and~~ Permian Basin, ~~regions of the United States, as well as in the~~Mid-Continent, Rocky Mountains and California. Fishing services involve recovering lost or stuck equipment in the wellbore using a ~~“fishing~~"fishing tool,”" which is a downhole tool designed to recover any such equipment lost in the wellbore. We also offer a full line of services and rental equipment designed for use both onshore and offshore for drilling and workover ~~services.~~services, and automated pipe handling solutions. Our rental tool inventory consists of tubulars, handling tools, pressure-controlled equipment, power swivels and foam air units.

The following discussion and analysis should be read in conjunction with the accompanying unaudited consolidated financial statements and related notes as of March 31, 2008 and for the three months ended March 31, 2008 and 2007, included elsewhere herein, and the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2007.

Performance Measures

In determining the overall health of the oilfield service industry, we believe that the Baker Hughes U.S. land drilling rig count is the best barometer of capital spending and activity levels, since this data is made publicly available on a weekly basis. Historically, our activity levels have correlated well with capital spending by oil and natural gas producers. When commodity prices are strong, capital spending by our customers tends to be high, as illustrated by the Baker Hughes U.S. land drilling rig count. As the following table indicates, the land drilling rig count has remained high over the past several quarters ~~as commodity~~and prices for both oil and natural gas have ~~continued to increase.~~

20remained strong.

		WTI Cushing Oil(1)		NYMEX Henry Hub Natural Gas(1)

2008:
	First Quarter	$	97.94	$	8.74	1,712
	Second Quarter	$	123.95	$	11.47	1,797
2007:
	First Quarter	$	58.08	$	7.18	1,651
	Second Quarter	$	64.97	$	7.66	1,680
	Third Quarter	$	75.46	$	6.24	1,717
	Fourth Quarter	$	90.75	$	7.39	1,733

WTI Cushing Oil (1)

NYMEX Henry
Hub Natural Gas (1)

Average Baker
Hughes Land
Drilling Rigs (2)

2008:

First Quarter

$
97.94

$
8.74

1,712

2007:

First Quarter

$
58.08

$
7.18

1,651

Second Quarter

$
64.97

$
7.66

1,680

Third Quarter

$
75.46

$
6.24

1,717

Fourth Quarter

$
90.75

$
7.39

1,733

(1)

Represents the average price for the periods presented. Source: ~~Bloomberg/Energy Information Administration~~

EIA / Bloomberg

(2)

~~(2)~~ Source:www.bakerhughes.com

Internally, we measure activity levels in our Well Servicing segment primarily through our rig and trucking hours. As capital spending by ~~oil and natural gas producers~~our customer base increases, demand for our services ~~also~~generally 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,~~our customer base, we generally provide fewer ~~rig and trucking~~ services, which results in lower hours worked. The number of rig and trucking hours, as well as pricing, may also be affected by increases in industry capacity. We publicly release our monthly rig and trucking hours. The

following table presents our quarterly rig and trucking hours from the first quarter of 2007 through the second quarter of 2008:



2008:
	First Quarter	659,462	585,040
	Second Quarter	701,286	603,632
2007:
	First Quarter	625,748	571,777
	Second Quarter	611,890	583,074
	Third Quarter	597,617	570,356
	Fourth Quarter	614,444	583,191

Total 2007		2,449,699	2,308,398

Acquisitions

Tri-Energy. On January 17, 2008, the Company, through a wholly owned subsidiary, purchased the fishing and rental assets of Tri-Energy for approximately $1.9 million in cash. These assets were integrated into our Fishing and Rental segment. We completed this acquisition in order to expand our fishing and rental service offerings in the Louisiana market. The purchase price was allocated to the tangible and intangible assets acquired and the purchase of the Tri-Energy assets did not result in the establishment of goodwill.

Western. On April 3, 2008, the Company, through a wholly-owned subsidiary, purchased all of the outstanding equity interests of Western, a privately owned company based in California that operated 22 working well service rigs, three stacked well service rigs, and equipment used in the workover and rig relocation process for approximately $51.6 million. The Western acquisition was completed to increase the Company's service footprint in the California market and the assets and results of operations of Western have been incorporated into our Well Servicing segment.

Hydra-Walk. On May 30, 2008, we completed the acquisition of Hydra-Walk for approximately $10.3 million in cash with a performance earn-out potential of up to $2.0 million over the next two years if certain performance measures are met. Hydra-Walk provides pipe handling solutions for the oil and gas industry and operated over 80 automated pipe handling units in Oklahoma, Texas and Wyoming. The assets and results of operations for Hydra-Walk are now incorporated into our Fishing and Rental segment.

Market Conditions—Quarter Ended June 30, 2008

The Baker-Hughes land rig count averaged 1,797 during the second quarter of 2008, which was an increase of approximately 7.0% over the same period in 2007 and an increase of approximately 5.0% from the first quarter of 2008.

Rig Hours

Trucking Hours

2008:

First Quarter

659,462

585,040

2007:

First Quarter

625,748

571,777

Second Quarter

611,890

583,074

Third Quarter

597,617

570,356

Fourth Quarter

614,444

583,191

Total 2007

2,449,699

2,308,398

~~Market Conditions – Quarter Ended March 31, 2008~~

~~The Baker Hughes land drilling rig count averaged 1,712 during~~ We believe that the ~~first quarter of 2008, an increase of approximately 3.7% from the average of 1,651 in the first quarter of 2007. The~~ higher ~~drilling~~ rig count is ~~indicative~~a clear indicator of the strength of the U.S. marketplace, ~~which~~and this belief is ~~directly associated with~~reinforced by the ~~strength~~robustness of oil and natural gas prices. As of June 30, 2008, average prices for West Texas Intermediate crude oil have increased approximately 36.6% and average prices for natural gas at the Henry Hub have climbed 55.2% since the end of 2007. Overall industry demand for the ~~types of~~ services that we provide ~~has~~ remained ~~high.~~

~~Including~~high throughout the ~~effect~~course of ~~acquisitions made during~~ the third and fourth quarters of 2007, activity levels in the first quarter of 2008 (as measured by our rig and truck hours) were higher compared to the same period in 2007. Acquisitions made during the third and fourth quarters of 2007 contributed approximately 72,000 rig hours and 10,500 trucking hours during the firstsecond quarter of 2008. ~~Additionally, our Mexico operations contributed approximately 6,000 rig hours during~~

Including the first quarter of 2008, as compared to zero in the same period of 2007. Absent the increases in activity due to acquisitions and international expansion, our rig hours were down in the first quarter of 2008 as compared to the same period in 2007 and our trucking hours were essentially flat. We anticipated these changes in activity levels because of the increased supply of well service rigs and trucking assets in the market. However, the strategic acquisitions made during the third and fourth quarters of 2007 more than offset the decline in our rig hours. In response to lower utilization of our assets, we began reducing pricing for some of our customers in certain markets during late 2007. We believe these reductions will lead to increased utilization of our equipment and recapture of market share.

~~In addition, we experienced an unexpected decline in activity in~~ our Southeastern division (which principally covers Louisiana), and particularly in the inland barge rig market where we are the largest supplier. We believe that that the decrease was due primarily to customers delaying projects this year in light of poor weather conditions that had occurred in prior first quarters and that resulted in them suffering high incidences of standby charges.

~~Market Outlook for the Remainder of 2008~~

We believe that our business remains strong and that our activity levels will improve for the balance of 2008. We believe that the slowdown in the Louisiana barge rig market in our Southeastern division has reversed, and that utilization rates will be higher for the remainder of the year than were experienced in the first quarter. The onshore segment in this region has improved from the fourth quarter as well, and our backlog is building.

Commodity prices are still at record levels and demand for well servicing remains strong. As of March 31, 2008, crude oil prices were in excess of $105 per barrel and natural gas prices exceeded $10 per MMbtu. We believe that the current level of high oil and natural gas prices should result in our customers increasing their capital spending budgets in 2008, which we believe will drive demand for our services higher. We are also encouraged by the announcements by some of our customers stating their plans to increase their exploration and production budgets over 2007 levels.

~~Our 2008 activity levels and financial performance are also expected to increase as a result~~effects of the acquisitions we made during the third and fourth quarters of 2007 and the second quarter of 2008, our activity levels, as measured by our rig and truck hours, have increased compared to the same period in 2007; our rig hours increased approximately 14.6% during the second quarter of 2008 compared to the same period in 2007 and our trucking hours increased approximately 3.5% during the same period. Acquisitions we made contributed approximately 97,000 rig hours and

8,000 trucking hours during the second quarter of 2008. Additionally, our Mexico operations contributed approximately 11,250 rig hours during the second quarter of 2008, compared to zero during the second quarter of 2007. Excluding the increases in rig and truck hours associated with our acquisitions and expansion in Mexico, our rig hours for the second quarter of 2008 were down slightly from their levels during the second quarter of 2007 and our trucking hours increased slightly.

The decline in our legacy asset utilization during the second quarter of 2008 compared to the second quarter of 2007 was partially due to a late spring in the Rocky Mountain region of the U.S., which hurt our activity levels, and to the full impact of the additional capacity that continues to enter the domestic marketplace. We anticipated a reduction in the utilization of our assets in our legacy well servicing operations because of the increased supply of well servicing assets entering the marketplace and aggressive pricing on the part of our competition in an attempt to capture market share, to which in certain locations we defended our market share with lower pricing.

Cost increases reduced our margins during the second quarter, primarily driven by fuel and labor cost increases. With the overall increase in our activity, we are now using more fuel than ever before, and the price of fuel—which we estimate has risen approximately 54% since the end of the second quarter of 2007—has had a distinct negative impact on our margins. In addition to increases in fuel costs, margins were impacted by increased labor costs. Because of the high demand for a quality workforce, our workers are continuously targeted by our competition. In order to retain them, we have implemented wage increases and paid bonuses. This, combined with the addition of crews to support the overall increase in our operations in certain of our principal markets, has led to a sharp increase in the cost of direct labor during the second quarter of 2008.

Our international operations continued to perform well during the second quarter of 2008, contributing approximately $41.1 million of revenue during the quarter, which was approximately 8.2% of our consolidated revenues. Our Argentina operations contributed approximately $29.7 million in revenues for the three months ended June 30, 2008, but also experienced a 42-day labor strike that hurt its performance. Operations in Mexico ~~operations. The Company’s recent Kings Tool~~continued to expand during the second quarter of 2008; during the second quarter we operated six rigs in Mexico, along with twelve KeyView® units. Subsequent to the end of the second quarter we delivered another three rigs, and ~~Western Drilling acquisitions~~all nine are now working.

In addition, we continue to experience softness in ~~California~~the south Louisiana market, both in the inland barge rig and land-based rig markets. We feel that some of the softness in this market is based on the focus of activity in Louisiana shifting from the coastal regions north into the shale formations of the North Louisiana Basin. We are ~~performing well~~continuing to aggressively deploy our assets in the southern Louisiana market and ~~have been fully integrated into~~anticipate that our ~~operations.~~operations in southern Louisiana should strengthen over the remainder of the year.

Market Outlook for the Remainder of 2008

We believe that ~~improvement in the Southeastern division, specifically the inland barge market, will continue. In addition, we anticipate~~our business remains strong and that our ~~Mexico operations~~activity levels will continue to ~~expand during~~improve for the remainder of 2008. We ~~have five rigs working in Mexico as~~believe that our overall utilization rates will increase during the second half of the ~~end~~year, and that the margin contraction that we have experienced during the first half of ~~April~~ 2008 has ended and will reverse during the second half of 2008. It is our belief that most of the additional capacity entering the marketplace is in place and that the supply and demand equation for equipment and services will be more balanced for the remainder of the year.

Commodity prices continue to be robust and the sixth is expected to start working by the end of May. The Company anticipates that it will have three additional rig packages in Mexico by the third quarter of 2008 and up to two more units by the end of 2008. Additionally, we have secured pricing increasesdemand for our ~~operations~~services remains strong. As of July 31, 2008, prices for West Texas Intermediate crude oil were in ~~Argentina~~excess of $133 per barrel and ~~anticipate margins~~natural gas prices at the Henry Hub topped $9 per MMBtu. We believe that if commodity prices remain at or near their current levels or increase, our customers will continue to expand their capital spending, which we believe will drive the prices for ~~those operations~~our services higher.

Our activity levels and financial performance are also expected to continue to improve over the remainder of 2008 as we fully integrate the acquisitions we have made and expand our presence in ~~2008.~~international markets. The assets we acquired from Western in April 2008 and Hydra-Walk in June 2008 are performing well and we expect that they will continue to do so in the future. Additionally, we acquired the U.S. based assets of Leader in July 2008, and these assets are already generating margins for us and helping us expand our service offerings in the Marcellus and Bakken shale plays, which we believe will provide us an excellent growth opportunity over the remainder of 2008 and for the near future.

~~During~~Over the ~~first quarter,~~last several quarters, we ~~deployed~~have been implementing a strategy to increase our market share in the shale plays, emphasizing our offerings in the gas ~~regions. We~~regions of the continental U.S. Additionally, we have ~~significantly increased~~begun shifting our ~~presence~~product offering mix away from the traditional oil-dominated services to a more balanced portfolio, including the expansion of services such as coiled tubing, cased-hole electric wireline services, pressure pumping, pipe handling, and drill string rental. Our capital expenditure program includes the delivery of a significant amount of this equipment in the ~~Barnett Shale, with a strong presence across most~~third and fourth quarters of ~~our service offerings, and, we~~2008. We believe that ~~we are a leading provider in each~~this strategy will position us well to increase our margins and asset utilization for the remainder of the ~~Fayette, Bakken~~year.

A continuing challenge for us for the balance of 2008 will be fuel costs. If gasoline and ~~Marcellus Shale. We expect these markets~~diesel prices continue to ~~provide significant prospects~~rise, it will continue to have a negative impact on our ability to maintain and improve margins. Another challenge to our ability to generate margins will be the cost of retaining and replacing labor. The labor market for ~~growth. Other growth opportunities for 2008 include the creation of a coiled tubing group that will consist of~~ our ~~existing fleet of coiled tubing units and six state-of-the-art coiled tubing units that are scheduled~~employees continues to be ~~delivered~~tight, and in order to retain our workers we have implemented wage increases and paid bonuses. If the labor market continues to be robust through the balance of 2008 or becomes even stronger, our direct labor costs will continue to escalate. During the late second quarter of 2008, we began implementing price increases in selected markets, and these increases should be fully in place by the end of the third quarter of 2008. ~~In addition, we intend to continue~~We believe that these increases will, at a minimum, offset the ~~expansion of~~increase in our ~~cased-hole electric wireline business. We currently anticipate that we will place an additional six cased-hole wireline trucks into service during 2008.~~fuel and labor costs.

Because the demand for our services is generally correlated to commodity prices and drilling activity, our activity levels could be negatively impacted in the event that commodity prices decline rapidly or unexpectedly. During the first quarter of 2008 ~~our business continued to face~~we experienced significant pressure from increased competition ~~due~~related to ~~additional capacity and~~ new market ~~entrants; however,~~entrants, but during the second quarter we ~~believe that industry capacity additions are beginning~~began to see these pressures moderate. A number of oilfield service companies, including us, have announced that capital spending will generally be lower in 2008 than 2007. This should reduce the rate of growth of new equipment entering the market.

Consolidated Results of Operations

22The following table shows our consolidated results of operations for the three and six months ended June 30, 2008 and 2007:

		Three Months Ended June 30,						Six Months Ended June 30,

		2008			2007			2008			2007
		(in thousands) (unaudited)
*REVENUES:*
	Well servicing	$	379,959		$	308,825		$	728,837		$	619,985
	Pressure pumping		91,952			77,289			173,804			151,366
	Fishing and rental		30,092			24,397			55,761			48,079

Total revenues			502,003			410,511			958,402			819,430

*COSTS AND EXPENSES:*
	Well servicing		241,634			177,304			453,385			352,832
	Pressure pumping		62,837			47,410			116,616			93,943
	Fishing and rental		18,017			13,509			34,128			26,960
	Depreciation and amortization		42,271			30,684			82,247			60,298
	General and administrative		58,249			56,154			125,981			108,217
	Interest expense, net of amounts capitalized		10,079			8,968			20,119			18,317
	Gain on sale of assets		(360	)		(703	)		(626	)		(453	)
	Interest income		(182	)		(1,798	)		(690	)		(3,737	)
	Other (income) expense, net		(1,789	)		512			(912	)		(112	)

Total costs and expenses, net			430,756			332,040			830,248			656,265

Income before income taxes and minority interest			71,247			78,471			128,154			163,165
Income tax expense			(27,446	)		(30,335	)		(49,903	)		(62,838	)
Minority interest			211			—			245			—

*NET INCOME*		$	44,012		$	48,136		$	78,496		$	100,327

Three Months Ended June 30, 2008 and 2007

~~Key Energy Services, Inc. and Subsidiaries~~

~~Condensed Consolidated Statements of Operations~~

~~(In thousands)~~

~~(Unaudited)~~

Three Months Ended March 31,

2008

2007

REVENUES:

Well servicing

$
348,878

$
311,160

Pressure pumping

81,852

74,077

Fishing and rental

25,669

23,682

Total revenues.

456,399

408,919

COSTS AND EXPENSES:

Well servicing

211,751

175,529

Pressure pumping

53,779

46,533

Fishing and rental

16,111

13,451

Depreciation and amortization

39,976

29,614

General and administrative

67,732

52,064

Interest expense, net of amounts capitalized

10,040

9,348

(Gain) loss on sale of assets

(266
)
250

Interest income

(508
)
(1,940
)
Other expense (income), net

877

(624
)

Total costs and expenses, net

399,492

324,225

Income before income taxes

56,907

84,694

Income tax expense

(22,457
)
(32,504
)
Minority interest

34

—

NET INCOME

$
34,484

$
52,190

For the three months ended ~~March 31,~~June 30, 2008, our net income was ~~$34.5~~$44.0 million, which represents ~~a 33.9%~~an 8.6% decrease from net income of $48.1 million for the three months ended ~~March 31,~~June 30, 2007. Our earnings per fully diluted share for the period was ~~$0.27~~$0.35 per share compared to ~~$0.39~~$0.36 per ~~fully diluted~~ share for the same period in 2007. The decline in earnings was primarily attributable to increased labor and fuel costs and higher depreciation and amortization expense, partially offset by increased revenues and lower income tax expense.

A detailed review of our operations, including a review of our segments, for the second quarter of 2008 compared to the same period in 2007 is provided below.

Revenues

Our revenue for the three months ended June 30, 2008 increased $91.5 million, or 22.3%, to $502.0 million from $410.5 million for the three months ended June 30, 2007. Changes in revenue for each of our reportable segments were (in millions):

		Change from Three Months Ended June 30, 2007

Well servicing segment		$	71.1
Pressure pumping segment			14.7
Fishing and rental segment			5.7

	Total change	$	91.5

Acquisitions made during the second half of 2007 and during the second quarter of 2008 contributed approximately $53.1 million to the increase in well servicing revenue over the second quarter of 2007. Other increases in well servicing revenue were attributable to the expansion of our cased-hole electric wireline business, whose revenues increased approximately $3.7 million for the second quarter of 2008 compared to the second quarter of 2007, and the expansion of our international operations in Mexico, whose revenues increased approximately $9.7 million during the second quarter of 2008 compared to the same period in 2007. Excluding these items, our well servicing revenue in the second quarter of 2008 increased approximately $4.6 million, or 1.5%, from the same period in 2007.

Revenues from our pressure pumping operations increased $14.7 million, or 19.0%, for the second quarter of 2008 compared to the same period in 2007. We expanded our pressure pumping operations during the third quarter of 2007 by adding frac crews in the Barnett Shale. As a result, the number of frac jobs we performed in the second quarter of 2008 increased compared to the second quarter of 2007, leading to higher revenues. This increase was offset by less cementing work during the second quarter of 2008 and pricing pressure due to increased competition.

Revenues for our fishing and rental operations increased $5.7 million, or 23.3%, for the second quarter of 2008 compared to the same period in 2007. The acquisition of Hydra-Walk in May 2008 contributed approximately $1.1 million in revenues during the second quarter. Excluding the Hydra-Walk acquisition, our fishing and rental revenue increased approximately $4.6 million, or 18.8%. The increase in fishing and rental segment revenue was driven by changes in our product offering mix between the two periods; during the second quarter of 2008 we performed more reverse unit work and more offshore fishing jobs, which have higher pricing than other types of jobs performed by this segment.

Direct Costs

Our consolidated direct costs ~~associated with~~increased $84.3 million, or 35.4%, to $322.5 million for the three months ended June 30, 2008 compared to $238.2 million for the three months ended June 30, 2007. Excluding depreciation, these costs were 64.2% of revenue during the second quarter of 2008, compared to 58.0% during the same period in 2007. The change in direct costs was the result of (in millions):

		Change from Three Months Ended June 30, 2007

Direct expenses of acquisitions		$	34.7
Employee compensation			15.9
Fuel			10.1
Supplies, equipment and maintenance			9.3
Pressure pumping supplies and equipment			9.2
Other direct expenses			5.1

	Total change	$	84.3

Direct expenses attributable to businesses acquired during the third and fourth quarters of 2007 and the second quarter of 2008 contributed approximately $34.7 million to the increase in direct expenses during the second quarter of 2008 compared to the same period in 2007. These direct expenses were comprised of employee compensation ($20.7 million), supplies, equipment, and maintenance ($8.0 million), self-insurance costs ($2.1 million), fuel ($2.0 million) and other direct expenses ($1.9 million).

Excluding employee compensation attributable to acquisitions, direct employee compensation, which includes salaries, cash bonuses, health insurance, 401(k) costs and payroll taxes, increased approximately $15.9 million during the second quarter of 2008 compared to the same period in 2007.

The labor market for our employees continues to be extremely tight, and our employees have consistently been targeted by our competition due to their high quality. As a result, we have increased wage rates for our employees and paid them bonuses in order to retain them, hired new crews to keep up with customer demand, and have incurred recruiting expenses to replace those employees who were lost to our competitors and other industries.

Our fuel costs increased $10.1 million, or 54.6%, during the second quarter of 2008 compared to the same period in 2007. Since the end of the second quarter of 2007, we estimate that our per-gallon price of fuel has increased approximately 54%. To a lesser extent, our fuel costs have also risen due to the increased amount of fuel used, as a result of the increase in our rig and truck hours.

Costs for supplies, consumable equipment, and repairs and maintenance increased approximately $9.3 million for the second quarter of 2008 compared to the same period in 2007. The increase in these costs is due to higher prices from our vendors and increased repairs and maintenance as a result of higher utilization of our assets.

Pressure pumping supplies and equipment, which consist primarily of frac sand, chemicals, and the related costs to transport those items, increased approximately $9.2 million, or 41.6%, during the second quarter of 2008 compared to the second quarter of 2007. Like fuel, the primary driver in the increase in these costs is the rise in commodity prices; to a lesser extent, we are also using more of these products during 2008 to support the expansion of our pressure pumping operations. Additionally, our freight vendors are passing along the increases in their fuel prices to us through fuel surcharges, thereby increasing our freight costs.

Depreciation and Amortization

Depreciation and amortization expense increased approximately $11.6 million during the second quarter of 2008 compared to the second quarter of 2007. Acquisitions made during the last 12 months contributed approximately $7.9 million of depreciation and amortization expense during the second quarter of 2008. The remainder of the increase can be attributed to our larger fixed asset base; since the end of the second quarter of 2007, we have cumulatively spent approximately $165.1 million on capital expenditures.

General and Administrative

General and administrative expenses increased $2.1 million, or 3.7%, to $58.2 million for the three months ended June 30, 2008, compared to $56.2 million for the three months ended June 30, 2007. General and administrative expense was 11.6% of revenue for the second quarter of 2008, compared to 13.7% of revenue for the same period in 2007. The change in general and administrative expense was the result of (in millions):

		Change from Three Months Ended June 30, 2007

General and administrative expenses of acquisitions		$	3.4
Employee compensation, other than equity-based			7.0
Equity-based compensation			2.0
Professional fees			(9.7	)
Other			(0.6	)

	Total change	$	2.1

General and administrative expenses associated with businesses that we acquired during the third and fourth quarters of 2007 and the second quarter of 2008 were approximately $3.4 million during the

second quarter of 2008. These costs were primarily comprised of employee compensation costs and travel expenses associated with the integration of these businesses into our operations.

Excluding acquisitions, general and administrative costs associated with non-equity employee compensation, which includes salaries, cash bonuses, health insurance, 401(k) fees and payroll taxes increased approximately $7.0 million for the three months ended June 30, 2008 compared to the three months ended June 30, 2007. The increase was the result of the expansion of our business development efforts (approximately $1.8 million), which included approximately $1.0 million resulting from the reassignment of certain operational employees previously classified as direct costs, and approximately $0.8 million resulting from the hiring of additional employees, plus increased incentive compensation based on a larger bonus pool and higher base wage rates ($3.2 million), the expansion of our international operations in Mexico and Argentina ($1.1 million), and other miscellaneous compensation related items ($0.9 million). Excluding the additional personnel hired to expand our business development group, corporate general and administrative headcount remained largely unchanged from the second quarter of 2007.

The increase in equity-based compensation was attributable to new equity awards granted to certain of our employees since the second quarter of 2007, as well as increased compensation associated with awards that are accounted for as liabilities whose value is calculated based on the price of our common stock, partially offset by awards that vested during the third and fourth quarters of 2007 that are not contributing to compensation expense during the second quarter of 2008.

Our professional fees declined approximately $9.7 million for the three months ended June 30, 2008 compared to the three months ended June 30, 2007. Since the completion of our delayed financial reporting process during 2007, our professional fees paid for legal, accounting and consulting services have declined significantly.

Interest Expense

Interest expense increased $1.1 million, or 12.4%, for the three months ended June 30, 2008, compared to the same period in 2007. The increase in interest expense is primarily attributable to increased debt levels and a higher weighted average interest rate on our outstanding debt.

Interest Income

Interest income declined approximately $1.6 million to $0.2 million for the second quarter of 2008 compared to $1.8 million for the second quarter of 2007. The decline in interest income is primarily attributable to the reduction in our cash and cash equivalents and short-term investments, which were used during the fourth quarter of 2007 to acquire Moncla Well Service, Inc. and related entities.

Other income and expense, net

Other income and expense, net increased approximately $2.3 million to other income, net of $1.8 million during the second quarter of 2008 compared to other expense, net of $0.5 million in the second quarter of 2007. The increase in other income, net is primarily attributable to our portion of the earnings of our equity-method investment in IROC and foreign currency transaction gains from our operations in Canada, Mexico and Argentina.

Income Tax Expense

Our income tax expense decreased $2.9 million, or 9.5%, to $27.4 million for the second quarter of 2008 from $30.3 million for the second quarter of 2007. The decrease in income tax expense during the second quarter of 2008 is primarily attributable to lower taxable income for the period. Our effective tax rates were 38.5% and 38.7% for the three months ended June 30, 2008 and 2007, respectively.

Six Months Ended June 30, 2008 and 2007

For the six months ended June 30, 2008, our net income was $78.5 million, which represents a 21.8% decrease from the six months ended June 30, 2007. Our earnings per fully diluted share for the period was $0.61 per share compared to $0.75 per share for the same period in 2007. The decline in earnings was primarily attributable to increased labor and fuel costs, increased depreciation and amortization expense, and higher general and administrative costs, partially offset by higher revenues.

A detailed review of our operations, including a review of our segments, for the ~~quarter~~first half of 2008 compared to the same period in 2007 is provided below.

Revenues

~~Revenues~~

Our revenue for the ~~three~~six months ended ~~March 31,~~June 30, 2008 increased ~~$47.5~~$139.0 million, or ~~11.6%~~17.0%, to ~~$456.4~~$958.4 million from ~~$408.9~~$819.4 million for the ~~three~~six months ended ~~March 31,~~June 30, 2007. Changes in revenue for each of our reportable segments were (in millions):

		Change from Six Months Ended June 30, 2007

Well servicing segment		$	108.9
Pressure pumping segment			22.4
Fishing and rental segment			7.7

	Total change	$	139.0

Change from Three
Months Ended March 31,
2007

Well servicing segment

$
37.7

Pressure pumping segment

7.8

Fishing and rental segment

2.0

Total change

$
47.5

Businesses acquired during the third and fourth quarters of 2007 and the second quarter of 2008 contributed approximately ~~$45.0~~$98.0 million to the increase in well servicing revenues ~~over~~during the ~~first quarter of 2007.~~six months ended June 30, 2008. Other increases in well servicing revenues were attributable to the expansion of our cased-hole electric wireline business, whose revenues increased approximately ~~$4.6~~

$8.3 million ~~for~~during the first ~~quarter~~half of 2008 compared to the ~~first quarter~~same period of 2007, and the expansion of our international operations in Mexico, which contributed ~~$5.7~~$15.4 million of revenue during the first ~~quarter~~two quarters of 2008. ~~Absent~~Excluding these items, well servicing revenue ~~decreased~~declined approximately ~~$17.6 million.~~$12.8 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007. This ~~decrease~~decline was ~~driven primarily~~caused by lower activity levels and ~~reduced~~ pricing inpressures during the first half of 2008 for our legacy domestic well servicing ~~operations as new competition and increased capacity entered the marketplace,~~businesses in many of our core markets, partially offset by higher ~~rates~~utilization and ~~increased rig utilization~~rate increases for our operations in Argentina.

Revenues from our pressure pumping operations increased ~~$7.8~~$22.4 million, or ~~10.5%~~14.8%, for the ~~first quarter of~~six months ended June 30, 2008 compared to the same period in 2007. During 2007, we expanded our pressure pumping operations in the Barnett Shale, and this segment saw a corresponding increase in the number of frac jobs performed for our customers. Offsetting the increase in frac revenue was a decline in the number of cement jobs performed by this segment ~~due mainly to~~and pricing pressures from increased ~~competition in the Permian Basin region and a reduction in our pricing as a result of increased competition from new market entrants.~~competition.

Revenues for our fishing and rental operations increased ~~$2.0~~$7.7 million, or ~~8.4%~~16.0%, for the first ~~quarter~~half of 2008 compared to the same period in 2007. ~~Poor~~The acquisition of Hydra-Walk during the second quarter of 2008 contributed approximately $1.1 million to the increase in fishing and rental revenues during the six months ended June 30, 2008. Excluding the Hydra-Walk acquisition, revenues increased approximately $6.6 million. The increase in fishing and rental revenue is due to the combination of poor weather in ~~January and February of 2007 hampered the operations of our Fishing and Rental segment during~~ the first quarter of 2007, which hampered the operations of this segment, and ~~this segment’s operations saw~~ a ~~significant increase~~change in ~~activity~~the product mix during the first ~~quarter~~half of 2008, ~~that corresponded to the overall increase in activity in the sector.~~which saw this segment perform more reverse unit and offshore fishing jobs, which have higher pricing than other types of work performed by this segment.

Direct Costs

~~Direct~~Consolidated direct costs increased ~~$46.1~~$130.4 million, or ~~19.6%~~27.5%, to ~~$281.6~~$604.1 million for the ~~three~~six months ended ~~March 31,~~June 30, 2008 compared to ~~$235.5~~$473.7 million for the ~~three~~six months ended ~~March 31,~~June 30, 2007. ~~Direct~~Excluding depreciation expense, direct costs ~~as a percentage~~were 63.0% of revenue ~~were 61.7%~~ during 2008, versus ~~57.6%~~57.8% during 2007. The change in direct costs was the result of (in millions):

		Change from Six Months Ended June 30, 2007

Direct expenses of acquisitions		$	64.9
Employee compensation			19.5
Fuel			16.9
Supplies, equipment and maintenance			10.7
Pressure pumping supplies and equipment			14.4
Other direct expenses			4.0

	Total change	$	130.4

Change from Three
Months Ended March 31,
2007

Employee compensation

$
8.4

Pressure pumping supplies and equipment

6.1

Well servicing supplies and equipment

5.9

Business acquisitions during 2007

26.3

Self-insurance costs

(1.9
)
Other

1.3

Total change

$
46.1

~~Exclusive of the effects of acquisitions made~~Direct expenses attributable to businesses acquired during the third and fourth quarters of 2007 and the second quarter of 2008 contributed approximately $64.9 million to the increase in direct expenses during the first half of 2008 compared to the same period in 2007. These direct expenses were comprised of employee compensation ($37.9 million), supplies, equipment, and maintenance ($16.4 million), self-insurance costs ($4.2 million), fuel ($3.2 million) and other direct expenses ($3.2 million).

Excluding acquisitions, direct employee compensation, which ~~include~~includes salaries, cash bonuses, health insurance, 401(k) ~~matching~~costs and ~~related expenses,~~payroll taxes, increased approximately ~~$8.4~~$19.5 million ~~primarily as a result of increased wage rates, higher incentive compensation and increased headcount.~~during the six months ended June 30, 2008 compared to the six months ended June 30, 2007. The labor market for our employees continues to be extremely tight, and ~~in order~~our employees have consistently been targeted by our competition due to ~~retain quality personnel,~~their high quality. As a result, we have increased wage rates ~~and bonuses from their levels in the first quarter of 2007.~~

~~Supply and equipment costs~~ for our ~~pressure pumping operations, which primarily include frac sand, chemicals,~~employees in order to retain them, hired new crews to keep up with customer demand, and ~~the transportation~~have had to incur recruiting costs ~~associated with obtaining~~to replace those ~~supplies,~~employees who were lost to our competitors and to other industries.

Our fuel costs increased ~~approximately $6.1~~$16.9 million, or ~~18.1%~~48.5%, during the first half of 2008 compared to the same period in 2007. Since the end of the second quarter of 2007, we estimate that our per-gallon price of fuel has increased approximately 54%. To a lesser extent, our fuel costs have also risen due to the increased amount of fuel used as a result of the increase in our rig and truck hours.

Costs for supplies, consumable equipment, and repairs and maintenance increased approximately $10.7 million for the first half of 2008, compared to the same period in 2007. The increase in these costs ~~was driven~~is due to higher prices from our vendors and increased repairs and maintenance as a result of higher utilization of our assets.

Pressure pumping supplies and equipment, which consist primarily byof frac sand, chemicals, and the related costs to transport those items, increased approximately $14.4 million, or 33.6%, during the six months ended June 30, 2008 compared to the six months ended June 30, 2007. Like fuel, the primary driver in the increase in these costs is the rise in commodity prices; we are also using more of these products during 2008 to support the expansion of our pressure pumping ~~fleet during 2007,~~operations.

Depreciation and ~~by increasing market prices for the purchase~~Amortization

Depreciation and transportation of supplies. During the fourth quarter of 2007, we began purchasing our own trucks to haul frac sand in order to reduce our reliance on third-party transportation services, and the cost savings associated with this partially offset the increase.

~~Supplies and equipment for our well servicing operations~~amortization expense increased approximately ~~$5.9~~$21.9 million ~~or 11.1%,~~ during the first ~~quarter~~six months of 2008, compared to the same period in 2007. ~~A major contributor to the increase was the cost of fuel, which increased approximately $4.8 million, or 39.0%.~~

Acquisitions made during the third and fourth quarters of ~~2007 also contributed to the increase in direct costs during the~~2007and first ~~quarter~~half of 2008 compared to the same period in 2007. Direct costs from acquired businesses included approximately $12.7 million of employee-compensation related costs, $9.1 million of repairs and maintenance and other equipment-related costs, and $4.5 million of other direct costs.

The Company’s self-insurance costs, which are primarily associated with workers’ compensation, vehicular liability coverage and insurance premiums, decreased during the first quarter of 2008 compared to the same period in 2007. We have

~~focused on improving safety performance, and over the last several years the number of reportable incidents has declined, leading to lower current period premiums and costs associated with incidents.~~

~~Depreciation and Amortization~~

Depreciation and amortization expense increased approximately $10.4 million during the first quarter of 2008 compared to the first quarter of 2007. Assets acquired through business combinations during the third and fourth quarters of 2007 contributed approximately ~~$6.1~~$14.0 million of depreciation and amortization expense during the ~~first quarter of~~six months ended June 30, 2008. The remainder of the increase can be

attributed to our larger fixed asset base; since the end of the ~~first~~second quarter of 2007, we have cumulatively spent approximately ~~$196.6~~$165.1 million on capital expenditures.

General and Administrative

General and administrative expenses increased ~~$15.7~~$17.8 million, or ~~30.1%~~16.4%, to ~~$67.7~~$126.0 million for the ~~three~~six months ended ~~March 31,~~June 30, 2008, compared to ~~$52.1~~$108.2 million for the ~~three~~six months ended ~~March 31,~~June 30, 2007. General and administrative expenses were 13.1% of revenue for the first half of 2008 and 13.2% of revenue for the first half of 2007. The change in general and administrative expense was the result of (in millions):

		Change from Six Months Ended June 30, 2007

General and administrative expenses of acquisitions		$	6.8
Employee compensation, other than equity-based			12.2
Equity-based compensation			3.4
Professional fees			(6.7	)
Other general and administrative expenses			2.1

	Total change	$	17.8

General and administrative expenses associated with businesses that we acquired during the third and fourth quarters of 2007 and the second quarter of 2008 were approximately $6.8 million during the first half of 2008. These costs were primarily comprised of employee compensation costs, communication costs, bad debt expense and travel expenses associated with the integration of these businesses into our operations.

Change from Three
Months Ended March 31,
2007

Employee compensation

$
6.6

Legal reserves and settlements

2.8

Bad debt

0.5

Acquisitions during 2007

3.3

Other

2.5

Total change

$
15.7

~~Employee~~Excluding acquired businesses, general and administrative costs associated with non-equity employee compensation, which ~~includes~~is comprised of salaries, cash bonuses, ~~equity-based compensation,~~ health insurance, 401(k) ~~matching~~fees and ~~other related costs,~~payroll taxes, increased ~~$6.6 million to $31.3~~approximately $12.2 million for the ~~three~~six months ended ~~March 31,~~June 30, 2008 compared to ~~$24.7 million for~~ the ~~three~~six months ended ~~March 31,~~June 30, 2007. ~~Increases~~The increase in ~~general and administrative employee~~non-equity based compensation ~~were driven primarily by~~was the result of the expansion of our business development efforts (approximately $3.4 million), which included approximately $1.9 million in costs attributable to the reassignment of certain operational employees previously classified as direct costs, ofand increased approximately ~~$1.9~~$1.5 million ~~and~~resulting from the hiring of additional employees, ~~of approximately $1.1 million,~~plus increased incentive compensation based on a larger bonus pool and higher base wage rates ($4.1 million), the expansion of our international operations ~~which contributed an~~in Mexico and Argentina ($1.8 million), payroll taxes related to these items (approximately $1.4 million), and other miscellaneous compensation related items ($1.5 million). Excluding the additional $1.4 million in general and administrative employee compensation. All other general and administrative employee compensation costs increased approximately $0.8 million during the first quarter of 2008. Absent the expansion ofpersonnel hired to expand our business development ~~operations,~~group, corporate general and administrative headcount remained largely unchanged from the first ~~quarter~~half of 2007. ~~Total equity-based employee compensation was $3.7 million for the quarter ended March 31, 2008, compared to $2.3 million for the first quarter of 2007. Increases~~

The increase in equity-based compensation ~~were driven primarily by~~was attributable to new equity ~~grants made~~awards granted to certain of our employees ~~during~~since the ~~third~~second quarter of ~~2007.~~

Reserves and settlements for legal matters increased approximately $2.8 million during the first quarter of 2008 compared to the same period in 2007. This increase was related to several matters and reflects management’s assessment of the probability and of and estimates of loss from the outcome of these matters.

Excluding bad debt expense related to our acquisitions, bad debt expense increased $0.5 million to $0.9 million during the first quarter of 2008, compared to $0.4 million during the same period in 2007. The2007, as well as an increase in ~~bad debt was primarily attributable to allowances recorded due to our assessment of~~ the ~~collectibility~~fair value of certain ~~receivables.~~

~~Business acquisitions completed~~awards classified as liabilities whose value is dependent on the price of our common stock. Partially offsetting these increases were awards that vested during the third and fourth quarters of 2007 ~~contributed approximately $3.3 million of general and administrative expenses~~that are not contributing to compensation expense during the first ~~quarter~~half of 2008. General and administrative expenses from acquired businesses during the three months ended March 31, 2008 consisted of approximately $1.6 million of employee compensation and related costs and $1.7 million of other general and administrative costs.

Our professional fees ~~were relatively flat between~~declined approximately $6.7 million for the ~~first quarter of~~six months ended June 30, 2008 compared to the ~~first quarter~~six months ended June 30, 2007. Since the completion of ~~2007. We anticipate these~~our delayed financial reporting process during 2007, our professional fees ~~to decline over the course of 2008 due to the timing of audit costs~~paid for legal, accounting and ~~an overall reduction in costs.~~consulting services have declined significantly.

Interest Expense

Interest expense increased ~~$0.7~~$1.8 million, or ~~7.4%~~9.8%, for the ~~three~~six months ended ~~March 31,~~June 30, 2008, compared to the same period in 2007. The increase in interest expense is primarily attributable to increased debt levels and a higher weighted average interest rate on our outstanding debt.

Interest Income

Interest income declined approximately ~~$1.4~~$3.0 million to ~~$0.5~~$0.7 million for the first ~~quarter~~two quarters of 2008 compared to ~~$1.9~~$3.7 million for the first ~~quarter~~two quarters of 2007. The decline in interest income is primarily attributable to the reduction in our cash and cash equivalents and short-term investments, as a result of cash payments during the fourth quarter of 2007 in connection with our acquisition of Moncla Well Service, Inc. and related entities.

Income Tax Expense

Our income tax expense decreased ~~$10.0~~$12.9 million, or ~~30.9%~~20.6%, to ~~$22.5~~$49.9 million for the first ~~quarter~~half of 2008 from ~~$32.5~~$62.8 million for the first ~~quarter~~half of ~~2007. The decrease in income tax expense during the first quarter of 2008 is~~2007, primarily ~~attributable~~due to lower taxable income. Our effective tax rates were ~~39.5%~~38.9% and ~~38.4%~~38.5% for the ~~three~~six months ended ~~March 31,~~June 30, 2008 and 2007, respectively. Our effective tax rate has increased because of the overall contraction of our ~~expansion into more international tax jurisdictions, while our~~margins. Our taxable income has decreased primarily due to margin contractions in certain of our core segments, partially offset by higher taxable income for our pressure pumping operations, and the acquisitions we made during the third and fourth quarters of ~~2007.~~2007 and the first half of 2008.

Results of Operations by Segment

Three Months Ended June 30, 2008 and 2007

The following table shows operating results for each of our ~~three~~ segments for the three month periods ended ~~March 31,~~June 30, 2008 and 2007, respectively:

Three Months Ended June 30,

2008 2007 Change

(in thousands, except percentages)

Well Servicing segment

Revenues
$ 379,959 $ 308,825 $ 71,134

Direct expenses, excluding depreciation
241,634 177,304 64,330

Direct costs as a percentage of revenue
63.6 % 57.4 % 6.2 %
Pressure Pumping segment

Revenues
$ 91,952 $ 77,289 $ 14,663

Direct expenses, excluding depreciation
62,837 47,410 15,427

Direct costs as a percentage of revenue
68.3 % 61.3 % 7.0 %
Fishing and Rental segment

Revenues
$ 30,092 $ 24,397 $ 5,695

Direct expenses, excluding depreciation
18,017 13,509 4,508

Direct costs as a percentage of revenue
59.9 % 55.4 % 4.5 %

Three Months Ended March 31,

2008

2007

Increase
(Decrease)

(in thousands, except for percentages)

Well Servicing segment

Revenues

$
348,878

$
311,160

$
37,718

Direct costs

211,751

175,529

36,222

Gross profit

137,127

135,631

1,496

Gross margin

39.3
%
43.6
%
-4.3
%

Pressure Pumping segment

Revenues

$
81,852

$
74,077

$
7,775

Direct costs

53,779

46,533

7,246

Gross profit

28,073

27,544

529

Gross margin

34.3
%
37.2
%
-2.9
%

Fishing and Rental segment

Revenues

$
25,669

$
23,682

$
1,987

Direct costs

16,111

13,451

2,660

Gross profit

9,558

10,231

(673
)
Gross margin

37.2
%
43.2
%
-6.0
%

Well Servicing Segment

Revenues for our Well Servicing segment increased ~~$37.7~~$71.1 million, or ~~12.1%~~23.0%, to ~~$348.9~~$380.0 million for the three months ended ~~March 31,~~June 30, 2008, compared to ~~$311.2~~$308.8 million for the three months ended ~~March 31,~~June 30, 2007. Businesses acquired during the third and fourth quarters of 2007 and the second quarter of 2008 contributed approximately ~~$45.0~~$53.1 million to the increase in our Well Servicing segment revenues for the ~~first~~second quarter of ~~2007.~~2008. Other increases in well servicing revenues were attributable to the expansion of our cased-hole electric wireline business, whose revenues increased approximately ~~$4.6~~$3.7 million for the ~~first~~second quarter of 2008 compared to the ~~first quarter of~~same period in 2007, and the expansion of our international operations in Mexico, which contributed ~~$5.7~~$9.7 million of revenue during the ~~first~~second quarter of 2008. ~~Absent~~Excluding these items, well servicing revenue ~~decreased~~increased approximately $17.6 million. This decrease was driven primarily by lower activity levels and reduced pricing in our domestic well servicing operations, resulting from new competition and increased capacity entered the marketplace, partially offset by higher rates and increased rig utilization for our operations in Argentina.$4.6 million, or 1.5%.

Direct costs for our Well Servicing segment were ~~$211.8~~$241.6 million during the three months ended ~~March 31,~~June 30, 2008, which represented an increase of ~~$36.2~~$64.3 million, or ~~20.6%~~36.3%, from the same period in 2007. Excluding depreciation, direct costs for the Well Servicing segment were 63.6% of revenue for the second quarter of 2008 and 57.4% of revenue for the same period in 2007. The increase in direct costs for our Well Servicing segment was attributable to (in millions):

Change from Three
Months Ended March 31,
2007

Employee compensation.

$
6.9

Business acquisitions during 2007

26.3

Self-insurance costs

(2.3
)
Equipment and supplies.

5.9

Other

(0.6
)
Total change

$
36.2

Change from
Three Months
Ended
June 30, 2007
Direct expenses of acquisitions
$ 34.3
Employee compensation
12.4
Fuel
6.9
Supplies, equipment and maintenance
6.7
Other direct expenses
4.0

Total change
$ 64.3
        Direct costs associated with the well servicing businesses we acquired during the second half of 2007 and during the second quarter of 2008 contributed approximately $34.3 million to the increase in direct costs compared to the second quarter of 2007. These costs were made up of employee compensation ($20.5 million), fuel ($2.0 million), self-insurance costs ($2.1 million), supplies, equipment and maintenance ($7.9 million) and other direct expenses ($1.8 million).
~~Employee~~        Excluding acquisitions, direct employee compensation ~~costs, which include salaries, bonuses, health insurance, 401(k) matching and related payroll taxes,~~for our Well Servicing segment increased approximately ~~$6.9~~$12.4 million ~~for~~during the ~~first~~second quarter of 2008 compared to the ~~same period in 2007, primarily as a result~~second quarter of ~~increased wage rates, higher incentive compensation and increased headcount.~~2007. The labor market for our employees continues to be extremely tight, and we have implemented wage rate increases in order to retain a quality ~~personnel,~~workforce and prevent our competitors from hiring away our workers. Additionally, we have added crews in several of our operating locations in order to support the increased ~~wage rates and bonuses from their levels~~utilization of our equipment in ~~the first quarter of 2007.~~those areas.

Businesses acquired during 2007 contributed approximately $26.3 million of direct costs during the first quarter of 2008. Direct costs from acquired businesses included approximately $12.7 million of employee compensation-related expenses, $9.1 million of repairs and maintenance and other equipment-related costs, and $4.5 million of other direct costs.
Self-insurance costs for our Well Servicing segment, which are primarily associated with workers’ compensation, vehicular liability coverage and insurance premiums, decreased approximately $2.3 million during the first quarter of 2008 compared to the first quarter of 2007. We have focused on improving safety performance, and over the last several years the number of reportable incidents has declined, leading to lower current period premiums and costs associated with incidents.
~~Equipment and supply~~Fuel costs for our Well Servicing segment increased approximately ~~$5.9~~$6.9 million, ~~during~~or 49.8%, for the ~~first~~quarter ended June 30, 2008 compared to the quarter ended June 30, 2007. The primary driver of this increase has been the rise in our per-gallon cost of fuel; since the end of the second quarter of 2007 these costs have increased approximately 54%. Also contributing to the increase is the fact that we are using more fuel to support the increased utilization in certain of our core well servicing markets.
        Supplies, equipment and maintenance costs increased approximately $6.7 million for the three months ended June 30, 2008, compared to the same period in 2007. The ~~majority~~primary drivers of ~~the~~this increase ~~in equipment and supply costs relates to the increased price of fuel. Fuel~~are higher costs for the chemicals we use in our well servicing operations ($2.1 million), increased ~~approximately $4.8 million, or 39.0%~~repairs and maintenance ($2.4 million) associated with the increased utilization of certain of our well servicing assets and higher prices from our vendors, increased costs for equipment rentals ($0.6 million), ~~from the first quarter of 2007.~~and other miscellaneous items ($1.6 million).
Pressure Pumping Segment

Revenues for our Pressure Pumping segment increased ~~$7.8~~$14.7 million, or ~~10.5%~~19.0%, to ~~$81.9~~$92.0 million for the quarter ended ~~March 31,~~June 30, 2008 compared to ~~$74.1~~$77.3 million for the three months ended ~~March 31,~~June 30, 2007. Increased revenue in our Pressure Pumping segment is primarily attributable to the addition of several frac crews to serve our customer base in the Barnett Shale region, partially offset by declines in cementing operations and pricing pressure due to increased competition.

Direct costs for our Pressure Pumping segment were ~~$53.8~~$62.8 million during the three months ended ~~March 31,~~June 30, 2008, which represented an increase of ~~$7.2~~$15.4 million, or ~~15.6%~~32.5%, from the same period in 2007. Excluding depreciation, direct costs for the Pressure Pumping segment were 68.3% of revenue for the

three months ended June 30, 2008 and 61.3% of revenue for the three months ended June 30, 2007. The increase in direct costs for our Pressure Pumping segment was attributable to (in millions):

Change from Three
Months Ended March 31,
2007

Employee compensation.

$
1.0

Equipment costs

1.3

Supply costs

4.8

Other

0.1

Total change

$
7.2

Change from
Three Months
Ended June 30,
Sand, chemicals and freight
$ 9.3
Fuel
2.7
Repairs and maintenance
1.6
Employee compensation
1.4
Other direct expenses
0.4

Total change
$ 15.4

27

~~Employee compensation~~Sand, chemicals and freight costs for our ~~pressure pumping operations~~Pressure Pumping segment increased approximately $1.0 million for the first quarter of 2008 compared to the same period in 2007. Increases in employee compensation were driven primarily by higher wage rates for our crews and the addition of several frac crews during 2007 to support our increased operations in the Barnett Shale.
~~Equipment and supply costs for our pressure pumping operations increased approximately $6.1~~$9.3 million during the ~~first~~second quarter of 2008 compared to the same period in 2007. The two major contributors to the increase in equipment and supply costs were the increased cost of fuel (approximately $1.7 million) and the increased cost of frac sand and chemicals ($2.8 million) and the related costs to transport those items ($2.3 million). The increase in these costs was driven ~~primarily~~ by higher usage and increased commodity prices, as well as the ~~expansion~~fact that in the second quarter of 2008, the Pressure Pumping segment began using coated sand, which is more expensive than normal sand. Our freight costs have also increased as a result of increased fuel costs, which increased the cost of shipping our ~~pressure pumping fleet during 2007, and by increasing market prices~~frac sand.
        Fuel costs for our Pressure Pumping segment increased approximately $2.7 million for the purchase and transportation of supplies. During the fourth quarter of 2007, we began purchasing our own trucks to haul frac sand in order to reduce our reliance on third-party transportation services, and the cost savings associated with this partially offset the increase.
~~Fishing and Rental Segment~~
~~Revenues for our fishing and rental operations increased $2.0 million, or 8.4%, for the first~~second quarter of 2008, compared to the same period in 2007. The increase in fuel costs was driven primarily by the rise in the per-gallon cost of gasoline and diesel; our unit costs on fuel have increased approximately 54% since the end of the second quarter of 2007. Also contributing to the increase in fuel costs were the higher activity levels of the Pressure Pumping segment during the second quarter of 2008.
        Repairs and maintenance increased approximately $1.6 million for the three months ended June 30, 2008 compared to the three months ended June 30, 2007. Our repairs and maintenance costs have increased due to the higher activity of the Pressure Pumping segment and higher prices from our vendors.
        Employee compensation costs increased approximately $1.4 million during the second quarter of 2008 compared to the same period in 2007. The increase in employee compensation was driven by higher headcount as we added several frac crews in order to support the expansion of our pressure pumping operations in the Barnett Shale and higher wage rates in order to retain quality employees.
Fishing and Rental Segment
        Revenues for our fishing and rental operations increased $5.7 million, or 23.3%, for the second quarter of 2008 compared to the same period in 2007. The acquisition of Hydra-Walk during the second quarter of 2008 contributed approximately $1.1 million to this increase. Excluding the acquisition, revenues for our fishing and rental segment increased approximately $4.6 million during the second quarter of 2008 compared to the same period in 2007. The increase in revenues was attributable to this segment having greater reverse unit revenues and offshore fishing jobs than in 2007, which have higher pricing than other types of jobs performed by this segment.
        Direct costs for our Fishing and Rental segment increased $4.5 million, or 33.4%, to $18.0 million for the second quarter of 2008 compared to $13.5 million for the second quarter of 2007. Excluding depreciation expense, direct costs for the Fishing and Rental segment were 59.9% of revenue during

the second quarter of 2008 and 55.4% of revenue during the same period in 2007. Increased direct costs for this segment are attributable to (in millions):

Change from
Three Months
Ended
June 30, 2007
Employee compensation
$ 2.1
Supplies, equipment and maintenance
1.3
Fuel
0.5
Direct costs of acquisitions
0.4
Other direct expenses
0.2

Total change
$ 4.5
        Employee compensation costs for our Fishing and Rental segment, which include salaries, bonuses, health insurance, 401(k) and related payroll taxes, increased approximately $2.1 million for the second quarter of 2008 compared to the same period in the prior year. The increase in employee compensation is primarily due to an increase in direct headcount of almost 26%, as this segment added fishing tool supervisors and reverse unit operators in order to support the increased activity in the segment.
        Supplies, equipment and maintenance costs for this segment increased approximately $1.3 million for the three months ended June 30, 2008 compared to the same period in 2007. Increases in repairs and maintenance were driven primarily by the increased activity levels of this segment and price increases from third parties that we use for repairs and maintenance. Also contributing to the increase are a larger number of subrentals, the costs of which are passed along to our customers through our billings.
        Fuel costs for our Fishing and Rental segment increased approximately $0.5 million during the second quarter of 2008 compared to the same period in 2007. Since the end of the second quarter of 2007, our per-gallon cost of gasoline and diesel has increased approximately 54%.
        Direct costs attributable to the operations of Hydra-Walk, which was acquired and integrated into the Fishing and Rental segment, were approximately $0.4 million for the second quarter of 2008. These costs were primarily related to employee compensation.

Six Months Ended June 30, 2008 and 2007
        The following table shows operating results for each of our segments for the six month periods ended June 30, 2008 and 2007, respectively:

Six Months Ended June 30,

2008 2007 Change

(in thousands, except percentages)

Well Servicing segment

Revenues
$ 728,837 $ 619,985 $ 108,852

Direct expenses, excluding depreciation
453,385 352,832 100,553

Direct costs as a percentage of revenue
62.2 % 56.9 % 5.3 %
Pressure Pumping segment

Revenues
$ 173,804 $ 151,366 $ 22,438

Direct expenses, excluding depreciation
116,616 93,943 22,673

Direct costs as a percentage of revenue
67.1 % 62.1 % 5.0 %
Fishing and Rental segment

Revenues
$ 55,761 $ 48,079 $ 7,682

Direct expenses, excluding depreciation
34,128 26,960 7,168

Direct costs as a percentage of revenue
61.2 % 56.1 % 5.1 %
Well Servicing Segment
        Revenues for our Well Servicing segment increased $108.9 million, or 17.6%, to $728.8 million for the six months ended June 30, 2008 compared to $620.0 million for the six months ended June 30, 2007. Businesses acquired during the third and fourth quarters of 2007 and the second quarter of 2008 contributed approximately $98.0 million to the increase in our Well Servicing segment revenues for the first half of 2008. Other increases in well servicing revenues were attributable to the expansion of our cased-hole electric wireline business, whose revenues increased approximately $8.3 million for the first half of 2008 compared to the same period in 2007, and the expansion of our international operations in Mexico, which contributed $15.4 million of revenue during the first half of 2008. Excluding these items, well servicing revenue decreased approximately $12.8 million. This decrease was driven primarily by lower activity levels and reduced pricing in certain of our domestic well servicing markets during the first quarter of 2008 resulting from new competition and increased capacity that entered the marketplace. These declines were partially offset by higher rates and increased rig utilization for our operations in Argentina.
        Direct costs for our Well Servicing segment were $453.4 million during the six months ended June 30, 2008, which represented an increase of $100.6 million, or 28.5%, from the same period in 2007. Excluding depreciation, direct costs for our Well Servicing segment were 62.2% of revenue for

the six months ended June 30, 2008 and 56.9% of revenue for the six months ended June 30, 2007. The increase in direct costs for our Well Servicing segment was attributable to (in millions):

Change from
Six Months
Ended
June 30, 2007
Direct expenses of acquisitions
$ 64.5
Employee compensation
14.5
Fuel
11.7
Supplies, equipment and maintenance
7.5
Other direct expenses
2.4

Total change
$ 100.6
        Direct expenses associated with the well servicing businesses we acquired during the second half of 2007 and the second quarter of 2008 contributed approximately $64.5 million to the overall increase in well servicing direct expenses during the first half of 2008 compared to the first half of 2007. These expenses were comprised of employee compensation ($37.7 million), supplies, equipment and maintenance ($16.2 million), fuel ($3.2 million), self-insurance costs ($4.2 million) and other direct expenses ($3.2 million).
        Excluding acquisitions, direct Well Servicing segment employee compensation increased approximately $14.5 million during the first half of 2008 compared to the same period in 2007. The labor market for our employees continues to be extremely tight, and we have implemented wage rate increases in order to retain a quality workforce and prevent our competitors from hiring away our workers.
        Fuel costs for the Well Servicing segment increased $11.7 million, or 44.3%, for the six months ended June 30, 2008 compared to the six months ended June 30, 2007. Our fuel usage has increased over the first half of 2007 in certain of our core well servicing markets, but the primary driver in the increase is the higher price of gasoline and diesel; since the end of the second quarter of 2007 our per-gallon price for fuel has increased approximately 54%.
        Expenses related to supplies, equipment and maintenance for our Well Servicing segment increased $7.5 million during the first half of 2008 compared to the same period in 2007. The increase in these costs is due to higher prices from our vendors and greater repairs and maintenance being performed on our well servicing equipment, as well as higher costs for the chemicals we use in our well servicing operations ($3.2 million) and higher freight costs ($1.5 million), as well as other miscellaneous items ($2.8 million).
Pressure Pumping Segment
        Revenues for our Pressure Pumping segment increased $22.4 million, or 14.8%, to $173.8 million for the six months ended June 30, 2008 compared to $151.4 million for the six months ended June 30, 2007. Increased revenue in our Pressure Pumping segment is primarily attributable to the addition of several frac crews to serve our customer base in the Barnett Shale region, partially offset by declines in cementing operations and pricing pressure due to increased competition.
        Direct costs for our Pressure Pumping segment were $116.6 million during the six months ended June 30, 2008, which represented an increase of $22.7 million, or 24.1%, from the same period in 2007. Excluding depreciation expense, direct costs for the Pressure Pumping segment were 67.1% of revenue

for the first half of 2008 compared to 62.1% for the first half of 2007. The increase in direct costs for our Pressure Pumping segment was attributable to (in millions):

Change from
Six Months
Ended
June 30, 2007
Sand, chemicals and freight
$ 14.3
Fuel
4.4
Employee compensation
2.3
Other direct expenses
1.7

Total change
$ 22.7
        Costs for frac sand, chemicals and freight increased approximately $14.3 million for the first half of 2008 compared to the first half of 2007. The increase in sand costs was attributable to higher commodity prices, the change to the use of coated sand, which is more expensive than normal sand, and increased volumes purchased to support the expansion of our pressure pumping operations in the Barnett Shale and other formations. Freight costs increased due to higher volumes of sand being transported and increased pricing from our freight vendors.
        Fuel costs for the Pressure Pumping segment increased approximately $4.4 million during the first half of 2008 compared to the first half of 2007. The increase in fuel costs is due directly to the increase in activity by this segment and the rise in the per-gallon cost of fuel, which has increased approximately 54% from the end of the second quarter of 2007.
        Employee compensation costs for the Pressure Pumping segment increased approximately $2.3 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007. The increase in employee compensation is attributable to the addition of several frac crews to serve our customer base in the Barnett Shale and other regions, as well as higher wage rates to our employees in order to retain a quality workforce.
Fishing and Rental Segment
        Revenues for our fishing and rental operations increased $7.7 million, or 16.0%, for the first half of 2008 compared to the same period in 2007. The acquisition of Hydra-Walk in the second quarter of 2008 contributed approximately $1.1 million to the increase in fishing and rental revenues during the first half of 2008 compared to the same period in 2007. Excluding the acquisition, fishing and rental revenues increased approximately $6.6 million. Poor weather in January and February of 2007 hampered the operations of our Fishing and Rental segment during the first quarter of 2007, and this ~~segment’s~~segment's operations saw a significant increase in activity during the first quarter of 2008 that corresponded to the overall increase in activity in the sector. Additionally, during the second quarter of 2008 the product mix for our Fishing and Rental segment changed, seeing them perform more reverse unit work and offshore fishing jobs, which have higher pricing than other types of jobs performed by this segment.

Direct costs for our Fishing and Rental segment increased ~~$2.7~~$7.2 million, or ~~19.8%~~26.6%, to ~~$16.1~~$34.1 million for the first ~~quarter~~half of 2008 compared to ~~$13.5~~$27.0 million for the first ~~quarter~~half of 2007. Excluding depreciation, direct costs were 61.2% of revenue for the six months ended June 30, 2008 and 56.1% of revenue for

the six months ended June 30, 2007. Increased direct costs for this segment are attributable to (in millions):

Change from Three Months
Ended March 31, 2007

Employee compensation

$
0.6

Equipment costs.

1.7

Other

0.4

Total change.

$
2.7

Change from
Six Months
Ended
June 30, 2007
Employee compensation
$ 2.7
Equipment and supplies
1.5
Repairs and maintenance
1.1
Fuel
0.9
Direct costs of acquisitions
0.4
Other direct expenses
0.6

Total change
$ 7.2

Employee compensation costs for ~~our fishing~~the Fishing and ~~rental operations~~Rental segment have increased approximately ~~$0.6~~$2.7 million ~~for~~over the ~~quarter~~first half of 2007. Increases in employee compensation are primarily attributable to an increase in headcount as the Fishing and Rental segment has added workers in order to support their increased activities, and higher wage rates and bonuses in order to retain quality personnel.
        Equipment and supply costs increased approximately $1.5 million during the six months ended ~~March 31,~~June 30, 2008 compared to the same period in 2007. The increase in ~~employee compensation was driven~~these costs is primarily ~~by increased headcount, which~~associated with subrentals, and these costs are passed along to our customers in our revenues.
        Repairs and maintenance costs for the Fishing and Rental segment increased approximately ~~5% in this segment during~~$1.1 million for the first ~~quarter~~half of 2008 compared to the ~~same period~~first half of 2007. The increase in ~~2007.~~repairs and maintenance is directly attributable to higher costs from our vendors for these services, as well as a higher level of repairs and maintenance to support the segment's expanded offshore operations.

~~Equipment~~Fuel costs for the Fishing and Rental segment increased approximately ~~$1.7~~$0.9 million for ~~our fishing and rental operations during~~ the ~~three~~six months ended ~~March 31,~~June 30, 2008 compared to the ~~three~~six months ended ~~March 31,~~June 30, 2007. ~~Contributing~~The increase in fuel costs is attributable to increased usage in order to support our operations, and an increase in per-gallon prices, which have risen approximately 54% since the end of the second quarter of 2007.
        The acquisition of Hydra-Walk in the second quarter of 2008 contributed approximately $0.4 million to the increase in ~~equipment~~the direct costs ~~are increased fuel expenses (approximately $0.4 million) associated with higher gas~~of the Fishing and ~~diesel prices, increases for supplies and small parts ($0.4 million) associated with the expansion~~Rental segment. These costs were comprised primarily of ~~this segment’s deepwater operations in southern Louisiana, and other third-party expenses ($0.7 million) incurred by this segment associated primarily with tool subrentals.~~employee compensation expenses.

Liquidity and Capital Resources
Historical Cash Flows

The following table summarizes our cash flows for the ~~three~~six months ended ~~March 31,~~June 30, 2008 and 2007:
28

Three Months Ended March 31,

2008

2007

Six Months Ended June 30,

(in thousands)

2008 2007

(in thousands)

Net cash provided by operating activities

$
70,311

$
86,850

$ 162,084 $ 148,640
Cash paid for capital expenditures

(30,375
)
(46,375
)
(71,371 ) (118,845 )
Cash paid for short-term investments.

—

(83,077
)
Proceeds received from sales of short-term investments

—

18,635

Cash paid for short-term investments
— (85,147 )
Proceeds from sale of short-term investments
268 31,900
Acquisitions, net of cash acquired
(61,619 ) —
Other investing activities, net

9

265

1,426 2,826
Repayments of long-term debt and capital leases

(3,006
)
(3,591
)
(5,936 ) (5,357 )
Borrowings under revolving credit facility
85,000 —
Payments under revolving credit facility
(35,000 ) (2,000 )
Cash paid to repurchase common stock

(65,376
)
—

(95,879 ) —
Other financing activities, net

147

—

7,353 —
Effect of changes in exchange rates on cash.

(342
)
(370
)
Effect of changes in exchange rates on cash
630 (305 )

Net decrease in cash and cash equivalents

$
(28,632
)
$
(27,663
)
$ (13,044 ) $ (28,288 )

Sources of Liquidity

Our sources of liquidity include our current cash and cash equivalents, availability under our Senior Secured Credit Facility, and internally generated cash flows from operations. During the fourth quarter of 2007, we refinanced our indebtedness. We issued $425.0 million of 8.375% Senior Notes (the ~~“Notes”~~"Notes") and used the proceeds from that issuance to retire our then-existing senior credit facility. The Notes have a coupon of 8.375%, do not require prepayments, and mature in 2014. We also entered into our current Senior Secured Credit Facility during the fourth quarter of 2007. The Senior Secured Credit Facility consists of a revolving credit facility, a letter of credit sub-facility and a swing line facility up to an aggregate principal amount of $400.0 million, all of which mature no later than 2012.
        During the second quarter of 2008, we borrowed approximately $85.0 million under the revolving credit facility to finance our acquisition of Western and for general corporate purposes. We subsequently paid down approximately $35.0 million on the balance of the revolving credit facility with cash generated by our operations. As of ~~March 31,~~June 30, 2008, ~~$50.0~~$100.0 million of borrowings were outstanding under the revolving credit facility and ~~$61.1~~$61.5 million of letters orof credit issued under the letter of credit sub-facility were outstanding, which reduces the total borrowing capacity under the Senior Secured Credit Facility. In July 2008 we borrowed $35.0 million under the revolving credit facility in order to finance our acquisition of the U.S. domiciled assets of Leader. As of ~~March~~July 31, 2008, we had ~~$288.9~~$61.3 million of letters of credit issued under the letter of credit sub-facility and $203.7 million of available borrowing capacity under the Senior Secured Credit Facility.

We believe that our liquidity position is strong. As of ~~March~~July 31, 2008, we had approximately ~~$522.2~~$605.4 million of total long-term debt and capital leases, including notes payable to affiliates, and we believe that this amount is acceptable given our recent financial performance and our belief that industry activity levels for the remainder of 2008 should remain stable. ~~On April 1, 2008, we borrowed an additional $50.0 million under our Senior Secured Credit Facility to complete our acquisition of Western on April 3, 2008.~~

Share Repurchase Plan

In October 2007, our Board of Directors authorized a share repurchase program of up to $300.0 million which is effective through March 31, 2009. From the inception of the program in November 2007 through ~~April 30,~~July 31, 2008, we have repurchased approximately ~~8.5~~10.1 million shares of our common stock through open market transactions for an aggregate price of approximately ~~$111.9~~$137.5 million. Share repurchases during the ~~first~~second quarter of 2008 were approximately ~~5.2~~1.8 million shares for an aggregate price of approximately ~~$65.3~~$27.0 million. Share repurchases during the six months ended June 30, 2008 were approximately 7.0 million shares for an aggregate price of approximately $92.3 million. Our repurchase program, as well as the amount and timing of future repurchases, is subject to market conditions, our financial condition, and our liquidity. Our Senior Secured Credit Facility permits us to make stock repurchases in excess of $200.0 million only if our consolidated debt to capitalization ratio (as defined) is below 50%; as of ~~March 31,~~June 30, 2008, that ratio was below 50%.
Future Cash Requirements

~~Cash Requirements~~
For the remainder of 2008, we anticipate our cash requirements to include working capital needs, capital expenditures, acquisitions and the repurchase of our common stock. We believe that our current cash and cash equivalents, our availability under our Senior Secured Credit Facility, and our internally generated cash flows from operations will be sufficient to finance the cash requirements of our current and near-term future operations, including the capital expenditures we have budgeted for the remainder of the year. We do not budget for acquisitions; however, we continuously evaluate opportunities that fit our specific acquisition profile. We anticipate financing any future acquisitions through a combination of our cash on hand, future cash flows from operations, and availability under our Senior Secured Credit Facility.

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 2007 Annual Report on Form 10-K. More detailed information concerning market risk can be found in Item 7A.
29

~~“Quantitative~~ "Quantitative and Qualitative Disclosures about Market ~~Risk”~~Risk" in our 2007 Annual Report on Form 10-K dated as of, and filed with the SEC on, February 29, 2008.
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 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~~SEC's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designated 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 the evaluation and the identification of the material weaknesses in internal control over financial reporting as disclosed in our Annual Report on Form 10-K for the year ended December 31, 2007 and discussed below, management concluded that, as of ~~March 31,~~June 30, 2008, the ~~Company’s~~Company's disclosure controls and procedures ~~were~~remained not effective.
Internal Control Over Financial Reporting
~~Because~~        In October 2006, we filed our 2003 Financial and Informational Report on Form 8-K/A that included an audited consolidated balance sheet that presented our financial condition as of ~~the material weaknesses identified in our evaluation of internal control over financial reporting for the year ended~~ December 31, ~~2007, we performed additional substantive procedures so that our condensed consolidated financial statements as of and for the quarter ended March 31, 2008, are presented~~2003 in accordance with ~~generally accepted accounting principles~~Generally Accepted Accounting Principles in the United States of America ~~(“GAAP”~~("GAAP").
We ~~believe that because we performed the substantial additional procedures referenced above, the~~did not present other consolidated ~~condensed~~ financial statements ~~for the periods included in this Quarterly Report are fairly presented in all material respects~~ in accordance with ~~GAAP.~~
~~Management is committed~~GAAP as we were unable to ~~achieving effective internal control over~~identify with sufficient certainty the period(s) in 2003 or before in which to record certain write-offs and write-downs that were identified in our restatement process. Investors should refer to the 2003 Financial and Information Report for a full description of our restatement and financial ~~reporting. Our remediation efforts are described in Item 9A in~~reporting process through the date of that report. In the third quarter of 2007, we filed our Annual Report on Form 10-K for the year ended December 31, 2006 (the "2006 Report"). Concurrently with that filing, we filed our Quarterly Reports on Form 10-Q for the years 2005 and 2006. In September 2007 we filed our Quarterly Reports on Form 10-Q for the first and second quarters of 2007, and, in November 2007, we filed our Quarterly Report on Form 10-Q for the third quarter of 2007. Our Annual Report on Form 10-K for the year ended December 31, 2007 (the "2007 Report") was filed timely in February 2008, and our Quarterly Report on Form 10-Q for the first quarter of 2008 was filed timely in May 2008.
        In our 2003 Financial and Informational Report, we described numerous material weaknesses in internal control over financial reporting that we identified during the restatement and financial reporting process. In our 2006 Report, we reported that nine of the material weaknesses that we had previously identified remained as of December 31, 2006, and in our 2007 Report, we reported that some of these material weaknesses had been remediated and that seven existed at December 31, 2007.
        The material weaknesses identified in our internal control environment over financial reporting that existed at December 31, 2007, and the status of our remediation efforts through June 30, 2008, are described below:
         Financial Close and Reporting.    In response to the material weaknesses in the financial close and reporting process disclosed in the 2006 Report, we instituted substantial changes to our internal control

structure in these areas during 2007. These changes included adding additional personnel, adding analytical procedures and reviews, refining the methodologies for the preparation of our financial statements, adding reconciliations of our accounts and reconciliations between our general ledger and subledger systems, as well as increasing the availability of evidence for those controls operating. However, as a result of our delayed reporting in 2007 and the devotion of resources to completing our required 2006 and 2007 filings, many of these improvements were not in place and evidenced as operating effectively until the financial close and reporting activities for the fourth quarter of 2007. Due to the timing of these improvements, sufficient instances of these controls in operation had not occurred for the controls to be assessed as effective at December 31, 2007. We have begun, but have not completed, our process of evaluating the operating effectiveness of these controls for 2008; we anticipate that this evaluation process will be largely completed in the fourth quarter of 2008. As a result, we cannot conclude that this material weakness had been remediated. Management believes that the remedial controls put in place in 2007, which continue in operation through the second quarter of 2008, will be sufficient to remediate the previously identified material weaknesses in the financial close and reporting process.
         Authorizations of Expenditures.    In our 2006 Report, we determined that at December 31, 2006 multiple control deficiencies existed regarding our ability to appropriately ensure and evidence that expenditures, covering substantially all aspects of spending, were approved by the appropriate level of management in accordance with our established policies and, as a result, we identified this as a material weakness. During 2007, changes were made that included the establishment of approval authorities and automated controls in our procurement system. Notwithstanding these changes, certain deficiencies remained at December 31, 2007. The remaining deficiencies resulting in a material weakness at December 31, 2007, were our inability to ensure and evidence that (i) timely approvals occurred for expenditures made through our procurement system or (ii) that expenditures not made through our procurement system were appropriately approved in accordance with our policies. In addition to the changes previously discussed, we also instituted compensating controls in 2007, such as analytical procedures; however, these compensating controls were not all in place and evidenced as operating effectively until the financial close and reporting for the fourth quarter of 2007. We have begun, but have not yet completed, our process for evaluating the operating effectiveness of these controls for 2008. We anticipate that this evaluation process will be largely completed in the fourth quarter of 2008; as a result, we cannot conclude that this deficiency has been remediated. Management believes that the remedial controls put in place in 2007, which continue in operation through the second quarter of 2008, will be sufficient to remediate previously identified material weaknesses related to authorizations of expenditures.
        In addition to these changes, in the second quarter of 2008 we implemented an automated and paperless invoicing and approval process. Because the automated approvals and payments process eliminates manual approvals, we believe this process provides increased controls for authorization of expenditures.
         Recording of Revenues.    Due to the fact that our revenue process is heavily dependent upon manual reviews and approvals of credit terms, amounts to be billed and recorded, and adjustments for bad debts, we determined that a material weakness existed at December 31, 2006 regarding the recording of revenues in our 2006 Report. At December 31, 2007, we determined that a material weakness still existed in our revenue process because sufficient evidence of manual approvals at the field level necessary to evidence the recognition of revenues could not be adequately substantiated. During 2007, we instituted compensating controls such as more detailed analytical reviews of accrued revenues, analysis of aged receivables and account reconciliations of our revenue systems to our general ledger. Sufficient instances of these compensating controls in operation had not occurred for these compensating controls to be assessed as effective at December 31, 2007. We have begun, but have not yet completed, our process for evaluating the operating effectiveness of these controls for 2008; we anticipate that this evaluation process will be largely completed in the fourth quarter of 2008. As a

result, we cannot conclude that this deficiency has been remediated. Management believes that the compensating controls put in place in 2007, which continue in operation through the second quarter of 2008, are sufficient to compensate for the identified deficiencies in approvals and that with the passage of sufficient close and reporting cycles to evidence operation of these controls, the material weakness related to recording of revenues will be remediated.
         Property, Plant & Equipment ("PP&E").    In our 2006 Report, we determined that a material weakness existed at December 31, 2006 regarding the recording of PP&E. In 2007, substantial changes were made to our processes and controls related to the accounting for PP&E; however, for two areas of our accounting for PP&E—the timing of assets being placed in service and the timing of recognition of gains and losses and approval for asset dispositions—we believe that a material weakness remains. Due to the design and utilization of our procurement system and practices, certain final costs for an asset may not be captured in a timely manner. As a result of this, the asset may be physically placed in service prior to all cost information being received. This delay in accumulating necessary cost information may delay the beginning of depreciation expense. Additionally, while we have implemented controls, including counts and observations, to ensure that information regarding asset dispositions is captured and recorded, obtaining evidence of appropriate approval for the disposition as well as the timing of the receipt of that information may result in delays in the recording of the disposition, which could potentially cross reporting periods.
        In the second quarter of 2008, we implemented enhancements to our control process to evaluate the status of assets recorded as work in process to ensure that the associated depreciation expense is correct in all material respects. We also implemented enhancements to our disposal process to ensure that the associated gains and losses are reflected in the appropriate periods. We believe that these changes will be sufficient to remediate the previously identified material weakness with respect to PP&E. We have begun, but have not completed, our process of evaluating the operating effectiveness of these controls for 2008 and we anticipate that this process will be largely completed in the fourth quarter of 2008. As a result, we cannot conclude that this deficiency has been remediated.
         User Developed Applications.    In the course of preparing our consolidated financial statements, numerous spreadsheets and database programs ("User Developed Applications") are employed. The User Developed Applications are utilized by us in calculating estimates, reconciling payroll hours, tracking inventory costs and making cost allocations, among other things. At December 31, 2006, we identified a material weakness as most User Developed Applications were not secured as to access, logical security, changes or data integrity. To mitigate the associated risk for situations where the above controls could not be implemented, compensating controls were put in place; however, for many of these compensating controls, sufficient instances had not occurred for these controls to be assessed as effective at December 31, 2007. In 2007, management began an effort to identify all of its User Developed Applications and remediate the weakness that had been identified through controls in the User Developed Applications themselves or compensating controls. These efforts, along with elimination of certain User Developed Applications from some of our critical processes, continue into 2008.
        Management believes that the controls and compensating controls put in place in 2007 and continuing into 2008 will be sufficient to remediate these deficiencies. We have begun, but have not completed, our process of evaluating the operating effectiveness of these controls for 2008. As a result, we cannot conclude that this deficiency has been remediated. We anticipate that this evaluation process will be largely completed in the fourth quarter of 2008.
         Application Access and Segregation of Duties.    In our 2006 Report, we determined that material weaknesses existed at December 31, 2006 in four aspects of information technology general controls over security and segregation of duties of our primary financial systems. These include security administration procedures, administrator access privileges, database and file access, and password controls. The weaknesses in these information technology general control areas were further evidenced

by, or related to, deficiencies in our various access controls at the financial system level, causing inappropriate access and lack of appropriate segregation of duties in some of our significant processes. In 2007 we implemented management reports for business owner review as well as administrative controls and procedures. Additionally, in late 2007 we put compensating controls in place, such as analytical reviews. These controls were not fully effective in remediating the identified weakness.
        In the second quarter of 2008, management implemented changes to its business owner review of access and segregation of duties across the systems we utilize and believes that these changes will enhance the controls associated with systems access and segregation of duties. In addition to these changes, management believes the compensating controls put in place will be sufficient to compensate for the identified deficiencies in access and segregation of duties. We have begun, but have not completed, our process of evaluating the operating effectiveness of these controls for 2008. As a result, we cannot conclude that this deficiency has been remediated. We anticipate that this evaluation process will be largely completed in the fourth quarter of 2008.
         Payroll.    We determined that at December 31, 2007, a material weakness in our system of internal controls existed related to certain control activities associated with our payroll process. The weaknesses identified related to lack of appropriate training and competency of certain personnel involved in the process, lack of appropriate documentation concerning hours worked or pay rate changes, and deficiencies in reconciliations related to payroll information. These deficiencies had been previously identified in our 2006 Report as part of Account Reconciliationsand Authorization for Expenditures.
        In 2007, we continued our process to improve our data quality and controls surrounding our payroll process, beginning with system enhancements and organizational changes. In late 2007, we initiated another phase of this process, which encompasses changes to payroll practices, further organizational changes and the replacement of our current payroll system. These changes continued into 2008, and in the second quarter, we made further organizational changes, including adding personnel to the payroll group. Due to the nature and functionality of our current payroll system, our cutover to a new payroll system has been delayed until the first quarter of 2009. We believe that these changes and compensating controls put in place in 2007 will further strengthen our control structure and increase our efficiency as well as transparency into payroll related data, will remediate this material weakness with respect to payroll. We have begun, but have not completed, our process of evaluating the operating effectiveness of these controls for 2008. As a result, we cannot conclude that this deficiency has been remediated. We anticipate that this evaluation process will be largely completed in the fourth quarter of 2008.
        Management is committed to achieving effective internal control over financial reporting. While ~~these~~our remediation efforts continue, we will rely on additional substantive procedures and other measures, as needed, to ~~assist us~~provide assurances that the financial statements presented are prepared in accordance with ~~meeting~~GAAP. We do not believe that our remediation efforts have resulted in additional material costs in the ~~objectives otherwise fulfilled by an effective control environment.~~first two quarters of 2008 or should result in additional material costs in the remainder of 2008.
Changes in Internal Control over Financial Reporting

~~There~~Except for those described above, there have been no changes in our internal control over financial reporting during the most recently completed fiscal quarter, that have materially affected or are reasonably likely to materially affect, our internal control over financial reporting.

PART ~~II —~~ II—OTHER INFORMATION

Item 1.Legal Proceedings.

Class Action Lawsuits and Derivative Activities

Since June 2004, we were named as a defendant in six class action complaints for alleged violations of federal securities laws, which have been filed in federal district court in Texas. They are as follows:

Cause No. MO-04-CV-082;Peter Kaltman, on behalf of himself and all others similarly situated v. Key Energy Services, Inc., Francis D. John, Royce W. Mitchell, Richard J. Alario and James J. Byerlotzer, filed in the United States District Court for the Western District of Texas

Cause No. MO-04-CV-083;Malcolm Lord, Individually and on Behalf of all Others Similarly situated v. Key Energy Services, Inc., Francis D. John, Richard J. Alario, James J. Byerlotzer and Royce W. Mitchell, filed in the United States District Court for the Western District of Texas

Cause No. MO-04-CV-090;Celeste Navon, on behalf of herself and all others similarly situated v. Key Energy Services, Inc., Francis John, Royce Mitchell, James Byerlotzer and Richard Alario, filed in the United States District Court for the Western District of Texas

Cause No. MO-04-CV-104;David W. Ortbals, on Behalf of Himself and All Others Similarly situated v. Key Energy Services, Inc., Richard J. Alario, James J. Byerlotzer, Francis D. John, and Royce W. Mitchell, filed in the United States District Court for the Western District of Texas

Cause No. MO-04-CV-0254;Paul E. Steward, on Behalf of Himself and All Others Similarly situated v. Key Energy Services, Inc., Francis D. John and Royce W. Mitchell, filed in the United States District Court for the Western District of Texas

Cause No. MO-04-CV-0227;Garco Investment LLP Individually and on Behalf of all Others Similarly Situated v. Key Energy Services, Inc., Richard J. Alario, James J. Byerlotzer, Francis D. John and Royce W. Mitchell, filed in the United States District Court for the Western District of Texas

These six actions were consolidated into one action. On November 1, 2005, the plaintiffs filed a consolidated amended class action complaint. The complaint was brought on behalf of a putative class of purchasers of our securities between April 29, 2003 and June 4, 2004. The complaint named Key, Francis D. John, Royce W. Mitchell, Richard J. Alario and James J. Byerlotzer as defendants. The complaint generally alleged that we made false and misleading statements and omitted material information from our public statements and SEC reports during the class period in violation of the Securities Exchange Act of 1934, including alleged: (i) overstatement of revenues, net income, and earnings per share, (ii) failure to take write-downs of assets, consisting of primarily idle equipment, (iii) failure to amortize the ~~Company’s~~Company's goodwill, (iv) failure to disclose that the Company lacked adequate internal controls and therefore was unable to ascertain the true financial condition of the Company, (v) material inflation of the ~~Company’s~~Company's financial results at all relevant times, (vi) misrepresentation of the value of acquired businesses, and (vii) failure to disclose misappropriation of funds by employees.

In addition, four shareholder derivative suits were filed by certain of our shareholders. They are as follows:

Cause No. 2004-CV-44728; Moonlight Investments, LTD. on Behalf of Nominal Defendant Key Energy Services, Inc., v. Francis D. John, Richard J. Alario, James J. Byerlotzer, Royce W. Mitchell, Kevin P. Collins, W. Phillip Marcum, and Ralph S. Michael, III, and Key Energy Services, Inc., filed in the 385th Judicial District Court, Midland County, Texas

Cause No. EP-04-CA-0457;Sandra Weissman, Derivatively on Behalf of Key Energy Services, Inc., v. Francis D. John, David J. Breazzano, Kevin P. Collins, William D. Fertig, W. Phillip Marcum, Ralph S. Michael III, J. Robinson West, James J. Byerlotzer, Royce W. Mitchell, Richard J. Alario and Key Energy Services, Inc., a Maryland Corporation, filed in the United States District Court Western District of Texas

Cause No. EP-04-CA-0456;Daniel Bloom, Derivatively on Behalf of Key Energy Services, Inc., v. Francis D. John, David J. Breazzano, Kevin P. Collins, William D. Fertig, W. Phillip Marcum, Ralph S. Michael III, J. Robinson West, James J. Byerlotzer, Royce W. Mitchell, Richard J. Alario and Key Energy Services, Inc., a Maryland Corporation, filed in the United States District Court Western District of Texas

Cause No. 2007-31254;Sandra Weissman, Derivatively on Behalf of Key Energy Services, Inc., v. Francis D. John, David J. Breazzano, Kevin P. Collins, William D. Fertig, W. Phillip Marcum, Ralph S. Michael III, J. Robinson West, James J. Byerlotzer, Royce W. Mitchell, Richard J. Alario and Key Energy Services, Inc., a Maryland Corporation filed in the 270^th Judicial District, Harris County, Texas

The first derivative suit was filed on August 9, 2004 in state court in Midland, Texas. Two other derivative suits were filed in federal court in El Paso, Texas on December 10, 2004 and subsequently transferred to federal court in Midland, Texas and consolidated by agreement of the parties. Following dismissal of those two actions for failure to make a demand, a fourth derivative suit was filed in Texas state court in Harris County, Texas on May 22, 2007. Francis D. John, David J. Breazzano, Kevin P. Collins, William D. Fertig, W. Phillip Marcum, Ralph S. Michael III, J. Robinson West, James J. Byerlotzer, Royce W. Mitchell, and Richard J. Alario were named as defendants in one or more of those actions. The actions were filed by individual shareholders purporting to act on our behalf, asserting various claims against the named officer and director defendants. The derivative actions generally allege the same facts as those in the shareholder class action suits. Those

suits also allege breach of fiduciary duty, abuse of control, waste of corporate assets, and unjust enrichment by these defendants.

On September 7, 2007, we reached agreements in principle to settle all pending securities class action and derivative lawsuits in consideration of payments totaling $16.6 million in exchange for full and complete releases for all defendants, of which Key will be required to pay approximately $1.1 million. We received final approval of the settlement of the shareholder and class action claims on March 6, 2008, and preliminary court approval on the derivative action on April 18, 2008. ~~Final~~A hearing for final approval on the derivative settlement was held on August 1, 2008. No objections were made by any party during the hearing. The Company anticipates that the final order dismissing the derivative actions will be signed in the third quarter. Following dismissal, all of the litigation in the shareholder and derivative matters will be concluded, and if there are no actions taken to reconsider the order that has been signed by the court, the court-approved administrator in these matters will begin distribution of payments to eligible class members according to the ~~derivative action is anticipated to occur~~terms of the settlement. We anticipate this will also be completed in the third quarter of 2008.

Other Matters

In addition to various suits and claims that have arisen in the ordinary course of business, we continue to be involved in litigation with our former executive officers as well as a class action lawsuit in California. We do not believe that the disposition of any of these items, including litigation with former management, will result in a material adverse effect on our consolidated financial position, results of operations or cash flows.

Item 1A.Risk Factors.

There have been no material changes in our risk factors from those disclosed in our 2007 Annual Report on Form 10-K dated as of, and filed with the SEC on, February 29, 2008. For a discussion of our risk factors, see Item 1A. ~~“Risk Factors”~~"Risk Factors" in our 2007 Annual Report on Form 10-K.

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

Stock ~~Repurchases~~Repurchases.. During the ~~first~~second quarter of 2008, the Company repurchased ~~an aggregate~~ approximately ~~5.2~~1.8 million shares of its common stock. The repurchases were made pursuant to the ~~Company’s~~Company's $300.0 million share repurchase program, which the Company announced in October 2007. The program expires March 31, 2009. Set forth below is a summary of the share repurchases during the three months ended ~~March 31,~~June 30, 2008:

ISSUER PURCHASES OF EQUITY SECURITIES

Period			Weighted Average Price Paid per Share				Approximate Dollar Amount of Shares that may yet be Purchased Under the Plans or Programs

April 1, 2008 to April 30, 2008	1,010,000		$	14.34		1,010,000	$	188,058,495
May 1, 2008 to May 31, 2008	614,290		$	15.17		614,290	$	178,719,406
June 1, 2008 to June 30, 2008	214,578	(1)	$	17.79	(2)	180,000	$	175,543,168

Total	1,838,868		$	15.02		1,804,290

(1): Includes 34,578 shares repurchased to satisfy tax withholding obligations of certain executive officers upon vesting of restricted stock.
(2): The price paid per share on the vesting date with respect to the tax withholding repurchases was determined using the closing price on June 23, 2008, as quoted on the NYSE.

Period

Total Number of
Shares Purchased

Weighted Average
Price Paid per Share

Total Number of
Shares Repurchased
as Part of Publicly
Announced Plans or
Programs

Appropriate Dollar
Value of Shares that
May Yet Be
Purchased Under the
Plans or Programs

January 1, 2008 to January 31, 2008

1,837,300

$
12.47

1,837,300

$
244,869,537

February 1, 2008 to February 29, 2008

1,689,896

$
12.59

1,689,896

$
223,540,071

March 1, 2008 to March 31, 2008

1,670,250

$
12.52

1,670,250

$
202,572,331

Total

5,197,446

$
12.53

5,197,446

$
202,572,331

Item 3.Defaults Upon Senior Securities.

None.

Item 4.Submission of Matters to a Vote of Security Holders.

At our 2008 Annual Meeting of Shareholders held on June 5, 2008, holders of 109,691,808 shares were present in person or by proxy, constituting 86.12% of the outstanding shares of common stock as of the record date for the annual meeting. The matters voted upon at the annual meeting were:

Election of four Class II Directors. The shareholders elected four Class II Directors to serve for a three year term, expiring in 2011:



David J. Breazzano	100,132,466	9,559,342
William D. Fertig	105,795,911	3,895,897
Robert K. Reeves	105,797,087	3,894,721
J. Robinson West	99,588,177	10,103,631

Four Class I Directors, Lynn R. Coleman, Kevin P. Collins, W. Phillip Marcum and William F. Owens, continued in office with terms expiring in 2010. Three Class III Directors, Richard J. Alario, Ralph S. Michael, III and Arlene M. Yocum, continued in office with terms expiring in 2009.

Ratification of Independent Registered Public Accounting Firm. The shareholders ratified the selection of Grant Thornton LLP as the Company's independent registered public accounting firm for the current fiscal year:

Ratification of Independent Registered Public Accounting Firm

Votes cast in favor			108,887,748
Votes cast against			48,840
Votes abstaining			755,217
Broker non-votes			0

Item 5. Other Information.

None.

~~Item 5.~~~~Other Information.~~

~~None.~~

Item 6.Exhibits.

~~3.1~~
	3.1		Articles of Restatement of the Company. (Incorporated by Reference to Exhibit 3.1 of the ~~Company’s~~Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2006, File No. 1-8038.)

~~3.2~~	3.2		Unanimous consent of the Board of Directors of the Company dated January 11, 2000, limiting the designation of the additional authorized shares to common stock. (Incorporated by reference to Exhibit 3.2 of the ~~Company’s~~Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2000, File No. 1-8038.)

3.3		Second Amended and Restated By-laws of Key Energy Services, Inc. (Incorporated by reference to Exhibit 3.1 of the ~~Company’s~~Company's Form 8-K filed on September 22, 2006, File No. 1-8038.)

3.4		Amendment to Second Amended and Restated By-laws of Key Energy Services, Inc. (Incorporated by Reference to Exhibit 3.1 of the ~~Company’s~~Company's Form 8-K filed on November 2, 2007, File No. 1-8038.)

3.5		Amendments to Second Amended and Restated By-laws of Key Energy Services, Inc. adopted April 4, 2008. (Incorporated by Reference to Exhibit 3.1 of the ~~Company’s~~Company's Form 8-K filed on April 9, 2008, File No. 1-8038.)

4.1		Warrant Agreement dated as of January 22, 1999 between the Company and the Bank of New York, a New York banking corporation as warrant agent. (Incorporated by reference to Exhibit 99(b) of the ~~Company’s~~Company's Form 8-K filed on February 3, 1999, File No. 1-8038.)

4.2		Warrant Registration Rights Agreement dated January 22, 1999, by and among the Company and Lehman Brothers Inc., Bear, Stearns & Co., Inc., F.A.C. / Equities, a division of First Albany Corporation, and Dain Rauscher Wessels, a division of Dain Rauscher Incorporated. (Incorporated by reference to Exhibit 99(e) of the ~~Company’s~~Company's Form 8-K filed on February 3, 1999, File No. 1-8038.)

4.3		Indenture, dated as of November 29, 2007, among Key Energy Services, Inc., the guarantors party thereto and The Bank of New York Trust Company, N.A., as trustee. (Incorporated by Reference to Exhibit 4.1 of the ~~Company’s~~Company's Form 8-K filed on November 30, 2007, File No. 1-8038.)



4.4		Registration Rights Agreement dated as of November 29, 2007, among Key Energy Services, Inc., the subsidiary guarantors of the Company party thereto, and Lehman Brothers Inc., Banc of America Securities LLC and Morgan Stanley & Co. Incorporated, as representatives of the several initial purchasers named therein. (Incorporated by Reference to Exhibit 4.2 of the ~~Company’s~~Company's Form 8-K filed on November 30, 2007, File No. 1-8038.)

4.5* 4.5		First Supplemental Indenture, dated as of January 22, 2008, among Key Marine Services, LLC, the existing Guarantors and The Bank of New York Trust Company, N.A., as trustee. (Incorporated by reference to Exhibit 4.5 of the Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2008, File No. 1-8038.)
	10.1		Purchase Agreement dated April 3, 2008 among Key Energy Services, LLC, Western Drilling Holdings, Inc., and Fred S. Holmes and Barbara J. Holmes. (Incorporated by Reference to Exhibit 10.1 of the Company's Form 8-K filed on April 9, 2008, File No. 1-8038.)
31.1*	10.2		Stock Purchase Agreement dated May 30, 2008, by and among Key Energy Services, LLC, and E. Kent Tolman, Nita Tolman, Ronald D. Jones and Melinda Jones. (Incorporated by Reference to Exhibit 10.1 of the Company's Form 8-K filed on June 5, 2008, File No. 1-8038.)
	31.1	*	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

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

32* 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.

*: Filed herewith

SIGNATURE

~~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)
		~~(Registrant)~~
By:
		/s/ RICHARD J. ALARIO Richard J. Alario
	~~By:~~	~~Richard J. Alario~~
		President and Chief Executive Officer
		(Principal Executive Officer)

Date: ~~May~~August 8, 2008

EXHIBITS INDEX

~~3.1~~
	3.1		Articles of Restatement of the Company. (Incorporated by Reference to Exhibit 3.1 of the ~~Company’s~~Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2006, File No. 1-8038.)

3.2		Unanimous consent of the Board of Directors of the Company dated January 11, 2000, limiting the designation of the additional authorized shares to common stock. (Incorporated by reference to Exhibit 3.2 of the ~~Company’s~~Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2000, File No. 1-8038.)

3.3		Second Amended and Restated By-laws of Key Energy Services, Inc. (Incorporated by reference to Exhibit 3.1 of the ~~Company’s~~Company's Form 8-K filed on September 22, 2006, File No. 1-8038.)

3.4		Amendment to Second Amended and Restated By-laws of Key Energy Services, Inc. (Incorporated by Reference to Exhibit 3.1 of the ~~Company’s~~Company's Form 8-K filed on November 2, 2007, File No. 1-8038.)

3.5		Amendments to Second Amended and Restated By-laws of Key Energy Services, Inc. adopted April 4, 2008. (Incorporated by Reference to Exhibit 3.1 of the ~~Company’s~~Company's Form 8-K filed on April 9, 2008, File No. 1-8038.)

4.1		Warrant Agreement dated as of January 22, 1999 between the Company and the Bank of New York, a New York banking corporation as warrant agent. (Incorporated by reference to Exhibit 99(b) of the ~~Company’s~~Company's Form 8-K filed on February 3, 1999, File No. 1-8038.)

4.2		Warrant Registration Rights Agreement dated January 22, 1999, by and among the Company and Lehman Brothers Inc., Bear, Stearns & Co., Inc., F.A.C. / Equities, a division of First Albany Corporation, and Dain Rauscher Wessels, a division of Dain Rauscher Incorporated. (Incorporated by reference to Exhibit 99(e) of the ~~Company’s~~Company's Form 8-K filed on February 3, 1999, File No. 1-8038.)

4.3		Indenture, dated as of November 29, 2007, among Key Energy Services, Inc., the guarantors party thereto and The Bank of New York Trust Company, N.A., as trustee. (Incorporated by Reference to Exhibit 4.1 of the ~~Company’s~~Company's Form 8-K filed on November 30, 2007, File No. 1-8038.)

4.4		Registration Rights Agreement dated as of November 29, 2007, among Key Energy Services, Inc., the subsidiary guarantors of the Company party thereto, and Lehman Brothers Inc., Banc of America Securities LLC and Morgan Stanley & Co. Incorporated, as representatives of the several initial purchasers named therein. (Incorporated by Reference to Exhibit 4.2 of the ~~Company’s~~Company's Form 8-K filed on November 30, 2007, File No. 1-8038.)

4.5* 4.5		First Supplemental Indenture, dated as of January 22, 2008, among Key Marine Services, LLC, the existing Guarantors and The Bank of New York Trust Company, N.A., as trustee. (Incorporated by reference to Exhibit 4.5 of the Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2008, File No. 1-8038.)
	10.1		Purchase Agreement dated April 3, 2008 among Key Energy Services, LLC, Western Drilling Holdings, Inc., and Fred S. Holmes and Barbara J. Holmes. (Incorporated by Reference to Exhibit 10.1 of the Company's Form 8-K filed on April 9, 2008, File No. 1-8038.)
31.1*	10.2		Stock Purchase Agreement dated May 30, 2008, by and among Key Energy Services, LLC, and E. Kent Tolman, Nita Tolman, Ronald D. Jones and Melinda Jones. (Incorporated by Reference to Exhibit 10.1 of the Company's Form 8-K filed on June 5, 2008, File No. 1-8038.)
	31.1	*	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

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

32* 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.

*: Filed herewith

QuickLinks

	March 31,			December 31,
	2008			2007
	(unaudited)
*ASSETS*
Current assets:
Cash and cash equivalents	$	29,871		$	58,503
Short-term investments	270			276
Accounts receivable, net of allowance for doubtful accounts of $13,500 and $13,501 at March 31, 2008 and December 31, 2007, respectively	355,327			343,408
Inventories	25,310			22,849
Prepaid expenses	12,644			12,997
Deferred tax assets	27,687			27,676
Income taxes receivable	1,261			15,796
Other current assets	8,420			6,360

Total current assets	460,790			487,865

Property and equipment, gross	1,623,594			1,595,225
Accumulated depreciation	(714,776		)	(684,017		)

Property and equipment, net	908,818			911,208

Goodwill	378,593			378,550
Other intangible assets, net	43,673			45,894
Deferred financing costs, net	11,925			12,117
Notes and accounts receivable - related parties	168			173
Investment in IROC Energy Services Corp	10,617			11,217
Other assets	12,222			12,053

TOTAL ASSETS	$	1,826,806		$	1,859,077

*LIABILITIES AND STOCKHOLDERS’ EQUITY*
Current liabilities:
Accounts payable	$	20,594		$	35,159
Accrued liabilities	187,935			183,364
Accrued interest	13,117			3,895
Current portion of capital lease obligations	9,899			10,701
Current notes payable - related parties, net of discount	1,714			1,678

Total current liabilities	233,259			234,797

Capital lease obligations, less current portion	15,105			16,114
Notes payable - related party, less current portion	20,500			20,500
Long-term debt	475,000			475,000
Workers’ compensation, vehicular, health and other insurance claims	42,629			43,818
Deferred tax liabilities	159,909			160,068
Other non-current accrued liabilities	19,150			19,531

Minority interest	207			251
Commitments and contingencies

Stockholders’ equity:
Common stock, $0.10 par value; 200,000,000 shares authorized, 126,005,998 and 131,142,905 shares issued and outstanding at March 31, 2008 and December 31, 2007, respectively	12,601			13,114
Additional paid-in capital	643,277			704,644
Accumulated other comprehensive loss	(38,536		)	(37,981		)
Retained earnings	243,705			209,221

Total stockholders’ equity	861,047			888,998
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	1,826,806		$	1,859,077

	Three Months Ended March 31,
	2008			2007

*REVENUES:*
Well servicing	$	348,878		$	311,160
Pressure pumping	81,852			74,077
Fishing and rental	25,669			23,682

Total revenues	456,399			408,919

*COSTS AND EXPENSES:*
Well servicing	211,751			175,529
Pressure pumping	53,779			46,533
Fishing and rental	16,111			13,451
Depreciation and amortization	39,976			29,614
General and administrative	67,732			52,064
Interest expense, net of amounts capitalized	10,040			9,348
(Gain) loss on sale of assets	(266		)	250
Interest income	(508		)	(1,940		)
Other expense (income), net	877			(624		)

Total costs and expenses, net	399,492			324,225

Income before income taxes	56,907			84,694
Income tax expense	(22,457		)	(32,504		)
Minority interest	34			—

*NET INCOME*	$	34,484		$	52,190

*EARNINGS PER SHARE:*
Basic	$	0.27		$	0.40
Diluted	$	0.27		$	0.39

*WEIGHED AVERAGE SHARES OUTSTANDING:*
Basic	127,966			131,629
Diluted	129,307			133,915

	Well Servicing Segment			Pressure Pumping Segment		Fishing and Rental Segment		Total
	(in thousands)

December 31, 2007	$	311,744		$	47,905	$	18,901	$	378,550
Purchase price and other adjustments, net	221			—		—		221
Foreign currency translation	(178		)	—		—		(178		)
March 31, 2008	$	311,787		$	47,905	$	18,901	$	378,593

				Pressure			Fishing and			Corporate /
	Well Servicing			Pumping			Rental			Other			Eliminations			Total
	(in thousands)
As of and for the three months ended March 31, 2008:
Operating revenues	$	349,418		$	81,852		$	25,669		$	—		$	(540	)	$	456,399
Gross margin	137,384			28,073			9,558			—			(257		)	174,758
Depreciation and amortization	29,531			4,812			2,601			3,032			—			39,976
Interest expense	(552		)	(391		)	(120		)	10,855			248			10,040
Net income (loss)	82,843			21,013			5,331			(74,445		)	(258		)	34,484
Property and equipment, net	695,362			131,282			48,672			33,502			—			908,818
Total assets	1,539,182			271,214			93,143			512,550			(589,283		)	1,826,806
Capital expenditures, excluding acquisitions	(25,895		)	(1,857		)	(1,406		)	(1,217		)	—			(30,375		)

	Argentina		Mexico			Canada			Total

As of and for the three months ended March 31, 2008:

Operating revenues	$	26,866	$	5,701		$		3,890	$	36,457
Total assets	83,563		34,110			6,596			124,269

As of and for the three months ended March 31, 2007:

Operating revenues	$	20,427	$	—		$	—		$	20,427
Total assets	76,049		10,198		(1)	—			86,247

	March 31, 2008
	Parent Company		Guarantor Subsidiaries			Non-Guarantor Subsidiaries		Eliminations			Consolidated
	(in thousands)
	(unaudited)
Assets:
Current assets	$	—	$	386,908		$	73,882	$	—		$	460,790
Net property and equipment	—		879,261			29,557		—			908,818
Goodwill	—		372,594			5,999		—			378,593
Deferred financing costs, net	11,925		—			—		—			11,925
Intercompany receivables and investments in subsidiaries	1,605,437		218,954			541		(1,824,932		)	—
Other assets	10,617		50,781			5,282		—			66,680
TOTAL ASSETS	$	1,627,979	$	1,908,498		$	115,261	$	(1,824,932	)	$	1,826,806

Liabilities and equity:
Current liabilities	18,867		190,111			24,281		—			233,259
Long-term debt	475,000		—			—		—			475,000
Capital lease obligations	—		14,982			123		—			15,105
Long-term notes payable - related party	—		20,500			—		—			20,500
Intercompany payables	113,156		1,271,699			29,013		(1,413,868		)	—
Deferred tax liabilities	159,909		(1,807		)	1,807		—			159,909
Other long-term liabilities	—		61,779			207		—			61,986
Stockholders’ equity	861,047		351,234			59,830		(411,064		)	861,047
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	1,627,979	$	1,908,498		$	115,261	$	(1,824,932	)	$	1,826,806

	Three Months Ended March 31, 2008
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Consolidated
	(in thousands)
	(unaudited)

Revenues	$	—		$	422,621		$	36,457		$	(2,679	)	$	456,399
Costs and expenses:
Direct expenses	—			257,771			25,666			(1,796		)	281,641
Depreciation and amortization	—			38,051			1,925			—			39,976
General and administrative	185			62,874			4,782			(109		)	67,732
Interest expense, net of amounts capitalized	10,756			(1,007		)	43			248			10,040
Other, net	35			(664		)	1,497			(765		)	103
Total costs and expenses, net	10,976			357,025			33,913			(2,422		)	399,492
(Loss) income before income taxes	(10,976		)	65,596			2,544			(257		)	56,907
Income tax expense	(20,484		)	(561		)	(1,412		)	—			(22,457		)
Minority interest	—			—			34			—			34
NET (LOSS) INCOME	$	(31,460	)	$	65,035		$	1,166		$	(257	)	$	34,484

	Three Months Ended March 31, 2007
	Parent Company			Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations		Consolidated
	(in thousands)
	(unaudited)

Revenues	$	—		$	388,492		$	20,427		$	—	$	408,919
Costs and expenses:
Direct expenses	—			219,302			16,211			—		235,513
Depreciation and amortization	—			28,315			1,299			—		29,614
General and administrative	235			50,601			1,228			—		52,064
Interest expense, net of amounts capitalized	9,732			(355		)	(29		)	—		9,348
Other, net	(549		)	(2,056		)	291			—		(2,314		)
Total costs and expenses, net	9,418			295,807			19,000			—		324,225
(Loss) income before income taxes	(9,418		)	92,685			1,427			—		84,694
Income tax expense	(32,069		)	—			(435		)	—		(32,504		)
NET (LOSS) INCOME	$	(41,487	)	$	92,685		$	992		$	—	$	52,190

	WTI Cushing Oil (1)		NYMEX Henry Hub Natural Gas (1)		Average Baker Hughes Land Drilling Rigs (2)

2008:
First Quarter	$	97.94	$	8.74	1,712

2007:
First Quarter	$	58.08	$	7.18	1,651
Second Quarter	$	64.97	$	7.66	1,680
Third Quarter	$	75.46	$	6.24	1,717
Fourth Quarter	$	90.75	$	7.39	1,733

	Rig Hours	Trucking Hours

2008:
First Quarter	659,462	585,040

2007:
First Quarter	625,748	571,777
Second Quarter	611,890	583,074
Third Quarter	597,617	570,356
Fourth Quarter	614,444	583,191
Total 2007	2,449,699	2,308,398

	Change from Three Months Ended March 31, 2007

Well servicing segment	$	37.7
Pressure pumping segment	7.8
Fishing and rental segment	2.0
Total change	$	47.5

	Change from Three Months Ended March 31, 2007

Employee compensation	$	6.6
Legal reserves and settlements	2.8
Bad debt	0.5
Acquisitions during 2007	3.3
Other	2.5
Total change	$	15.7

		Three Months Ended June 30,

		2008			2007			Change
		(in thousands, except percentages)
Well Servicing segment
	Revenues	$	379,959		$	308,825		$	71,134
	Direct expenses, excluding depreciation		241,634			177,304			64,330
	Direct costs as a percentage of revenue		63.6	%		57.4	%		6.2	%
Pressure Pumping segment
	Revenues	$	91,952		$	77,289		$	14,663
	Direct expenses, excluding depreciation		62,837			47,410			15,427
	Direct costs as a percentage of revenue		68.3	%		61.3	%		7.0	%
Fishing and Rental segment
	Revenues	$	30,092		$	24,397		$	5,695
	Direct expenses, excluding depreciation		18,017			13,509			4,508
	Direct costs as a percentage of revenue		59.9	%		55.4	%		4.5	%

	Change from Three Months Ended March 31, 2007

Employee compensation.	$	6.9
Business acquisitions during 2007	26.3
Self-insurance costs	(2.3		)
Equipment and supplies.	5.9
Other	(0.6		)
Total change	$	36.2

		Change from Three Months Ended June 30, 2007

Direct expenses of acquisitions		$	34.3
Employee compensation			12.4
Fuel			6.9
Supplies, equipment and maintenance			6.7
Other direct expenses			4.0

	Total change	$	64.3

	Change from Three Months Ended March 31, 2007

Employee compensation.	$	1.0
Equipment costs	1.3
Supply costs	4.8
Other	0.1
Total change	$	7.2

		Change from Three Months Ended June 30,

Sand, chemicals and freight		$	9.3
Fuel			2.7
Repairs and maintenance			1.6
Employee compensation			1.4
Other direct expenses			0.4

	Total change	$	15.4

		Change from Six Months Ended June 30, 2007

Direct expenses of acquisitions		$	64.5
Employee compensation			14.5
Fuel			11.7
Supplies, equipment and maintenance			7.5
Other direct expenses			2.4

	Total change	$	100.6

		Change from Six Months Ended June 30, 2007

Sand, chemicals and freight		$	14.3
Fuel			4.4
Employee compensation			2.3
Other direct expenses			1.7

	Total change	$	22.7

	Change from Three Months Ended March 31, 2007

Employee compensation	$	0.6
Equipment costs.	1.7
Other	0.4
Total change.	$	2.7

		Change from Six Months Ended June 30, 2007

Employee compensation		$	2.7
Equipment and supplies			1.5
Repairs and maintenance			1.1
Fuel			0.9
Direct costs of acquisitions			0.4
Other direct expenses			0.6

	Total change	$	7.2

Period	Total Number of Shares Purchased	Weighted Average Price Paid per Share		Total Number of Shares Repurchased as Part of Publicly Announced Plans or Programs	Appropriate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs
January 1, 2008 to January 31, 2008	1,837,300	$	12.47	1,837,300	$	244,869,537
February 1, 2008 to February 29, 2008	1,689,896	$	12.59	1,689,896	$	223,540,071
March 1, 2008 to March 31, 2008	1,670,250	$	12.52	1,670,250	$	202,572,331
Total	5,197,446	$	12.53	5,197,446	$	202,572,331

Large accelerated filer ýx

Accelerated filer o

Non-accelerated filer o

~~Smaller reporting company~~
o

(Do not check if a smaller reporting company)

Smaller reporting company o