e10vq

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

(MARK ONE)


þ		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2008


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

Commission File No. 1-32858

Complete Production Services, Inc.

(Exact name of registrant as specified in its charter)


Delaware (State or Other Jurisdiction of Incorporation or Organization)		72-1503959 (I.R.S. Employer Identification No.)


11700 Katy Freeway, Suite 300 Houston, Texas (Address of principal executive offices)		77079 (Zip Code)

Registrant’s telephone number, including area code: (281) 372-2300

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

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

Large accelerated filer þ

Accelerated filer o

Non-accelerated filer o
(Do not check if a smaller reporting company)

Smaller reporting company o

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

Number of shares of the Common Stock of the registrant outstanding as of July 31, 2008: 74,948,194

PART I—FINANCIAL INFORMATION

Item 1. Financial Statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Balance Sheets
June 30, 2008 (unaudited) and December 31, 2007


	2008			2007
	(In thousands, except
	share data)
ASSETS
Current assets:
Cash and cash equivalents	$	17,719		$	13,624
Trade accounts receivable, net		329,090			305,682
Inventory, net		34,482			29,877
Prepaid expenses		25,610			23,743
Other current assets		13,823			5,092
Current assets held for sale		—			50,307

Total current assets		420,724			428,325
Property, plant and equipment, net		1,107,897			1,013,190
Intangible assets, net of accumulated amortization of $7,327 and $5,762, respectively		16,088			10,606
Deferred financing costs, net of accumulated amortization of $3,246 and $2,455, respectively		13,403			14,194
Goodwill		569,569			549,130
Other long-term assets		3,947			6,264
Long-term assets held for sale		—			33,050

Total assets	$	2,131,628		$	2,054,759


LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current maturities of long-term debt	$	3,742		$	398
Accounts payable		60,214			56,407
Accrued liabilities		73,343			57,125
Accrued payroll and payroll burdens		21,782			24,050
Notes payable		5,414			15,354
Taxes payable		1,786			6,506
Current liabilities of held for sale operations		—			9,705

Total current liabilities		166,281			169,545
Long-term debt		788,150			825,985
Deferred income taxes		148,186			126,821
Long-term liabilities of held for sale operations		—			2,085

Total liabilities		1,102,617			1,124,436
Commitments and contingencies
Stockholders’ equity:
Common stock, $0.01 par value per share, 200,000,000 shares authorized, 73,793,667 (2007 — 72,509,511) issued		738			725
Preferred stock, $0.01 par value per share, 5,000,000 shares authorized, no shares issued and outstanding		—			—
Additional paid-in capital		605,706			581,404
Retained earnings		394,447			317,535
Treasury stock, 35,570 shares at cost		(202	)		(202	)
Accumulated other comprehensive income		28,322			30,861

Total stockholders’ equity		1,029,011			930,323

Total liabilities and stockholders’ equity	$	2,131,628		$	2,054,759

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Statements of Operations
Quarters and Six Months Ended June 30, 2008 and 2007 (unaudited)


	Quarter Ended						Six Months Ended
	June 30,						June 30,
	2008			2007			2008			2007
	(In thousands, except per share data)
Revenue:
Service	$	425,848		$	355,620		$	830,811		$	710,347
Product		15,237			11,194			27,452			22,689

		441,085			366,814			858,263			733,036
Service expenses		264,142			197,344			506,354			393,762
Product expenses		10,730			8,000			18,550			16,285
Selling, general and administrative expenses		48,036			51,134			95,454			97,528
Depreciation and amortization		43,037			32,375			82,288			60,329

Income before interest, taxes and minority interest		75,140			77,961			155,617			165,132
Interest expense		15,515			15,055			31,430			30,668
Interest income		(762	)		(316	)		(1,387	)		(528	)

Income before taxes and minority interest		60,387			63,222			125,574			134,992
Taxes		20,544			23,322			43,956			50,615

Income before minority interest		39,843			39,900			81,618			84,377
Minority interest		—			(205	)		—			56

Income from continuing operations		39,843			40,105			81,618			84,321
Income (loss) from discontinued operations (net of tax expense of $2,569, $2,213, $3,865 and $4,099, respectively)		(6,857	)		3,678			(4,706	)		6,812

Net income	$	32,986		$	43,783		$	76,912		$	91,133


Earnings per share information:
Continuing operations	$	0.54		$	0.56		$	1.12		$	1.18
Discontinued operations		(0.09	)		0.05			(0.06	)		0.09

Basic earnings per share	$	0.45		$	0.61		$	1.06		$	1.27


Continuing operations	$	0.54		$	0.55		$	1.10		$	1.15
Discontinued operations		(0.10	)		0.05			(0.06	)		0.10

Diluted earnings per share	$	0.44		$	0.60		$	1.04		$	1.25


Weighted average shares:
Basic		73,171			71,916			72,866			71,711
Diluted		74,407			73,367			74,059			73,195

Consolidated Statements of Comprehensive Income
Quarters and Six Months Ended June 30, 2008 and 2007 (unaudited)


	Quarter Ended				Six Months Ended
	June 30,				June 30,
	2008		2007		2008			2007
	(In thousands)				(In thousands)
Net income	$	32,986	$	43,783	$	76,912		$	91,133
Change in cumulative translation adjustment		1,107		7,096		(2,539	)		7,852

Comprehensive income	$	34,093	$	50,879	$	74,373		$	98,985

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Statement of Stockholders’ Equity
Six Months Ended June 30, 2008 (unaudited)


													Accumulated
					Additional								Other
	Number		Common		Paid-in			Retained		Treasury			Comprehensive
	of Shares		Stock		Capital			Earnings		Stock			Income			Total
	(In thousands, except share data)

Balance at December 31, 2007		72,509,511	$	725	$	581,404		$	317,535	$	(202	)	$	30,861		$	930,323
Net income		—		—		—			76,912		—			—			76,912
Cumulative translation adjustment		—		—		—			—		—			(2,539	)		(2,539	)
Issuance of common stock:
Exercise of stock options		1,148,761		12		10,986			—		—			—			10,998
Expense related to employee stock options		—		—		2,566			—		—			—			2,566
Excess tax benefit from share-based compensation		—		—		8,500			—		—			—			8,500
Vested restricted stock		135,395		1		(1	)		—		—			—			—
Amortization of non-vested restricted stock		—		—		2,251			—		—			—			2,251

Balance at June 30, 2008		73,793,667	$	738	$	605,706		$	394,447	$	(202	)	$	28,322		$	1,029,011

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Statements of Cash Flows
Six Months Ended June 30, 2008 and 2007 (unaudited)


	Six Months Ended
	June 30,
	2008			2007
	(In thousands)
Cash provided by (used in):
Operating activities:
Net income	$	76,912		$	91,133
Items not affecting cash:
Depreciation and amortization		84,354			62,462
Deferred income taxes		23,491			7,665
Loss on sale of discontinued operations		6,782			—
Minority interest		—			56
Excess tax benefit from share-based compensation		(8,500	)		(4,599	)
Non-cash compensation expense		4,817			3,731
Other		2,572			4,354
Changes in operating assets and liabilities, net of effect of acquisitions:
Accounts receivable		(408	)		(12,463	)
Inventory		(2,798	)		(13,929	)
Prepaid expense and other current assets		(1,796	)		6,997
Accounts payable		(7,440	)		(948	)
Accrued liabilities and other		2,017			(4,535	)

Net cash provided by operating activities		180,003			139,924

Investing activities:
Business acquisitions, net of cash acquired		(71,862	)		(40,468	)
Additions to property, plant and equipment		(134,381	)		(194,479	)
Proceeds from sale of discontinued operations		50,150			—
Collection of notes receivable		2,016			—
Proceeds from disposal of capital assets		3,602			3,840

Net cash used in investing activities		(150,475	)		(231,107	)

Financing activities:
Issuances of long-term debt		138,200			192,901
Repayments of long-term debt		(173,120	)		(103,605	)
Repayment of notes payable		(9,940	)		(14,604	)
Proceeds from issuances of common stock		10,998			2,944
Excess tax benefit from share-based compensation		8,500			4,599

Net cash (used in) provided by financing activities		(25,362	)		82,235

Effect of exchange rate changes on cash		(71	)		(1,265	)

Change in cash and cash equivalents		4,095			(10,213	)
Cash and cash equivalents, beginning of period		13,624			19,874

Cash and cash equivalents, end of period	$	17,719		$	9,661


Supplemental cash flow information:
Cash paid for interest, net of interest capitalized	$	27,205		$	27,750
Cash paid for taxes	$	30,606		$	44,340

Non-cash investing and financing activities:
Debt acquired in acquisition	$	429		$	—
Assets received as proceeds from the sale of disposal group	$	7,987		$	—

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Notes to Consolidated Financial Statements
(Unaudited, in thousands, except share and per share data)

1. General:

(a) Nature of operations:

Complete Production Services, Inc. is a provider of specialized services and products focused on developing hydrocarbon reserves, reducing operating costs and enhancing production for oil and gas companies. Complete Production Services, Inc. focuses its operations on basins within North America and manages its operations from regional field service facilities located throughout the U.S. Rocky Mountain region, Texas, Oklahoma, Louisiana, Arkansas, Kansas, North Dakota, western Canada, Mexico and Southeast Asia.

References to “Complete,” the “Company,” “we,” “our” and similar phrases used throughout this Quarterly Report on Form 10-Q relate collectively to Complete Production Services, Inc. and its consolidated affiliates.

On April 20, 2006, in connection with our initial public offering, we became subject to the reporting requirements of the Securities Exchange Act of 1934. On April 21, 2006, our common stock began trading on the New York Stock Exchange under the symbol “CPX”. On April 26, 2006, we completed our initial public offering.

(b) Basis of presentation:

The unaudited interim consolidated financial statements reflect all normal recurring adjustments that are, in the opinion of management, necessary for a fair statement of the financial position of Complete as of June 30, 2008 and the statements of operations and the statements of comprehensive income for the quarters and six-month periods ended June 30, 2008 and 2007, as well as the statement of stockholders’ equity for the six months ended June 30, 2008 and the statements of cash flows for the six-month periods ended June 30, 2008 and 2007. Certain information and disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted. These unaudited interim consolidated financial statements should be read in conjunction with our audited consolidated financial statements for the year ended December 31, 2007. We believe that these financial statements contain all adjustments necessary so that they are not misleading.

In preparing financial statements, we make informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. We review our estimates on an on-going basis, including those related to impairment of long-lived assets and goodwill, contingencies, and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.

The results of operations for interim periods are not necessarily indicative of the results of operations that could be expected for the full year. Certain reclassifications have been made to 2007 amounts in order to present these results on a comparable basis with amounts for 2008.

In May 2008, our Board of Directors authorized and committed to a plan to sell certain operations in the Barnett Shale region of north Texas, consisting primarily of our supply store business, as well as certain non-strategic drilling logistics assets and other completion and production services assets. On May 19, 2008, we sold these operations to a company owned by a former officer of one of our subsidiaries, for which we received proceeds of $50,150 and assets with a fair market value of $7,987. Accordingly, we have revised our financial statement presentation for all periods presented to classify the assets and liabilities of this disposal group as held for sale and the related results of operations as discontinued operations. See Note 10, Discontinued Operations.

2. Business combinations:

On February 29, 2008, we acquired substantially all the assets of KR Fishing & Rental, Inc. for $9,464 in cash, which includes a working capital adjustment of $184, resulting in goodwill of $6,227. KR Fishing & Rental, Inc. is a provider of fishing, rental and foam unit services in the Piceance Basin and the Raton Basin, and is based in Rangely, Colorado. We believe this acquisition complements our completion and production services business in the Rocky Mountain Region.

On April 15, 2008, we acquired all the equity interests of Frac Source, Inc., a pressure pumping business based in Granbury, Texas, for $62,369 in cash, net of cash acquired, and recorded goodwill of $15,068. This acquisition supplements our pressure pumping business in the Barnett Shale of north Texas. Upon closing this transaction, we entered into a contract with one of our major customers to provide pressure pumping services in the Barnett Shale utilizing three frac fleets under a contract with a term that extends up to three years from the date each fleet is placed into service.

We accounted for each of these acquisitions using the purchase method of accounting, whereby the purchase price was allocated to the fair value of net assets acquired, including intangibles and property, plant and equipment at depreciated replacement costs, with the excess recorded as goodwill. Results for these acquired businesses were included in our accounts and results of operations since the date of acquisition, and the related goodwill was allocated entirely to the completion and production services business segment. The following table summarizes our preliminary purchase price allocations for these acquisitions as of June 30, 2008, each of which is yet to be finalized:


	KR Fishing
	& Rental		Frac Source			Totals
Net assets acquired:
Property, plant and equipment	$	2,673	$	42,265		$	44,938
Non-cash working capital		234		(1,806	)		(1,572	)
Net deferred tax assets		—		311			311
Long-term capital lease obligations		—		(279	)		(279	)
Intangible assets		330		6,810			7,140
Goodwill		6,227		15,068			21,295

Net assets acquired	$	9,464	$	62,369		$	71,833

Consideration:
Cash, net of cash and cash equivalents acquired	$	9,464	$	62,369		$	71,833

The purchase price of these acquired businesses was negotiated as an arm’s length transaction with the seller. We use various valuation techniques, including an earnings multiple approach, to evaluate acquisition targets. We also consider precedent transactions which we have undertaken and similar transactions of others in our industry. To determine the fair value of assets acquired, we generally retain third-party consultants to assist with the valuation of identifiable intangible assets and to evaluate property, plant and equipment acquired based upon, at minimum, the replacement cost of the assets. Working capital items are deemed to be acquired at fair market value.

We calculated the pro forma impact of the businesses we acquired on our operating results for the quarters and six months ended June 30, 2008 and 2007. The following pro forma results give effect to each of these acquisitions, assuming that each occurred on January 1, 2008 and 2007, as applicable. For purposes of this pro forma calculation, we use historical financial information obtained from the sellers and certain management assumptions. We assume debt service costs based on the actual cash investments, calculated at a rate of 7% per annum, less an assumed tax benefit calculated at our statutory rate of 35%. Each of these acquisitions related to our continuing operations, and thus had no pro forma impact on discontinued operations presented in the accompanying statements of operations.

In conjunction with the sale of a disposal group in May 2008, we received cash, as well as property, plant and equipment with a fair market value of $7,987. The receipt of this equipment has been treated as a non-cash item in the accompanying cash flow statement at June 30, 2008. To value these assets, a valuation was obtained from an independent third-party appraiser.


	Pro Forma Results
	Quarter Ended				Six Months Ended
	June 30,				June 30,
	2008		2007		2008		2007
Revenue	$	443,490	$	371,567	$	876,072	$	742,542
Income from continuing operations before taxes and minority interest	$	60,882	$	62,575	$	129,373	$	133,698
Net income from continuing operations	$	40,140	$	39,649	$	83,903	$	83,410

Earnings per share information:
Basic	$	0.55	$	0.55	$	1.15	$	1.16

Diluted	$	0.54	$	0.54	$	1.13	$	1.14

These pro forma results do not purport to be indicative of the results that would have been obtained had the transactions described above been completed on the indicated dates or that may be obtained in the future.

3. Accounts receivable:


	June 30,		December 31,
	2008		2007
Trade accounts receivable	$	267,062	$	251,361
Related party receivables		9,456		8,048
Unbilled revenue		47,934		41,334
Notes receivable		312		3,378
Other receivables		9,309		7,048

		334,073		311,169
Allowance for doubtful accounts		4,983		5,487

	$	329,090	$	305,682

4. Inventory:


	June 30,		December 31,
	2008		2007
Finished goods	$	21,123	$	22,235
Manufacturing parts, materials and other		14,398		9,312

		35,521		31,547
Inventory reserves		1,039		1,670

	$	34,482	$	29,877

5. Property, plant and equipment:


			Accumulated
June 30, 2008	Cost		Depreciation		Net Book Value
Land	$	10,001	$	—	$	10,001
Building		18,569		1,853		16,716
Field equipment		1,147,224		292,593		854,631
Vehicles		136,773		41,583		95,190
Office furniture and computers		15,539		6,451		9,088
Leasehold improvements		17,159		2,771		14,388
Construction in progress		107,883		—		107,883

	$	1,453,148	$	345,251	$	1,107,897


			Accumulated
December 31, 2007	Cost		Depreciation		Net Book Value
Land	$	9,259	$	—	$	9,259
Building		17,667		1,545		16,122
Field equipment		1,049,761		237,481		812,280
Vehicles		91,853		20,550		71,303
Office furniture and computers		12,391		4,212		8,179
Leasehold improvements		16,368		1,588		14,780
Construction in progress		81,267		—		81,267

	$	1,278,566	$	265,376	$	1,013,190

Construction in progress at June 30, 2008 and December 31, 2007 primarily included progress payments to vendors for equipment to be delivered in future periods and component parts to be used in final assembly of operating equipment, which in all cases were not yet placed into service at the time. For the quarter and six months ended June 30, 2008, we recorded capitalized interest of $1,598 and $2,646, respectively, related to assets that we are constructing for internal use and amounts paid to vendors under progress payments for assets that are being constructed on our behalf.

6. Notes payable:

We entered into a note arrangement to finance our annual insurance premiums for the policy term beginning December 1, 2007 and extending through April 30, 2009. As of December 31, 2007, we recorded a note payable totaling $15,354 and an offsetting prepaid asset which included a broker’s fee of approximately $625. Of this prepaid asset, $3,257 was recorded as a long-term asset at December 31, 2007. At June 30, 2008, this note balance totaled $5,414 and was classified as a current liability. We expect to repay this note payable in full prior to December 31, 2008.

7. Long-term debt:

The following table summarizes long-term debt as of June 30, 2008 and December 31, 2007:


	2008		2007
U.S. revolving credit facility (a)	$	127,400	$	160,000
Canadian revolving credit facility (a)		10,088		12,219
8.0% senior notes (b)		650,000		650,000
Subordinated seller notes		3,450		3,450
Capital leases and other		954		714

		791,892		826,383
Less: current maturities of long-term debt and capital leases		3,742		398

	$	788,150	$	825,985

	(a)		We maintain a credit agreement related to a syndicated senior secured credit facility (the “Credit Agreement”). The Credit Agreement was initially comprised of a $310,000 U.S. revolving credit facility that matures in December 2011 and a $40,000 Canadian revolving credit facility (with Integrated Production Services, Ltd., one of our wholly-owned subsidiaries, as the borrower thereof) that matures in December 2011. The Credit Agreement is secured by substantially all of our assets. On June 29, 2007, we amended our Credit Agreement in conjunction with the restructuring of certain legal entities for tax purposes with no material changes to the financial provisions or covenants. On October 19, 2007, we amended our Credit Agreement to increase the borrowing capacity of the U.S. revolving portion of the facility from $310,000 to $360,000 and to include a provision for a “commitment increase” clause, as defined in the Credit Agreement, which permits us to effect up to two separate increases in the aggregate commitments under the facility by designating a participating lender to increase its commitment, by mutual agreement, in increments of at least $50,000, with the aggregate of such commitment increases not to exceed $100,000, and in accordance with other provisions as stipulated in the amendment.

			Subject to certain limitations, we have the ability to elect how interest under the Credit Agreement will be computed. Interest under the Credit Agreement may be determined by reference to (1) the London Inter-bank Offered Rate, or LIBOR, plus an applicable margin between 0.75% and 1.75% per annum (with the applicable margin depending upon our ratio of total debt to EBITDA (as defined in the agreement)) or (2) the Base Rate (i.e., the higher of the Canadian bank’s prime rate or the CDOR rate plus 1.0%, in the case of Canadian loans or the greater of the prime rate and the federal funds rate plus 0.5%, in the case of U.S. loans), plus an applicable margin between 0.00% and 0.75% per annum. If an event of default exists under the Credit Agreement, advances will bear interest at the then-applicable rate plus 2%. Interest is payable quarterly for base rate loans and at the end of applicable interest periods for LIBOR loans, except that if the interest period for a LIBOR loan is six months, interest will be paid at the end of each three-month period.

			The Credit Agreement also contains various covenants that limit our and our subsidiaries’ ability to: (1) grant certain liens; (2) make certain loans and investments; (3) make capital expenditures; (4) make distributions; (5) make acquisitions; (6) enter into hedging transactions; (7) merge or consolidate; or (8) engage in certain asset dispositions. Additionally, the Credit Agreement limits our and our subsidiaries’ ability to incur additional indebtedness if: (1) we are not in pro forma compliance with all terms under the Credit Agreement, (2) certain covenants of the additional indebtedness are more onerous than the covenants set forth in the Credit Agreement, or (3) the additional indebtedness provides for amortization, mandatory prepayment or repurchases of senior unsecured or subordinated debt during the duration of the Credit Agreement with certain exceptions. The Credit Agreement also limits additional secured debt to 10% of our consolidated net worth (i.e., the excess of our assets over the sum of our liabilities plus the minority interests). The Credit Agreement contains covenants which, among other things, require us and our subsidiaries, on a consolidated basis, to maintain specified ratios or conditions as follows (with such ratios tested at the end of each fiscal quarter): (1) total debt to EBITDA, as defined in the Credit Agreement, of not more than 3.0 to 1.0 and (2) EBITDA, as defined, to total interest expense of not less than 3.0 to 1.0. We were in compliance with all debt covenants under the amended and restated Credit Agreement as of June 30, 2008.

			Under the Credit Agreement, we are permitted to prepay our borrowings.

			All of the obligations under the U.S. portion of the Credit Agreement are secured by first priority liens on substantially all of the assets of our U.S. subsidiaries as well as a pledge of approximately 66% of the stock of our first-tier foreign subsidiaries. Additionally, all of the obligations under the U.S. portion of the Credit Agreement are guaranteed by substantially all of our U.S. subsidiaries. All of the obligations under the Canadian portions of the Credit Agreement are secured by first priority liens on substantially all of the assets of our subsidiaries. Additionally, all of the obligations under the Canadian portions of the Credit Agreement are guaranteed by us as well as certain of our subsidiaries.

			If an event of default exists under the Credit Agreement, as defined, the lenders may accelerate the maturity of the obligations outstanding under the Credit Agreement and exercise other rights and remedies. While an event of default is continuing, advances will bear interest at the then-applicable rate plus 2%.

			Borrowings under the U.S. revolving facility bore interest at rates ranging from 4.16% to 5.25%, a weighted average interest rate of 4.22%, and the Canadian revolving credit facility bore interest at 5.0% at June 30, 2008. For the six months ended June 30, 2008, the weighted average interest rate on average borrowings under the amended Credit Agreement was 4.32%. There were letters of credit outstanding under the U.S. revolving portion of the facility totaling $37,669, which reduced the available borrowing capacity as of June 30, 2008. We incurred fees calculated at 1.25% of the total amount outstanding under letter of credit arrangements through June 30, 2008. Our available borrowing capacity under the U.S. and Canadian revolving facilities at June 30, 2008 was $194,931 and $29,912, respectively.

	(b)		On December 6, 2006, we issued 8.0% senior notes with a face value of $650,000 through a private placement of debt. These notes mature in 10 years, on December 15, 2016 and require semi-annual interest payments, paid in arrears and calculated based on an annual rate of 8.0%, on June 15 and December 15 of each year, commencing on June 15, 2007. There was no discount or premium associated with the issuance of these notes. The senior notes are guaranteed on a senior unsecured basis by all of our current domestic subsidiaries. The senior notes have covenants which, among other things: (1) limit the amount of additional indebtedness we can incur; (2) limit restricted payments such as a dividend; (3) limit our ability to incur liens or encumbrances; (4) limit our ability to purchase, transfer or dispose of significant assets; (5) purchase or redeem stock or subordinated debt; (6) enter into transactions with affiliates; (7) merge with or into other companies or transfer all or substantially all our assets; and (8) limit our ability to enter into sale and leaseback transactions. We have the option to redeem all or part of these notes on or after December 15, 2011. We can redeem 35% of these notes on or before December 15, 2009 using the proceeds of certain equity offerings. Additionally, we may redeem some or all of the notes prior to December 15, 2011 at a price equal to 100% of the principal amount of the notes plus a make-whole premium.

Pursuant to a registration rights agreement with the holders of our 8.0% senior notes, on June 1, 2007, we filed a registration statement on Form S-4 with the Securities and Exchange Commission which enabled these holders to exchange their notes for publicly registered notes with substantially identical terms. These holders exchanged 100% of the notes for publicly traded notes on July 25, 2007. On August 28, 2007, we entered into a supplement to the indenture governing the 8.0% senior notes, whereby additional domestic subsidiaries became guarantors under the indenture.

8. Stockholders’ equity:

(a) Stock-based Compensation—Stock Options:

We maintain option plans under which stock-based compensation could be granted to employees, officers and directors. Stock option grants under these plans have an exercise price based on the fair value of our common stock on the date of grant. These stock options may be exercised over a five or ten-year period and generally a third of the options vest on each of the first three anniversaries from the grant date. Upon exercise of stock options, we issue our common stock.

We account for our stock-based compensation awards pursuant to Statement of Financial Accounting Standards (“SFAS”) No. 123R, whereby we measure the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award, with limited exceptions, by using an option pricing model to determine fair value. We record stock compensation expense associated with our stock-based compensation awards pursuant to SFAS No. 123R in accordance with the transition guidance of that statement, as further described in our Annual Report on Form 10-K as of December 31, 2007.

On January 31, 2008, the Compensation Committee of our Board of Directors approved the annual grant of stock options and non-vested restricted stock to certain employees, officers and directors. Pursuant to this authorization, we issued 287,500 shares of non-vested restricted stock at a grant price of $15.90 per share. We expect to recognize compensation expense associated with this grant of non-vested restricted stock totaling $4,571 ratably over the three-year vesting period. In addition, we granted 345,000 stock options to purchase shares of our common stock at an exercise price of $15.90 per share. These stock options vest ratably over a three-year period. We will recognize compensation expense associated with these stock option grants over the vesting period in accordance with SFAS No. 123R. Further, we obtained shareholder approval in May 2008 to increase the shares available for grant through our stock compensation plans. Pursuant to this approval, we issued 302,856 shares of non-vested restricted stock during the quarter ended June 30, 2008, of which 289,400 shares had grant prices ranging from $29.88 to $32.08 per share and were granted to certain members of senior management and other employees and 13,456 shares had grant prices of $29.88 per share and were granted to our directors. The fair value of the stock options granted during the six months ended June 30, 2008 was determined by applying a Black-Scholes option pricing model based on the following assumptions:


	Six Months Ended
	June 30,
Assumptions:	2008
Risk-free rate	2.82% to 3.24%
Expected term (in years)		5.1
Volatility	16.7% to 24.5%

Calculated fair value per option		$4.39 to $7.27

We completed our initial public offering in April 2006. Prior to the quarter ended June 30, 2008, we did not have sufficient historical market data in order to determine the volatility of our common stock. In accordance with the provisions of SFAS No. 123R, we analyzed the market data of peer companies and calculated an average volatility factor based upon changes in the closing price of these companies’ common stock for a three-year period. This volatility factor was then applied as a variable to determine the fair value of our stock options granted prior to the quarter ended June 30, 2008. For the second quarter of 2008, we calculated an average volatility factor for our common stock for the period April 21, 2006 through June 30, 2008. This factor was used as a variable to calculate the value of stock options granted during the quarter ended June 30, 2008.

We projected a rate of stock option forfeitures based upon historical experience and management assumptions related to the expected term of the options. After adjusting for these forfeitures, we expect to recognize expense totaling $1,624 over the vesting period of these 2008 stock option grants. For the quarter and six months ended June 30, 2008, we have recognized expense related to these stock option grants totaling $123 and $198, respectively, which represents a reduction of net income before taxes. The impact on net income for the quarter and six months ended June 30, 2008 was a reduction of $82 and $129, respectively, resulting in no impact on diluted earnings per share as reported. The unrecognized compensation costs related to the non-vested portion of these awards was $1,426 as of June 30, 2008 and will be recognized over the applicable remaining vesting periods.

For the quarters ended June 30, 2008 and 2007, we recognized compensation expense associated with all stock option awards totaling $1,300 and $1,149, respectively, resulting in a reduction of net income of $858 and $725, respectively, and a $0.01 reduction in diluted earnings per share for each of the quarters ended June 30, 2008 and 2007. For the six months ended June 30, 2008 and 2007, we recognized compensation expense associated with all stock option awards totaling $2,566 and $2,259, respectively, resulting in a reduction of net income of $1,668 and $1,412, respectively, and a $0.02 and $0.01 reduction in diluted earnings per share for the six months ended June 30, 2008 and 2007, respectively. Total unrecognized compensation expense associated with outstanding stock option awards at June 30, 2008 was $7,272, or $4,509, net of tax.

The following tables provide a roll forward of stock options from December 31, 2007 to June 30, 2008 and a summary of stock options outstanding by exercise price range at June 30, 2008:


	Options Outstanding
				Weighted
				Average
				Exercise
	Number			Price
Balance at December 31, 2007		3,730,761		$	13.36
Granted		385,000		$	17.35
Exercised		(1,148,761	)	$	9.66
Cancelled		(120,994	)	$	20.11

Balance at June 30, 2008		2,846,006		$	15.12


	Options Outstanding						Options Exercisable
			Weighted		Weighted				Weighted		Weighted
	Outstanding at		Average		Average		Exercisable at		Average		Average
	June 30,		Remaining		Exercise		June 30,		Remaining		Exercise
Range of Exercise Price	2008		Life (months)		Price		2008		Life (months)		Price
$2.00		61,074		13	$	2.00		61,074		13	$	2.00
$4.48 — $4.80		84,610		17	$	4.75		84,610		17	$	4.75
$5.00		127,865		52	$	5.00		93,619		49	$	5.00
$6.69		622,666		81	$	6.69		463,240		82	$	6.69
$11.66		305,423		87	$	11.66		146,667		88	$	11.66
$15.90		345,000		115	$	15.90		—		—		—
$17.60 — $19.87		679,855		103	$	19.83		150,940		103	$	19.83
$22.55 — $24.07		534,513		94	$	23.95		277,335		94	$	23.98
$26.26 — $27.11		45,000		107	$	26.35		15,000		107	$	26.35
$29.88		40,000		119	$	29.88		—		—		—

		2,846,006		90	$	15.12		1,292,485		78	$	12.26

The total intrinsic value of stock options exercised during the quarter and six months ended June 30, 2008 was $10,428 and $11,757, respectively. The total intrinsic value of all vested outstanding stock options at June 30, 2008 was $31,232. Assuming all stock options outstanding at June 30, 2008 were vested, the total intrinsic value of all outstanding stock options would have been $60,613.

(b) Non-vested Restricted Stock:

We recognize compensation expense associated with grants of non-vested restricted stock based on the fair value of the shares on the date of grant and recorded ratably over the applicable vesting period. At

June 30, 2008, amounts not yet recognized related to non-vested restricted stock totaled $14,218, which represented the unamortized expense associated with awards of non-vested stock granted to employees, officers and directors under our compensation plans, including $12,529 related to grants during the six months ended June 30, 2008. We recognized compensation expense associated with non-vested restricted stock totaling $1,331 and $787 for the quarters ended June 30, 2008 and 2007, respectively, and $2,251 and $1,472 for the six months ended June 30, 2008 and 2007, respectively.

The following table summarizes the change in non-vested restricted stock from December 31, 2007 to June 30, 2008:


	Non-vested
	Restricted Stock
				Weighted
				Average
	Number			Grant Price
Balance at December 31, 2007		625,871		$	9.46
Granted		594,356		$	23.09
Vested		(135,395	)	$	14.65
Forfeited		(19,196	)	$	11.94

Balance at June 30, 2008		1,065,636		$	16.36

9. Earnings per share:

We compute basic earnings per share by dividing net income by the weighted average number of common shares outstanding during the period. Diluted earnings per common and potential common share includes the weighted average of additional shares associated with the incremental effect of dilutive employee stock options, non-vested restricted stock and contingent shares, as determined using the treasury stock method prescribed by SFAS No. 128, “Earnings Per Share.” The following table reconciles basic and diluted weighted average shares used in the computation of earnings per share for the quarters and six months ended June 30, 2008 and 2007:


	Quarter Ended				Six Months Ended
	June 30,				June 30,
	2008		2007		2008		2007
			(in thousands)
Weighted average basic common shares outstanding		73,171		71,916		72,866		71,711
Effect of dilutive securities:
Employee stock options		890		1,190		843		1,218
Non-vested restricted stock		346		261		350		266

Weighted average diluted common and potential common shares outstanding		74,407		73,367		74,059		73,195

We excluded the impact of anti-dilutive potential common shares from the calculation of diluted weighted average shares for the quarters and six months ended June 30, 2008 and 2007. If these potential common shares were included in the calculation, the impact would have been a decrease in diluted weighted average shares outstanding of 40,639 shares and 96,183 shares for the quarters ended June 30, 2008 and 2007, respectively, and a decrease in diluted weighted average shares outstanding of 194,498 shares and 224,648 shares for the six months ended June 30, 2008 and 2007, respectively.

10. Discontinued operations:

In May 2008, our Board of Directors authorized and committed to a plan to sell certain business assets located primarily in north Texas which included our product supply stores, certain drilling logistics assets and other completion and production services assets. Although this sale does not represent a material disposition of assets relative to our total assets as presented in the accompanying balance sheets, the disposal group does represent a significant portion of the assets and operations which were attributable to our product sales business segment for the periods presented, and therefore, was accounted for as a disposal group that is held for sale in accordance with SFAS No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets.” We revised our financial statements, pursuant to SFAS No. 144, and reclassified the assets and liabilities of the disposal group as held for sale as of the date of each balance sheet presented and removed the results of operations of the disposal group from net income from continuing operations,

and presented these separately as income from discontinued operations, net of tax, for each of the accompanying statements of operations. We ceased depreciating the assets of this disposal group in May 2008 and adjusted the net assets to the lower of carrying value or fair value less selling costs, which resulted in a pre-tax charge of approximately $200. In addition, we allocated $11,109 of goodwill associated with the original formation of Complete Production Services, Inc. to this business. Our company was formed from the combination of three entities under common control in September 2005, which resulted in goodwill of $93,792. Of this amount, $11,109 was deemed to be attributable to this disposal group and was impaired as of the date of the transaction. Thus, this amount has been included in the calculation of the loss on the sale of this disposal group.

On May 19, 2008, we completed the sale of the disposal group for $50,150 in cash and we received assets with a fair market value of $7,987. In addition, we retained the receivables and payables associated with the operating results of these entities as of the date of the sale. There is a potential working capital settlement, primarily associated with inventory, which is expected during the third quarter of 2008. The carrying value of the related net assets was approximately $51,200 on May 19, 2008, excluding allocated goodwill of $11,109. We recorded a loss of $6,782 associated with the sale of this disposal group, which represents the excess of the carrying value of the assets less selling costs over the sales price and a charge of approximately $2,610 related to income tax on the transaction. The income tax on the disposal was primarily attributable to the $11,109 of allocated goodwill which was non-deductible for tax purposes and resulted in a taxable gain on the disposal. We sold this disposal group to Select Energy Services, L.L.C., an oilfield service company located in Gainesville, Texas which is owned by a former officer of one of our subsidiaries. Pursuant to the agreement, we will sublet office space to Select Energy Services, L.L.C., and provide certain administrative functions for a period of one year at an agreed-upon rate for services per hour. Proceeds from the sale of this disposal group were used to repay outstanding borrowings under our U.S. revolving credit facility and for other general corporate purposes.

The following table summarizes operating results for the disposal group for the periods indicated:


	Period
	April 1, 2008					Period January 1,
	through			Quarter Ended		2008 through			Six Months Ended
	May 19,			June 30,		May 19,			June 30,
	2008			2007		2008			2007
Revenue	$	21,468		$	43,901	$	59,553		$	84,746
Income (loss) before taxes	$	(117	)	$	5,891	$	3,330		$	10,911
Net income (loss) before loss on disposal in 2008	$	(75	)	$	3,678	$	2,076		$	6,812
Net income (loss)	$	(6,857	)	$	3,678	$	(4,706	)	$	6,812

The captions related to discontinued operations in the accompanying balance sheet at December 31, 2007 were comprised of the following accounts:


	December 31,
	2007
Current assets held for sale:
Accounts receivable	$	23,003
Inventory		27,191
Other		113

	$	50,307


Long-term assets held for sale:
Property, plant and equipment, net	$	21,505
Goodwill		11,358
Intangible assets		187

	$	33,050


Current liabilities of held for sale operations:
Accounts payable	$	8,260
Accrued expenses		1,168
Other		277

	$	9,705


Long-term liabilities of held for sale operations:
Long-term deferred tax liabilities and other	$	2,085

	$	2,085

11. Segment information:

SFAS No. 131, “Disclosure About Segments of an Enterprise and Related Information,” establishes standards for the reporting of information about operating segments, products and services, geographic areas, and major customers. The method of determining what information to report is based on the way our management organizes the operating segments for making operational decisions and assessing financial performance. We evaluate performance and allocate resources based on net income (loss) from continuing operations before net interest expense, taxes, depreciation and amortization, minority interest and impairment loss (“EBITDA”). The calculation of EBITDA should not be viewed as a substitute for calculations under U.S. GAAP, in particular, with respect to net income. EBITDA calculated by us may not be comparable to the EBITDA calculation of another company.

We have three reportable operating segments: completion and production services (“C&PS”), drilling services and product sales. The accounting policies of our reporting segments are the same as those used to prepare our unaudited consolidated financial statements as of June 30, 2008. Inter-segment transactions are accounted for on a cost recovery basis.


			Drilling		Product
Quarter Ended June 30, 2008	C&PS		Services		Sales		Corporate			Total
Revenue from external customers	$	368,656	$	57,192	$	15,237	$	—		$	441,085
Inter-segment revenues	$	286	$	269	$	4,500	$	(5,055	)	$	—
EBITDA, as defined	$	107,536	$	15,512	$	3,532	$	(8,403	)	$	118,177
Depreciation and amortization	$	36,998	$	4,888	$	559	$	592		$	43,037

Operating income (loss)	$	70,538	$	10,624	$	2,973	$	(8,995	)	$	75,140
Capital expenditures	$	64,111	$	16,764	$	1,380	$	795		$	83,050

Quarter Ended June 30, 2007
Revenue from external customers	$	302,304	$	53,316	$	11,194	$	—		$	366,814
Inter-segment revenues	$	262	$	1,136	$	12,979	$	(14,377	)	$	—
EBITDA, as defined	$	99,606	$	16,589	$	2,411	$	(8,270	)	$	110,336
Depreciation and amortization	$	27,836	$	3,414	$	486	$	639		$	32,375

Operating income (loss)	$	71,770	$	13,175	$	1,925	$	(8,909	)	$	77,961
Capital expenditures	$	70,561	$	22,714	$	454	$	848		$	94,577

As of June 30, 2008
Segment assets	$	1,762,267	$	279,153	$	46,752	$	43,456		$	2,131,628

Six Months Ended June 30, 2008
Revenue from external customers	$	720,308	$	110,503	$	27,452	$	—		$	858,263
Inter-segment revenues	$	370	$	272	$	10,539	$	(11,181	)	$	—
EBITDA, as defined	$	219,712	$	27,728	$	6,822	$	(16,357	)	$	237,905
Depreciation and amortization	$	70,728	$	9,304	$	1,105	$	1,151		$	82,288

Operating income (loss)	$	148,984	$	18,424	$	5,717	$	(17,508	)	$	155,617
Capital expenditures	$	106,379	$	25,234	$	1,725	$	1,043		$	134,381

Six Months Ended June 30, 2007
Revenue from external customers	$	605,126	$	105,221	$	22,689	$	—		$	733,036
Inter-segment revenues	$	332	$	1,157	$	18,542	$	(20,031	)	$	—
EBITDA, as defined	$	202,126	$	32,839	$	4,980	$	(14,484	)	$	225,461
Depreciation and amortization	$	51,832	$	6,527	$	958	$	1,012		$	60,329

Operating income (loss)	$	150,294	$	26,312	$	4,022	$	(15,496	)	$	165,132
Capital expenditures	$	158,911	$	29,986	$	4,495	$	1,087		$	194,479

As of December 31, 2007
Segment assets	$	1,651,653	$	287,563	$	89,492	$	26,051		$	2,054,759

The following table reconciles segment information for our business segments as originally reported for the quarter and six months ended June 30, 2007, to the information revised for discontinued operations:


	Original		Discontinued		Revised
	Presentation		Operations		Presentation
Quarter Ended June 30, 2007
*Completion and production services:*
Revenue from external customers	$	307,212	$	4,908	$	302,304

EBITDA, as defined	$	101,180	$	1,574	$	99,606
Depreciation and amortization		28,134		298		27,836

Operating income	$	73,046	$	1,276	$	71,770

*Drilling services:*
Revenue from external customers	$	60,193	$	6,877	$	53,316

EBITDA, as defined	$	19,004	$	2,415	$	16,589
Depreciation and amortization		4,017		603		3,414

Operating income	$	14,987	$	1,812	$	13,175

*Product Sales:*
Revenue from external customers	$	43,310	$	32,116	$	11,194

EBITDA, as defined	$	5,440	$	3,029	$	2,411
Depreciation and amortization		702		216		486

Operating income	$	4,738	$	2,813	$	1,925


Six Months Ended June 30, 2007
*Completion and production services:*
Revenue from external customers	$	614,851	$	9,725	$	605,126

EBITDA, as defined	$	205,342	$	3,216	$	202,126
Depreciation and amortization		52,418		586		51,832

Operating income	$	152,924	$	2,630	$	150,294

*Drilling services:*
Revenue from external customers	$	118,589	$	13,368	$	105,221

EBITDA, as defined	$	37,072	$	4,233	$	32,839
Depreciation and amortization		7,652		1,125		6,527

Operating income	$	29,420	$	3,108	$	26,312

*Product Sales:*
Revenue from external customers	$	84,342	$	61,653	$	22,689

EBITDA, as defined	$	10,596	$	5,616	$	4,980
Depreciation and amortization		1,380		422		958

Operating income	$	9,216	$	5,194	$	4,022

We do not allocate net interest expense, tax expense or minority interest to the operating segments. The following table reconciles operating income as reported above to net income from continuing operations for the quarters and six months ended June 30, 2008 and 2007:


	Quarters Ended						Six Months Ended
	June 30,						June 30,
	2008			2007			2008			2007
Segment operating income	$	75,140		$	77,961		$	155,617		$	165,132
Interest expense		15,515			15,055			31,430			30,668
Interest income		(762	)		(316	)		(1,387	)		(528	)
Income taxes		20,544			23,322			43,956			50,615
Minority interest		—			(205	)		—			56

Net income from continuing operations	$	39,843		$	40,105		$	81,618		$	84,321

Changes in the carrying amount of goodwill by segment for the six months ended June 30, 2008 are summarized below:


				Drilling			Product
	C&PS			Services			Sales			Total
Balance at December 31, 2007	$	513,704		$	34,297		$	12,487		$	560,488
Impairment associated with discontinued operations (b)		(1,341	)		(1,324	)		(8,693	)		(11,358	)

Balance at December 31, 2007 (adjusted for discontinued operations)		512,393			32,973			3,794			549,130
Acquisitions		21,438			—			—			21,438

Contingency adjustment and other (a)		46			—			—			46
Foreign currency translation		(1,045	)		—			—			(1,045	)

Balance at June 30, 2008	$	532,802		$	32,973		$	3,794		$	569,569


(a)		The contingency adjustment represents additional costs associated with 2007 acquisitions.

(b)		See Note 10, Discontinued operations.

12. Legal matters and contingencies:

In the normal course of our business, we are a party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages or other remedies concerning our commercial operations, products, employees and other matters, including warranty and product liability claims and occasional claims by individuals alleging exposure to hazardous materials, on the job injuries and fatalities as a result of our products or operations. Many of the claims filed against us relate to motor vehicle accidents which can result in the loss of life or serious bodily injury. Some of these claims relate to matters occurring prior to our acquisition of businesses. In certain cases, we are entitled to indemnification from the sellers of the businesses.

Although we cannot know or predict with certainty the outcome of any claim or proceeding or the effect such outcomes may have on us, we believe that any liability resulting from the resolution of any of these matters to the extent not otherwise provided for or covered by insurance, will not have a material adverse effect on our financial position, results of operations or liquidity.

We have historically incurred additional insurance premium related to a cost-sharing provision of our general liability policy, and we cannot be certain that we will not incur additional costs until either existing claims become further developed or until the limitation periods expire for each respective policy year. Any such additional premiums should not have a material adverse effect on our financial position, results of operations or liquidity.

13. Guarantor and Non-Guarantor Condensed Consolidating Financial Statements:

On December 6, 2006, we issued 8.0% Senior Notes at a face value of $650,000 in a private placement transaction. On June 1, 2007, we filed a registration statement on Form S-4 with the SEC to register these 8.0% Senior Notes and became subject to the disclosure requirements of SEC Regulation S-X Rule 3-10(f). The following tables present the financial data required pursuant to SEC Regulation S-X Rule 3-10(f), which includes: (1) unaudited condensed consolidating balance sheets as of June 30, 2008 and December 31, 2007; (2) unaudited condensed consolidating statements of operations for the quarters ended June 30, 2008 and 2007; (3) unaudited condensed consolidating statements of operations for the six months ended June 30, 2008 and 2007; and (4) unaudited condensed consolidating statements of cash flows for the six months ended June 30, 2008 and 2007.

Condensed Consolidating Balance Sheet
June 30, 2008


				Guarantor		Non-guarantor		Eliminations/
	Parent			Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Current assets
Cash and cash equivalents	$	17,935		$	2,532	$	6,096	$	(8,844	)	$	17,719
Trade accounts receivable, net		2,071			295,989		31,030		—			329,090
Inventory, net		—			21,255		13,227		—			34,482
Prepaid expenses and other current assets		12,119			24,627		2,687		—			39,433

Total current assets		32,125			344,403		53,040		(8,844	)		420,724
Property, plant and equipment, net		5,085			1,033,585		69,227		—			1,107,897
Investment in consolidated subsidiaries		945,203			120,847		—		(1,066,050	)		—
Inter-company receivable		872,020			607		—		(872,627	)		—
Goodwill		82,683			452,777		34,109		—			569,569
Other long-term assets, net		15,089			14,723		3,626		—			33,438

Total assets	$	1,952,205		$	1,966,942	$	160,002	$	(1,947,521	)	$	2,131,628

Current liabilities
Current maturities of long-term debt	$	—		$	3,704	$	38	$	—		$	3,742
Accounts payable		(1,104	)		60,380		9,782		(8,844	)		60,214
Accrued liabilities		22,324			42,086		8,933		—			73,343
Accrued payroll and payroll burdens		2,975			17,474		1,333		—			21,782
Notes payable		5,414			—		—		—			5,414


			Guarantor		Non-guarantor		Eliminations/
	Parent		Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Taxes payable		—		—		1,786		—			1,786

Total current liabilities		29,609		123,644		21,872		(8,844	)		166,281
Long-term debt		777,400		593		10,157		—			788,150
Inter-company payable		—		872,020		607		(872,627	)		—
Deferred income taxes		116,185		25,482		6,519		—			148,186

Total liabilities		923,194		1,021,739		39,155		(881,471	)		1,102,617
Stockholders’ equity
Total stockholders’ equity		1,029,011		945,203		120,847		(1,066,050	)		1,029,011

Total liabilities and stockholders’ equity	$	1,952,205	$	1,966,942	$	160,002	$	(1,947,521	)	$	2,131,628

Condensed Consolidating Balance Sheet
December 31, 2007


			Guarantor		Non-guarantor		Eliminations/
	Parent		Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Current assets
Cash and cash equivalents	$	8,217	$	5,549	$	6,605	$	(6,747	)	$	13,624
Trade accounts receivable, net		62		276,706		28,914		—			305,682
Inventory, net		—		16,022		13,855		—			29,877
Prepaid expenses and other current assets		7,113		20,826		896		—			28,835
Current assets held for sale		—		50,307		—		—			50,307

Total current assets		15,392		369,410		50,270		(6,747	)		428,325
Property, plant and equipment, net		4,623		953,169		55,398		—			1,013,190
Investment in consolidated subsidiaries		850,238		114,529		—		(964,767	)		—
Inter-company receivable		894,356		371		—		(894,727	)		—
Goodwill		82,683		418,035		48,412		—			549,130
Other long-term assets, net		14,804		12,321		3,939		—			31,064
Long-term assets held for sale		—		33,050		—		—			33,050

Total assets	$	1,862,096	$	1,900,885	$	158,019	$	(1,866,241	)	$	2,054,759

Current liabilities
Current maturities of long-term debt	$	—	$	328	$	70	$	—		$	398
Accounts payable		1,364		53,159		8,631		(6,747	)		56,407
Accrued liabilities		10,254		39,355		7,516		—			57,125
Accrued payroll and payroll burdens		1,278		21,555		1,217		—			24,050
Notes payable		15,319		35		—		—			15,354
Taxes payable		—		—		6,506		—			6,506
Current liabilities of held for sale operations		—		9,705		—		—			9,705

Total current liabilities		28,215		124,137		23,940		(6,747	)		169,545
Long-term debt		810,000		3,690		12,295		—			825,985
Inter-company payable		—		894,356		371		(894,727	)		—
Deferred tax liabilities		93,557		26,379		6,885		—			126,821
Long-term liabilities of held for sale operations		—		2,085		—		—			2,085

Total liabilities		931,772		1,050,647		43,491		(901,474	)		1,124,436
Stockholders’ equity
Total stockholders’ equity		930,324		850,238		114,528		(964,767	)		930,323

Total liabilities and stockholders’ equity	$	1,862,096	$	1,900,885	$	158,019	$	(1,866,241	)	$	2,054,759

Condensed Consolidated Statement of Operations
Quarter Ended June 30, 2008


			Guarantor		Non-guarantor		Eliminations/
	Parent		Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Revenue:
Service	$	—	$	399,327	$	27,654	$	(1,133	)	$	425,848
Product		—		1,907		13,330		—			15,237

		—		401,234		40,984		(1,133	)		441,085
Service expenses		—		241,396		23,879		(1,133	)		264,142
Product expenses		—		1,484		9,246		—			10,730


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Selling, general and administrative expenses		8,402			36,059			3,575			—			48,036
Depreciation and amortization		366			39,538			3,133			—			43,037

Income from continuing operations before interest and taxes		(8,768	)		82,757			1,151			—			75,140
Interest expense		15,513			4,104			130			(4,232	)		15,515
Interest income		(4,296	)		(677	)		(21	)		4,232			(762	)
Equity in earnings of consolidated affiliates		(43,012	)		(1,656	)		—			44,668			—

Income from continuing operations before taxes		23,027			80,986			1,042			(44,668	)		60,387
Taxes		(9,958	)		31,116			(614	)		—			20,544

Income (loss) from continuing operations	$	32,985		$	49,870		$	1,656		$	(44,668	)	$	39,843
Income (loss) from discontinued operations (net of tax)		—			(6,857	)		—			—			(6,857	)

Net income (loss)	$	32,985		$	43,013		$	1,656		$	(44,668	)	$	32,986

Condensed Consolidated Statement of Operations
Quarter Ended June 30, 2007


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Revenue:
Service	$	—		$	335,745		$	20,779			(904	)	$	355,620
Product		—			1,415			9,779			—			11,194

		—			337,160			30,558			(904	)		366,814
Service expenses		—			180,715			17,533			(904	)		197,344
Product expenses		—			1,348			6,652			—			8,000
Selling, general and administrative expenses		8,632			39,135			3,367			—			51,134
Depreciation and amortization		377			29,566			2,432			—			32,375

Income from continuing operations before interest and taxes		(9,009	)		86,396			574			—			77,961
Interest expense		15,591			5,878			368			(6,782	)		15,055
Interest income		(6,803	)		(200	)		(95	)		6,782			(316	)
Equity in earnings of consolidated affiliates		(53,845	)		(497	)		—			54,342			—

Income from continuing operations before Taxes		36,048			81,215			301			(54,342	)		63,222
Taxes		(7,735	)		31,048			9			—			23,322

Income (loss) from continuing operations before minority interest		43,783			50,167			292			(54,342	)		39,900
Minority interest		—			—			(205	)		—			(205	)

Income from continuing operations		43,783			50,167			497			(54,342	)		40,105
Income (loss) from discontinued operations (net of tax)		—			3,678			—			—			3,678

Net income (loss)	$	43,783		$	53,845		$	497		$	(54,342	)	$	43,783

Condensed Consolidated Statement of Operations
Six Months Ended June 30, 2008


				Guarantor		Non-guarantor		Eliminations/
	Parent			Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Revenue:
Service	$	—		$	763,561	$	69,475	$	(2,225	)	$	830,811
Product		—			2,542		24,910		—			27,452

		—			766,103		94,385		(2,225	)		858,263
Service expenses		—			456,058		52,521		(2,225	)		506,354
Product expenses		—			1,916		16,634		—			18,550
Selling, general and administrative expenses		16,357			71,582		7,515		—			95,454
Depreciation and amortization		688			75,666		5,934		—			82,288

Income from continuing operations before interest and taxes		(17,045	)		160,881		11,781		—			155,617
Interest expense		31,704			7,434		308		(8,016	)		31,430


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Interest income		(8,096	)		(1,238	)		(69	)		8,016			(1,387	)
Equity in earnings of consolidated affiliates		(97,331	)		(8,865	)		—			106,196			—

Income from continuing operations before Taxes		56,678			163,550			11,542			(106,196	)		125,574
Taxes		(20,234	)		61,513			2,677			—			43,956

Income (loss) from continuing operations	$	76,912		$	102,037		$	8,865		$	(106,196	)	$	81,618
Income (loss) from discontinued operations (net of tax)		—			4,706			—			—			4,706

Net income (loss)	$	76,912		$	97,331		$	8,865		$	(106,196	)	$	76,912

Condensed Consolidated Statement of Operations
Six Months Ended June 30, 2007


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Revenue:
Service	$	—		$	652,166		$	60,334			(2,153	)	$	710,347
Product		—			1,760			20,929			—			22,689

		—			653,926			81,263			(2,153	)		733,036
Service expenses		—			350,646			45,269			(2,153	)		393,762
Product expenses		—			1,760			14,525			—			16,285
Selling, general and administrative expenses		14,846			75,988			6,694			—			97,528
Depreciation and amortization		574			55,156			4,599			—			60,329

Income from continuing operations before interest and taxes		(15,420	)		170,376			10,176			—			165,132
Interest expense		31,041			12,275			673			(13,321	)		30,668
Interest income		(13,380	)		(321	)		(148	)		13,321			(528	)
Equity in earnings of consolidated affiliates		(110,584	)		(6,924	)		—			117,508			—

Income from continuing operations before Taxes		77,503			165,346			9,651			(117,508	)		134,992
Taxes		(13,630	)		61,574			2,671			—			50,615

Income (loss) from continuing operations before minority interest		91,133			103,772			6,980			(117,508	)		84,377
Minority interest		—			—			56			—			56

Income from continuing operations		91,133			103,772			6,924			(117,508	)		84,321
Income (loss) from discontinued operations (net of tax)		—			6,812			—			—			6,812

Net income (loss)	$	91,133		$	110,584		$	6,924		$	(117,508	)	$	91,133

Condensed Consolidated Statement of Cash Flows
Six Months Ended June 30, 2008


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Cash provided by:
Net income	$	76,912		$	97,331		$	8,865		$	(106,196	)	$	76,912
Items not affecting cash:
Equity in earnings of consolidated affiliates		(97,331	)		(8,865	)		—			106,196			—
Depreciation and amortization		688			77,732			5,934			—			84,354
Other		(3,081	)		32,153			86			—			29,158
Changes in operating assets and liabilities, net of effect of acquisitions		45,967			(49,341	)		(4,950	)		(2,097	)		(10,421	)

Net cash provided by operating activities		23,155			149,010			9,935			(2,097	)		180,003
Investing activities:
Business acquisitions, net of cash acquired		—			(71,862	)		—			—			(71,862	)
Additions to property, plant and equipment		(1,040	)		(124,049	)		(9,292	)		—			(134,381	)
Inter-company receipts		11,227			—			—			(11,227	)		—
Proceeds from sale of discontinued operations		—			50,150			—			—			50,150


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Other		—			5,197			421			—			5,618

Net cash provided by (used for) investing activities		10,187			(140,564	)		(8,871	)		(11,227	)		(150,475	)
Financing activities:
Issuances of long-term debt		131,716			—			6,484			—			138,200
Repayments of long-term debt		(164,898	)		—			(8,222	)		—			(173,120	)
Repayments of notes payable		(9,940	)		—			—			—			(9,940	)
Inter-company borrowings (repayments)		—			(11,463	)		236			11,227			—
Proceeds from issuances of common stock		10,998			—			—			—			10,998
Other		8,500			—			—			—			8,500

Net cash provided by (used in) financing Activities		(23,624	)		(11,463	)		(1,502	)		11,227			(25,362	)
Effect of exchange rate changes on cash		—			—			(71	)		—			(71	)

Change in cash and cash equivalents		9,718			(3,017	)		(509	)		(2,097	)		4,095
Cash and cash equivalents, beginning of period		8,217			5,549			6,605			(6,747	)		13,624

Cash and cash equivalents, end of period	$	17,935		$	2,532		$	6,096		$	(8,844	)	$	17,719

Condensed Consolidated Statement of Cash Flows
For the Six Months Ended June 30, 2007


				Guarantor			Non-guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
	(in thousands)
Cash provided by:
Net income	$	91,133		$	110,584		$	6,924		$	(117,508	)	$	91,133
Items not affecting cash:
Equity in earnings of consolidated affiliates		(110,584	)		(6,924	)		—			117,508			—
Depreciation and amortization		574			57,289			4,599			—			62,462
Other		7,239			3,252			716			—			11,207
Changes in operating assets and liabilities, net of effect of acquisitions		27,341			(38,311	)		(14,410	)		502			(24,878	)

Net cash provided by operating activities		15,703			125,890			(2,171	)		502			139,924
Investing activities:
Business acquisitions		—			(40,468	)		—			—			(40,468	)
Additions to property, plant and equipment		(1,084	)		(188,143	)		(5,252	)		—			(194,479	)
Inter-company advances		(104,659	)		—			—			104,659			—
Other		—			3,302			538			—			3,840

Net cash used for investing activities		(105,743	)		(225,309	)		(4,714	)		104,659			(231,107	)
Financing activities:
Issuances of long-term debt		186,225			341			6,335			—			192,901
Repayments of long-term debt		(91,073	)		(535	)		(11,997	)		—			(103,605	)
Issuances (repayments) of notes payable		(14,604	)		—			—			—			(14,604	)
Inter-company borrowings (repayments)		—			93,751			10,908			(104,659	)		—
Proceeds from issuances of common stock		2,944			—			—			—			2,944
Other		4,599			—			—			—			4,599

Net cash provided by financing activities		88,091			93,557			5,246			(104,659	)		82,235
Effect of exchange rate changes on cash		—			—			(1,265	)		—			(1,265	)

Change in cash and cash equivalents		(1,949	)		(5,862	)		(2,904	)		502			(10,213	)
Cash and cash equivalents, beginning of period		6,517			9,533			7,312			(3,488	)		19,874

Cash and cash equivalents, end of period	$	4,568		$	3,671		$	4,408		$	(2,986	)	$	9,661

13. Recent accounting pronouncements and authoritative literature:

costs during the period the change occurred. SFAS No. 159 became effective on January 1, 2008. We have not elected to adopt the fair value option prescribed by SFAS No. 159 for assets and liabilities held as of June 30, 2008, but we will consider the provisions of SFAS No. 159 and may elect to apply the fair value option for assets or liabilities associated with future transactions.

In December 2007, the FASB issued SFAS No. 160, “Non-controlling Interests in Consolidating Financial Statements—an Amendment of ARB No. 51.” This pronouncement establishes accounting and reporting standards for non-controlling interests, commonly referred to as minority interests. Specifically, this statement requires that the non-controlling interest be presented as a component of equity on the balance sheet, and that net income be presented prior to adjustment for the non-controlling interests’ portion of earnings with the portion of net income attributable to the parent company and the non-controlling interest both presented on the face of the statement of operations. In addition, this pronouncement provides a single method of accounting for changes in the parent’s ownership interest in the non-controlling entity, and requires the parent to recognize a gain or loss in net income when a subsidiary with a non-controlling interest is deconsolidated. Additional disclosure items are required related to the non-controlling interest. This pronouncement becomes effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. The statement should be applied prospectively as of the beginning of the fiscal year that the statement is adopted. However, the disclosure requirements must be applied retrospectively for all periods presented. We are currently evaluating the impact that SFAS No. 160 may have on our financial position, results of operations and cash flows.

In December 2007, the FASB revised SFAS No. 141, “Business Combinations” which will replace that pronouncement in its entirety. While the revised statement will retain the fundamental requirements of SFAS No. 141, it will also require that all assets and liabilities and non-controlling interests of an acquired business be measured at their fair value, with limited exceptions, including the recognition of acquisition-related costs and anticipated restructuring costs separate from the acquired net assets. In addition, the statement provides guidance for recognizing pre-acquisition contingencies and states that an acquirer must recognize assets and liabilities assumed arising from contractual contingencies as of the acquisition date, measured at acquisition-date fair values, but must recognize all other contractual contingencies as of the acquisition date, measured at their acquisition-date fair values only if it is more likely than not that these contingencies meet the definition of an asset or liability in FASB Concepts Statement No. 6, “Elements of Financial Statements.” Furthermore, this statement provides guidance for measuring goodwill and recording a bargain purchase, defined as a business combination in which total acquisition-date fair value of the identifiable net assets acquired exceeds the fair value of the consideration transferred plus any non-controlling interest in the acquiree, and it requires that the acquirer recognize that excess in earnings as a gain attributable to the acquirer. This statement becomes effective at the beginning of the first annual reporting period beginning on or after December 15, 2008, and must be applied prospectively. We are currently evaluating the impact that this statement may have on our financial position, results of operations and cash flows.

In June 2008, the FASB issued a FASB Staff Position (“FSP”) No. EITF 03-6-1, “Determining Whether Instruments Granted in Share-Based Payment Transactions Are Participating Securities,” which states that unvested share-based awards which have nonforfeitable rights to participate in dividend distributions should be considered participating securities in order to calculate earnings per share in accordance with the “Two-Class Method” described in SFAS No. 128, “Earnings per Share.” This guidance becomes effective for fiscal years beginning after December 15, 2008, with retrospective application to prior periods. Early adoption is not permitted. We are currently evaluating the impact that this guidance may have on our financial position, results of operations and cash flows.

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

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 quarters and six months ended June 30, 2008 and 2007, included elsewhere herein. This discussion contains forward-looking statements based on our current expectations, assumptions, estimates and projections about us and the oil and gas industry. These forward-looking statements involve risks and uncertainties that may be outside of our control and could cause actual results to differ materially from those in the forward-looking statements. For examples of those risks and uncertainties, see the cautionary statement contained in Item 1A. “Risk Factors” included in our Annual Report on Form 10-K for the year ended December 31, 2007. Factors that could cause or contribute to such differences include, but are not limited to: market prices for oil and gas, the level of oil and gas drilling, economic and competitive conditions, capital expenditures, regulatory changes and other uncertainties. In light of these risks, uncertainties and assumptions, the forward-looking events discussed below may not occur. Unless otherwise required by law, we undertake no obligation to update publicly any forward-looking statements, even if new information becomes available or other events occur in the future.

The words “believe,” “may,” “estimate,” “continue,” “anticipate,” “intend,” “plan,” “expect” and similar expressions are intended to identify forward-looking statements. All statements other than statements of current or historical fact contained in this Quarterly Report on Form 10-Q are forward-looking statements.

References to “Complete,” the “Company,” “we,” “our” and similar phrases are used throughout this Quarterly Report on Form 10-Q and relate collectively to Complete Production Services, Inc. and its consolidated affiliates.

Overview

We are a leading provider of specialized services and products focused on helping oil and gas companies develop hydrocarbon reserves, reduce operating costs and enhance production. We focus on basins within North America that we believe have attractive long-term potential for growth, and we deliver targeted, value-added services and products required by our customers within each specific basin. We believe our range of services and products positions us to meet the many needs of our customers at the wellsite, from drilling and completion through production and eventual abandonment. We manage our operations from regional field service facilities located throughout the U.S. Rocky Mountain region, Texas, Oklahoma, Louisiana, Arkansas, Kansas, North Dakota, western Canada, Mexico and Southeast Asia.

We operate in three business segments:

Completion and Production Services. Through our completion and production services segment, we establish, maintain and enhance the flow of oil and gas throughout the life of a well. This segment is divided into the following primary service lines:

	•		Intervention Services. Well intervention requires the use of specialized equipment to perform an array of wellbore services. Our fleet of intervention service equipment includes coiled tubing units, pressure pumping units, nitrogen units, well service rigs, snubbing units and a variety of support equipment. Our intervention services provide customers with innovative solutions to increase production of oil and gas.

	•		Downhole and Wellsite Services. Our downhole and wellsite services include electric-line, slickline, production optimization, production testing, rental and fishing services. We also offer several proprietary services and products that we believe create significant value for our customers.

	•		Fluid Handling. We provide a variety of services to help our customers obtain, move, store and dispose of fluids that are involved in the development and production of their reservoirs. Through our fleet of specialized trucks, frac tanks and other assets, we provide fluid transportation, heating, pumping and disposal services for our customers.

Drilling Services. Through our drilling services segment, we provide services and equipment that initiate or stimulate oil and gas production by providing land drilling, specialized rig logistics and site preparation throughout our service area. Our drilling rigs primarily operate in and around the Barnett Shale region of north Texas.

Product Sales. We provide oilfield service equipment and refurbishment of used equipment through our Southeast Asia business, and we provide repair work and fabrication services for our customers at a business located in Gainesville, Texas.

Substantially all service and rental revenue we earn is based upon a charge for a period of time (an hour, a day, a week) for the actual period of time the service or rental is provided to our customer. Product sales are recorded when the actual sale occurs and title or ownership passes to the customer.

General

The primary factor influencing demand for our services and products is the level of drilling, completion and maintenance activity of our customers, which in turn, depends on current and anticipated future oil and gas prices, production depletion rates and the resultant levels of cash flows generated and allocated by our customers to their drilling, completion and maintenance budgets. As a result, demand for our services and products is cyclical, substantially depends on activity levels in the North American oil and gas industry and is highly sensitive to current and expected oil and natural gas prices.

We believe there is a correlation between the number of active drilling rigs and the level of spending for exploration and development of new and existing hydrocarbon reserves by our customers in the oil and gas industry. These spending levels are a primary driver of our business, and we believe that our customers tend to invest more in these activities when oil and gas prices are at higher levels or are increasing. The following tables summarize average North American drilling and well service rig activity, as measured by Baker Hughes Incorporated (“BHI”) and the Weatherford/AESC Service Rig Count for “Active Rigs,” respectively.

AVERAGE RIG COUNTS


	Quarter		Quarter		Six Months		Six Months
	Ended		Ended		Ended		Ended
	6/30/08		6/30/07		6/30/08		6/30/07
BHI Rotary Rig Count:
U.S. Land		1,797		1,680		1,755		1,666
U.S. Offshore		67		77		62		80

Total U.S		1,864		1,757		1,817		1,746
Canada		166		144		341		333

Total North America		2,030		1,901		2,158		2,079

Source: BHI (www.BakerHughes.com)


	Quarter		Quarter		Six Months		Six Months
	Ended		Ended		Ended		Ended
	6/30/08		6/30/07		6/30/08		6/30/07
Weatherford/AESC Service Rig Count (Active Rigs):
United States		2,533		2,381		2,498		2,375
Canada		632		491		674		622

Total North America		3,165		2,872		3,172		2,997

Source: Weatherford/AESC Service Rig Count for “Active Rigs”

Outlook

Our growth strategy includes a focus on internal growth in the basins in which we currently operate and we seek to maximize our equipment utilization, add additional like-kind equipment and expand service and product offerings. In addition, we identify new basins in which to replicate this approach. We also augment our internal growth through strategic acquisitions.

Strategic acquisitions are an integral part of our growth strategy. We consider acquisitions that will add to our service offerings in a current operating area or that will expand our geographical footprint into a targeted basin. We invested $9.5 million to acquire a fishing, rental and foam unit services business in February 2008, and $62.4 million, net of cash acquired, to acquire a pressure pumping business in north Texas in April 2008 (see “—Acquisitions”).

During the six months ended June 30, 2008 and 2007, we invested $134.4 million and $194.5 million, respectively, in equipment additions and other capital expenditures. We originally planned to spend approximately $150.0 million on capital expenditures for 2008 compared to actual capital expenditures in 2007 of $372.6 million. This decrease in planned capital expenditures for 2008 was due to concerns of potential equipment over-capacity in the oil and gas industry in the markets in which we serve. However, due to more favorable market conditions and planned expansion into the Haynesville Shale area of Louisiana and Bakken Shale area of North Dakota, we have increased our capital expenditure projection for 2008 to approximately $250.0 million. Our capital expenditures for the twelve months ended June 30, 2008 were $312.5 million, the majority of which was spent for growth capital. We expect to continue to benefit from equipment placed into service during the past twelve months, assuming that utilization of our equipment remains at current levels or higher. However, our future results remain subject to the risks described in our Annual Report on Form 10-K for the year ended December 31, 2007.

Our customers are directly impacted by the volatility of commodity prices in the oil and gas industry, which affects their spending levels, and directly impacts the use of oilfield service providers. As we have evaluated our business environment over recent periods, we believe the following trends have emerged: (1) our competitors have placed additional equipment into service in the markets in which we operate; (2) we have experienced pricing pressure in certain geographic areas for certain business lines due to competitive market forces; (3) oilfield activity is steady and rig counts are favorable due to relatively high oil and gas commodity prices; (4) fuel and labor costs have risen and inflationary forces may continue to increase our operating costs in the short-term, which, in turn, may require additional pricing initiatives in the form of fuel surcharges or higher pricing for our services; and (5) our customers are investing in unconventional resource plays, which may require service companies to provide newer, more complex equipment and to possess more technical expertise to assist the customer to explore and develop these resource plays.

We, and many of our competitors, have invested in new equipment over the past several years, some of which requires long lead times to manufacture. As more of this equipment is placed into service, there could be excess capacity in the industry, which we believe may negatively impact our utilization rates and pricing for certain service offerings. In addition, as new equipment enters the market, we must compete for employees to crew the equipment, which puts inflationary pressure on labor costs. Our equipment fleet is relatively new, as we made significant investments in new equipment over the past two years and expect to continue to invest in equipment to the extent that we expect demand to remain high for certain of our service offerings, in particular, our pressure pumping, well service and coiled tubing services. We continue to monitor our equipment utilization and poll our customers to assess demand levels. As more equipment enters the marketplace, we believe our customers will increasingly rely upon service providers with local knowledge and expertise, which we believe we have and which constitutes a fundamental aspect of our strategic acquisition growth strategy.

We continue to believe that the overall long-term outlook for our business remains favorable from an activity perspective, particularly in the basins in which we operate and in the basins in which we anticipate future expansion, including the Haynesville Shale area of Louisiana and the Bakken Shale area of North Dakota. We believe that the fundamentals in our markets are good, and we expect to continue to invest in these markets. In April 2008, we made an acquisition of a pressure pumping business in north Texas which increased the size of our pressure pumping operation in that area (see “—Acquisitions”) and we are investing in the start-up of frac services in the emerging resource play in the Bakken Shale area of North Dakota. We believe that pricing for our products and services will remain relatively steady during the short-term and may improve for many of our business lines during the remainder of 2008. Our customers have indicated that they are optimistic about activity levels for the remainder of 2008, and we believe we have the technical

expertise and operational capabilities to assist these customers to achieve their production and development goals.

Acquisitions

During the period from January 1, 2008 through April 30, 2008, we acquired substantially all the assets of two oilfield service companies for $71.8 million in cash, net of cash acquired. These acquisitions are subject to final working capital adjustments.

	•		On February 29, 2008, we acquired substantially all the assets of KR Fishing & Rental, Inc., for $9.5 million in cash, resulting in goodwill of $6.4 million. KR Fishing & Rental, Inc. is a provider of fishing, rental and foam unit services in the Piceance Basin and the Raton Basin, and is based in Rangely, Colorado. We believe this acquisition complements our completion and production services business in the Rocky Mountain region.

	•		On April 15, 2008, we acquired all the outstanding common stock of Frac Source Services, Inc., a provider of pressure pumping services to customers in the Barnett Shale of north Texas, for $62.4 million in cash, net of cash acquired, which includes a working capital adjustment of $1.6 million. Upon closing this transaction, we entered into a contract with one of our major customers to provide pressure pumping services in the Barnett Shale utilizing three frac fleets under a contract with a term that extends up to three years from the date each fleet is placed into service. We expect to spend an additional $20.0 million in 2008 on capital equipment related to these contracted frac fleets. Thus, we expect our total investment in this operation to be approximately $82.4 million. The initial purchase price allocation associated with this acquisition has not yet been finalized. We believe this acquisition expands our pressure pumping business in north Texas and that the related contract provides a stable revenue stream from which to expand our pressure pumping business outside of this region.

We accounted for these acquisitions using the purchase method of accounting, whereby the purchase price was allocated to the fair value of net assets acquired, including intangibles and property, plant and equipment at depreciated replacement costs, with the excess recorded as goodwill. Results for each of these acquisitions were included in our accounts and results of operations since the date of acquisition, and goodwill associated with these acquisitions was allocated entirely to the completion and production services business segment.

In May 2008, our Board of Directors authorized and committed to a plan to sell certain operations in the Barnett Shale region of north Texas, consisting primarily of our supply store business, as well as certain non-strategic drilling logistics assets and other completion and production services assets. On May 19, 2008, we sold these operations to Select Energy Services, L.L.C., a company owned by a former officer of one of our subsidiaries, for which we received proceeds of $50.2 million and assets with a fair market value of $8.0 million. The carrying value of the net assets sold was approximately $51.2 million, excluding $11.1 million of allocated goodwill associated with the combination that formed Complete Production Services, Inc. in September 2005. We recorded a loss on the sale of this disposal group totaling approximately $6.8 million, which included $2.6 million related to income taxes. In accordance with the sales agreement, we agreed to sublet office space to Select Energy, Inc. and to provide certain administrative services for an initial term of one year, at an agreed-upon rate.

Critical Accounting Policies and Estimates

The preparation of our consolidated financial statements in conformity with U.S. GAAP requires the use of estimates and assumptions that affect the reported amount of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, and provide a basis for making judgments about the carrying value of assets and liabilities that are not readily available through open market quotes. Estimates and assumptions are reviewed periodically, and actual results may differ from those estimates under different assumptions or conditions. We must use our judgment related to uncertainties in order to make these estimates and assumptions.

For a description of our critical accounting policies and estimates as well as certain sensitivity

disclosures related to those estimates, see our Annual Report on Form 10-K for the year ended December 31, 2007. Our critical accounting policies and estimates have not changed materially during the six months ended June 30, 2008.

Results of Operations (Continuing Operations)


										Percent
	Quarter			Quarter			Change			Change
	Ended			Ended			2008/			2008/
	6/30/08			6/30/07			2007			2007
	(unaudited, in thousands)
Revenue:
Completion and production services	$	368,656		$	302,304		$	66,352			22	%
Drilling services		57,192			53,316			3,876			7	%
Product sales		15,237			11,194			4,043			36	%

Total	$	441,085		$	366,814		$	74,271			20	%


EBITDA:
Completion and production services	$	107,536		$	99,606		$	7,930			8	%
Drilling services		15,512			16,589			(1,077	)		(6	%)
Product sales		3,532			2,411			1,121			46	%
Corporate		(8,403	)		(8,270	)		(133	)		2	%

Total	$	118,177		$	110,336		$	7,841			7	%


										Percent
	Six Months			Six Months			Change			Change
	Ended			Ended			2008/			2008/
	6/30/08			6/30/07			2007			2007
	(unaudited, in thousands)
Revenue:
Completion and production services	$	720,308		$	605,126		$	115,182			19	%
Drilling services		110,503			105,221			5,282			5	%
Product sales		27,452			22,689			4,763			21	%

Total	$	858,263		$	733,036		$	125,227			17	%


EBITDA:
Completion and production services	$	219,712		$	202,126		$	17,586			9	%
Drilling services		27,728			32,839			(5,111	)		(16	%)
Product sales		6,822			4,980			1,842			37	%
Corporate		(16,357	)		(14,484	)		(1,873	)		13	%

Total	$	237,905		$	225,461		$	12,444			6	%

“Corporate” includes amounts related to corporate personnel costs, other general expenses and stock-based compensation charges.

“EBITDA” consists of net income (loss) from continuing operations before net interest expense, taxes, depreciation and amortization, minority interest and impairment loss. EBITDA is a non-GAAP measure of performance. We use EBITDA as the primary internal management measure for evaluating performance and allocating additional resources. The following table reconciles EBITDA for the quarters ended March 31, 2008 and 2007 to the most comparable U.S. GAAP measure, operating income (loss).

Reconciliation of EBITDA to Most Comparable U.S. GAAP Measure—Operating Income (Loss)


	Completion
	and
	Production		Drilling		Product
	Services		Services		Sales		Corporate			Total
	(unaudited, in thousands)
Quarter Ended June 30, 2008
EBITDA, as defined	$	107,536	$	15,512	$	3,532	$	(8,403	)	$	118,177
Depreciation and amortization	$	36,998	$	4,888	$	559	$	592		$	43,037

Operating income (loss)	$	70,538	$	10,624	$	2,973	$	(8,995	)	$	75,140


	Completion
	and
	Production		Drilling		Product
	Services		Services		Sales		Corporate			Total
	(unaudited, in thousands)
Quarter Ended June 30, 2007
EBITDA, as defined	$	99,606	$	16,589	$	2,411	$	(8,270	)	$	110,336
Depreciation and amortization	$	27,836	$	3,414	$	486	$	639		$	32,375

Operating income (loss)	$	71,770	$	13,175	$	1,925	$	(8,909	)	$	77,961


Six Months Ended June 30, 2008
EBITDA, as defined	$	219,712	$	27,728	$	6,822	$	(16,357	)	$	237,905
Depreciation and amortization	$	70,728	$	9,304	$	1,105	$	1,151		$	82,288

Operating income (loss)	$	148,984	$	18,424	$	5,717	$	(17,508	)	$	155,617


Six Months Ended June 30, 2007
EBITDA, as defined	$	202,126	$	32,839	$	4,980	$	(14,484	)	$	225,461
Depreciation and amortization	$	51,832	$	6,527	$	958	$	1,012		$	60,329

Operating income (loss)	$	150,294	$	26,312	$	4,022	$	(15,496	)	$	165,132

Below is a detailed discussion of our operating results by segment for these periods.

Quarter and Six Months Ended June 30, 2008 Compared to the Quarter and Six Months Ended June 30, 2007 (Unaudited)

Revenue

Revenue from continuing operations for the quarter ended June 30, 2008 increased by $74.3 million, or 20%, to $441.1 million from $366.8 million for the same period in 2007. Revenue from continuing operations for the six months ended June 30, 2008 increased $125.2 million, or 17%, to $858.3 million from $733.0 million for the same period in 2007. The changes by segment were as follows:

	•		Completion and Production Services. Segment revenue increased $66.4 million, or 22% for the quarter, and $115.2 million, or 19% for the six months, primarily due to revenues earned as a result of additional capital investment in our coiled tubing, pressure pumping, well servicing, rental and fluid-handling businesses in 2007 and during the six months ended June 30, 2008. We experienced favorable results for our pressure pumping, fluid handling, well service and Mexican coiled tubing businesses, when comparing the first six months of 2008 to the same period in 2007. In addition, we acquired a small fishing and rental business in February 2008 and a pressure pumping business in April 2008, each of which provided incremental revenues for 2008. During 2007, we completed a series of small acquisitions which provided incremental revenues for 2008 compared to 2007 due to the timing of those acquisitions. These increases were partially offset by lower pricing and utilization for some of our business lines in certain geographic markets.

	•		Drilling Services. Segment revenue increased $3.9 million, or 7% for the quarter, and $5.3 million, or 5% for the six months, primarily due to additional capital invested in our contract drilling and drilling logistics businesses in 2007 and into 2008, somewhat offset by lower pricing and lower utilization of our equipment during early 2008 compared to the same period in 2007. The lower utilization resulted from less rig moving activity during early 2008 and an increase in equipment placed into service by our competitors in the markets we serve. Pricing and utilization improved during the second quarter of 2008 compared to the first quarter of 2008.

	•		Product Sales. Segment revenue increased $4.0 million, or 36% for the quarter, and $4.8 million, or 21% for the six months, due primarily to the sales mix and the timing of product sales and equipment refurbishment for our Southeast Asian business, which tends to be project-specific. We also had a larger volume of third-party sales at our repair and fabrication shop in north Texas during 2008 compared to the same period in 2007.

Service and Product Expenses

Service and product expenses include labor costs associated with the execution and support of our services, materials used in the performance of those services and other costs directly related to the support and maintenance of equipment. These expenses increased $69.5 million, or 34%, to $274.9 million for the

quarter ended June 30, 2008 from $205.3 million for the quarter ended June 30, 2007. For the six months ended June 30, 2008, service and product expenses increased $114.9 million, or 28%, to $524.9 million from $410.0 million for the same period in 2007. The following table summarizes service and product expenses as a percentage of revenues for the quarters and six months ended June 30, 2008 and 2007:

Service and Product Expenses as a Percentage of Revenue


	Quarter Ended									Six Months Ended
Segment:	6/30/08			6/30/07			Change			6/30/08			6/30/07			Change
Completion and production services		63	%		55	%		(8	)%		61	%		55	%		(6	)%
Drilling services		66	%		58	%		(8	)%		68	%		58	%		(10	)%
Product sales		70	%		72	%		2	%		68	%		72	%		4	%
Total		62	%		56	%		(6	)%		61	%		56	%		(5	)%

Service and product expenses as a percentage of revenue increased for the quarter and six months ended June 30, 2008 compared to the same period in 2007. Margins by business segment were impacted by acquisitions, pricing, utilization and costs.

	•		Completion and Production Services. The increase in service and product expenses as a percentage of revenue for this business segment reflects higher operating costs in 2008, especially labor and fuel costs. Our equipment utilization rates in some markets in which we operate have declined for certain business lines, such as our rental business, when comparing the first half of 2008 to the same period in 2007. We have also experienced pricing pressure for many of our service lines throughout 2007 and into 2008, resulting in less favorable operating margins on a year-over-year basis. In our pressure pumping business, we have experienced higher sand and cement costs. During the second quarter of 2008, we incurred additional costs associated with the start-up of a pressure pumping and fracing business in the Bakken Shale area of North Dakota. Although pricing for the second quarter of 2008 was less favorable in some markets than in the prior year, we were able to obtain some pricing considerations, such as fuel surcharges, which improved our margins for the quarter relative to the first quarter of 2008. Our results for this business segment were also impacted by the acquisitions of Frac Source and KR Fishing and Rental, Inc. during 2008.

	•		Drilling Services. The increase in service and product expenses as a percentage of revenue for this business segment resulted from decline in margin during 2008 compared to 2007 due to: (1) lower pricing for our contract drilling and drilling logistics businesses, (2) higher operating costs associated primarily with labor and fuel, (3) lower utilization of our equipment, specifically impacting our drilling rigs business, due primarily to more market competition, as our competitors have recently deployed additional rigs into the markets we serve. For the second quarter of 2008 compared to the first quarter of 2008, our margins improved for our drilling services business as demand for our drilling logistics business increased, and the increase in revenues offset a larger percentage of our fixed costs for this business segment. In addition, our contract drilling business experienced higher utilization and improved margins during the second quarter of 2008 compared to the prior quarter.

	•		Product Sales. The decrease in service and product expenses as a percentage of revenue for the products segments was primarily due to the timing of equipment sales and refurbishment associated with our Southeast Asian operations and the product mix associated with our fabrication and repair business located in Gainesville, Texas.

Selling, General and Administrative Expenses

Selling, general and administrative expenses include salaries and other related expenses for our selling, administrative, finance, information technology and human resource functions. Selling, general and administrative expenses decreased $3.1 million, or 6%, for the quarter ended June 30, 2008 to $48.0 million from $51.1 million during the quarter ended June 30, 2007. For the six months ended June 30, 2008, selling, general and administrative expense decreased $2.1 million, or 2%, to $95.5 million from $97.5 million for the six months ended June 30, 2007. These expense declines were due primarily to lower self insurance costs in 2008 compared to 2007, resulting from favorable claims experience, and a one-time $1.6 million charge incurred in June 2007 associated with the cost sharing provision of an insurance policy. In addition, we experienced lower bad debt expense and a decline in the loss on fixed asset disposals during the six months ended June 30, 2008 compared to the same period in 2007.

Partially offsetting these expense declines was an increase in selling, general and administrative expense associated with business acquisitions. As a percentage of revenues, selling, general and administrative expense was 11% and 13% for the six months ended June 30, 2008 and 2007, respectively.

Depreciation and Amortization

Depreciation and amortization expense increased $10.7 million, or 33%, to $43.0 million for the quarter ended June 30, 2008 from $32.4 million for the quarter ended June 30, 2007. For the six months ended June 30, 2008, depreciation and amortization expense increased $22.0 million to $82.3 million from $60.3 million for the six months ended June 30, 2007. The increases in depreciation and amortization expense resulted from placing into service much of the equipment that was purchased during the twelve months ended June 30, 2008, which totaled approximately $312.5 million. In addition, we recorded depreciation and amortization expense related to assets associated with businesses acquired in 2007 and two businesses acquired in 2008, which may not have contributed a full-quarter of depreciation expense during the respective periods in 2007 due to the timing of the acquisitions. Amortization expense increased during the quarter and six months ended June 30, 2008 compared to the same periods in 2007 as a result of the amortization of new intangible assets associated with business acquisitions in 2007 and 2008, especially the Frac Source acquisition in April 2008, which contributed $6.8 million of intangible assets. As a percentage of revenue, depreciation and amortization expense increased to 10% from 8% for the six months ended June 30, 2008 and 2007, respectively. We expect depreciation and amortization expense as a percentage of revenue to continue to remain higher than in recent years as we continue to place equipment into service.

Interest Expense

Interest expense was consistent for the quarters ended June 30, 2008 and 2007. For the six months ended June 30, 2008, interest expense increased $0.8 million, or 3%, to $31.4 million from $30.7 million for the same period in 2007. The increase in interest expense was attributable to an increase in the average amount of debt outstanding during the first half of 2008, offset by lower interest rates in 2008 compared to 2007. The weighted-average interest rate of borrowings outstanding at June 30, 2008 and 2007 was 7.4% and 7.8%, respectively.

Taxes

Tax expense is comprised of current income taxes and deferred income taxes. The current and deferred taxes added together provide an indication of an effective rate of income tax. Tax expense was 34.0% and 36.9% of pretax income for the quarters ended June 30, 2008 and 2007, respectively, and 35.0% and 37.5% for the six months ended June 30, 2008 and 2007, respectively. The decrease in the effective tax rate in 2008 compared to 2007 related to: (1) the impact of state and provincial taxes, (2) the incremental benefit of the domestic production activities deduction, and (3) tax rate differentials in the jurisdictions in which we operate and the mix of earnings for the respective periods in those jurisdictions.

Discontinued Operations

We recorded a loss of $6.8 million on May 19, 2008 associated with the sale of certain operating assets primarily in north Texas including our supply store business, certain drilling logistics assets and other completion and production services assets. This disposal group provided comparable operating results in 2008 and 2007 prior to the loss on disposal.

Liquidity and Capital Resources

Our primary liquidity needs are to fund capital expenditures, such as expanding our coiled tubing, wireline and production testing fleets, pressure pumping fleets and fluid handling equipment; increasing and replacing rental tool and well service rigs; and funding general working capital needs. In addition, we need capital to fund strategic business acquisitions. Our primary sources of funds have historically been cash flow from operations, proceeds from borrowings under bank credit facilities, a private placement of debt which was subsequently exchanged for publicly registered debt and the issuance of equity securities in our initial public offering on April 26, 2006. In addition, we received $50.2 million from the sale of certain

assets primarily associated with our supply store business based in the Barnett Shale of north Texas in May 2008.

We anticipate that we will rely on cash generated from operations, borrowings under our amended revolving credit facility, future debt offerings and/or future public equity offerings to satisfy our liquidity needs. We believe that funds from these sources should be sufficient to meet both our short-term working capital requirements and our long-term capital requirements. We believe that our operating cash flows and availability under our revolving credit facility will be sufficient to fund our operations for the next twelve months. Our ability to fund planned capital expenditures and to make acquisitions will depend upon our future operating performance, and more broadly, on the availability of equity and debt financing, which will be affected by prevailing economic conditions in our industry, and general financial, business and other factors, some of which are beyond our control.

The following table summarizes cash flows by type for the periods indicated (in thousands):


	Six Months Ended
	June 30,
	2008			2007
Cash flows provided by (used in):
Operating activities	$	180,003		$	139,924
Investing activities		(150,475	)		(231,107	)
Financing activities		(25,362	)		82,235

Net cash provided by operating activities increased $40.1 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007. This increase in operating cash flows in 2008 reflects an increase in cash receipts due to an increase in oilfield activity which resulted in increased revenues, partially offset by the use of cash to pay higher operating costs due to inflationary factors, specifically payroll and fuel costs. In addition, our operating cash flows were impacted by the timing of business acquisitions throughout 2007 and during the six months ended June 30, 2008.

Net cash used in investing activities declined by $80.6 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007, primarily due to a decline in capital expenditures for equipment in 2008. Due to concerns of potential equipment over-capacity in the oil and gas industry in the markets in which we serve, we reduced our capital spending plan for 2008 and focused our efforts on equipment investments which expand our strategic growth initiatives. In response to improved market conditions during 2008 evidenced by an increase in active rig counts, our Board of Directors increased our expected capital expenditures levels for 2008 from $150.0 million to $250.0 million in June 2008. In addition, we received proceeds of $50.2 million from the sale of a disposal group in May 2008. These declines were partially offset by a $31.4 million increase in funds invested in business acquisitions during the six months ended June 30, 2008 compared to the same period in 2007. We continue to expand our current business and enter new markets through acquisitions. We expect to continue to evaluate acquisition opportunities for the foreseeable future, and expect that new acquisitions will provide incremental cash flows.

Net cash used by financing activities was $25.4 million for the six months ended June 30, 2008 compared to net cash provided by financing activities of $82.2 million for the six months ended June 30, 2007. The primary use of funds for financing activities in 2008 was net repayments of borrowings under long-term revolving credit facilities of $34.9 million, compared to net borrowings of $89.3 million for the same period in 2007. In the prior year, we utilized borrowings under our debt facilities to fund a larger portion of our capital expenditures, acquisitions, federal income tax payments and interest on our long-term senior notes. For the six months ended June 30, 2008 compared to the same period in 2007, we have invested less in acquisitions and capital expenditures and used the funds generated from operating activities to retire a portion of our outstanding borrowings under our revolving credit facilities. Our long-term debt balances, including current maturities, were $791.9 million and $826.4 million as of June 30, 2008 and December 31, 2007, respectively.

We believe that our operating cash flows and borrowing capacity will be sufficient to fund our operations for the next 12 months. In addition to investing in capital expenditures, we expect to continue to evaluate acquisitions of complementary companies. We evaluate each acquisition based upon the circumstances and our financing capabilities at that time.

Dividends

We do not intend to pay dividends in the foreseeable future, but rather plan to reinvest such funds in our business. Furthermore, our senior notes and revolving credit facilities, as amended on December 6, 2006, contain restrictive debt covenants which preclude us from paying future dividends on our common stock.

Description of Our Indebtedness

On December 6, 2006, we issued 8.0% senior notes with a face value of $650.0 million through a private placement of debt. These notes mature in 10 years, on December 15, 2016, and require semi-annual interest payments, paid in arrears and calculated based on an annual rate of 8.0%, on June 15 and December 15 of each year, commencing on June 15, 2007. There was no discount or premium associated with the issuance of these notes. The senior notes are guaranteed, on a senior unsecured basis, by all of our current domestic subsidiaries. The senior notes have covenants which, among other things: (1) limit the amount of additional indebtedness we can incur; (2) limit restricted payments such as a dividend; (3) limit our ability to incur liens or encumbrances; (4) limit our ability to purchase, transfer or dispose of significant assets; (5) purchase or redeem stock or subordinated debt; (6) enter into transactions with affiliates; (7) merge with or into other companies or transfer all or substantially all our assets; and (8) limit our ability to enter into sale and leaseback transactions. We have the option to redeem all or part of these notes on or after December 15, 2011. We can redeem 35% of these notes on or before December 15, 2009 using the proceeds of certain equity offerings. Additionally, we may redeem some or all of the notes prior to December 15, 2011 at a price equal to 100% of the principal amount of the notes plus a make-whole premium.

On August 28, 2007, we entered into a supplement to the indenture governing the 8.0% senior notes, whereby additional domestic subsidiaries became guarantors under the indenture.

On December 6, 2006, we amended and restated our existing senior secured credit facility (the “Credit Agreement”) with Wells Fargo Bank, National Association, as U.S. Administrative Agent, and certain other financial institutions. The Credit Agreement initially provided for a $310.0 million U.S. revolving credit facility that will mature in 2011 and a $40.0 million Canadian revolving credit facility (with Integrated Production Services, Ltd., one of our wholly-owned subsidiaries, as the borrower thereof) that will mature in 2011. In addition, certain portions of the credit facilities are available to be borrowed in U.S. Dollars, Canadian Dollars, Pounds Sterling, Euros and other currencies approved by the lenders.

Subject to certain limitations, we have the ability to elect how interest under the Credit Agreement will be computed. Interest under the Credit Agreement may be determined by reference to (1) the London Inter-bank Offered Rate, or LIBOR, plus an applicable margin between 0.75% and 1.75% per annum (with the applicable margin depending upon our ratio of total debt to EBITDA (as defined in the agreement)), or (2) the Base Rate (i.e., the higher of the Canadian bank’s prime rate or the CDOR rate plus 1.0%, in the case of Canadian loans or the greater of the prime rate and the federal funds rate plus 0.5%, in the case of U.S. loans), plus an applicable margin between 0.00% and 0.75% per annum. If an event of default exists under the Credit Agreement, advances will bear interest at the then-applicable rate plus 2%. Interest is payable quarterly for base rate loans and at the end of applicable interest periods for LIBOR loans, except that if the interest period for a LIBOR loan is six months, interest will be paid at the end of each three-month period.

The Credit Agreement also contains various covenants that limit our and our subsidiaries’ ability to: (1) grant certain liens; (2) make certain loans and investments; (3) make capital expenditures; (4) make distributions; (5) make acquisitions; (6) enter into hedging transactions; (7) merge or consolidate; or (8) engage in certain asset dispositions. Additionally, the Credit Agreement limits our and our subsidiaries’ ability to incur additional indebtedness if: (1) we are not in pro forma compliance with all terms under the Credit Agreement, (2) certain covenants of the additional indebtedness are more onerous than the covenants set forth in the Credit Agreement, or (3) the additional indebtedness provides for amortization, mandatory

prepayment or repurchases of senior unsecured or subordinated debt during the duration of the Credit Agreement with certain exceptions. The Credit Agreement also limits additional secured debt to 10% of our consolidated net worth (i.e., the excess of our assets over the sum of our liabilities plus the minority interests). The Credit Agreement contains covenants which, among other things, require us and our subsidiaries, on a consolidated basis, to maintain specified ratios or conditions as follows (with such ratios tested at the end of each fiscal quarter): (1) total debt to EBITDA, as defined in the Credit Agreement, of not more than 3.0 to 1.0 and (2) EBITDA, as defined, to total interest expense of not less than 3.0 to 1.0. We were in compliance with all debt covenants under the amended and restated Credit Agreement as of June 30, 2008.

Under the Credit Agreement, we are permitted to prepay our borrowings.

All of the obligations under the U.S. portion of the Credit Agreement are secured by first priority liens on substantially all of the assets of our U.S. subsidiaries as well as a pledge of approximately 66% of the stock of our first-tier foreign subsidiaries. Additionally, all of the obligations under the U.S. portion of the Credit Agreement are guaranteed by substantially all of our U.S. subsidiaries. All of the obligations under the Canadian portions of the Credit Agreement are secured by first priority liens on substantially all of the assets of our subsidiaries. Additionally, all of the obligations under the Canadian portions of the Credit Agreement are guaranteed by us as well as certain of our subsidiaries.

If an event of default exists under the Credit Agreement, as defined, the lenders may accelerate the maturity of the obligations outstanding under the Credit Agreement and exercise other rights and remedies. While an event of default is continuing, advances will bear interest at the then-applicable rate plus 2%. For a description of an event of default, see our Credit Agreement which was filed with the Securities and Exchange Commission on December 8, 2006 as an exhibit to a Current Report on Form 8-K.

On June 29, 2007, we amended our Credit Agreement in conjunction with the restructuring of certain legal entities for tax purposes with no material changes to the financial provisions or covenants.

Effective October 19, 2007, we amended certain terms of our Credit Agreement including: (1) a provision to increase the borrowing capacity of the U.S. revolving portion of the facility from $310.0 million to $360.0 million; and (2) a provision to include a “commitment increase” clause, as defined in our Credit Agreement, which permits us to effect up to two separate increases in the aggregate commitments under the facility by designating a participating lender to increase its commitment, by mutual agreement, in increments of at least $50.0 million with the aggregate of such commitment increases not to exceed $100.0 million and in accordance with other provisions as stipulated in the amendment. In addition, the amendment specifies the terms for prepayment of outstanding advances and new borrowings and replaces Schedule II to the amended Credit Agreement which allocates the commitments amongst the member financial institutions.

Borrowings of $127.4 million and $10.1 million were outstanding under the U.S. and Canadian revolving credit facilities at June 30, 2008, respectively. The U.S. revolving credit facility bore interest at rates ranging from 4.16% to 5.25%, a weighted average interest rate of 4.22% at June 30, 2008, and the Canadian revolving credit facility bore interest at 5.00% at June 30, 2008. For the six months ended June 30, 2008, the weighted average interest rate on borrowings under the amended Credit Agreement was approximately 4.32%. In addition, there were letters of credit outstanding which totaled $37.7 million under the U.S. revolving portion of the facility that reduced the available borrowing capacity at June 30, 2008 to $194.9 million under the U.S. revolving portion of the facility and $29.9 million under the Canadian revolving portion of the facility. In addition, we incurred fees of 1.25% of the total amount outstanding under our letter of credit arrangements. As of July 31, 2008, we had $130.1 million outstanding under our Credit Agreement.

Outstanding Debt and Commitments

Our contractual commitments have not changed materially since December 31, 2007, except for additional borrowings under our U.S. revolving credit facility, primarily to fund capital expenditures.

We have entered into agreements to purchase certain equipment for use in our business. The manufacture of this equipment requires lead-time and we generally are committed to accept this equipment at the time of delivery, unless arrangements have been made to cancel delivery in accordance with the purchase agreement terms. We have spent $134.4 million for equipment purchases and other capital

expenditures during the six months ended June 30, 2008, which does not include amounts paid in connection with acquisitions.

We expect to continue to acquire complementary companies and evaluate potential acquisition targets. We may use cash from operations, proceeds from future debt or equity offerings and borrowings under our revolving credit facilities for this purpose.

Recent Accounting Pronouncements and Authoritative Guidance

In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities—Including an Amendment of FASB Statement No. 115.” This pronouncement permits entities to use the fair value method to measure certain financial assets and liabilities by electing an irrevocable option to use the fair value method at specified election dates. After election of the option, subsequent changes in fair value would result in the recognition of unrealized gains or losses as period costs during the period the change occurred. SFAS No. 159 became effective on January 1, 2008. We have not elected to adopt the fair value option prescribed by SFAS No. 159 for assets and liabilities held as of June 30, 2008, but we will consider the provisions of SFAS No. 159 and may elect to apply the fair value option for assets or liabilities associated with future transactions.

application to prior periods. Early adoption is not permitted. We are currently evaluating the impact that this guidance may have on our financial position, results of operations and cash flows.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The demand, pricing and terms for oil and gas services provided by us are largely dependent upon the level of activity for the U.S. and Canadian oil and gas industry. Industry conditions are influenced by numerous factors over which we have no control, including, but not limited to: the supply of and demand for oil and gas; the level of prices, and expectations about future prices, of oil and gas; the cost of exploring for, developing, producing and delivering oil and gas; the expected rates of declining current production; the discovery rates of new oil and gas reserves; available pipeline and other transportation capacity; weather conditions; domestic and worldwide economic conditions; political instability in oil-producing countries; technical advances affecting energy consumption; the price and availability of alternative fuels; the ability of oil and gas producers to raise equity capital and debt financing; and merger and divestiture activity among oil and gas producers.

The level of activity in the U.S. and Canadian oil and gas exploration and production industry is volatile. No assurance can be given that our expectations of trends in oil and gas production activities will reflect actual future activity levels or that demand for our services will be consistent with the general activity level of the industry. Any prolonged substantial reduction in oil and gas prices would likely affect oil and gas exploration and development efforts and therefore affect demand for our services. A material decline in oil and gas prices or U.S. and Canadian activity levels could have a material adverse effect on our business, financial condition, results of operations and cash flows.

For the six months ended June 30, 2008, approximately 5% of our revenues from continuing operations and 5% of our total assets were denominated in Canadian dollars, our functional currency in Canada. As a result, a material decrease in the value of the Canadian dollar relative to the U.S. dollar may negatively impact our revenues, cash flows and net income. Each one percentage point change in the value of the Canadian dollar would have impacted our revenues for the quarter and six months ended June 30, 2008 by approximately $0.1 million and $0.4 million, respectively. We do not currently use hedges or forward contracts to offset this risk.

Our Mexican operation uses the U.S. dollar as its functional currency, and as a result, all transactions and translation gains and losses are recorded currently in the financial statements. The balance sheet amounts are translated into U.S. dollars at the exchange rate at the end of the month and the income statement amounts are translated at the average exchange rate for the month. We estimate that a hypothetical one percentage point change in the value of the Mexican peso relative to the U.S. dollar would have impacted our revenues for the quarter and six months ended June 30, 2008 by approximately $0.1 million and $0.3 million, respectively. Currently, we conduct a portion of our business in Mexico in the local currency, the Mexican peso.

Approximately 17% of our debt at June 30, 2008 is structured under floating rate terms and, as such, our interest expense is sensitive to fluctuations in the prime rates in the U.S. and Canada. Based on the debt structure in place as of June 30, 2008, a 100 basis point increase in interest rates relative to our floating rate obligations would increase interest expense by approximately $1.4 million per year and reduce operating cash flows by approximately $0.9 million, net of tax.

Item 4. Controls and Procedures.

Our management, under the supervision of and with the participation of our Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures, as such terms are defined in Rules 13a — 15(e) and 15d — 15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as of the end of the period covered by this report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in our reports filed or submitted under the Exchange Act is accumulated and communicated to management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission. Based on

such evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures were effective as of June 30, 2008 at the reasonable assurance level.

PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

Item 1A. Risk Factors.

There have been no material changes to our risk factors disclosed in our Annual Report on Form 10-K as of December 31, 2007.

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

None.

Item 3. Defaults Upon Senior Securities.

None.

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

The annual meeting of stockholders of Complete Production Services, Inc. was held on May 22, 2008 in Houston, Texas. At the annual meeting, holders of 73,488,736 shares were entitled to vote on the specified stockholder matters, of which 69,203,975 shares were present and voting, or 94.17% of the outstanding shares of capital stock, which constituted a quorum.

Proposals submitted to a vote of the stockholders were:

(1)

The election of three directors of Complete Production Services, Inc. for the three-year term expiring at the 2011 annual meeting of stockholders.


	Number of Voting Shares
					Broker
Director’s Name	For		Withheld		Non-Votes
Robert S. Boswell		68,731,818		472,157		—
Michael McShane		68,715,768		488,207		—
Marcus A. Watts		55,111,696		14,092,279		—

Directors continuing in office until the 2009 annual meeting of stockholders are Andrew L. Waite, Joseph C. Winkler and R. Graham Whaling. Directors continuing in office until the 2010 annual meeting of stockholders are Harold G. Hamm, W. Matt Ralls and James D. Woods.

(2)

To approve the Complete Production Services, Inc. 2008 Incentive Award Plan.


					Broker
For	Against		Abstained		Non-Votes
61,662,561		1,355,402		162,511		6,023,501

(3)

The ratification of Grant Thornton LLP as our independent registered public accountants for the fiscal year ended December 31, 2008.


					Broker
For	Against		Abstained		Non-Votes
68,971,809		51,552		180,614		—

Item 5. Other Information.

None.

Item 6. Exhibits.

EXHIBIT INDEX


Exhibit
No.		Exhibit Title
3.1	—	Amended and Restated Articles of Incorporation (incorporated herein by reference to the Registration Statement on Form S-1/A filed on January 17, 2006 (File No. 333-128750)

3.2	—	Amended and Restated Bylaws, dated February 21, 2008 (incorporated herein by reference to the Current Report on Form 8-K filed on February 27, 2008)

10.1*	—	Form of Non-qualified Stock Option Agreement for Non-employee Directors

10.2*	—	Form of Signature Page for Stock Option Agreement Terms and Conditions (Revised 2008)

10.3*	—	Restricted Stock Agreement Terms and Conditions (Revised 2008)

10.4*	—	Form of Stock Option Agreement (Revised 2008)

10.5*	—	Signature Page to the Restricted Stock Award Agreement Terms and Conditions (2008)

10.6*	—	Restricted Stock Agreement for Non-Employee Directors

31.1*	—	Certification of Chief Executive Officer Pursuant to Rule 13a — 14 of the Securities and Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2*	—	Certification of Chief Financial Officer Pursuant to Rule 13a — 14 of the Securities and Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1*	—	Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2*	—	Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002


*		Filed herewith

EXHIBIT INDEX


Exhibit
No.		Exhibit Title
3.1	—	Amended and Restated Articles of Incorporation (incorporated herein by reference to the Registration Statement on Form S-1/A filed on January 17, 2006 (File No. 333-128750)

3.2	—	Amended and Restated Bylaws, dated February 21, 2008 (incorporated herein by reference to the Current Report on Form 8-K filed on February 27, 2008)

10.1*	—	Form of Non-qualified Stock Option Agreement for Non-employee Directors

10.2*	—	Form of Signature Page for Stock Option Agreement Terms and Conditions (Revised 2008)

10.3*	—	Restricted Stock Agreement Terms and Conditions (Revised 2008)

10.4*	—	Form of Stock Agreement (Revised 2008)

10.5*	—	Signature Page to the Restricted Stock Award Agreement Terms and Conditions (2008)

10.6*	—	Restricted Stock Agreement for Non-Employee Directors

31.1*	—	Certification of Chief Executive Officer Pursuant to Rule 13a — 14 of the Securities and Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2*	—	Certification of Chief Financial Officer Pursuant to Rule 13a — 14 of the Securities and Exchange Act of 1934, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1*	—	Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2*	—	Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002


*		Filed herewith


		Page
	PART I—FINANCIAL INFORMATION
Item 1.	Financial Statements.

	Consolidated Balance Sheets as of June 30, 2008 and December 31, 2007	3

	Consolidated Statements of Operations and Consolidated Statements of Comprehensive Income for the Quarters and Six Months Ended June 30, 2008 and 2007	4

	Consolidated Statement of Stockholders’ Equity for the Six Months Ended June 30, 2008	5

	Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2008 and 2007	6

	Notes to Consolidated Financial Statements	7

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations.	24

Item 3.	Quantitative and Qualitative Disclosures About Market Risk.	36

Item 4.	Controls and Procedures.	36

	PART II—OTHER INFORMATION

Item 1.	Legal Proceedings.	37

Item 1A.	Risk Factors.	37

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds.	37

Item 3.	Defaults Upon Senior Securities.	37

Item 4.	Submission of Matters to a Vote of Security Holders.	37

Item 5.	Other Information.	38

Item 6.	Exhibits.	38

	Signature	39
Form of Non-Qualified Stock Option Agreement for Non-Employee Directors
Form of Signature Page for Stock Option Agreement Terms and Conditions
Restricted Stock Agreement Terms and Conditions
Form of Stock Agreement
Signature Page to the Restricted Stock Award Agreement Terms and Conditions
Restricted Stock Agreement for Non-Employee Directors
Certification of CEO Pursuant to Section 302
Certification of CFO Pursuant to Section 302
Certification of CEO Pursuant to Section 906
Certification of CFO Pursuant to Section 906

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	COMPLETE PRODUCTION SERVICES, INC.

August 1, 2008	By:	/s/ J. Michael Mayer

Date		J. Michael Mayer
		Senior Vice President and
		Chief Financial Officer