Edgar Filing: Complete Production Services, Inc.

Large accelerated filer þ

Accelerated filer o

Non-accelerated filer o

Smaller reporting company o

(Do not check if a smaller reporting company)

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 September 30, 2010


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 Number: 1-32858

Complete Production Services, Inc.

(Exact name of registrant as specified in its charter)


Delaware		72-1503959

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

11700 Katy Freeway,
Suite 300
Houston, Texas		77079

(Address of principal executive offices)		(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 has submitted electronically and posted on its Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a small 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):

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, par value $0.01 per share, of the registrant outstanding as of October 25, 2010: 77,901,427

INDEX TO FINANCIAL STATEMENTS

Complete Production Services, Inc.


	Page
PART I—FINANCIAL INFORMATION
Item 1. Financial Statements.
Consolidated Balance Sheets as of September 30, 2010 and December 31, 2009		3
Consolidated Statements of Operations and Consolidated Statements of Comprehensive Income (Loss) for the Quarters and Nine Months Ended September 30, 2010 and 2009		4
Consolidated Statement of Stockholders’ Equity for the Nine Months Ended September 30, 2010		5
Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2010 and 2009		6
Notes to Consolidated Financial Statements		7

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.		23

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.		38

Item 3. Defaults Upon Senior Securities.		38

Item 5. Other Information.		38

Item 6. Exhibits.		38

Signatures		39

PART I—FINANCIAL INFORMATION

Item 1. Financial Statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Balance Sheets
September 30, 2010 (unaudited) and December 31, 2009


	2010			2009
	(In thousands, except
	share data)
ASSETS
Current assets:
Cash and cash equivalents	$	143,265		$	77,360
Accounts receivable, net		281,480			171,284
Inventory, net		32,101			37,464
Prepaid expenses		20,839			17,943
Income tax receivable		6,815			57,606
Current deferred tax assets		908			8,158
Other current assets		163			111

Total current assets		485,571			369,926
Property, plant and equipment, net		913,307			941,133
Intangible assets, net of accumulated amortization of $19,775 and $15,476, respectively		8,664			13,243
Deferred financing costs, net of accumulated amortization of $8,554 and $6,266, respectively		10,457			12,744
Goodwill		249,751			243,823
Restricted cash		17,000			—
Other long-term assets		6,122			7,985

Total assets	$	1,690,872		$	1,588,854


LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current maturities of long-term debt	$	89		$	228
Accounts payable		49,268			31,745
Accrued liabilities		42,653			41,102
Accrued payroll and payroll burdens		27,340			13,559
Accrued interest		15,655			3,206
Notes payable		—			1,069
Income taxes payable		589			813

Total current liabilities		135,594			91,722
Long-term debt		650,000			650,002
Deferred income taxes		148,210			148,240

Total liabilities		933,804			889,964
Commitments and contingencies
Stockholders’ equity:
Common stock, $0.01 par value per share, 200,000,000 shares authorized, 76,180,549 (2009 — 75,278,406) issued and outstanding		762			752
Preferred stock, $0.01 par value per share, 5,000,000 shares authorized, no shares issued and outstanding		—			—
Additional paid-in capital		649,183			636,904
Retained earnings		87,946			42,007
Treasury stock, 167,207 (2009 — 54,313) shares at cost		(1,752	)		(334	)
Accumulated other comprehensive income		20,929			19,561

Total stockholders’ equity		757,068			698,890

Total liabilities and stockholders’ equity	$	1,690,872		$	1,588,854

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Statements of Operations
Quarters and Nine Months Ended September 30, 2010 and 2009 (unaudited)


	Quarter Ended						Nine Months Ended
	September 30,						September 30,
	2010			2009			2010			2009
	(In thousands, except per share data)
Revenue:
Service	$	410,057		$	223,429		$	1,062,354		$	767,496
Product		8,552			6,484			26,204			37,496

		418,609			229,913			1,088,558			804,992
Service expenses		257,487			157,708			687,872			519,694
Product expenses		6,346			4,596			19,793			28,583
Selling, general and administrative expenses		41,790			45,204			126,658			140,115
Depreciation and amortization		44,805			50,379			135,596			153,470
Impairment loss		—			36,158			—			36,158

Income (loss) before interest and taxes		68,181			(64,132	)		118,639			(73,028	)
Interest expense		14,152			13,987			43,653			42,344
Interest income		(57	)		(13	)		(200	)		(43	)

Income (loss) before taxes		54,086			(78,106	)		75,186			(115,329	)
Taxes		21,056			(26,081	)		29,247			(37,136	)

Net income (loss)	$	33,030		$	(52,025	)	$	45,939		$	(78,193	)


Earnings (loss) per share information:
Basic earnings (loss) per share	$	0.43		$	(0.69	)	$	0.60		$	(1.04	)


Diluted earnings (loss) per share	$	0.42		$	(0.69	)	$	0.59		$	(1.04	)


Weighted average shares:
Basic		76,130			75,200			75,957			75,045
Diluted		77,792			75,200			77,395			75,045

Consolidated Statements of Comprehensive Income (Loss)
Quarters and Nine Months Ended September 30, 2010 and 2009
(unaudited)


	Quarter Ended					Nine Months Ended
	September 30,					September 30,
	2010		2009			2010		2009
	(In thousands)					(In thousands)
Net income (loss)	$	33,030	$	(52,025	)	$	45,939	$	(78,193	)
Change in cumulative translation adjustment		1,309		3,002			1,368		5,346

Comprehensive income (loss)	$	34,339	$	(49,023	)	$	47,307	$	(72,847	)

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Statement of Stockholders’ Equity
Nine Months Ended September 30, 2010 (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, 2009		75,278,406		$	752	$	636,904		$	42,007	$	(334	)	$	19,561	$	698,890
Net income		—			—		—			45,939		—			—		45,939
Cumulative translation adjustment		—			—		—			—		—			1,368		1,368
Issuance of common stock:
Exercise of stock options		336,747			3		3,103			—		—			—		3,106
Expense related to employee stock options		—			—		1,831			—		—			—		1,831
Excess tax benefit from share-based compensation		—			—		612			—		—			—		612
Purchase of treasury shares		(112,894	)		—		—			—		(1,418	)		—		(1,418	)
Vested restricted stock		678,290			7		(7	)		—		—			—		—
Amortization of non-vested restricted stock		—			—		6,740			—		—			—		6,740

Balance at September 30, 2010		76,180,549		$	762	$	649,183		$	87,946	$	(1,752	)	$	20,929	$	757,068

See accompanying notes to consolidated financial statements.

COMPLETE PRODUCTION SERVICES, INC.

Consolidated Statements of Cash Flows
Nine Months Ended September 30, 2010 and 2009 (unaudited)


	Nine Months Ended
	September 30,
	2010			2009
	(In thousands)
Cash provided by:
Operating activities:
Net income (loss)	$	45,939		$	(78,193	)
Items not affecting cash:
Depreciation and amortization		135,596			153,470
Impairment loss		—			36,158
Deferred income taxes		7,575			2,491
Excess tax benefit from share-based compensation		(612	)		(106	)
Non-cash compensation expense		8,571			9,571
(Gain) loss on non-monetary asset exchange		(458	)		4,868
(Recoveries of) provision for bad debt expense		(158	)		9,311
Provision for write-off of note receivable		1,926			—
(Gain) loss on the disposal of assets		(94	)		7,637
Other		2,288			1,412
Changes in operating assets and liabilities:
Accounts receivable		(109,824	)		173,370
Inventory		5,606			1,666
Prepaid expense and other current assets		(2,935	)		14,536
Accounts payable		17,480			(33,702	)
Income taxes		50,410			(27,672	)
Restricted cash		(17,000	)		—
Accrued liabilities and other		27,130			(4,754	)

Net cash provided by operating activities		171,440			270,063

Investing activities:
Additions to property, plant and equipment		(89,855	)		(29,094	)
Acquisitions		(21,332	)		—
Proceeds from disposal of capital assets		4,436			20,155

Net cash used in investing activities		(106,751	)		(8,939	)

Financing activities:
Issuances of long-term debt		—			3,204
Repayments of long-term debt		(141	)		(200,454	)
Repayment of notes payable		(1,069	)		(6,241	)
Proceeds from issuances of common stock		3,106			197
Purchase of treasury shares		(1,418	)		(126	)
Excess tax benefit from share-based compensation		612			106

Net cash provided by (used in) financing activities		1,090			(203,314	)

Effect of exchange rate changes on cash		126			(167	)

Change in cash and cash equivalents		65,905			57,643
Cash and cash equivalents, beginning of period		77,360			18,500

Cash and cash equivalents, end of period	$	143,265		$	76,143


Supplemental cash flow information:
Cash paid for interest, net of interest capitalized	$	28,489		$	26,744
Cash paid (refund received) for income taxes	$	(29,033	)	$	(17,064	)
Note issued to finance insurance premiums	$	—		$	7,960

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, Pennsylvania, 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 21, 2006, our common stock began trading on the New York Stock Exchange under the symbol “CPX”.

(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 September 30, 2010 and the statements of operations and the statements of comprehensive income for the quarters and nine-month periods ended September 30, 2010 and 2009, as well as the statement of stockholders’ equity for the nine months ended September 30, 2010 and the statements of cash flows for the nine months ended September 30, 2010 and 2009. Certain information and disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“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 and the notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2009 filed with the Securities and Exchange Commission on February 19, 2010. 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.

2. Business combinations:

On May 11, 2010, we acquired certain assets of a provider of gas lift services based in Oklahoma City, Oklahoma for $1,365 in cash, subject to an additional $75 holdback. We recorded goodwill totaling $1,017 in conjunction with this acquisition which has been allocated entirely to the completion and production services business segment. We believe this acquisition supplements our plunger lift service offering for the completion and production services business segment.

On September 3, 2010, we completed the purchase of assets associated with the well service and fluid handling operations of DHW Well Service, Inc, a well service and fluid handling service provider based in Carrizo Springs, Texas. The total purchase price for the assets was $19,967, subject to an

additional $1,000 holdback, and included goodwill of $4,911, all of which was allocated to the completion and production services business segment. We believe this acquisition enhances our position in the Eagle Ford Shale in south Texas.

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. The following table summarizes our preliminary purchase price allocations for these acquisitions as of September 30, 2010:


Net assets acquired:
Property, plant and equipment	$	15,538
Inventory		322
Accrued liabilities		(956	)
Intangible assets		500
Goodwill		5,928

Net assets acquired	$	21,332

Consideration:
Cash, net of cash and cash equivalents acquired	$	21,332

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.

3. Accounts receivable:


	September 30,		December 31,
	2010		2009
Trade accounts receivable	$	215,229	$	155,871
Related party receivables		26,156		6,593
Unbilled revenue		45,380		19,409
Other receivables		961		1,975

		287,726		183,848
Allowance for doubtful accounts		6,246		12,564

	$	281,480	$	171,284

Of the related party receivables at September 30, 2010 and December 31, 2009, $24,609 and $5,968, respectively, related to amounts due from a company for which one of our directors has an ownership interest and serves as chief executive officer and chairman of the board.

4. Inventory:


	September 30,		December 31,
	2010		2009
Finished goods	$	21,100	$	23,435
Manufacturing parts, materials and other		13,046		14,486
Work in process		465		431

		34,611		38,352
Inventory reserves		2,510		888

	$	32,101	$	37,464

5. Property, plant and equipment:


			Accumulated
September 30, 2010	Cost		Depreciation		Net Book Value
Land	$	9,963	$	—	$	9,963
Buildings		30,963		4,034		26,929
Field equipment		1,352,426		601,081		751,345
Vehicles		128,877		63,784		65,093
Office furniture and computers		17,427		10,858		6,569
Leasehold improvements		25,760		6,299		19,461
Construction in progress		33,947		—		33,947

	$	1,599,363	$	686,056	$	913,307


			Accumulated
December 31, 2009	Cost		Depreciation		Net Book Value
Land	$	8,884	$	—	$	8,884
Buildings		30,200		3,168		27,032
Field equipment		1,293,292		497,632		795,660
Vehicles		126,256		55,035		71,221
Office furniture and computers		17,087		9,108		7,979
Leasehold improvements		25,006		4,771		20,235
Construction in progress		10,122		—		10,122

	$	1,510,847	$	569,714	$	941,133

Construction in progress at September 30, 2010 and December 31, 2009 primarily included progress payments to vendors for equipment to be delivered in future periods and component parts to be used in the final assembly of operating equipment, which in all cases were not yet placed into service at the time. For the quarter and nine months ended September 30, 2010, we recorded capitalized interest of $583 and $773, 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. Long-term notes receivable:

On October 31, 2006, we completed the sale of a disposal group which included certain manufacturing and production enhancement product operations of a subsidiary located in Alberta, Canada, as well as operations in south Texas. We sold this disposal group to an oilfield service company located in Calgary, Alberta, Canada. In conjunction with this asset disposal, the buyer issued a note to us for $2,000 denominated in Canadian dollars. During the second quarter of 2010, we were notified that the buyer was in default on a term loan and security agreement which was senior to our note. Therefore, management recorded a provision of $1,926 for bad debt associated with this note during June 2010, but we will continue to pursue our interest in this note to the extent a portion may be recoverable in a future period.

7. Notes payable:

We entered into a note arrangement to finance certain of our annual insurance premiums for the policy term from December 1, 2007 to April 30, 2009. Effective May 1, 2009, we renewed our insurance policies and entered into a similar financing arrangement for the twelve-month policy term which extended through April 2010. Concurrently, we renewed our workers’ compensation, general liability and auto insurance policies through our insurance broker for the same policy term. Our accounting policy has been to record a prepaid asset associated with certain of these policies which is amortized over the term and which takes into account actual premium payments and deposits made to date, to record an accrued liability for premiums which are contractually committed for the policy term and to make monthly premium payments in accordance with our premium commitments and monthly note payments for amounts financed. Effective May 1, 2010, we renewed our annual insurance premiums for the policy term May 1, 2010 through April 30, 2011, but chose to prepay our premiums which had been financed through a note arrangement in prior renewals. As a result, we recorded a prepaid asset of $4,267 in May 2010 associated with these renewals. We will continue to make monthly premium payments through our broker for our workers’ compensation, general liability and auto insurance policies during this twelve-month policy term.

8. Long-term debt:

The following table summarizes long-term debt as of September 30, 2010 and December 31, 2009:


	2010		2009
U.S. revolving credit facility (a)	$	—	$	—
Canadian revolving credit facility (a)		—		—
8.0% senior notes (b)		650,000		650,000
Capital leases and other		89		230

		650,089		650,230
Less: current maturities of long-term debt and capital leases		89		228

	$	650,000	$	650,002


(a)		We maintain a senior secured facility (the “Credit Agreement”) with Wells Fargo Bank, National Association, as U.S. Administrative Agent, HSBC Bank Canada, as Canadian Administrative Agent, and certain other financial institutions. On October 13, 2009, we entered into the Third Amendment (the Credit Agreement after giving effect to the Third Amendment, the “Amended Credit Agreement”) and modified the structure of our existing credit facility to an asset-based facility subject to borrowing base restrictions. In connection with the Third Amendment, Wells Fargo Capital Finance, LLC (formerly known as Wells Fargo Foothill, LLC) replaced Wells Fargo Bank, National Association, as U.S. Administrative Agent and also serves as U.S. Issuing Lender and U.S. Swingline Lender under the Amended Credit Agreement. The Amended Credit Agreement provides for a U.S. revolving credit facility of up to $225,000 that matures in December 2011 and a Canadian revolving credit facility of up to $15,000 (with Integrated Production Services Ltd., one of our wholly-owned subsidiaries, as the borrower thereof (“Canadian Borrower”)) that matures in December 2011. The Amended Credit Agreement includes a provision for a “commitment increase”, as defined therein, which permits us to effect up to two separate increases in the aggregate commitments under the Amended Credit Agreement by designating one or more existing lenders or other banks or financial institutions, subject to the bank’s sole discretion as to participation, to provide additional aggregate financing up to $75,000, with each committed increase equal to at least $25,000 in the U.S., or $5,000 in Canada, and in accordance with other provisions as stipulated in the Amended Credit Agreement. Certain portions of the credit facilities are available to be borrowed in U.S. dollars, Canadian dollars and other currencies approved by the lenders.

		We were not subject to the fixed charge coverage ratio covenant in the Amended Credit Agreement as of September 30, 2010 since the Excess Availability Amount plus Qualified Cash Amount (each as defined in the Amended Credit Agreement) exceeded $50,000. If we had been subject to the fixed charge coverage ratio covenant at September 30, 2010, we would have been in compliance. For a discussion of the methodology to calculate the borrowing base for the U.S. and Canadian portions of the facility, as well as our debt covenant requirements, prepayment options and potential exposure in the event of a default under the Amended Credit Agreement, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our Annual Report on Form 10-K as of December 31, 2009.

		All of the obligations under the U.S. portion of the Amended Credit Agreement are secured by first priority liens on substantially all of our assets and 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 Amended Credit Agreement are guaranteed by substantially all of our U.S. subsidiaries. The obligations under the Canadian portion of the Amended Credit Agreement are secured by first priority liens on substantially all of our assets and the assets of our subsidiaries (other than our Mexican subsidiary). Additionally, all of the obligations under the Canadian portion of the Amended Credit Agreement are guaranteed by us as well as certain of our subsidiaries.

		Subject to certain limitations set forth in the Amended Credit Agreement, we have the ability to elect how interest under the Amended Credit Agreement will be computed. Interest under the Amended Credit Agreement may be determined by reference to (1) the London Inter-bank Offered Rate, or LIBOR, plus an applicable margin between 3.75% and 4.25% per annum (with the


		applicable margin depending upon our “excess availability amount”, as defined in the Amended Credit Agreement) or (2) the “Base Rate” (which means the higher of the Prime Rate, Federal Funds Rate plus 0.50%, 3-month LIBOR plus 1.00% and 3.50%), plus the applicable margin, as described above. For the period from the effective date of the Third Amendment until the six month anniversary of the effective date of the Third Amendment, interest was computed with an applicable margin rate of 4.00%. If an event of default exists or continues under the Amended Credit Agreement, advances will bear interest as described above with an applicable margin rate of 4.25% plus 2.00%. Additionally, if an event of default exists under the Amended Credit Agreement, as defined therein, the lenders could accelerate the maturity of the obligations outstanding thereunder and exercise other rights and remedies. Interest is payable monthly.

		There were no borrowings outstanding under our U.S. or Canadian revolving credit facilities as of September 30, 2010. There were letters of credit outstanding under the U.S. revolving portion of the facility totaling $26,381, which reduced the available borrowing capacity as of September 30, 2010. We incurred fees related to our letters of credit as of September 30, 2010 at 4.0% per annum. For the nine months ended September 30, 2010, fees related to our letters of credit were calculated using a 360-day provision, at 4.1% per annum. The availability of the U.S. and Canadian revolving credit facilities is determined by our borrowing base less any borrowings and letters of credit outstanding. The net excess availability under our borrowing base calculations for the U.S. and Canadian revolving facilities at September 30, 2010 was $183,898 and $6,965, respectively.

		The primary purpose of our letters of credit is to secure potential future claim liability which may be incurred by our insurance providers. During the quarter ended September 30, 2010, we negotiated a reduction in our letter of credit requirements of $5,569. In addition, we placed $17,000 in escrow as a compensating balance, effectively cash collateralizing a portion of our letters of credit, in order to better utilize excess cash and reduce interest expense. This compensating balance has been recorded as a long-term asset called “Restricted Cash” on the accompanying consolidated balance sheet at September 30, 2010.

		We incur unused commitment fees under the Amended Credit Agreement ranging from 0.50% to 1.00% based on the average daily balance of amounts outstanding. The unused commitment fees were calculated at 1.00% as of September 30, 2010.

(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, which commenced on June 15, 2007. There was no discount or premium associated with the issuance of these notes. The senior notes are guaranteed 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) limit our ability to purchase or redeem stock or subordinated debt; (6) limit our ability to enter into transactions with affiliates; (7) limit our ability to merge with or into other companies or transfer all or substantially all of 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. 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 SEC 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. Effective April 1, 2009, we entered into a second supplement to this indenture whereby additional domestic subsidiaries became guarantors under the indenture.

9. Stockholders’ equity:

(a) Stock-based Compensation—Stock Options:

We maintain option plans under which we grant stock-based compensation to employees, officers and directors to purchase our common stock. The exercise price of each option is based on the fair value of the company’s stock at the date of grant. 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 calculate stock compensation expense for our stock-based compensation awards by measuring 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. A further description can be found in our Annual Report on Form 10-K as of December 31, 2009.

Effective January 29, 2010, 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 790,396 shares of non-vested restricted stock on January 29, 2010 at a grant price of $12.53 per share. We expect to recognize compensation expense associated with these grants of non-vested restricted stock totaling $9,904. Subsequent to the annual grant on January 29, 2010, we have granted an additional 18,700 shares of non-vested restricted stock at an average price of $16.45 and expect to recognize compensation expense of $308 associated with these grants ratably over the three-year vesting periods.

On January 29, 2010, we granted 510,300 stock options to purchase shares of our common stock at an exercise price of $12.53 per share. We will recognize compensation expense associated with these stock option grants ratably over the three-year vesting period. The fair value of the stock options granted during the nine months ended September 30, 2010 was determined by applying a Black-Scholes option pricing model based on the following assumptions:


	Nine Months Ended
	September 30,
	2010
Assumptions:
Risk-free rate	1.38% to 2.34%
Expected term (in years)		3.7 to 5.1
Volatility		50.4	%
Calculated fair value per option	$	4.83 to $5.81

We calculated an average volatility factor for our common stock for the three-year period just prior to the grant date of the award. This volatility calculation was used to compute the fair market value of stock option grants made during the nine months ended September 30, 2010.

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 $2,635 over the vesting period of these 2010 stock option grants. For the quarter and nine months ended September 30, 2010, we have recognized expense related to these stock option grants totaling $220 and $588, respectively, which represents a reduction of net income before taxes. The impact on net income for the quarter and nine months ended September 30, 2010 was a decrease of $134 and $359, respectively, with a $0.01 reduction in earnings per share for the quarter and nine months ended September 30, 2010. The unrecognized compensation costs related to the non-vested portion of these awards was $2,047 as of September 30, 2010 and will be recognized over the applicable remaining vesting periods.

For the quarters ended September 30, 2010 and 2009, we recognized compensation expense associated with all stock option awards totaling $488 and $869, respectively, resulting in a decrease in net income of $298 and an increase in net loss of $579, respectively. The impact of this compensation expense on earnings per share was a $0.01 reduction in earnings per share for the quarter ended September 30, 2010 and a $0.01 increase in loss per share for the quarter ended September 30, 2009. For the nine months ended September 30, 2010 and 2009, we recognized compensation expense associated with all stock option awards totaling $1,831 and $3,259, respectively, resulting in a

decrease in net income of $1,118 and an increase in net loss of $2,210, respectively. This resulted in a $0.02 reduction in earnings per share for the nine months ended September 30, 2010 and a $0.03 reduction in earnings per share for the nine months ended September 30, 2009. Total unrecognized compensation expense associated with outstanding stock option awards at September 30, 2010 was $2,837 or $1,733, net of tax.

The following tables provide a roll forward of stock options from December 31, 2009 to September 30, 2010 and a summary of stock options outstanding by exercise price range at September 30, 2010:


	Options Outstanding
				Weighted
				Average
				Exercise
	Number			Price
Balance at December 31, 2009		3,383,620		$	13.09
Granted		510,300		$	12.53
Exercised		(336,747	)	$	9.23
Cancelled		(151,805	)	$	18.41

Balance at September 30, 2010		3,405,368		$	13.15


	Options Outstanding						Options Exercisable
			Weighted		Weighted				Weighted		Weighted
	Outstanding at		Average		Average		Exercisable at		Average		Average
	September 30,		Remaining		Exercise		September 30,		Remaining		Exercise
Range of Exercise Prices	2010		Life (months)		Price		2010		Life (months)		Price
$5.00		68,500		32	$	5.00		68,500		32	$	5.00
$6.41 – $8.16		1,409,932		81	$	6.54		814,979		67	$	6.62
$11.66 – $12.53		582,836		32	$	12.42		72,536		60	$	11.66
$15.90		296,267		88	$	15.90		197,511		76	$	15.90
$17.60 – $19.87		554,089		76	$	19.83		554,088		76	$	19.83
$22.55 – $24.07		397,244		67	$	23.96		397,244		67	$	23.96
$26.26 – $27.11		45,000		80	$	26.35		45,000		80	$	26.35
$29.88		40,000		92	$	29.88		26,667		92	$	29.88
$34.19		11,500		93	$	34.19		7,667		93	$	34.19

		3,405,368		70	$	13.15		2,184,192		69	$	14.87

The total intrinsic value of stock options exercised during the quarter and nine months ended September 30, 2010 was $842 and $2,914, respectively. The total intrinsic value of all in-the-money vested outstanding stock options at September 30, 2010 was $12,329. Assuming all stock options outstanding at September 30, 2010 were vested, the total intrinsic value of all in-the-money outstanding stock options would have been $20,558.

(b) Non-vested Restricted Stock:

We present the amortization of non-vested restricted stock as an increase in additional paid-in capital. At September 30, 2010, amounts not yet recognized related to non-vested restricted stock totaled $12,201, which represented the unamortized expense associated with awards of non-vested stock granted to employees, officers and directors under our compensation plans, including $2,379 related to grants during the nine months ended September 30, 2010. We recognized compensation expense associated with non-vested restricted stock totaling $2,428 and $1,998 for the quarters ended September 30, 2010 and 2009, respectively, and $6,740 and $6,312 for the nine months ended September 30, 2010 and 2009, respectively.

The following table summarizes the change in non-vested restricted stock from December 31, 2009 to September 30, 2010:


	Non-vested
	Restricted Stock
				Weighted
				Average
	Number			Grant Price
Balance at December 31, 2009		1,635,565		$	10.27
Granted		809,096		$	12.62
Vested		(678,290	)	$	10.88
Forfeited		(91,992	)	$	10.89

Balance at September 30, 2010		1,674,379		$	11.12

(c) Treasury Shares:

In accordance with the provisions of the 2008 Incentive Award Plan, as amended, holders of non-vested restricted stock were given the option to either remit to us the required withholding taxes associated with the vesting of restricted stock, or to authorize us to purchase shares equivalent to the cost of the withholding tax and to remit the withholding taxes on behalf of the holder. Pursuant to this provision, we purchased the following shares of our common stock during the nine months ended September 30, 2010:


	Shares		Average Price		Extended
Period	Purchased		Paid per Share		Amount
January 1 – 31, 2010		109,360	$	12.53	$	1,370
March 1 – 31, 2010		902		14.06		13
April 1 – 30, 2010		426		11.84		5
May 1 – 31, 2010		1,260		14.48		18
June 1– 30, 2010		355		14.83		4
July 1 – 31, 2010		591		14.38		8

		112,894			$	1,418

10. Earnings per share:

We compute basic earnings per share by dividing net income (loss) by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per common and potential common share includes the weighted average of additional shares associated with the incremental effect of dilutive employee stock options and non-vested restricted stock, as determined using the treasury stock method prescribed by the Financial Accounting Standards Board (“FASB”) guidance on earnings per share. The following table reconciles basic and diluted weighted average shares used in the computation of earnings (loss) per share for the quarters and nine months ended September 30, 2010 and 2009:


	Quarter Ended				Nine Months Ended
	September 30,				September 30,
	2010		2009		2010		2009
	(In thousands)
Weighted average basic common shares outstanding		76,130		75,200		75,957		75,045
Effect of dilutive securities:
Employee stock options		751		—		628		—
Non-vested restricted stock		914		—		812		—

Weighted average diluted common and potential common shares outstanding		77,795		75,200		77,397		75,045

For the quarter and nine months ended September 30, 2009, we incurred a net loss and thus all potential common shares were deemed to be anti-dilutive. We excluded the impact of anti-dilutive potential common shares from the calculation of diluted weighted average shares for the quarters and nine months ended September 30, 2010 and 2009. If these potential common shares were included in the calculation, the impact would have been a decrease in diluted weighted average shares outstanding of 47,890 shares and 1,253,920 shares for the quarters ended September 30, 2010 and 2009, respectively, and 257,781 shares and 3,060,105 shares for the nine months ended September 30, 2010 and 2009, respectively.

11. Segment information:

We report segment information based on how our management organizes the operating segments to make operational decisions and to assess financial performance. We evaluate performance and allocate resources based on net income (loss) from continuing operations before net interest expense, taxes, depreciation and amortization, non-controlling interest and impairment loss (“Adjusted EBITDA”). The calculation of Adjusted EBITDA should not be viewed as a substitute for calculations under U.S. GAAP, in

particular net income. Adjusted EBITDA is included in this Quarterly Report on Form 10-Q because our management considers it an important supplemental measure of our performance and believes that it is frequently used by securities analysts, investors and other interested parties in the evaluation of companies in our industry, some of which present EBITDA when reporting their results. We regularly evaluate our performance as compared to other companies in our industry that have different financing and capital structures and/or tax rates by using Adjusted EBITDA. In addition, we use Adjusted EBITDA in evaluating acquisition targets. Management also believes that Adjusted EBITDA is a useful tool for measuring our ability to meet our future debt service, capital expenditures and working capital requirements, and Adjusted EBITDA is commonly used by us and our investors to measure our ability to service indebtedness. Adjusted EBITDA is not a substitute for the U.S. GAAP measures of earnings or cash flow and is not necessarily a measure of our ability to fund our cash needs. In addition, it should be noted that companies calculate EBITDA differently and, therefore, EBITDA has material limitations as a performance measure because it excludes interest expense, taxes, depreciation and amortization. Adjusted EBITDA calculated by us may not be comparable to the calculation of EBITDA as defined and used under our credit facilities (see Note 7, Long-term debt in the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2009 for a description of the calculation of EBITDA under our existing credit facility, as amended). See also the table below for a reconciliation of Adjusted EBITDA to operating income (loss) by segment.

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 consolidated financial statements as of September 30, 2010. Inter-segment transactions are accounted for on a cost recovery basis.


				Drilling			Product
	C&PS			Services			Sales		Corporate			Total
Quarter Ended September 30, 2010
Revenue from external customers	$	361,457		$	48,600		$	8,552	$	—		$	418,609
Inter-segment revenues	$	33		$	(10	)	$	3,177	$	(3,200	)	$	—
Adjusted EBITDA, as defined	$	108,104		$	12,936		$	1,689	$	(9,743	)	$	112,986
Depreciation and amortization	$	39,078		$	4,673		$	539	$	515		$	44,805

Operating income (loss)	$	69,026		$	8,263		$	1,150	$	(10,258	)	$	68,181
Capital expenditures	$	46,479		$	1,036		$	116	$	330		$	47,961

Quarter Ended September 30, 2009
Revenue from external customers	$	198,014		$	25,415		$	6,484	$	—		$	229,913
Inter-segment revenues	$	1,211		$	122		$	1,295	$	(2,628	)	$	—
Adjusted EBITDA, as defined	$	31,396		$	(3,757	)	$	1,791	$	(7,025	)	$	22,405
Depreciation and amortization	$	43,744		$	5,466		$	603	$	566		$	50,379
Impairment charge	$	—		$	36,158		$	—	$	—		$	36,158

Operating income (loss)	$	(12,348	)	$	(45,381	)	$	1,188	$	(7,591	)	$	(64,132	)
Capital expenditures	$	3,844		$	1,912		$	18	$	561		$	6,335

As of September 30, 2010
Segment assets	$	1,380,903		$	173,149		$	29,470	$	107,350		$	1,690,872

Nine Months Ended September 30, 2010
Revenue from external customers	$	938,205		$	124,149		$	26,204	$	—		$	1,088,558
Inter-segment revenues	$	225		$	231		$	4,567	$	(5,023	)	$	—
Adjusted EBITDA, as defined	$	250,609		$	27,018		$	4,501	$	(27,893	)	$	254,235
Depreciation and amortization	$	118,641		$	13,775		$	1,676	$	1,504		$	135,596

Operating income (loss)	$	131,968		$	13,243		$	2,825	$	(29,397	)	$	118,639
Capital expenditures	$	80,194		$	8,400		$	220	$	1,041		$	89,855

Nine Months Ended September 30, 2009
Revenue from external customers	$	681,981		$	85,515		$	37,496	$	—		$	804,992
Inter-segment revenues	$	4,460		$	734		$	3,581	$	(8,775	)	$	—
Adjusted EBITDA, as defined	$	129,044		$	6,698		$	6,427	$	(25,569	)	$	116,600
Depreciation and amortization	$	133,393		$	16,502		$	1,861	$	1,714		$	153,470
Impairment charge	$	—		$	36,158		$	—	$	—		$	36,158

Operating income (loss)	$	(4,349	)	$	(45,962	)	$	4,566	$	(27,283	)	$	(73,028	)
Capital expenditures	$	25,267		$	3,004		$	175	$	648		$	29,094

As of December 31, 2009
Segment assets	$	1,292,199		$	172,605		$	37,270	$	86,780		$	1,588,854

We do not allocate net interest expense or tax expense to our operating segments. The following table reconciles operating income (loss) as reported above to net income (loss) for the quarters and nine months ended September 30, 2010 and 2009:


	Quarters Ended						Nine Months Ended
	September 30,						September 30,
	2010			2009			2010			2009
Segment operating income (loss)	$	68,181		$	(64,132	)	$	118,639		$	(73,028	)
Interest expense		14,152			13,987			43,653			42,344
Interest income		(57	)		(13	)		(200	)		(43	)
Income taxes		21,056			(26,081	)		29,247			(37,136	)

Net income (loss)	$	33,030		$	(52,025	)	$	45,939		$	(78,193	)

The following table summarizes the change in the carrying amount of goodwill by segment for the nine months ended September 30, 2010:


			Drilling		Product
	C&PS		Services		Sales		Total
Balance at December 31, 2009	$	235,859	$	5,563	$	2,401	$	243,823
Acquisitions (a)		5,928		—		—		5,928

Balance at September 30, 2010	$	241,787	$	5,563	$	2,401	$	249,751


(a)		For a description of our business acquisitions as of September 30, 2010, see Note 2, Business Combinations.

12. Financial instruments:

The financial instruments recognized in the balance sheet consist of cash and cash equivalents, trade accounts receivable, accounts payable and accrued liabilities, long-term debt and senior notes. The fair value of all financial instruments approximates their carrying amounts due to their current maturities or market rates of interest, except the senior notes which were issued in December 2006 with a fixed 8% coupon rate. At September 30, 2010, the fair value of these notes was $673,563 based on the published closing price.

A significant portion of our trade accounts receivable is from companies in the oil and gas industry, and as such, we are exposed to normal industry credit risks. We evaluate the credit-worthiness of our major new and existing customers’ financial condition and generally do not require collateral. For the nine months ended September 30, 2010, one customer provided 11.4% of our sales and another customer provided 11.3% of our sales.

We have entered into contracts with major customers, including the customer that provided 11.4% of our consolidated sales for the nine months ended September 30, 2010, to provide pressure pumping services. These contracts generally extend for up to three years from the date each fleet is placed into service and contain provisions which establish minimum price and utilization requirements and include provisions to account for certain inflationary market changes. We accrue revenue under these contracts as stages are completed, but typically bill our customers at the completion of the well or once per month. Unbilled receivables pursuant to these long-term contracts totaled $6,969 and $632 as of September 30, 2010 and December 31, 2009, respectively.

13. 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 such 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 insurance 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.

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

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 September 30, 2010 and December 31, 2009; (2) unaudited condensed consolidating statements of operations for the quarters and nine months ended September 30, 2010 and 2009 and (3) unaudited condensed consolidating statements of cash flows for the nine months ended September 30, 2010 and 2009.

Condensed Consolidating Balance Sheet
September 30, 2010


						Non-
				Guarantor		guarantor		Eliminations/
	Parent			Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Current assets
Cash and cash equivalents	$	132,830		$	969	$	21,384	$	(11,918	)	$	143,265
Accounts receivable, net		389			250,515		30,576		—			281,480
Inventory, net		—			20,082		12,019		—			32,101
Prepaid expenses		7,561			11,992		1,286		—			20,839
Income tax receivable		(10,448	)		13,678		3,585		—			6,815
Current deferred tax assets		908			—		—		—			908
Other current assets		—			163		—		—			163

Total current assets		131,240			297,399		68,850		(11,918	)		485,571
Property, plant and equipment, net		4,253			853,523		55,531		—			913,307
Investment in consolidated subsidiaries		847,251			114,301		—		(961,552	)		—
Inter-company receivable		559,052			—		642		(559,694	)		—
Goodwill		15,531			231,362		2,858		—			249,751
Other long-term assets, net		30,726			9,627		1,890		—			42,243

Total assets	$	1,588,053		$	1,506,212	$	129,771	$	(1,533,164	)	$	1,690,872

Current liabilities
Current maturities of long-term debt	$	—		$	89	$	—	$	—		$	89
Accounts payable		831			54,226		6,129		(11,918	)		49,268
Accrued liabilities		17,418			20,814		4,421		—			42,653
Accrued payroll and payroll burdens		3,364			21,331		2,645		—			27,340
Accrued interest		15,644			3		8		—			15,655
Accrued taxes payable		—			—		589		—			589

Total current liabilities		37,257			96,463		13,792		(11,918	)		135,594
Long-term debt		650,000			—		—		—			650,000
Inter-company payable		—			558,704		990		(559,694	)		—
Deferred income taxes		143,728			3,794		688		—			148,210

Total liabilities		830,985			658,961		15,470		(571,612	)		933,804
Stockholders’ equity
Total stockholders’ equity		757,068			847,251		114,301		(961,552	)		757,068

Total liabilities and stockholders’ equity	$	1,588,053		$	1,506,212	$	129,771	$	(1,533,164	)	$	1,690,872

Condensed Consolidating Balance Sheet
December 31, 2009


			Guarantor		Non- guarantor		Eliminations/
	Parent		Subsidiaries		Subsidiaries		Reclassifications			Consolidated
Current assets
Cash and cash equivalents	$	64,871	$	519	$	17,001	$	(5,031	)	$	77,360
Accounts receivable, net		610		143,135		27,539		—			171,284
Inventory, net		—		23,001		14,463		—			37,464
Prepaid expenses		3,897		13,052		994		—			17,943
Income tax receivable		35,404		20,201		2,001		—			57,606
Current deferred tax assets		8,158		—		—		—			8,158
Other current assets		—		111		—		—			111

Total current assets		112,940		200,019		61,998		(5,031	)		369,926
Property, plant and equipment, net		4,222		876,304		60,607		—			941,133
Investment in consolidated subsidiaries		755,435		104,974		—		(860,409	)		—
Inter-company receivable		607,325		—		—		(607,325	)		—
Goodwill		15,531		225,434		2,858		—			243,823
Other long-term assets, net		16,026		13,803		4,143		—			33,972

Total assets	$	1,511,479	$	1,420,534	$	129,606	$	(1,472,765	)	$	1,588,854

Current liabilities
Current maturities of long-term debt	$	—	$	228	$	—	$	—		$	228
Accounts payable		445		30,028		6,303		(5,031	)		31,745
Accrued liabilities		14,064		18,257		8,781		—			41,102
Accrued payroll and payroll burdens		388		10,847		2,324		—			13,559
Accrued interest		3,198		—		8		—			3,206
Notes payable		1,068		1		—		—			1,069
Income taxes payable		—		—		813		—			813

Total current liabilities		19,163		59,361		18,229		(5,031	)		91,722
Long-term debt		650,000		—		2		—			650,002
Inter-company payable		—		601,947		5,378		(607,325	)		—
Deferred income taxes		143,427		3,793		1,020		—			148,240

Total liabilities		812,590		665,101		24,629		(612,356	)		889,964
Stockholders’ equity
Total stockholders’ equity		698,889		755,433		104,977		(860,409	)		698,890

Total liabilities and stockholders’ equity	$	1,511,479	$	1,420,534	$	129,606	$	(1,472,765	)	$	1,588,854

Condensed Consolidated Statement of Operations
Quarter Ended September 30, 2010


							Non-
				Guarantor			guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Revenue:
Service	$	—		$	380,985		$	30,804		$	(1,732	)	$	410,057
Product		—			209			8,343			—			8,552

		—			381,194			39,147			(1,732	)		418,609
Service expenses		—			235,375			23,844			(1,732	)		257,487
Product expenses		—			122			6,224			—			6,346
Selling, general and administrative expenses		9,743			29,492			2,555			—			41,790
Depreciation and amortization		345			41,570			2,890			—			44,805

Income (loss) before interest and taxes		(10,088	)		74,635			3,634			—			68,181
Interest expense		14,478			1,188			18			(1,532	)		14,152
Interest income		(1,580	)		(1	)		(8	)		1,532			(57	)
Equity in earnings of consolidated affiliates		(49,101	)		(2,864	)		—			51,965			—

Income (loss) before taxes		26,115			76,312			3,624			(51,965	)		54,086
Taxes		(6,915	)		27,211			760			—			21,056

Net income (loss)	$	33,030		$	49,101		$	2,864		$	(51,965	)	$	33,030

Condensed Consolidated Statement of Operations
Quarter Ended September 30, 2009


							Non-
				Guarantor			guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Revenue:
Service	$	—		$	197,004		$	28,019		$	(1,594	)	$	223,429
Product		—			(194	)		6,678			—			6,484

		—			196,810			34,697			(1,594	)		229,913
Service expenses		—			139,093			20,209			(1,594	)		157,708
Product expenses		—			224			4,372			—			4,596
Selling, general and administrative expenses		7,030			35,925			2,249			—			45,204
Depreciation and amortization		414			46,884			3,081			—			50,379
Impairment charge		—			36,158			—			—			36,158

Income (loss) before interest and taxes		(7,444	)		(61,474	)		4,786			—			(64,132	)
Interest expense		13,894			1,809			52			(1,768	)		13,987
Interest income		(1,777	)		(2	)		(2	)		1,768			(13	)
Equity in earnings of consolidated affiliates		47,359			(3,740	)		—			(43,619	)		—

Income (loss) before taxes		(66,920	)		(59,541	)		4,736			43,619			(78,106	)
Taxes		(14,895	)		(12,182	)		996			—			(26,081	)

Net income (loss)	$	(52,025	)	$	(47,359	)	$	3,740		$	43,619		$	(52,025	)

Condensed Consolidated Statement of Operations
Nine Months Ended September 30, 2010


							Non-
				Guarantor			guarantor		Eliminations/
	Parent			Subsidiaries			Subsidiaries		Reclassifications			Consolidated
Revenue:
Service	$	—		$	973,389		$	94,159	$	(5,194	)	$	1,062,354
Product		—			2,135			24,069		—			26,204

		—			975,524			118,228		(5,194	)		1,088,558
Service expenses		—			621,371			71,695		(5,194	)		687,872
Product expenses		—			1,654			18,139		—			19,793
Selling, general and administrative expenses		27,893			88,393			10,372		—			126,658
Depreciation and amortization		1,011			125,186			9,399		—			135,596

Income (loss) before interest and taxes		(28,904	)		138,920			8,623		—			118,639
Interest expense		43,923			4,627			50		(4,947	)		43,653
Interest income		(5,142	)		(5	)		—		4,947			(200	)
Equity in earnings of consolidated affiliates		(90,456	)		(7,948	)		—		98,404			—

Income (loss) before taxes		22,771			142,246			8,573		(98,404	)		75,186
Taxes		(23,168	)		51,790			625		—			29,247

Net income (loss)	$	45,939		$	90,456		$	7,948	$	(98,404	)	$	45,939

Condensed Consolidated Statement of Operations
Nine Months Ended September 30, 2009


							Non-
				Guarantor			guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Revenue:
Service	$	—		$	686,237		$	85,273		$	(4,014	)	$	767,496
Product		—			13,639			23,857			—			37,496

		—			699,876			109,130			(4,014	)		804,992
Service expenses		—			462,332			61,376			(4,014	)		519,694
Product expenses		—			12,979			15,604			—			28,583
Selling, general and administrative expenses		25,569			98,888			15,658			—			140,115
Depreciation and amortization		1,190			142,524			9,756			—			153,470
Impairment charge		—			36,158			—			—			36,158

Income (loss) before interest and taxes		(26,759	)		(53,005	)		6,736			—			(73,028	)
Interest expense		42,373			5,243			146			(5,418	)		42,344
Interest income		(5,452	)		(5	)		(4	)		5,418			(43	)


							Non-
				Guarantor			guarantor		Eliminations/
	Parent			Subsidiaries			Subsidiaries		Reclassifications			Consolidated
Equity in earnings of consolidated affiliates		44,998			(5,778	)		—		(39,220	)		—

Income (loss) before taxes		(108,678	)		(52,465	)		6,594		39,220			(115,329	)
Taxes		(30,485	)		(7,467	)		816		—			(37,136	)

Net income (loss)	$	(78,193	)	$	(44,998	)	$	5,778	$	39,220		$	(78,193	)

Condensed Consolidated Statement of Cash Flows
Nine Months Ended September 30, 2010


							Non-
				Guarantor			guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Cash provided by:
Net income (loss)	$	45,939		$	90,456		$	7,948		$	(98,404	)	$	45,939
Items not affecting cash:
Equity in earnings of consolidated affiliates		(90,456	)		(7,948	)		—			98,404			—
Depreciation and amortization		1,011			125,186			9,399			—			135,596
Other		12,173			7,316			(451	)		—			19,038
Changes in operating assets and liabilities		50,829			(68,475	)		(5,242	)		(6,245	)		(29,133	)

Net cash provided by (used in) operating activities		19,496			146,535			11,654			(6,245	)		171,440

Investing activities:
Additions to property, plant and equipment		(1,041	)		(85,682	)		(3,132	)		—			(89,855	)
Inter-company receipts		48,273			—			—			(48,273	)		—
Acquisitions		—			(21,332	)		—			—			(21,332	)
Proceeds from the disposal of capital assets		—			4,311			125			—			4,436

Net cash provided by (used for) investing activities		47,232			(102,703	)		(3,007	)		(48,273	)		(106,751	)

Financing activities:
Repayments of long-term debt		—			(139	)		(2	)		—			(141	)
Repayments of notes payable		(1,069	)		—			—			—			(1,069	)
Inter-company borrowings		—			(43,243	)		(4,388	)		47,631			—
Proceeds from issuances of common stock		3,106			—			—			—			3,106
Purchase of treasury shares		(1,418	)		—			—			—			(1,418	)
Other		612			—			—			—			612

Net cash provided by (used in) financing activities		1,231			(43,382	)		(4,390	)		47,631			1,090
Effect of exchange rate changes on cash		—			—			126			—			126

Change in cash and cash equivalents		67,959			450			4,383			(6,887	)		65,905
Cash and cash equivalents, beginning of period		64,871			519			17,001			(5,031	)		77,360

Cash and cash equivalents, end of period	$	132,830		$	969		$	21,384		$	(11,918	)	$	143,265

Condensed Consolidated Statement of Cash Flows
Nine Months Ended September 30, 2009


							Non-
				Guarantor			guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Cash provided by:
Net income (loss)	$	(78,193	)	$	(44,998	)	$	5,778		$	39,220		$	(78,193	)
Items not affecting cash:
Equity in earnings of consolidated affiliates		44,998			(5,778	)		—			(39,220	)		—
Depreciation and amortization		1,190			142,524			9,756			—			153,470
Impairment charge		—			36,158			—			—			36,158
Other		10,877			20,520			3,787			—			35,184
Changes in operating assets and liabilities, net of effect of acquisitions		65,708			54,019			(4,836	)		8,553			123,444

Net cash provided by operating activities		44,580			202,445			14,485			8,553			270,063


							Non-
				Guarantor			guarantor			Eliminations/
	Parent			Subsidiaries			Subsidiaries			Reclassifications			Consolidated
Investing activities:
Additions to property, plant and equipment		(649	)		(25,016	)		(3,429	)		—			(29,094	)
Inter-company receipts		187,949			(502	)		—			(187,447	)		—
Proceeds from the disposal of capital assets		—			19,860			295			—			20,155

Net cash provided by (used for) investing activities		187,300			(5,658	)		(3,134	)		(187,447	)		(8,939	)

Financing activities:
Issuances of long-term debt		1,645			—			1,559			—			3,204
Repayments of long-term debt		(187,638	)		(3,759	)		(9,057	)		—			(200,454	)
Repayments of notes payable		(6,241	)		—			—			—			(6,241	)
Inter-company borrowings		—			(192,501	)		5,054			187,447			—
Proceeds from issuances of common stock		197			—			—			—			197
Other		(20	)		—			—			—			(20	)

Net cash provided by (used in) financing activities		(192,057	)		(196,260	)		(2,444	)		187,447			(203,314	)
Effect of exchange rate changes on cash		—			—			(167	)		—			(167	)

Change in cash and cash equivalents		39,823			527			8,740			8,553			57,643
Cash and cash equivalents, beginning of period		25,399			346			5,078			(12,323	)		18,500

Cash and cash equivalents, end of period	$	65,222		$	873		$	13,818		$	(3,770	)	$	76,143

15. Recent accounting pronouncements and authoritative literature:

In May 2009, the FASB issued a standard regarding subsequent events that provides guidance as to when an entity should recognize events or transactions occurring after a balance sheet date in its financial statements and the necessary disclosures related to these events. Specifically, the entity should recognize subsequent events that provide evidence about conditions that existed at the balance sheet date, including significant estimates used to prepare financial statements. Originally, this standard required entities to disclose the date through which subsequent events had been evaluated and whether that date was the date the financial statements were issued or the date the financial statements were available to be issued. We adopted this accounting standard effective June 30, 2009 and applied its provisions prospectively. In February 2010, the FASB modified this standard to eliminate the requirement for publicly-traded entities to disclose the date through which subsequent events have been evaluated. Therefore, we omitted the disclosure in this Quarterly Report on Form 10-Q as of September 30, 2010.

In January 2010, the FASB issued “Fair Value Measurements and Disclosure (Topic 820)” which clarified the disclosure requirements of existing U.S. GAAP related to fair value measurements. This standard requires additional disclosures about recurring and non-recurring fair value measurements as follows: (1) for transfers in and out of Level 1 and Level 2 fair value measurements, as those terms are currently defined in existing authoritative literature, a reporting entity is required to disclose the amount of the movement between levels and an explanation for the movement; (2) for activity at Level 3, primarily fair value measurements based on unobservable inputs, a reporting entity is required to present separately information about purchases, sales, issuances and settlements, as opposed to presenting such transactions on a net basis; (3) in the event of a disaggregation, a reporting entity is required to provide fair value measurement disclosure for each class of assets and liabilities; and (4) a reporting entity is required to provide disclosures about the valuation techniques and inputs used to measure fair value for both recurring and non-recurring fair value measurements for items that fall in either Level 2 or Level 3. These disclosure requirements are effective for interim and annual reporting periods beginning after December 15, 2009, except for disclosures about purchases, sales, issuances and settlements in the roll forward of activity in Level 3 fair value measurements for which disclosure becomes effective for fiscal years beginning after December 15, 2010, and for interim periods within those fiscal years. This standard did not impact our financial position, results of operations and cash flows as of and for the quarter ended September 30, 2010.

significant impact on the operation of our existing health insurance plan. However, future provisions under the law which become effective in subsequent periods may impact our health insurance plan and our overall financial position. We are evaluating these provisions as they become effective and continue to seek guidance from the FASB and SEC related to the implications of this new legislation on accounting and disclosure requirements. We expect that this legislation will have an impact on our financial position, results of operations and cash flows, but we cannot determine the extent of the impact at this time.

In July 2010, the FASB issued “Receivables (Topic 310): Disclosure about the Credit Quality of Financing Receivables and the Allowance for Credit Losses.” This guidance will require companies to provide more information about the credit quality of their financing receivables in financial statements including, but not limited to, significant purchases and sales of financing receivables, aging information and credit quality indicators. We do not currently factor our receivables. We will adopt this accounting standard upon its effective date for periods ending on or after December 15, 2010, and we do not anticipate that this adoption will have a significant impact on our financial position, results of operations or cash flows.

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

Certain statements and information in this Quarterly Report on Form 10-Q may constitute “forward-looking statements” within the meaning of the Private Securities Litigation Act of 1995. These forward-looking statements are based on our current expectations, assumptions, estimates and projections about us and the oil and gas industry. While management believes that these forward-looking statements are reasonable as and when made, there can be no assurance that future developments affecting us will be those that we anticipate. 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. 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. Other factors that could cause our actual results to differ from our projected results are described in: (1) Part II, “Item 1A. Risk Factors” and elsewhere in this report, (2) our Annual Report on Form 10-K for the fiscal year ended December 31, 2009, (3) our reports and registration statements filed from time to time with the SEC and (4) other announcements we make from time to time. 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.

Reference 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 subsidiaries.

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 September 30, 2010 and for the quarters and nine months ended September 30, 2010 and 2009, included elsewhere herein.

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, Pennsylvania, 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.

	•		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 contract drilling and specialized rig relocation and logistics services.

Product Sales. We provide oilfield service equipment and refurbishment of used equipment through our Southeast Asian 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 or on a fixed per-stage-completed fee. Product sales are recorded when the actual sale occurs and title or ownership passes to the customer.

General

The primary factors influencing demand for our services and products are the level of drilling and workover activity of our customers and the complexity of such activity, 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 and workover 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 consider the drilling and well service rig counts to be an indication of spending by our customers in the oil and gas industry for exploration and development of new and existing hydrocarbon reserves. 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, are increasing, or are expected to increase. The following tables summarize average North American drilling and well service rig activity, as measured by Baker Hughes Incorporated (“BHI”) and the Cameron International Corporation/Guiberson /AESC Service Rig Count for “Active Rigs”:

AVERAGE RIG COUNTS


	Quarter		Quarter		Nine Months		Nine Months
	Ended		Ended		Ended		Ended
	9/30/10		9/30/09		9/30/10		9/30/09
BHI Rotary Rig Count:
U.S. Land		1,601		936		1,459		1,036
U.S. Offshore		18		34		35		47

Total U.S.		1,619		970		1,494		1,083
Canada		360		186		327		203

Total North America		1,979		1,156		1,821		1,286


Source: BHI (www.BakerHughes.com)


	Quarter		Quarter		Nine Months		Nine Months
	Ended		Ended		Ended		Ended
	9/30/10		9/30/09		9/30/10		9/30/09
Cameron International Corporation/Guiberson/AESC Well Service Rig Count (Active Rigs):
United States		1,890		1,620		1,816		1,755
Canada		553		428		479		452

Total North America		2,443		2,048		2,295		2,207


Source:		Cameron International Corporation/Guiberson/AESC Well Service Rig Count for “Active Rigs,” formerly the Weatherford/AESC Service Rig Count for “Active Rigs.”

Outlook

We are positive about the outlook for our business in 2010. Despite relatively low natural gas commodity prices, we have experienced an increase in utilization of our assets and more favorable pricing for many of our service lines during 2010 compared to 2009. Although we cannot be certain that these improvements will continue, we believe the sustainability of current oil prices, due to economic indicators of an improved global economy relative to 2009, and the need for our customers to hold recently acquired acreage, will create incentives to maintain, if not expand, activity in oil and liquid-rich fields and emerging basins such as the Bakken Shale in North Dakota, the Eagle Ford Shale in south Texas and the Marcellus Shale in Pennsylvania. Activity levels in the more mature gas markets are less certain and may experience declines due to lower natural gas prices, however we remain optimistic regarding the long-term outlook for natural gas. We continue to believe that growth in oil and gas activity in North America will be largely related to multi-stage, horizontal well completions, and we believe that customers will continue to seek relationships with service providers who offer quality reliable service.

Our long-term growth strategy has not changed. We seek to maximize our equipment utilization and grow through organic investments in like equipment and by acquiring complementary businesses to expand our service offerings in a current operating area or to extend our geographical footprint into targeted basins. In 2009, we reduced our overall capital investment to $38.5 million, and we did not complete any business acquisitions. For 2010, we expect to spend between $170.0 million and $180.0 million for capital investment, and we invested $21.3 million to acquire two businesses. We continue to evaluate additional business acquisition opportunities.

Recent Transactions

In March 2009, our Canadian subsidiary exchanged certain non-monetary assets with a net book value of $9.3 million related to our production testing business for certain e-line assets of a competitor. We recorded a non-cash loss on the transaction of $4.9 million, which represented the difference between the carrying value and the fair market value of the assets surrendered. We believe the e-line assets will generate incremental future cash flows compared to the production testing assets exchanged.

On May 11, 2010, we acquired certain assets of a provider of gas lift services based in Oklahoma City, Oklahoma for $1.4 million in cash, subject to an additional $0.1 million holdback. We recorded goodwill totaling $1.0 million in conjunction with this acquisition which has been allocated entirely to the completion and production services business segment. We believe this acquisition supplements our plunger lift service offering for the completion and production services business segment.

Effective June 30, 2010, we exchanged certain property, plant and equipment used in our fluid handling business for other equipment. This exchange was determined to have commercial substance for us and therefore we recorded the new assets at the fair market value of the assets received, which was more readily determinable than the fair market value of the assets surrendered. The fair market value of the assets received was $0.8 million, resulting in a gain on the non-monetary exchange of $0.5 million.

On September 3, 2010, we completed the purchase of assets associated with a well service and fluid handling service provider based in Carrizo Springs, Texas. The total purchase price for the assets was $19.9 million, subject to an additional $1.0 million holdback, and included goodwill of $4.9 million, all of which was allocated to the completion and production services business segment. We believe this acquisition enhances our position in the Eagle Ford Shale in south Texas.

Critical Accounting Policies and Estimates

The preparation of our consolidated financial statements in conformity with U.S. generally accepted accounting principles (“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, 2009. Our critical accounting policies and estimates have not changed materially during the nine months ended September 30, 2010.

Results of Operations


										Percent
	Quarter			Quarter			Change			Change
	Ended			Ended			2010/			2010/
	9/30/10			9/30/09			2009			2009
	(unaudited, in thousands)
Revenue:
Completion and production services	$	361,457		$	198,014		$	163,443			83	%
Drilling services		48,600			25,415			23,185			91	%
Product sales		8,552			6,484			2,068			32	%

Total	$	418,609		$	229,913		$	188,696			82	%


Adjusted EBITDA:
Completion and production services	$	108,104		$	31,396		$	76,708			244	%
Drilling services		12,936			(3,757	)		16,693			444	%
Product sales		1,689			1,791			(102	)		(6	%)
Corporate		(9,743	)		(7,025	)		(2,718	)		(39	%)

Total	$	112,986		$	22,405		$	90,581			404	%


										Percent
	Nine Months			Nine Months			Change			Change
	Ended			Ended			2010/			2010/
	9/30/10			9/30/09			2009			2009
	(unaudited, in thousands)
Revenue:
Completion and production services	$	938,205		$	681,981		$	256,224			38	%
Drilling services		124,149			85,515			38,634			45	%
Product sales		26,204			37,496			(11,292	)		(30	%)

Total	$	1,088,558		$	804,992		$	283,566			35	%


Adjusted EBITDA:
Completion and production services	$	250,609		$	129,044		$	121,565			94	%
Drilling services		27,018			6,698			20,320			303	%
Product sales		4,501			6,427			(1,926	)		(30	%)
Corporate		(27,893	)		(25,569	)		(2,324	)		(9	%)

Total	$	254,235		$	116,600		$	137,635			118	%


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

“Adjusted EBITDA” consists of net income (loss) from continuing operations before net interest expense, taxes, depreciation and amortization, non-controlling interest and impairment loss. Adjusted EBITDA is a non-GAAP measure of performance. We use Adjusted EBITDA as the primary internal management measure for evaluating performance and allocating additional resources because our management considers it an important supplemental measure of our performance and believes that it is frequently used by securities analysts, investors and other interested parties in the evaluation of companies in our industry, some of which present EBITDA when reporting their results. We regularly evaluate our performance as compared to other companies in our industry that have different financing and capital structures and/or tax rates by using Adjusted EBITDA. In addition, we use Adjusted EBITDA in evaluating acquisition targets.


Management also believes that Adjusted EBITDA is a useful tool for measuring our ability to meet our future debt service, capital expenditures and working capital requirements, and Adjusted EBITDA is commonly used by us and our investors to measure our ability to service indebtedness. Adjusted EBITDA is not a substitute for the GAAP measures of earnings or cash flow and is not necessarily a measure of our ability to fund our cash needs. In addition, it should be noted that companies calculate EBITDA differently and, therefore, EBITDA has material limitations as a performance measure because it excludes interest expense, taxes, depreciation and amortization. The calculation of Adjusted EBITDA is different from the calculation of “EBITDA,” as defined and used in our credit facilities. For a discussion of the definition of “EBITDA” under our existing credit facilities, as recently amended, see Note 7, Long-term debt in the Notes to Consolidated Financial Statements to our Annual Report on Form 10-K for the year ended December 31, 2009. The following table reconciles Adjusted EBITDA for the quarters and nine-month periods ended September 30, 2010 and 2009 to the most comparable U.S. GAAP measure, operating income (loss).

Reconciliation of Adjusted 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 September 30, 2010
Adjusted EBITDA, as defined	$	108,104		$	12,936		$	1,689	$	(9,743	)	$	112,986
Depreciation and amortization	$	39,078		$	4,673		$	539	$	515		$	44,805

Operating income (loss)	$	69,026		$	8,263		$	1,150	$	(10,258	)	$	68,181


Quarter Ended September 30, 2009
Adjusted EBITDA, as defined	$	31,396		$	(3,757	)	$	1,791	$	(7,025	)	$	22,405
Depreciation and amortization	$	43,744		$	5,466		$	603	$	566		$	50,379
Impairment charge	$	—		$	36,158		$	—	$	—		$	36,158

Operating income (loss)	$	(12,348	)	$	(45,381	)	$	1,188	$	(7,591	)	$	(64,132	)


Nine Months Ended September 30, 2010
Adjusted EBITDA, as defined	$	250,609		$	27,018		$	4,501	$	(27,893	)	$	254,235
Depreciation and amortization	$	118,641		$	13,775		$	1,676	$	1,504		$	135,596

Operating income (loss)	$	131,968		$	13,243		$	2,825	$	(29,397	)	$	118,639


Nine Months Ended September 30, 2009
Adjusted EBITDA, as defined	$	129,044		$	6,698		$	6,427	$	(25,569	)	$	116,600
Depreciation and amortization	$	133,393		$	16,502		$	1,861	$	1,714		$	153,470
Impairment charge	$	—		$	36,158		$	—	$	—		$	36,158

Operating income (loss)	$	(4,349	)	$	(45,962	)	$	4,566	$	(27,283	)	$	(73,028	)


	Quarters Ended						Nine Months Ended
	September 30,						September 30,
	2010			2009			2010			2009
Segment operating income (loss)	$	68,181		$	(64,132	)	$	118,639		$	(73,028	)
Interest expense		14,152			13,987			43,653			42,344
Interest income		(57	)		(13	)		(200	)		(43	)
Income taxes		21,056			(26,081	)		29,247			(37,136	)

Net income (loss)	$	33,030		$	(52,025	)	$	45,939		$	(78,193	)

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

Quarter Ended September 30, 2010 Compared to the Quarter Ended September 30, 2009 (Unaudited)

Revenue

Revenue for the quarter ended September 30, 2010 increased by $188.7 million, or 82%, to $418.6 million from $229.9 million for the same period in 2009. The changes by segment were as follows:

	•		Completion and Production Services. Segment revenue increased $163.4 million, or 83%, for the third quarter of 2010 primarily due to a substantial increase in investment by our customers in oil and gas exploration and development activities resulting in higher utilization of our equipment. Activity levels and pricing in some service lines and select geographic areas began to improve during the latter part of the fourth quarter of 2009 and continued improving throughout the nine months ended September 30, 2010. The segment continued to benefit from increased horizontal drilling and completion related activity within resource plays and also benefitted from the deployment of approximately 40,000 hydraulic horse power of new pressure pumping equipment into the Eagle Ford and Bakken shales during the latter part of the third quarter of 2010.

	•		Drilling Services. Segment revenue increased $23.2 million, or 91%, for the third quarter of 2010 primarily due to improved utilization and pricing in our rig relocation and contract drilling businesses. The drilling services segment continues to benefit from long rig moves as customers reposition assets into emerging markets such as the Bakken and Eagle Ford Shales.

	•		Product Sales. Segment revenue increased $2.1 million, or 32%, for the third quarter of 2010 due to an increase in product sales from our Asian operations and an improvement in third-party sales at our fabrication and repair business in Texas over the third quarter of 2009.

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 $101.5 million, or 63%, to $263.8 million for the quarter ended September 30, 2010 from $162.3 million for the quarter ended September 30, 2009. The following table summarizes service and product expenses as a percentage of revenues for the quarters ended September 30, 2010 and 2009:

Service and Product Expenses as a Percentage of Revenue


	Quarter Ended
	9/30/10			9/30/09			Change
Segment:
Completion and production services		62	%		69	%		(7	%)
Drilling services		69	%		83	%		(14	%)
Product sales		74	%		71	%		3	%
Total		63	%		71	%		(8	%)

Service and product expenses as a percentage of revenue decreased for the quarter ended September 30, 2010 compared to the same period in 2009 primarily due to increased asset utilization and pricing improvements. Service and product expenses as a percentage of revenue for the completion and production and drilling services business segments decreased when comparing the quarter ended September 30, 2010 to the same period in 2009 due to an increase in overall oilfield activity, pricing and service mix, particularly a shift to historically higher-margin service lines. Service and product expenses as a percentage of revenue for the products segments increased 3% for the quarter ended September 30, 2010 compared to the quarter ended September 2009 primarily due to changes in product mix. Our products business is generally project-specific and margins can fluctuate between periods depending upon the type of products sold and repair work being performed.

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 $3.4 million, or 8%, for the quarter ended September 30, 2010 to $41.8 million from $45.2 million during the quarter ended September 30, 2009. The results for 2009 include charges for bad debt associated with specifically-identified uncollectible accounts, losses on the retirement of fixed assets and inventory adjustments. Excluding these items, selling, general and administrative expenses increased in 2010 compared to 2009 due to an increase in payroll costs associated with increased headcount and an increase in incentive compensation based upon earnings. As a percentage of revenues, selling, general and administrative expense was 10% and 20% for the quarters ended September 30, 2010 and 2009, respectively.

Depreciation and Amortization

Depreciation and amortization expense decreased $5.6 million, or 11%, to $44.8 million for the quarter ended September 30, 2010 from $50.4 million for the quarter ended September 30, 2009. The decrease in depreciation and amortization expense was attributable to the normal run-off of depreciation associated with existing assets while relatively few assets have been placed in service during the current year. In addition, there were significant asset retirements in 2009 including an impairment of our drilling rigs totaling $36.2 million as of September 30, 2009 and an impairment charge in late 2009 related to certain intangible assets acquired in 2008. As a percentage of revenue, depreciation and amortization was 11% and 22% for the quarters ended September 30, 2010 and 2009, respectively.

Impairment loss

We recorded an impairment charge related to our contract drilling business of $36.2 million in the third quarter of 2009 after determining that the carrying value of certain of these drilling rigs exceeded the undiscounted cash flows associated with these assets and the fair market value estimates for these assets.

Taxes

We recorded a provision of $21.1 million for the quarter ended September 30, 2010 at an effective rate of approximately 39% and a tax benefit of $26.1 million for the quarter ended September 30, 2009 at an effective rate of approximately 33%. The increase in the effective tax rate was primarily due to an increase in pre-tax earnings in various tax jurisdictions resulting in higher state income taxes, a decrease in benefit from the foreign tax rate differential and the impact of non-deductible items.

Nine Months Ended September 30, 2010 Compared to the Nine Months Ended September 30, 2009 (Unaudited)

Revenue

Revenue for the nine months ended September 30, 2010 increased by $283.6 million, or 35%, to $1,088.6 million from $805.0 million for the nine months ended September 30, 2009. The changes by segment were as follows:

•

Completion and Production Services. Segment revenue increased $256.2 million, or 38%, for the nine months ended September 30, 2010 primarily due to an increase in demand for our services and an overall increase in activity levels for the oil and gas industry during 2010 compared to 2009, resulting in higher utilization of our equipment. Activity levels and pricing in some service lines and select geographic areas began to improve during the latter part of the fourth quarter of 2009 and continued improving throughout the nine months ended September 30, 2010. The segment continued to benefit from increased horizontal drilling and completion related activity within resource plays and also benefitted from the deployment of approximately 40,000 hydraulic horse power of new pressure pumping equipment into the Eagle Ford and Bakken shales during the latter part of the third quarter of 2010.

	•		Drilling Services. Segment revenue increased $38.6 million, or 45%, for the nine months ended September 30, 2010 primarily due to improved utilization and pricing in our rig relocation and contract drilling businesses. The drilling services segment benefitted from long rig moves as customers repositioned assets into emerging markets such as the Bakken and Eagle Ford shales.

	•		Product Sales. Segment revenue decreased $11.3 million, or 30%, for the nine months ended September 30, 2010 due primarily to lower third-party sales at our repair and fabrication shop in north Texas as several large projects were completed during the first quarter of 2009, partially offset by a slight improvement in our Southeast Asian business during the nine months ended September 30, 2010 compared to the same period in 2009.

Service and Product Expenses

Service and product expenses increased $159.4 million, or 29%, to $707.7 million for the nine months ended September 30, 2010 from $548.3 million for the nine months ended September 30, 2009. The following table summarizes service and product expenses as a percentage of revenues for the nine months ended September, 2010 and 2009:

Service and Product Expenses as a Percentage of Revenue


	Nine Months Ended
	9/30/10			9/30/09			Change
Segment:
Completion and production services		64	%		67	%		(3	%)
Drilling services		71	%		74	%		(3	%)
Product sales		76	%		76	%		(0	%)
Total		65	%		68	%		(3	%)

Service and product expenses as a percentage of revenue decreased 3% for the nine months ended September 30, 2010 compared to the same period in 2009. Margins by business segment were primarily impacted by utilization and pricing.

	•		Completion and Production Services. Service and product expenses as a percentage of revenue for this business segment decreased when comparing the nine months ended September 30, 2010 to the same period in 2009. The year-over-year favorable margin improvement was attributable to an increase in overall oilfield activity, improved pricing and service mix, with an increase in sales for historically higher-margin offerings, partially offset by some inflationary factors including higher labor costs.

	•		Drilling Services. Service and product expenses as a percentage of revenue for this business segment decreased 3% for the nine months ended September 30, 2010 compared to the same period in 2009 primarily due to increased asset utilization and improved pricing.

	•		Product Sales. Service and product expenses as a percentage of revenue for the products segments remained consistent for the nine months ended September 30, 2010 compared to the same period in 2009.

Selling, General and Administrative Expenses

Selling, general and administrative expenses decreased $13.4 million, or 10% to $126.7 million, for the nine months ended September 30, 2010 compared to $140.1 million for the same period in 2009. The results for 2009 include charges for bad debt associated with specifically-identified uncollectible accounts, losses on the retirement of fixed assets and inventory adjustments. In addition, we recorded a loss on the non-monetary exchange of certain assets in Canada during the first quarter of 2009 which totaled $4.9 million. The overall decrease in selling, general and administrative expense in 2010 was partially offset by higher earnings-based incentive compensation, as well as higher insurance costs and the write-off of a $1.9 million note receivable in Canada. Excluding the impact of the non-monetary asset exchange in 2009, as a

percentage of revenues, selling, general and administrative expense was 12% and 17% for the nine months ended September 30, 2010 and 2009, respectively.

Depreciation and Amortization

Depreciation and amortization expense decreased $17.9 million, or 12%, to $135.6 million for the nine months ended September 30, 2010 from $153.5 million for the nine months ended September 30, 2009. The decrease in depreciation and amortization expense was attributable to the normal run-off of depreciation associated with existing assets while relatively few assets have been placed in service during the current year. In addition, there were significant asset retirements in 2009 including an impairment of our drilling rigs totaling $36.2 million as of September 30, 2009, sale-leaseback transactions associated with our small vehicle fleet and a facility in Wyoming and an impairment charge in late 2009 related to certain intangible assets acquired in 2008. As a percentage of revenue, depreciation and amortization expense decreased to 12% from 19% for the nine months ended September 30, 2010 and 2009, respectively.

Impairment loss

Interest Expense

Interest expense increased $1.4 million, or 3%, to $43.7 million for the nine months ended September 30, 2010 from $42.3 million for the nine months ended September 30, 2009. The increase in interest expense was primarily attributable to higher costs associated with our credit facility, which was amended during the fourth quarter of 2009. The weighted-average interest rate of borrowings outstanding at September 30, 2010 and 2009 was 8.0%.

Taxes

We recorded a tax provision of $29.2 million for the nine months ended September 30, 2010 at an effective rate of approximately 39% and a tax benefit of $37.1 million for the nine months ended September 30, 2009 at an effective rate of 32%. The lower effective rate for the nine months ended September 30, 2009 was due to our foreign tax rate differential, the impact of state and provincial tax expense relative to our operating loss and certain non-deductible items for the years in which losses occurred.

Liquidity and Capital Resources

As of September 30, 2010, we had working capital, net of cash, of $206.7 million and cash and cash equivalents of $143.3 million, compared to working capital, net of cash, of $200.8 million and cash and cash equivalents of $77.4 million at December 31, 2009. This increase in working capital was primarily due to an increase in accounts receivable, associated with favorable operational results, partially offset by an increase in accrued expenses including interest expense associated with the semi-annual payments on our senior notes. Cash increased primarily due to favorable operating results for the first nine months of 2010.

Our total outstanding debt was $650.1 million at September 30, 2010, and we have no significant debt maturities until 2016. We had no borrowings and $26.4 million in committed letters of credit outstanding under our revolving credit facility. We are not currently a party to any interest rate swaps, currency hedges or derivative contracts of any type and have no exposure to commercial paper or auction rate securities markets.

We anticipate that our cash generated from operations and our current cash balance will be sufficient to fund the majority of our cash requirements for the next twelve months, however borrowings under our amended revolving credit facility, future debt offerings and/or future public equity offerings may also be used to fund future acquisitions or satisfy our other liquidity

needs. We believe that funds from these sources will be sufficient to meet both our short-term working capital requirements and our long-term capital requirements.

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


	Nine Months Ended
	September 30,
	2010			2009
Cash flows provided by (used in):
Operating activities	$	171,440		$	270,063
Investing activities		(106,751	)		(8,939	)
Financing activities		1,090			(203,314	)

Net cash provided by operating activities decreased by $98.6 million for the nine months ended September 30, 2010 compared to the same period in 2009. Operating cash flows for 2009 were positively impacted by an increase in cash receipts, as overall oilfield activity levels declined and receivables were collected. During the first nine months of 2010, and in the quarter ended September 30, 2010 in particular, cash receipts activity has remained favorable, but an increase in sales has resulted in an increase in outstanding receivables at September 30, 2010. Partially offsetting this decrease in operating cash flows associated with trade receivables was the receipt of a $43.7 million tax refund in April 2010.

Net cash used in investing activities increased by $97.8 million for the nine months ended September 30, 2010 compared to the same period in 2009. This increase was the result of our investment in capital equipment and business acquisitions which totaled $89.9 million and $21.3 million, respectively, for the nine months ended September 30, 2010. For the nine months ended September 30, 2009, our investment in capital equipment was approx. $29.1 million, partially offset by proceeds from the retirement of fixed assets, with no business acquisitions.

Net cash provided by financing activities was $1.1 million for the nine months ended September 30, 2010 compared to net cash used for financing activities of $203.3 million for the same period in 2009. In the first nine months of 2009, we repaid $197.2 million of net borrowings under our debt facilities. No borrowings or repayments were made under these debt facilities for the first nine months of 2010. Our long-term debt, including current maturities, was $650.1 million as of September 30, 2010 and $650.2 million as of December 31, 2009.

Dividends

We did not pay dividends on our $0.01 par value common stock during the nine months ended September 30, 2010 or during the years ended December 31, 2009, 2008 and 2007. We do not intend to pay dividends in the foreseeable future, but rather plan to build our cash balance near-term and reinvest such funds in our business. Furthermore, our credit facility contains restrictive debt covenants which preclude us from paying future dividends on our common stock.

Description of Our Indebtedness

Senior Notes.

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, which commenced on June 15, 2007. There was no discount or premium associated with the issuance of these notes. The senior notes are guaranteed 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) limit our ability to purchase or redeem stock or subordinated debt; (6) limit our ability to enter into transactions with affiliates; (7) limit our ability to merge with or into other companies or transfer all or substantially all of 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. 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 SEC 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. Effective April 1, 2009, we entered into a second supplement to this indenture whereby additional domestic subsidiaries became guarantors under the indenture.

Credit Facility.

We maintain a senior secured facility (the “Credit Agreement”) with Wells Fargo Bank, National Association, as U.S. Administrative Agent, HSBC Bank Canada, as Canadian Administrative Agent, and certain other financial institutions. On October 13, 2009, we entered into the Third Amendment (the Credit Agreement after giving effect to the Third Amendment, the “Amended Credit Agreement”) and modified the structure of our existing credit facility to an asset-based facility subject to borrowing base restrictions. In connection with the Third Amendment, Wells Fargo Capital Finance, LLC (formerly known as Wells Fargo Foothill, LLC) replaced Wells Fargo Bank, National Association, as U.S. Administrative Agent and also serves as U.S. Issuing Lender and U.S. Swingline Lender under the Amended Credit Agreement. The Amended Credit Agreement provides for a U.S. revolving credit facility of up to $225 million that matures in December 2011 and a Canadian revolving credit facility of up to $15 million (with Integrated Production Services Ltd., one of our wholly-owned subsidiaries, as the borrower thereof (“Canadian Borrower”)) that matures in December 2011. The Amended Credit Agreement includes a provision for a “commitment increase”, as defined therein, which permits us to effect up to two separate increases in the aggregate commitments under the Amended Credit Agreement by designating one or more existing lenders or other banks or financial institutions, subject to the bank’s sole discretion as to participation, to provide additional aggregate financing up to $75 million, with each committed increase equal to at least $25 million in the U.S., or $5 million in Canada, and in accordance with other provisions as stipulated in the Amended Credit Agreement. Certain portions of the credit facilities are available to be borrowed in U.S. dollars, Canadian dollars and other currencies approved by the lenders.

We were not subject to the fixed charge coverage ratio covenant in the Amended Credit Agreement as of September 30, 2010 since the Excess Availability Amount plus Qualified Cash Amount (each as defined in the Amended Credit Agreement) exceeded $50 million. If we were subject to the fixed charge coverage ratio covenant, we would have been in compliance as of September 30, 2010. For a discussion of the methodology to calculate the borrowing base for the U.S. and Canadian portions of the facility, as well as our debt covenant requirements, prepayment options and potential exposure in the event of a default under the Amended Credit Agreement, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our Annual Report on Form 10-K as of December 31, 2009.

All of the obligations under the U.S. portion of the Amended Credit Agreement are secured by first priority liens on substantially all of our assets and 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 Amended Credit Agreement are guaranteed by substantially all of our U.S. subsidiaries. The obligations under the Canadian portion of the Amended Credit Agreement are secured by first priority liens on substantially all of our assets and the assets of our subsidiaries (other than our Mexican subsidiary). Additionally, all of the obligations under the Canadian portion of the Amended Credit Agreement are guaranteed by us as well as certain of our subsidiaries.

Subject to certain limitations set forth in the Amended Credit Agreement, we have the ability to elect how interest under the Amended Credit Agreement will be computed. Interest under the Amended Credit Agreement may be determined by reference to (1) the London Inter-bank Offered Rate, or LIBOR, plus an applicable margin between 3.75% and 4.25% per annum (with the applicable margin depending upon our “excess availability amount”, as defined in the Amended Credit Agreement) or (2) the “Base Rate” (which means the higher of the Prime Rate, Federal Funds Rate plus 0.50%, 3-month LIBOR plus 1.00% and 3.50%), plus the applicable margin, as described above. For the period from the effective date of the Third Amendment until the six month anniversary of the effective date of the Third Amendment, interest was computed with an applicable margin rate of 4.00%. If an event of default exists or continues under the Amended Credit Agreement, advances will bear interest as described above with an applicable margin rate of 4.25% plus 2.00%. Additionally, if an event of default exists under the Amended Credit Agreement, as defined therein, the lenders could accelerate the maturity of the obligations outstanding thereunder and exercise other rights and remedies. Interest is payable monthly.

There were no borrowings outstanding under our U.S. or Canadian revolving credit facilities as of or during the nine months ended September 30, 2010. There were letters of credit outstanding under the U.S. revolving portion of the facility totaling $26.4 million, which reduced the available borrowing capacity as of September 30, 2010. We incurred fees related to our letters of credit as of September 30, 2010 at 4.0% per annum. For the nine months ended September 30, 2010, fees related to our letters of credit were calculated using a 360-day provision, at 4.1% per annum. The net excess availability under our borrowing base calculations for the U.S. and Canadian revolving facilities at September 30, 2010 was $183.9 million and $7.0 million respectively.

The primary purpose of our letters of credit is to secure potential future claim liability which may be incurred by our insurance providers. During the quarter ended September 30, 2010, we negotiated a reduction in our letter of credit requirements of $5.6 million. In addition, we placed $17.0 million in escrow as a compensating balance, effectively cash collateralizing a portion of our letters of credit, in order to better utilize excess cash and reduce interest expense. This compensating balance has been recorded as a long-term asset called “Restricted Cash” on the accompanying consolidated balance sheet at September 30, 2010.

We incur unused commitment fees under the Amended Credit Agreement ranging from 0.50% to 1.00% based on the average daily balance of amounts outstanding. The unused commitment fees were calculated at 1.00% as of September 30, 2010.

Outstanding Debt and Commitments

Our long-term debt and lease obligations have not changed materially since December 31, 2009, however we have entered into agreements to purchase certain equipment for use in our business during the first nine months of 2010 which exceed $31.0 million. 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 believe that our cash on hand, available borrowing capacity under our credit facilities and our operating cash flows should be sufficient to fund our firm purchase commitments.

We entered into an agreement in October 2010 to purchase two saltwater disposal wells for approximately $11.0 million in cash in the Rocky Mountain Region. However, this acquisition has not funded as of October 28, 2010, and remains subject to finalization.

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

amended revolving credit facility for this purpose.

Recent Accounting Pronouncements and Authoritative Guidance

In May 2009, the Financial Accounting Standards Board “FASB” issued a standard regarding subsequent events that provides guidance as to when an entity should recognize events or transactions occurring after a balance sheet date in its financial statements and the necessary disclosures related to these events. Specifically, the entity should recognize subsequent events that provide evidence about conditions that existed at the balance sheet date, including significant estimates used to prepare financial statements. Originally, this standard required entities to disclose the date through which subsequent events had been evaluated and whether that date was the date the financial statements were issued or the date the financial statements were available to be issued. We adopted this accounting standard effective June 30, 2009 and applied its provisions prospectively. In February 2010, the FASB modified this standard to eliminate the requirement for publicly-traded entities to disclose the date through which subsequent events have been evaluated. Therefore, we omitted the disclosure in this Quarterly Report on Form 10-Q as of September 30, 2010.

On March 30, 2010, the President of the United States signed the Health Care and Education Reconciliation Act of 2010, which is a reconciliation bill that amends the Patient Protection and Affordable Care Act that was signed by the President on March 23, 2010. Certain provisions of this law became effective during the quarter ended September 30, 2010. We have reviewed our health insurance plan provisions with third-party consultants and continue to evaluate our position relative to the changes in the law. We do not believe that the provisions which have taken effect during the quarter will have a significant impact on the operation of our existing health insurance plan. However, future provisions under the law which become effective in subsequent periods may impact our health insurance plan and our overall financial position. We are evaluating these provisions as they become effective and continue to seek guidance from the FASB and SEC related to the implications of this new legislation on accounting and disclosure requirements. We expect that this legislation will have an impact on our financial position, results of operations and cash flows, but we cannot determine the extent of the impact at this time.

Off Balance Sheet Arrangements

We have entered into operating lease arrangements for our light vehicle fleet, certain of our specialized equipment and for our office and field operating locations in the normal course of business. The terms of the facility leases range from monthly to ten years. The terms of the light vehicle leases range from three to four years. The terms of the specialized equipment leases range from monthly to seven years.

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 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 nine months ended September 30, 2010, approximately 5% of our revenues and approximately 4% 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 nine months ended September 30, 2010 by approximately $0.5 million. 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 statement of operations. 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 nine months ended September 30, 2010 by approximately $0.4 million. Currently, we conduct a portion of our business in Mexico in the local currency, the Mexican peso.

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. In designing and evaluating our disclosure controls and procedures, our management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving

the desired control objectives, and management was required to apply its judgment in evaluating and implementing possible controls and procedures. Based on such evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures were effective as of September 30, 2010 at the reasonable assurance level.

In 2010, our management approved a plan to implement new accounting software which will replace our existing accounting systems at several of our operating divisions in a phased approach, whereby two divisions will convert during the fourth quarter of 2010 and two divisions will convert effective January 1, 2011. In addition, we are implementing a new chart of accounts which is being adopted as these divisions convert to the new software. Although we believe the new software, once implemented, will enhance our internal controls over financial reporting and we believe that we have taken the necessary steps to maintain appropriate internal control over financial reporting during this period of system change, we will continuously monitor controls through and around the system to provide reasonable assurance that controls are effective during and after each step of this implementation process.

There have been no changes in our internal control over financial reporting during the quarter ended September 30, 2010 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

Item 1A. Risk Factors.

Our business faces many risks. Any of the risks discussed elsewhere in this Form 10-Q or our other SEC filings, could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations. For a detailed discussion of the risk factors that should be understood by any investor contemplating investment in our stock, please refer to the section entitled “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2009 and our Quarterly Report on Form 10-Q for the quarter ended June 30, 2010.

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

In accordance with the provisions of the 2008 Incentive Award Plan, as amended, holders of unvested restricted stock were given the option to either remit to us the required withholding taxes associated with the vesting of restricted stock, or to authorize us to purchase shares equivalent to the cost of the withholding tax and to remit the withholding taxes on behalf of the holder. Such purchases for the quarter ended September 30, 2010 are summarized in the following table:

(d)

Maximum

Number (or

Approximate

Dollar

number of

Value) of

Purchased

that May

(b)

as Part of

Yet Be

Average

Publicly

Purchased

(a) Total Number

Price

Announced

Under the

of Shares

Paid per

Plans or

Period

Purchased

Programs

July 1 - 31, 2010

591

14.38


*		We do not have a publicly announced stock repurchase program. We had 1,674,379 shares of non-vested restricted stock outstanding at September 30, 2010. The holders of these shares have the option to either remit taxes due related to the vesting of these shares or to authorize us to purchase the shares at the current market value in a sufficient amount to settle the related tax withholding. The amount purchased will depend on the market value at the time and whether or not the holders choose to surrender shares in settlement of the related tax withholding.

Item 3. Defaults Upon Senior Securities.

None.

Item 5. Other Information.

None.

Item 6. Exhibits.

The exhibits listed in the accompanying Exhibit Index are incorporated by reference into this Item 6.

SIGNATURE

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


	COMPLETE PRODUCTION SERVICES, INC.

October 28, 2010	By:	/s/ Jose A. Bayardo
Date		Jose A. Bayardo
		Sr. Vice President and
		Chief Financial Officer
		(Duly Authorized Officer and
		Principal Financial Officer)

EXHIBIT INDEX


Exhibit
No.		Exhibit Title
31.1*	—	Certification of Chief Executive Officer Pursuant to Rule 13a – 14(a) and Rule 15a – 14(a) of the Securities and Exchange Act of 1934, as Amended

31.2*	—	Certification of Chief Financial Officer Pursuant to Rule 13a – 14(a) and Rule 15a – 14(a) of the Securities and Exchange Act of 1934, as Amended

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

101**	—	Complete Production Services, Inc. Quarterly Report on Form 10-Q for the quarter ended September 30, 2010, formatted in Extensible Business Reporting Language (XBRL): (i) the Consolidated Balance Sheets at September 30, 2010 and December 31, 2009, (ii) the Consolidated Statements of Operations for the three and nine months ended September 30, 2010, and September 30, 2009, (iii) the Consolidated Stockholders’ Equity for the nine months ended September 30, 2010, (iv) the Consolidated Statements of Cash Flows for the nine months ended September 30, 2010, and September 30, 2009, and (v) the Notes to Consolidated Financial Statements (tagged as blocks of text).


*		Filed herewith.

**		Furnished herewith.