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As filed with the Securities and Exchange Commission on March 17, 2006
Registration No. 333-128750
 
 
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
AMENDMENT NO. 4 TO
FORM S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
 
Complete Production Services, Inc.
(Exact name of registrant as specified in its charter)
         
Delaware   1389   72-1503959
(State or other jurisdiction of
incorporation or organization)
  (Primary Standard Industrial Classification
Code Number)
  (I.R.S. Employer
Identification No.)
 
11700 Old Katy Road, Suite 300
Houston, Texas 77079
(281) 372-2300
(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)
 
Joseph C. Winkler
Chief Executive Officer and President
11700 Old Katy Road, Suite 300
Houston, Texas 77079
(281) 372-2300
(Name, address, including zip code, and telephone number, including area code, of agent for service)
Copies to:
     
Vinson & Elkins L.L.P.
  Baker Botts L.L.P.
First City Tower, Suite 2300
  One Shell Plaza, 910 Louisiana Street
Houston, Texas 77002
  Houston, Texas 77002
(713) 758-2222
  (713) 229-1234
Attn: Scott N. Wulfe
  Attn: R. Joel Swanson
Attn: Nicole E. Clark
  Attn: Felix P. Phillips
      Approximate date of commencement of proposed sale to the public: As soon as practicable after this Registration Statement becomes effective.
      If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, please check the following box.     o
      If this form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.     o
      If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.     o
      If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.     o
      If delivery of the prospectus is expected to be made pursuant to Rule 434, please check the following box.     o
 
      The Registrant hereby amends this Registration Statement on such date or dates as may be necessary to delay its effective date until the Registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until the Registration Statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.
 
 


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The information in this prospectus is not complete and may be changed. We may not sell these securities until the registration statement filed with the Securities and Exchange Commission is effective. This prospectus is not an offer to sell these securities and it is not soliciting an offer to buy these securities in any state where the offer or sale is not permitted.
SUBJECT TO COMPLETION, DATED MARCH 17, 2006
                             Shares
(COMPLETE PRODUCTION SERVICES LOGO)
Complete Production Services, Inc.
Common Stock
 
        We are selling            shares of our common stock and the selling stockholders are selling            shares of our common stock. Prior to this offering, there has been no public market for our common stock. The initial public offering price of our common stock is expected to be between $          and $           per share. Our common stock has been approved for listing on the New York Stock Exchange under the symbol “CPX”. We will not receive any of the proceeds from the shares of common stock sold by the selling stockholders.
      The underwriters have an option to purchase a maximum of                      additional shares from the selling stockholders to cover over-allotments of shares.
      Investing in our common stock involves risks. See “Risk Factors” beginning on page 9.
                                 
            Proceeds to    
        Underwriting   Complete   Proceeds to
    Price to   Discounts and   Production   Selling
    Public   Commissions   Services   Stockholders
                 
Per Share
     $          $          $          $    
Total
  $       $       $       $    
      Delivery of the shares of common stock will be made on or about                     , 2006.
      Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.
Credit Suisse UBS Investment Bank
Banc of America Securities LLC
  Jefferies & Company
  Johnson Rice & Company L.L.C.
  Raymond James
  Simmons & Company
  International
  Pickering Energy Partners
The date of this prospectus is                     , 2006.


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(Operating Segments)


 

 
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 Amended Stockholders' Agreement
 Compensation Package Term Sheet - J. Michael Mayer
 Compensation Package Term Sheet - James F. Maroney III
 Compensation Package Term Sheet - Kenneth L. Nibling
 Consent of Grant Thornton LLP
 Consent of KPMG LLP
 Consent of Darnall, Sikes, Gardes & Frederick
 Consent of BKD LLP
 
      You should rely only on the information contained in this prospectus or to which we have referred you. We have not authorized anyone to provide you with information that is different. This document may only be used where it is legal to sell these securities. The information in this document may only be accurate on the date of this document.
Dealer Prospectus Delivery Obligation
      Until                     , 2006 (25 days after the commencement of the offering), all dealers that effect transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to the dealers’ obligation to deliver a prospectus when acting as an underwriter and with respect to unsold allotments or subscriptions.
Cautionary Note Regarding Industry and Market Data
      This prospectus includes industry data and forecasts that we obtained from publicly available information, industry publications and surveys. Our forecasts are based upon management’s understanding of industry conditions. We believe that the information included in this prospectus from industry surveys, publications and forecasts is reliable.
Non-GAAP Financial Measures
      The body of accounting principles generally accepted in the United States is commonly referred to as “GAAP.” A non-GAAP financial measure is generally defined by the Securities and Exchange Commission, or SEC, as one that purports to measure historical or future financial performance, financial position or cash flows, but excludes or includes amounts that would not be so adjusted in the most comparable GAAP measures. In this prospectus, we disclose EBITDA, a non-GAAP financial measure. EBITDA is calculated as net income before interest expense, taxes, depreciation and amortization and minority interest. EBITDA is not a substitute for the GAAP measures of earnings and cash flow. EBITDA is included in this prospectus 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.

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PROSPECTUS SUMMARY
      This prospectus summary highlights information contained in this prospectus. Before investing in our common stock, you should read this entire prospectus carefully, including the section entitled “Risk Factors” and our financial statements and related notes, for a more detailed description of our business and this offering. In this prospectus, “Complete,” “company,” “we,” “us” and “our” refer to Complete Production Services, Inc. and its subsidiaries, except as otherwise indicated. Please read “Glossary of Selected Industry Terms” included in this prospectus for definitions of certain terms that are commonly used in the oilfield services industry. Unless otherwise indicated, all references to “dollars” and “$” in this prospectus are to, and amounts are presented in, U.S. dollars. Unless the context indicates otherwise, all information in this prospectus assumes that the underwriters do not exercise their over-allotment option.
Our Company
      We provide specialized services and products focused on helping oil and gas companies develop hydrocarbon reserves, reduce 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 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 and Kansas, western Canada and Mexico.
      We seek to differentiate ourselves from our competitors through our local leadership, basin-level expertise and the innovative application of proprietary and other technologies. We deliver solutions to our customers that we believe lower their costs and increase their production in a safe and environmentally friendly manner.
      Our business is comprised of three segments:
      Completion and Production Services. Through our completion and production services segment, we establish, maintain and enhance the flow of oil and gas throughout the life of a well. This segment is divided into the following primary service lines:
  •  Intervention Services. Well intervention requires the use of specialized equipment to perform an array of wellbore services. Our fleet of intervention service equipment includes coiled tubing units, pressure pumping units, nitrogen units, well service rigs, snubbing units and a variety of support equipment. Our intervention services provide customers with innovative solutions to increase production of oil and gas.
 
  •  Downhole and Wellsite Services. Our downhole and wellsite services include electric-line, slickline, production optimization, production testing, rental and fishing services. We also offer several proprietary services and products that we believe create significant value for our customers.
 
  •  Fluid Handling. We provide a variety of services to help our customers obtain, move, store and dispose of fluids that are involved in the development and production of their reservoirs. Through our fleet of specialized trucks, frac tanks and other assets, we provide fluid transportation, heating, pumping and disposal services for our customers.
      Drilling Services. Through our drilling services segment, we provide services and equipment that initiate or stimulate oil and gas production by providing land drilling, specialized rig logistics and site preparation. Through this segment, we also provide pressure control, drill string, pipe handling and other equipment. Our drilling rigs currently operate exclusively in the Barnett Shale region of north Texas.
      Product Sales. Through our product sales segment, we provide a variety of equipment used by oil and gas companies throughout the lifecycle of their wells. Our current product offering includes completion, flow control and artificial lift equipment as well as tubular goods.
      For further information on our company, please read “Business – Our Company.”

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Our Industry
      Our business depends on the level of exploration, development and production expenditures made by our customers. These expenditures are driven by the current and expected future prices for oil and gas, and the perceived stability and sustainability of those prices. Our business is primarily driven by natural gas drilling activity in North America. We believe the following two principal economic factors will positively affect our industry in the coming years:
  •  Higher demand for natural gas in North America. We believe that natural gas will be in high demand in North America over the next several years because of the growing popularity of this clean-burning fuel.
 
  •  Constrained North American gas supply. Although the demand for natural gas is projected to increase, supply is likely to be constrained as North American natural gas basins are becoming more mature and experiencing increased decline rates.
      Higher demand for natural gas and a constrained gas supply have resulted in higher prices and increased drilling activity. The increase in prices and drilling activity are driving three additional trends that we believe will benefit us:
        Trend toward drilling and developing unconventional North American natural gas resources. Due to the maturity of conventional North American oil and gas reservoirs and their accelerating production decline rates, unconventional oil and gas resources will comprise an increasing proportion of future North American oil and gas production. Unconventional resources include tight sands, shales and coalbed methane. These resources require more wells to be drilled and maintained, frequently on tighter acreage spacing. The appropriate technology to recover unconventional gas resources varies from region to region; therefore, knowledge of local conditions and operating procedures, and selection of the right technologies is key to providing customers with appropriate solutions.
 
        The advent of the resource play. A “resource play” is a term used to describe an accumulation of hydrocarbons known to exist over a large area which, when compared to a conventional play, has lower commercial development risks and a lower average decline rate. Once identified, resource plays have the potential to make a material impact because of their size and low decline rates. The application of appropriate technology and program execution are important to obtain value from resource plays.
 
        Increasingly complex technologies. Increasing prices and the development of unconventional oil and gas resources are driving the need for complex, new technologies to help increase recovery rates, lower production costs and accelerate field development. We believe that the increasing complexity of technology used in the oil and gas development process coupled with limited engineering resources will require production companies to increase their reliance on service companies to assist them in developing and applying these technologies.
      While we believe that these trends will benefit us, our markets may be adversely affected by industry conditions that are largely beyond our control. Any prolonged substantial reduction in oil and gas prices would likely affect oil and gas drilling and production levels and therefore affect demand for the services we provide. For more information on this and other risks to our business and our industry, please read “Risk Factors – Risks Related to Our Business and Our Industry.”
      For further information on our industry, please read “Business – Our Industry.”

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Our Business Strategy
      Our goal is to build the leading oilfield services company focused on the completion and production phases in the life of an oil and gas well. We intend to capitalize on the emerging trends in the North American marketplace through the execution of a growth strategy that consists of the following components:
      Expand and capitalize on local leadership and basin-level expertise. A key component of our strategy is to build upon our base of strong local leadership and basin-level expertise. We have a significant presence in most of the key onshore continental U.S. and Canadian gas plays we believe have the potential for long-term growth. We intend to leverage our existing market presence, strong local leadership, expertise and customer relationships to expand our business within these gas plays. We also intend to replicate this approach in new regions by building and acquiring new businesses that have strong regional management with extensive local knowledge.
      Develop and deploy technical and operational solutions. We are focused on developing and deploying technical services, equipment and expertise that lower our customer’s costs.
      Capitalize on organic and acquisition-related growth opportunities. We believe there are numerous opportunities to sell new services and products to customers in our current geographic areas and to sell our current services and products to customers in new geographic areas. We have a proven track record of organic growth and successful acquisitions, and we intend to continue using capital investments and acquisitions to strategically expand our business.
      Focus on execution and performance. We have established and intend to develop further a culture of performance and accountability. Senior management spends a significant portion of its time ensuring that our customers receive the highest quality of service.
      Successful execution of our business strategy depends on our ability to retain key personnel and to continue to employ a sufficient number of skilled and qualified workers. The demand for skilled workers is high, and the supply is limited. If we are not able to retain key personnel and continue to employ a sufficient number of skilled and qualified workers, our business could be harmed. For more information on this and other risks to our business and our industry, please read “Risk Factors – Risks Related to Our Business and Our Industry.”
      For further information on our business strategy, please read “Business – Our Business Strategy.”
Our Competitive Strengths
      We believe that we are well positioned to execute our strategy and capitalize on opportunities in the North American oil and gas market based on the following competitive strengths:
      Strong local leadership and basin-level expertise. We operate our business with a focus on each regional basin complemented by our local reputations. We believe our local and regional businesses, some of which have been operating for more than 50 years, provide us with a significant advantage over many of our competitors. Our managers, sales engineers and field operators have extensive expertise in their local geological basins, understand the regional challenges our customers face and have long-term relationships with many customers. We strive to leverage this basin-level expertise to establish ourselves as the preferred provider of our services in the basins in which we operate.
      Significant presence in major North American basins. We operate in major oil and gas producing regions of the U.S. Rocky Mountains, Texas, Oklahoma, Louisiana, Arkansas and Kansas, western Canada and Mexico, with concentrations in key “resource play” and unconventional basins. Resource plays are expected to become increasingly important in future North American oil and gas production as more conventional resources enter later stages of the exploration cycle. We believe we have an excellent position in highly active markets such as the Barnett Shale region of north Texas. Accelerating production and driving down development and production costs are key goals for oil and gas operators in these areas,

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resulting in strong demand for our services and products. In addition, our strong presence in these regions allows us to build solid customer relationships and take advantage of cross-selling opportunities.
      Focus on complementary production and field development services. Our breadth of service and product offerings well positions us relative to our competitors. Our complementary services encompass the entire lifecycle of a well from drilling and completion, through production and eventual abandonment. This suite of services and products gives us the opportunity to cross-sell to our customer base and throughout our geographic regions. Leveraging our strong local leadership and basin-level expertise, we are able to offer expanded services and products to existing customers or current services and products to new customers.
      Innovative approach to technical and operational solutions. We develop and deploy services and products that enable our customers to increase production rates, stem production declines and reduce the costs of drilling, completion and production. The significant expertise we have developed in our areas of operation offers our customers customized operational solutions to meet their particular needs.
      Modern and active asset base. We have a modern and well-maintained fleet of coiled tubing units, pressure pumping equipment, wireline units, well service rigs, snubbing units, fluid transports, frac tanks and other specialized equipment. We believe our ongoing investment in our equipment allows us to better serve the diverse and increasingly challenging needs of our customer base. Our fleet is active with high utilization. We believe our future expenditures will be used to capitalize on growth opportunities within the areas we currently operate and to build out new platforms obtained through targeted acquisitions.
      Experienced management team with proven track record. Each executive officer and member of our key operational management team has over 20 years of experience in the oilfield services industry. We believe that their considerable knowledge of and experience in our industry enhances our ability to operate effectively throughout industry cycles. Our management also has substantial experience in identifying, completing and integrating acquisitions.
      While we believe that these strengths differentiate us from our competitors, the markets in which we operate are highly competitive and have relatively few barriers to entry. We face competition from large national and multi-national companies that have greater resources and greater name recognition than we do as well as from several smaller companies capable of competing effectively on a regional basis. In addition, we may face substantial competition from new entrants in the future. For more information on these and other risks to our business and our industry, please read “Risk Factors – Risks Related to Our Business and Our Industry.”
      For further information on our competitive strengths, see “Business – Our Competitive Strengths.”
The Combination
      Prior to 2001, SCF Partners, a private equity firm, began to target investment opportunities in service-oriented companies in the North American natural gas market with specific focus on the production phase of the exploration and production cycle. On May 22, 2001, SCF Partners, through SCF-IV, L.P. (“SCF”), formed Saber Energy Services, Inc. (“Saber”), a new company, in connection with its acquisition of two companies primarily focused on completion and production related services in Louisiana. In July 2002, SCF became the controlling stockholder of Integrated Production Services, Ltd., a production enhancement company that, at the time, focused its operation in Canada. In September 2002, Saber acquired this company and changed its name to Integrated Production Services, Inc. (“IPS”). Subsequently, IPS began to grow organically and through several acquisitions, with the ultimate objective of creating a technical leader in the enhancement of natural gas production. In November 2003, SCF formed another production services company, Complete Energy Services, Inc. (“CES”), establishing a platform from which to grow in the Barnett Shale region of north Texas. Subsequently, through organic growth and several acquisitions, CES extended its presence to the U.S. Rocky Mountain and the Mid-Continent regions. In the summer of 2004, SCF formed I.E. Miller Services, Inc. (“IEM”), which at the

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time had a presence in Louisiana and Texas. During 2004, IPS and IEM independently began to execute strategic initiatives to establish a presence in both the Barnett Shale and U.S. Rocky Mountain regions.
      On September 12, 2005, IPS, CES and IEM were combined and became Complete Production Services, Inc. in a transaction we refer to as the “Combination.” We believe that operational and financial benefits realized through the Combination establish the foundation for long-term growth for the combined company. Immediately after the Combination, SCF held approximately 70% of our outstanding common stock. For additional information regarding the Combination, see “Business – The Combination.”
How You Can Contact Us
      Our principal executive offices are located at 11700 Old Katy Road, Suite 300, Houston, Texas 77079 and our telephone number is (281) 372-2300. Our corporate website address is www.completeproduction.com. The information contained in or accessible from our corporate website is not part of this prospectus.

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The Offering
Common stock offered by us                      shares.
 
Common stock offered by the selling stockholders                      shares.
 
Common stock to be outstanding after the offering                      shares.
 
Common stock owned by the selling stockholders after the offering                      shares (                     shares if the underwriters’ over-allotment option is fully exercised).
 
Use of proceeds We estimate that our net proceeds from the sale of the shares offered by us, after deducting estimated expenses and underwriting discounts and commissions, will be approximately $240 million. We plan to use $50 million of our net proceeds from this offering to repay a portion of our term loan facility, $5 million to repay seller financed notes and the remainder to pay all outstanding balances under our revolving credit facility and for general corporate purposes, which may include cash payments made in connection with future acquisitions. Affiliates of some of the underwriters of this offering are lenders under our revolving credit facility and therefore will receive a portion of the proceeds from this offering that we use to repay indebtedness. In addition, affiliates of the underwriters may have positions from time to time in our term loan facility. We will not receive any of the proceeds from the sale of any shares of our common stock by the selling stockholders. See “Use of Proceeds” and “Underwriting.”
 
Over-allotment option The selling stockholders have granted the underwriters a 30-day option to purchase a maximum of                     additional shares of our common stock at the initial public offering price to cover over-allotments.
 
NYSE symbol “CPX”
 
Risk factors See “Risk Factors” included in this prospectus for a discussion of factors that you should carefully consider before deciding to invest in shares of our common stock.
      The number of shares of common stock that will be outstanding after the offering includes shares of restricted common stock issued to officers and other employees under our stock incentive plans (our “stock incentive plans”) that are subject to vesting. As of December 31, 2005, there were 786,170 shares of restricted stock outstanding that remain subject to vesting.
      The number of shares of common stock that will be outstanding after the offering excludes:
  •  3,512,444 shares issuable upon the exercise of options outstanding as of December 31, 2005 under our stock incentive plans;
 
  •  an aggregate of 1,726,886 shares of common stock reserved and available for future issuance as of December 31, 2005 under our stock incentive plans; and
 
  •  an aggregate of approximately 1,200,000 shares, which may be issued as contingent consideration based on certain operating results of companies previously acquired.

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Summary Consolidated Financial Data
      The following table presents summary historical consolidated financial and operating data for the periods shown. The summary consolidated financial data as of December 31, 2001 and for the year ended December 31, 2001, have been derived from IPS’s consolidated financial statements for such date and period. The summary consolidated financial data as of December 31, 2002 and for the year ended December 31, 2002 have been derived from the audited consolidated financial statements of IPS for such date and period. In addition, the following summary consolidated financial data as of December 31, 2005, 2004 and 2003 and for the three-year period ended December 31, 2005 have been derived from our audited consolidated financial statements for those dates and periods. The following information should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our financial statements and related notes included in this prospectus.
      On December 29, 2005, we effected a 2-for-1 split of common stock. As a result, all common stock and per share data, as well as data related to other securities including stock warrants, restricted stock and stock options, have been adjusted retroactively to give effect to this stock split for all periods presented within this prospectus, except par value which remained at $0.01 per share, resulting in an insignificant reclassification between common stock and additional paid-in-capital.
                                             
    Year Ended December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands, except per share data)
Statement of Operations Data:
                                       
Revenue:
                                       
 
Completion and production services
  $ 5,855     $ 30,110     $ 65,025     $ 194,953     $ 510,304  
 
Drilling services
                2,707       44,474       129,117  
 
Products sales
          10,494       35,547       81,320       118,305  
                               
   
Total
    5,855       40,604       103,279       320,747       757,726  
Expenses:
                                       
 
Service and product expenses(1)
    3,528       28,531       73,124       216,173       481,394  
 
Selling, general and administrative
    1,563       7,764       16,591       46,077       111,754  
 
Depreciation and amortization
    402       4,187       7,648       21,616       48,840  
 
Write-off of deferred financing fees
                            3,315  
                               
   
Operating income
    362       122       5,916       36,881       112,423  
Interest expense
    176       1,260       2,687       7,471       24,461  
Taxes
    86       (477 )     1,506       10,821       33,716  
                               
 
Income (loss) before minority interest
    100       (661 )     1,723       18,589       54,246  
Minority interest
                247       4,705       384  
                               
 
Net income (loss)
  $ 100     $ (661 )   $ 1,476     $ 13,884     $ 53,862  
                               
Earnings (loss) per share – basic
  $ 0.03     $ (0.12 )   $ 0.11     $ 0.47     $ 1.16  
                               
Earnings (loss) per share – diluted
  $ 0.03     $ (0.12 )   $ 0.10     $ 0.46     $ 1.06  
                               
Weighted average shares – basic
    2,890       5,514       13,675       29,548       46,603  
Weighted average shares – diluted
    2,890       5,514       14,109       30,083       50,656  
 
(1)  Service and product expenses is the aggregate of service expenses and product expenses.

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    Year Ended December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands)
Other Financial Data:
                                       
EBITDA(2)
  $ 764     $ 4,309     $ 13,564     $ 58,497     $ 161,263  
Cash flows from operating activities
    1,683       (8 )     13,965       34,622       76,427  
Cash flows from financing activities
    33,320       36,279       55,281       157,630       112,139  
Cash flows from investing activities
    (32,538 )     (35,616 )     (66,214 )     (186,776 )     (188,358 )
Capital expenditures:
                                       
 
Acquisitions, net of cash acquired(3)
    9,860       27,851       54,798       139,362       67,689  
 
Property, plant and equipment
    2,678       6,799       11,084       46,904       127,215  
                                         
    As of December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands)
Balance Sheet Data:
                                       
Cash and cash equivalents
  $ 2,465     $ 3,120     $ 6,094     $ 11,547     $ 11,405  
Net property, plant and equipment
    7,110       47,808       95,217       235,211       384,580  
Total assets
    38,571       110,596       206,066       515,153       937,653  
Long-term debt, excluding current portion
    2,522       22,270       50,144       169,190       509,990  
Total stockholders’ equity
    34,550       65,262       97,956       172,080       250,761  
 
(2)  EBITDA consists of net income (loss) before interest expense, taxes, depreciation and amortization and minority interest. See “Non-GAAP Financial Measures.” EBITDA is included in this prospectus 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 EBITDA. In addition, we use EBITDA in evaluating acquisition targets. Management also believes that EBITDA is a useful tool for measuring our ability to meet our future debt service, capital expenditures and working capital requirements, and EBITDA is commonly used by us and our investors to measure our ability to service indebtedness. EBITDA is not a substitute for the GAAP measures of earnings or of 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 and minority interest. The following table reconciles EBITDA with our net income (loss).
 
(3)  Acquisitions, net of cash required, consists only of the cash component of acquisitions. It does not include common stock and notes issued for acquisitions, nor does it include other non-cash assets issued for acquisitions.
Reconciliation of EBITDA
                                         
    Year Ended December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands)
Net income (loss)
  $ 100     $ (661 )   $ 1,476     $ 13,884     $ 53,862  
Plus: interest expense
    176       1,260       2,687       7,471       24,461  
Plus: tax expense
    86       (477 )     1,506       10,821       33,716  
Plus: depreciation and amortization
    402       4,187       7,648       21,616       48,840  
Plus: minority interest
                247       4,705       384  
                               
EBITDA
  $ 764     $ 4,309     $ 13,564     $ 58,497     $ 161,263  
                               

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RISK FACTORS
      An investment in our common stock involves a high degree of risk. You should carefully consider the following risk factors, together with the other information contained in this prospectus, before deciding to invest in our common stock. If any of the following risks develop into actual events, our business, financial condition, results of operations or cash flows could be materially adversely affected, the trading price of shares of our common stock could decline, and you may lose all or part of your investment.
Risks Related to Our Business and Our Industry
Our business depends on the oil and gas industry and particularly on the level of activity for North American oil and gas. Our markets may be adversely affected by industry conditions that are beyond our control.
      We depend on our customers’ willingness to make operating and capital expenditures to explore for, develop and produce oil and gas in North America. If these expenditures decline, our business will suffer. Our customers’ willingness to explore, develop and produce depends largely upon prevailing industry conditions that are influenced by numerous factors over which management has no control, such as:
  •  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, including hurricanes that can affect oil and gas operations over a wide area;
 
  •  domestic and worldwide economic conditions;
 
  •  political instability in oil and gas 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 North American oil and gas exploration and production industry is volatile. Expected trends in oil and gas production activities may not continue and demand for the services provided by us may not reflect the level of activity in the industry. Any prolonged substantial reduction in oil and gas prices would likely affect oil and gas production levels and therefore affect demand for the services we provide. A material decline in oil and gas prices or North American activity levels could have a material adverse effect on our business, financial condition, results of operations and cash flows. In addition, a decrease in the development rate of oil and gas reserves in our market areas may also have an adverse impact on our business, even in an environment of stronger oil and gas prices.
Because the oil and gas industry is cyclical, our operating results may fluctuate.
      Oil and gas prices are volatile. For example, over the last three years, the WTI Cushing crude oil spot price has ranged from a low of $25.24 per bbl on April 29, 2003 to a high of $69.81 per bbl on August 24, 2005. The Henry Hub natural gas spot price has ranged from $3.99 per mcf on October 31, 2003 to $15.39 per mcf on December 13, 2005. Until recently, these prices have generally been at historically high levels. Gas prices have recently declined substantially. The Henry Hub natural gas spot price on March 1, 2006 was $6.62 per mcf. Oil prices have also declined. The WTI Cushing crude oil spot price on March 1,

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2006 was $61.97. The increase in prices over the last few years has caused oil and gas companies and drilling contractors to change their strategies and expenditure levels, which has benefited us. However, the recent decline in oil and gas prices may result in a decrease in the expenditure levels of oil and gas companies and drilling contractors which would in turn adversely affect us. We have experienced in the past, and may experience in the future, significant fluctuations in operating results as a result of the reactions of our customers to changes in oil and gas prices. We reported a loss in 2002, and our income in 2005 was $53.9 million compared to $13.9 million in 2004 and $1.5 million in 2003.
      Substantially all of the service and rental revenue we earn is based upon a charge for a relatively short period of time (an hour, a day, a week) for the actual period of time the service or rental is provided to our customer. By contracting services on a short-term basis, we are exposed to the risks of a rapid reduction in market price and utilization and volatility in our revenues. Product sales are recorded when the actual sale occurs and title or ownership passes to the customer and the product is shipped or delivered to the customer.
There is potential for excess capacity in our industry.
      Because oil and gas prices and drilling activity have been at historically high levels, oilfield service companies have been acquiring new equipment to meet their customers’ increasing demand for services. If these levels of price and activity do not continue, there is a potential for excess capacity in the oilfield service industry. This could result in an increased competitive environment for oilfield service companies, which could lead to lower prices and utilization for our services and could adversely affect our business.
We may be unable to employ a sufficient number of skilled and qualified workers.
      The delivery of our services and products requires personnel with specialized skills and experience who can perform physically demanding work. As a result of the volatility of the oilfield service industry and the demanding nature of the work, workers may choose to pursue employment in fields that offer a more desirable work environment at wage rates that are competitive. Our ability to be productive and profitable will depend upon our ability to employ and retain skilled workers. In addition, our ability to expand our operations depends in part on our ability to increase the size of our skilled labor force. The demand for skilled workers is high, and the supply is limited, particularly in the U.S. Rocky Mountain region, which is one of our key regions. A significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force, increases in the wage rates that we must pay, or both. If either of these events were to occur, our capacity and profitability could be diminished and our growth potential could be impaired.
Our executive officers and certain key personnel are critical to our business and these officers and key personnel may not remain with us in the future.
      Our future success depends upon the continued service of our executive officers and other key personnel. If we lose the services of one or more of our executive officers or key employees, our business, operating results and financial condition could be harmed.
Our operating history may not be sufficient for investors to evaluate our business and prospects.
      We are a recently combined company with a short combined operating history. In addition, two of our combining companies, IPS and CES, have grown significantly over the last few years through acquisitions. This may make it more difficult for investors to evaluate our business and prospects and to forecast our future operating results. The historical combined financial statements and the unaudited pro forma combined financial statements included in this prospectus are based on the separate businesses of IPS, CES and IEM for the periods prior to the Combination. As a result, the historical and pro forma information may not give you an accurate indication of what our actual results would have been if the Combination had been completed at the beginning of the periods presented or of what our future results of

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operations are likely to be. Our future results will depend on our ability to efficiently manage our combined operations and execute our business strategy.
We participate in a capital intensive business. We may not be able to finance future growth of our operations or future acquisitions.
      Historically, we have funded the growth of our operations and our acquisitions from bank debt and private placement of shares in addition to cash generated by our business. In the future, we may not be able to continue to obtain sufficient bank debt at competitive rates or complete equity and other debt financings. If we do not generate sufficient cash from our business to fund operations, our growth could be limited unless we are able to obtain additional capital through equity or debt financings. Our inability to grow as planned may reduce our chances of maintaining and improving profitability.
Our inability to control the inherent risks of acquiring and integrating businesses could adversely affect our operations.
      We are a recently combined company and integrating our ongoing businesses may be difficult. In particular, the integration of businesses and operations that are located in disparate regions of North America may prove difficult to achieve in a cost-effective manner. The inability of management to successfully integrate the combining companies could have a material adverse effect on our business, operating results and financial position. Moreover, we may not be able to cross sell our services and penetrate new markets successfully and we may not obtain the anticipated or desired benefits of the Combination. In addition to the Combination, acquisitions have been, and our management believes acquisitions will continue to be, a key element of our business strategy. We may not be able to identify and acquire acceptable acquisition candidates on favorable terms in the future. We may be required to incur substantial indebtedness to finance future acquisitions and also may issue equity securities in connection with such acquisitions. Such additional debt service requirements may impose a significant burden on our results of operations and financial condition. The issuance of additional equity securities could result in significant dilution to stockholders. Acquisitions may not perform as expected when the acquisition was made and may be dilutive to our overall operating results. Additional risks we will face include:
  •  retaining and attracting key employees;
 
  •  retaining and attracting new customers;
 
  •  increased administrative burden;
 
  •  developing our sales and marketing capabilities;
 
  •  managing our growth effectively;
 
  •  integrating operations;
 
  •  operating a new line of business; and
 
  •  increased logistical problems common to large, expansive operations.
If we fail to manage these risks successfully, our business could be harmed.
Our customer base is concentrated within the oil and gas production industry and loss of a significant customer could cause our revenue to decline substantially.
      Our top five customers accounted for approximately 22% of our revenue for the year ended December 31, 2005. Although none of our customers in 2005 accounted for more than 10% of our revenue, collectively, our top ten customers represented approximately 34% of our revenue. It is likely that we will continue to derive a significant portion of our revenue from a relatively small number of customers in the future. If a major customer decided not to continue to use our services, revenue would decline and our operating results and financial condition could be harmed.

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Our indebtedness could restrict our operations and make us more vulnerable to adverse economic conditions.
      At December 31, 2005, our long-term debt (excluding the current portion) was $510 million and our stockholders’ equity was $251 million. Our level of indebtedness may adversely affect operations and limit our growth, and we may have difficulty making debt service payments on our indebtedness as such payments become due. Our level of indebtedness may affect our operations in several ways, including the following:
  •  our level of debt increases our vulnerability to general adverse economic and industry conditions;
 
  •  the covenants that are contained in the agreements that govern our indebtedness limit our ability to borrow funds, dispose of assets, pay dividends and make certain investments;
 
  •  our debt covenants also affect our flexibility in planning for, and reacting to, changes in the economy and in our industry;
 
  •  any failure to comply with the financial or other covenants of our debt could result in an event of default, which could result in some or all of our indebtedness becoming immediately due and payable;
 
  •  our level of debt may impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions or other general corporate purposes; and
 
  •  our business may not generate sufficient cash flow from operations to enable us to meet our obligations under our indebtedness.
      The majority of our debt is structured under floating interest rate terms. A one percentage point increase in the interest rates on our $419 million of term debt outstanding as of February 28, 2006 would cause a $4.2 million pre-tax annual increase in interest expense.
Our business depends upon our ability to obtain key raw materials and specialized equipment from suppliers.
      Should our current suppliers be unable to provide the necessary raw materials or finished products (such as workover rigs or fluid-handling equipment) or otherwise fail to deliver the products timely and in the quantities required, any resulting delays in the provision of services could have a material adverse effect on our business, financial condition, results of operations and cash flows.
We may not be able to provide services that meet the specific needs of oil and gas exploration and production companies at competitive prices.
      The markets in which we operate are highly competitive and have relatively few barriers to entry. The principal competitive factors in our markets are price, product and service quality and availability, responsiveness, experience, technology, equipment quality and reputation for safety. We compete with large national and multi-national companies that have longer operating histories, greater financial, technical and other resources and greater name recognition than we do. Several of our competitors provide a broader array of services and have a stronger presence in more geographic markets. In addition, we compete with several smaller companies capable of competing effectively on a regional or local basis. Our competitors may be able to respond more quickly to new or emerging technologies and services and changes in customer requirements. Some contracts are awarded on a bid basis, which further increases competition based on price. As a result of competition, we may lose market share or be unable to maintain or increase prices for our present services or to acquire additional business opportunities, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.

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Our operations are subject to hazards inherent in the oil and gas industry.
      Risks inherent to our industry, such as equipment defects, vehicle accidents, explosions and uncontrollable flows of gas or well fluids, can cause personal injury, loss of life, suspension of operations, damage to formations, damage to facilities, business interruption and damage to or destruction of property, equipment and the environment. These risks could expose us to substantial liability for personal injury, wrongful death, property damage, loss of oil and gas production, pollution and other environmental damages. The frequency and severity of such incidents will affect operating costs, insurability and relationships with customers, employees and regulators. In particular, our customers may elect not to purchase our services if they view our safety record as unacceptable, which could cause us to lose substantial revenues. In addition, these risks may be greater for us because we sometimes acquire companies that have not allocated significant resources and management focus to safety and have a poor safety record.
      We work in a dangerous business. For example, in 2005, our operations resulted in several fatalities. Many of the claims filed against us arise from vehicle-related accidents that result in the loss of life or serious bodily injury. Our safety procedures may not always prevent such damages. Our insurance coverage may be inadequate to cover our liabilities. In addition, we may not be able to maintain adequate insurance in the future at rates we consider reasonable and commercially justifiable and insurance may not continue to be available on terms as favorable as our current arrangements. The occurrence of a significant uninsured claim, a claim in excess of the insurance coverage limits maintained by us or a claim at a time when we are not able to obtain liability insurance could have a material adverse effect on our ability to conduct normal business operations and on our financial condition, results of operations and cash flows. Although our senior management is committed to improving the Company’s overall safety record, they may not be successful in doing so.
If we become subject to product liability claims, it could be time-consuming and costly to defend.
      Since our customers use our products or third party products that we sell through our supply stores, errors, defects or other performance problems could result in financial or other damages to us. Our customers could seek damages from us for losses associated with these errors, defects or other performance problems. If successful, these claims could have a material adverse effect on our business, operating results or financial condition. Our existing product liability insurance may not be enough to cover the full amount of any loss we might suffer. A product liability claim brought against us, even if unsuccessful, could be time-consuming and costly to defend and could harm our reputation.
We are subject to extensive and costly environmental laws and regulations that may require us to take actions that will adversely affect our results of operations.
      Our business is significantly affected by stringent and complex foreign, federal, state and local laws and regulations governing the discharge of substances into the environment or otherwise relating to environmental protection. As part of our business, we handle, transport, and dispose of a variety of fluids and substances used or produced by our customers in connection with their oil and gas exploration and production activities. We also generate and dispose of hazardous waste. The generation, handling, transportation, and disposal of these fluids, substances, and waste are regulated by a number of laws, including the Resource Recovery and Conservation Act; the Comprehensive Environmental Response, Compensation, and Liability Act; the Clean Water Act; the Safe Drinking Water Act; and analogous state laws. Failure to properly handle, transport, or dispose of these materials or otherwise conduct our operations in accordance with these and other environmental laws could expose us to liability for governmental penalties, cleanup costs associated with releases of such materials, damages to natural resources, and other damages, as well as potentially impair our ability to conduct our operations. We could be exposed to liability for cleanup costs, natural resource damages and other damages under these and other environmental laws as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior operators or other third parties. Environmental laws and regulations have changed in the past, and they are likely to change in the future. If existing regulatory requirements or enforcement policies change, we may be required to make significant unanticipated capital and operating expenditures.

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      Any failure by us to comply with applicable environmental laws and regulations may result in governmental authorities taking actions against our business that could adversely impact our operations and financial condition, including the:
  •  issuance of administrative, civil and criminal penalties;
 
  •  denial or revocation of permits or other authorizations;
 
  •  imposition of limitations on our operations; and
 
  •  performance of site investigatory, remedial or other corrective actions.
      The effect of environmental laws and regulations on our business is discussed in greater detail under “Business – Environmental Matters.”
The nature of our industry subjects us to compliance with other regulatory laws.
      Our business is significantly affected by state and federal laws and other regulations relating to the oil and gas industry in general, and more specifically with respect to health and safety, waste management and the manufacture, storage, handling and transportation of hazardous materials and by changes in and the level of enforcement of such laws. The failure to comply with these rules and regulations can result in substantial penalties, revocation of permits, corrective action orders and criminal prosecution. The regulatory burden on the oil and gas industry increases our cost of doing business and, consequently, affects our profitability. We may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances. It is impossible for management to predict the cost or impact of such laws and regulations on our future operations.
If we fail to develop or maintain an effective system of internal controls, we may not be able to accurately report our financial results or prevent fraud.
      Effective internal controls are necessary for us to provide reliable financial reports and effectively prevent fraud. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results would be harmed. Our efforts to continue to develop and maintain internal controls may not be successful, and we may be unable to maintain adequate controls over our financial processes and reporting in the future, including compliance with the obligations under Section 404 of the Sarbanes-Oxley Act of 2002. Any failure to develop or maintain effective controls, or difficulties encountered in our implementation or other effective improvement of our internal controls, could harm our operating results.
A terrorist attack or armed conflict could harm our business.
      Terrorist activities, anti-terrorist efforts and other armed conflicts involving the United States or other countries may adversely affect the United States and global economies and could prevent us from meeting our financial and other obligations. If any of these events occur, the resulting political instability and societal disruption could reduce overall demand for oil and gas, potentially putting downward pressure on demand for our services and causing a reduction in our revenues. Oil and gas related facilities could be direct targets of terrorist attacks, and our operations could be adversely impacted if infrastructure integral to our customers’ operations is destroyed or damaged. Costs for insurance and other security may increase as a result of these threats, and some insurance coverage may become more difficult to obtain, if available at all.
Conservation measures and technological advances could reduce demand for oil and gas.
      Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to oil and gas, technological advances in fuel economy and energy generation devices could reduce demand for oil and gas. Management cannot predict the impact of the changing demand for oil and gas services and products, and any major changes may have a material adverse effect on our business, financial condition, results of operations and cash flows.

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Fluctuations in currency exchange rates in Canada could adversely affect our business.
      We have substantial operations in Canada. As a result, fluctuations in currency exchange rates in Canada could materially and adversely affect our business. For the year ended December 31, 2005, our Canadian operations represented approximately 14% of our revenue and 8% of our net income before taxes and minority interest.
We are susceptible to seasonal earnings volatility due to adverse weather conditions in Canada.
      Our operations are directly affected by seasonal differences in weather in Canada. The level of activity in the Canadian oilfield services industry declines significantly in the second calendar quarter, when frost leaves the ground and many secondary roads are temporarily rendered incapable of supporting the weight of heavy equipment. The duration of this period is referred to as “spring breakup” and has a direct impact on our activity levels in Canada. The timing and duration of “spring breakup” depend on weather patterns but generally “spring breakup” occurs in April and May. Additionally, if an unseasonably warm winter prevents sufficient freezing, we may not be able to access wellsites and our operating results and financial condition may, therefore, be adversely affected. The demand for our services may also be affected by the severity of the Canadian winters. In addition, during excessively rainy periods, equipment moves may be delayed, thereby adversely affecting operating results. The volatility in weather and temperature in the Canadian oilfield can therefore create unpredictability in activity and utilization rates. As a result, full-year results are not likely to be a direct multiple of any particular quarter or combination of quarters.
Our operations in Mexico are subject to specific risks, including dependence on Petróleos Mexicanos (“PEMEX”) as the sole customer, exposure to fluctuation in the Mexican peso and workforce unionization.
      Our business in Mexico is substantially all performed for PEMEX pursuant to multi-year contracts. These contracts are generally two years in duration and are subject to competitive bid for renewal. Any failure by us to renew our contracts could have a material adverse effect on our financial condition, results of operations and cash flows.
      The PEMEX contracts provide that 70% to 80% of the value of our billings under the contracts is charged to PEMEX in U.S. dollars with the remainder billed in Mexican pesos. The portion billed in U.S. dollars to PEMEX is converted to pesos on the date of payment. Invoices are paid approximately 45 days after the invoice date. As such, we are exposed to fluctuations in the value of the peso. A material decrease in the value of the Mexican peso relative to the U.S. dollar could negatively impact our revenues, cash flows and net income.
      Our operations in Mexico are party to a collective labor contract made effective as of October 1, 2003 between Servicios Petrotec S.A. DE C.V., one of our subsidiaries, and Unión Sindical de Trabajadores de la Industria Metálica y Similares, the metal and similar industry workers labor union. We have not experienced work stoppages in the past but cannot guarantee that we will not experience work stoppages in the future. A prolonged work stoppage could negatively impact our revenues, cash flows and net income.
Our U.S. operations in the Gulf of Mexico are adversely impacted by the hurricane season, which generally occurs in the third calendar quarter.
      Hurricanes and the threat of hurricanes during this period will often result in the shut-down of oil and gas operations in the Gulf of Mexico as well as land operations within the hurricane path. During a shut-down period, we are unable to access wellsites and our services are also shut down. This situation can therefore create unpredictability in activity and utilization rates, which can have a material adverse impact on our business, financial conditions, results of operations and cash flows.
When rig counts are low, our rig relocation customers may not have a need for our services.
      Many of the major U.S. onshore drilling services contractors have significant capabilities to move their own drilling rigs and related oilfield equipment and to erect rigs. When regional rig counts are high, drilling services contractors exceed their own capabilities and contract for additional oilfield equipment hauling and rig erection capacity. Our rig relocation business activity is highly correlated to the rig count;

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however, the correlation varies over the rig count range. As rig count drops, some drilling services contractors reach a point where all of their oilfield equipment hauling and rig erection needs can be met by their own fleets. If one or more of our rig relocation customers reach this “tipping point,” our revenues attributable to rig relocation will decline much faster than the corresponding overall decline in the rig count. This non-linear relationship between our rig relocation business activity and the rig count in the areas in which we have rig relocation operations can increase significantly our earnings volatility with respect to rig relocation.
Increasing trucking regulations may increase our costs and negatively impact our results of operations.
      Among the services we provide, we operate as a motor carrier and therefore are subject to regulation by the U.S. Department of Transportation and by various state agencies. These regulatory authorities exercise broad powers, governing activities such as the authorization to engage in motor carrier operations and regulatory safety. There are additional regulations specifically relating to the trucking industry, including testing and specification of equipment and product handling requirements. The trucking industry is subject to possible regulatory and legislative changes that may affect the economics of the industry by requiring changes in operating practices or by changing the demand for common or contract carrier services or the cost of providing truckload services. Some of these possible changes include increasingly stringent environmental regulations, changes in the hours of service regulations which govern the amount of time a driver may drive in any specific period, onboard black box recorder devices or limits on vehicle weight and size.
      Interstate motor carrier operations are subject to safety requirements prescribed by the U.S. Department of Transportation. To a large degree, intrastate motor carrier operations are subject to state safety regulations that mirror federal regulations. Such matters as weight and dimension of equipment are also subject to federal and state regulations.
      From time to time, various legislative proposals are introduced, including proposals to increase federal, state, or local taxes, including taxes on motor fuels, which may increase our costs or adversely impact the recruitment of drivers. We cannot predict whether, or in what form, any increase in such taxes applicable to us will be enacted.
Risks Related to Our Relationship with SCF
L.E. Simmons, through SCF, controls the outcome of stockholder voting and may exercise this voting power in a manner adverse to you.
      After the offering, SCF will own approximately             % of our outstanding common stock and approximately      % of our outstanding common stock if the over-allotment option is exercised in full. L.E. Simmons is the sole owner of L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF. Accordingly, Mr. Simmons, through his ownership of the ultimate general partner of SCF, will be in a position to control the outcome of matters requiring a stockholder vote, including the election of directors, adoption of amendments to our certificate of incorporation or bylaws or approval of transactions involving a change of control. The interests of Mr. Simmons may differ from yours, and SCF may vote its common stock in a manner that may adversely affect you.
SCF’s ownership interest and provisions contained in our certificate of incorporation and bylaws could discourage a takeover attempt, which may reduce or eliminate the likelihood of a change of control transaction and, therefore, your ability to sell your shares for a premium.
      In addition to SCF’s controlling position, provisions contained in our certificate of incorporation and bylaws, such as a classified board, limitations on the removal of directors, on stockholder proposals at meetings of stockholders and on stockholder action by written consent and the inability of stockholders to call special meetings, could make it more difficult for a third party to acquire control of our company. Our certificate of incorporation also authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could increase the

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difficulty for a third party to acquire us, which may reduce or eliminate your ability to sell your shares of common stock at a premium. See “Description of Our Capital Stock.”
Two of our directors may have conflicts of interest because they are affiliated with SCF. The resolution of these conflicts of interest may not be in our or your best interests.
      Two of our directors, David C. Baldwin and Andrew L. Waite, are current officers of L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF. This may create conflicts of interest because these directors have responsibilities to SCF and its owners. Their duties as officers of L.E. Simmons and Associates, Incorporated may conflict with their duties as directors of our company regarding business dealings between SCF and us and other matters. The resolution of these conflicts may not always be in our or your best interests.
We have renounced any interest in specified business opportunities, and SCF and its director nominees on our board of directors generally have no obligation to offer us those opportunities.
      SCF has investments in other oilfield service companies that may compete with us, and SCF and its affiliates, other than our company, may invest in other such companies in the future. We refer to SCF and its other affiliates and its portfolio companies as the SCF group. Our certificate of incorporation provides that, so long as we have a director or officer that is affiliated with SCF (an “SCF Nominee”), we renounce any interest or expectancy in any business opportunity in which any member of the SCF group participates or desires or seeks to participate in and that involves any aspect of the energy equipment or services business or industry, other than (i) any business opportunity that is brought to the attention of an SCF Nominee solely in such person’s capacity as a director or officer of our company and with respect to which no other member of the SCF group independently receives notice or otherwise identifies such opportunity and (ii) any business opportunity that is identified by the SCF group solely through the disclosure of information by or on behalf of our company. We are not prohibited from pursuing any business opportunity with respect to which we have renounced any interest.
Risks Related to this Offering
Future sales of shares of our common stock may affect their market price and the future exercise of options may depress our stock price and result in immediate and substantial dilution.
      We cannot predict what effect, if any, future sales of shares of our common stock, or the availability of shares for future sale, will have on the market price of our common stock. Upon completion of this offering, SCF will own                      shares of our common stock, or           % of our outstanding common stock (or                      shares of our common stock, or           %, if the over-allotment option is fully exercised) and our existing stockholders (other than SCF) will own                      shares of our common stock, or           % of our outstanding common stock (or                      shares of our common stock or           % of our outstanding common stock if the over-allotment option is fully exercised). We and our officers and directors and the selling stockholders are subject to the lock-up agreements described in “Underwriting” for a period of 180 days after the date of this prospectus. Existing stockholders are parties to a registration rights agreement granting them certain demand and piggyback registrations in the future. In addition, shares beneficially held for at least one year will be eligible for sale in the public market pursuant to Rule 144 under the Securities Act of 1933, as amended, or the Securities Act, subject to the lock-up agreements. Sales of substantial amounts of our common stock in the public market following our initial public offering, or the perception that such sales could occur, could adversely affect the market price of our common stock and may make it more difficult for you to sell your shares at a time and price that you deem appropriate. Please read “Shares Eligible for Future Sale.”
      As soon as practicable after this offering, we intend to file one or more registration statements with the SEC on Form S-8 providing for the registration of shares of our common stock issued or reserved for issuance under our stock incentive plans. Subject to the expiration of lock-ups that we and certain of our stockholders have entered into and any applicable restrictions or conditions contained in our stock

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incentive plans, the shares registered under these registration statements on Form S-8 will be available for resale immediately in the public market without restriction.
Purchasers of common stock will experience immediate and substantial dilution.
      Based on an assumed initial public offering price of $           per share, purchasers of our common stock in this offering will experience an immediate and substantial dilution of $           per share in the net tangible book value per share of common stock from the initial public offering price, and our pro forma net tangible book value as of December 31, 2005, after giving effect to this offering, would be $           per share. You will incur further dilution if outstanding options to purchase common stock are exercised. In addition, our certificate of incorporation allows us to issue significant numbers of additional shares, including shares that may be issued under our stock incentive plans. Please read “Dilution” for a complete description of the calculation of net tangible book value.
Because we have no current plans to pay dividends on our common stock, investors must look solely to stock appreciation for a return on their investment in us.
      We do not anticipate paying cash dividends on our common stock in the foreseeable future. We currently intend to retain all future earnings to fund the development and growth of our business. Any payment of future dividends will be at the discretion of our board of directors and will depend on, among other things, our earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applying to the payment of dividends and other considerations that the board of directors deems relevant. Investors must rely on sales of their common stock after price appreciation, which may never occur, as the only way to realize a return on their investment.
There has been no active trading market for our common stock, and an active trading market may not develop.
      Prior to this offering, there has been no public market for our common stock. Our common stock has been approved for listing on the New York Stock Exchange, or NYSE, under the symbol “CPX”. We do not know if an active trading market will develop for our common stock or how the common stock will trade in the future, which may make it more difficult for you to sell your shares. Negotiations between the underwriters and us determined the initial public offering price, which may not be indicative of the price at which our common stock will trade following the completion of this offering. You may not be able to resell your shares at or above the initial public offering price.
If our stock price fluctuates after the initial public offering, you could lose a significant part of your investment.
      In recent years, the stock market has experienced extreme price and volume fluctuations. This volatility has had a significant effect on the market price of securities issued by many companies for reasons unrelated to the operating performance of these companies. The market price of our common stock could similarly be subject to wide fluctuations in response to a number of factors, most of which we cannot control, including:
  •  changes in securities analysts’ recommendations and their estimates of our financial performance;
 
  •  the public’s reaction to our press releases, announcements and our filings with the SEC and those of our competitors;
 
  •  fluctuations in broader stock market prices and volumes, particularly among securities of oil and gas service companies;
 
  •  changes in market valuations of similar companies;
 
  •  investor perception of our industry or our prospects;
 
  •  additions or departures of key personnel;
 
  •  commencement of or involvement in litigation;

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  •  changes in environmental and other governmental regulations;
 
  •  announcements by us or our competitors of strategic alliances, significant contracts, new technologies, acquisitions, commercial relationships, joint ventures or capital commitments;
 
  •  variations in our quarterly results of operations or cash flows or those of other oil and gas service companies;
 
  •  revenue and operating results failing to meet the expectations of securities analysts or investors in a particular quarter;
 
  •  changes in our pricing policies or pricing policies of our competitors;
 
  •  future issuances and sales of our common stock;
 
  •  demand for and trading volume of our common stock;
 
  •  domestic and worldwide supplies and prices of and demand for oil and gas; and
 
  •  changes in general conditions in the domestic and worldwide economies, financial markets or the oil and gas industry.
      The realization of any of these risks and other factors beyond our control could cause the market price of our common stock to decline significantly. In particular, the market price of our common stock may be influenced by variations in oil and gas commodity prices, because demand for our services is closely related to the prices of these commodities. This may cause our stock price to fluctuate with these underlying commodity prices, which are highly volatile.

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FORWARD-LOOKING STATEMENTS
      This prospectus contains forward-looking statements. We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends affecting the financial condition of our business. These forward-looking statements are subject to a number of risks, uncertainties and assumptions, including, among other things, the risk factors discussed in this prospectus and other factors, most of which are beyond our control.
      The words “believe,” “may,” “will,” “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 prospectus are forward-looking statements.
      Although we believe that the forward-looking statements contained in this prospectus are based upon reasonable assumptions, the forward-looking events and circumstances discussed in this prospectus may not occur and actual results could differ materially from those anticipated or implied in the forward-looking statements.
      Important factors that may affect our expectations, estimates or projections include:
  •  a decline in or substantial volatility of oil and gas prices, and any related changes in expenditures by our customers;
 
  •  the effects of future acquisitions on our business;
 
  •  changes in customer requirements in markets or industries we serve;
 
  •  competition within our industry;
 
  •  general economic and market conditions;
 
  •  our access to current or future financing arrangements;
 
  •  our ability to replace or add workers at economic rates;
 
  •  environmental and other governmental regulations; and
 
  •  the effects of severe weather on our services centers or equipment.
      Our forward-looking statements speak only as of the date of this prospectus. Unless otherwise required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

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USE OF PROCEEDS
      We expect to receive net proceeds from the sale of                      shares of common stock by us in this offering of approximately $240 million, assuming an initial public offering price of $           per share and after deducting underwriting discounts and commissions and estimated offering expenses. A $1.00 increase (decrease) in the assumed initial public offering price of $           per share would increase (decrease) the net proceeds to us from this offering by $           million, assuming no change in the number of shares offered by us as set forth on the cover page of this prospectus and after deducting the estimated underwriting discounts and commissions and estimated offering expenses payable by us. We will not receive any of the proceeds from any sale of shares of our common stock by the selling stockholders.
      We plan to use $50 million of our net proceeds from this offering to repay a portion of our term loan facility, $5 million to repay seller financed notes and the remainder to pay all outstanding balances under our revolving credit facility and for general corporate purposes, which may include cash payments made in connection with future acquisitions. Our current senior credit facility consists of a $130 million U.S. revolver, a $30 million Canadian revolver and a term loan facility of $420 million. As of February 28, 2006, we had $419 million of indebtedness outstanding under the term loan portion of our senior credit facility. The current term loan bears interest at either a base rate plus 1.75%, or the London Interbank Offered Rate (“LIBOR”) plus 2.75%, and matures in September 2012. As of February 28, 2006, we had approximately $124.4 million in indebtedness outstanding under our revolving credit facility. The revolving credit facility bears interest at either a base rate plus an applicable margin ranging between 0.25% and 1.75%, or LIBOR plus an applicable margin between 1.25% and 2.75% in the case of U.S. borrowings. In the case of borrowings under the Canadian revolving credit facility, interest is based on the Canadian Base Rate (as defined in the Credit Agreement) plus an applicable margin ranging between 0.25% and 1.75%. Our borrowings under the term loan and revolving credit facility were used to refinance existing debt, to pay the Dividend as described below and to provide for ongoing working capital and general corporate purposes.
      Please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Description of Our Indebtedness” for a description of our outstanding indebtedness and our senior credit facility following this offering.
      An affiliate of Credit Suisse Securities (USA) LLC and an affiliate of UBS Securities LLC have each committed $9 million (or approximately 7%) of our $130 million U.S. revolver and therefore will receive a portion of the proceeds from this offering that we use to repay our U.S. revolver. In addition, affiliates of the underwriters may have positions from time to time in our term loan facility. Credit Suisse Securities (USA) LLC and UBS Securities LLC are underwriters of this offering. Please read “Underwriting.”
DIVIDEND POLICY
      Immediately after the closing of the Combination, we paid a dividend of $2.62 per share of our common stock or an aggregate of approximately $147 million to our stockholders. The term “Dividend” refers to this payment. Other than the Dividend, we have not declared or paid any cash dividends on our common stock, and we do not anticipate paying any cash dividends on our common stock in the foreseeable future. We currently intend to retain all future earnings to fund the development and growth of our business. Any future determination relating to our dividend policy will be at the discretion of our board of directors and will depend on our results of operations, financial condition, capital requirements and other factors deemed relevant by our board. We are also currently restricted in our ability to pay dividends under our senior credit facility.

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CAPITALIZATION
      The following table sets forth our capitalization at December 31, 2005:
  •  on an actual basis; and
 
  •  on an as adjusted basis to give effect to this offering and the application of our estimated net proceeds from this offering as set forth under “Use of Proceeds” as if the offering occurred on December 31, 2005.
      The information was derived from and is qualified by reference to our consolidated financial statements included elsewhere in this prospectus. You should read this information in conjunction with these consolidated financial statements, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Use of Proceeds.”
                       
    December 31, 2005
     
    Actual   As Adjusted
         
    (In thousands)
Cash and cash equivalents(1)
  $ 11,405     $ 111,293  
             
Total long-term debt, including current portion:
               
 
Notes payable:
               
   
Revolving credit facility(2)
  $ 85,112     $  
   
Term loan facility
    418,950       368,950  
   
Other debt
    11,881       6,881  
             
     
Total
    515,943       375,831  
             
Stockholders’ equity:
               
 
Common stock, $0.01 par value, 200,000,000 shares authorized, 55,531,510 shares issued and outstanding, actual;            shares issued and outstanding, as adjusted
    555          
 
Additional paid-in capital(1)
    220,786          
 
Treasury stock, 35,570 shares at cost
    (202 )     (202 )
 
Deferred compensation
    (3,803 )     (3,803 )
 
Retained earnings
    16,885       16,885  
 
Accumulated other comprehensive income
    16,540       16,540  
             
     
Total stockholders’ equity(1)
    250,761       490,761  
             
     
Total capitalization(1)
  $ 766,704     $ 866,592  
             
 
(1)  A $1.00 increase (decrease) in the assumed initial public offering price of $           per share would increase (decrease) each of cash and cash equivalents, additional paid-in capital, total stockholders’ equity and total capitalization by $           million, assuming no change in the number of shares offered by us as set forth on the cover page of this prospectus and after deducting the estimated underwriting discounts and commissions and estimated offering expenses payable by us.
 
(2)  As of February 28, 2006, we had $124.4 million outstanding under our revolving credit facility.

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DILUTION
      If you invest in our common stock, your interest will be diluted to the extent of the difference between the public offering price per share and the net tangible book value per share of the common stock after this offering. Our unaudited consolidated net tangible book value as of December 31, 2005 was $(0.98) per share of common stock, after giving effect to the Combination and the Dividend. Net tangible book value per share represents the amount of the total tangible assets less our total liabilities, divided by the number of shares of common stock that are outstanding. After giving effect to the sale of                     shares of common stock in this offering at an assumed initial public offering price of $           per share and after the deduction of underwriting discounts and commissions and estimated offering expenses, the as adjusted net tangible book value at December 31, 2005 would have been $           million or $           per share. This represents an immediate increase in such net tangible book value of $           per share to existing stockholders and an immediate and substantial dilution of $           per share to new investors purchasing common stock in this offering. The following table illustrates this per share dilution:
                   
Assumed initial public offering price per share
          $    
 
Net tangible book value per share as of December 31, 2005
  $ (0.98 )        
 
Increase attributable to new public investors
               
             
As adjusted net tangible book value per share after this offering
               
             
Dilution in as adjusted net tangible book value per share to new investors
          $    
             
      A $1.00 increase (decrease) in the assumed initial public offering price of $          per share would increase (decrease) our net tangible book value by $           million, the net tangible book value per share, after giving effect to this offering, by $          per share and the dilution in net tangible book value per share to new investors in this offering by $          per share, assuming no change in the number of shares offered by us as set forth on the cover page of this prospectus, and after deducting the estimated underwriting discounts and commissions and estimated offering expenses payable by us.
      The following table summarizes, on an as adjusted basis set forth above as of December 31, 2005, the total number of shares of common stock owned by existing stockholders, the total number of shares acquirable under outstanding options and the total number of shares to be owned by new investors, the total consideration paid or to be paid, and the average price per share paid by our existing stockholders and to be paid by our option holders and by new investors in this offering at $          , the mid-point of the range of the initial public offering prices set forth on the cover page of this prospectus, calculated before deduction of estimated underwriting discounts and commissions and estimated offering expenses.
                                           
    Shares Purchased(1)   Total Consideration    
            Average Price
    Number   Percent   Amount   Percent   Per Share
                     
Existing stockholders(2)(3)
    56,317,680       %     $ 71,970,000       %     $ 1.28  
Option holders
    3,512,444       %       19,037,446       %       5.42  
New public investors
            %               %          
                               
 
Total
            100%     $         100%     $    
                               
 
(1)  The number of shares disclosed for the existing stockholders includes                     shares being sold by the selling stockholders in this offering. The number of shares disclosed for the new investors does not include the                     shares being purchased by the new investors from the selling stockholders in this offering.
 
(2)  Includes 786,170 shares of restricted stock that are subject to forfeiture restrictions as of December 31, 2005.
 
(3)  The amount paid by the existing stockholders was calculated by deducting from our common stock and additional paid-in capital as of December 31, 2005 ($221.3 million) the following amounts: (i) the amount of goodwill recognized in the Combination ($93.8 million), (ii) the portion of the Dividend paid in connection with the Combination that reduced retained earnings ($51.8 million) and (iii) deferred compensation ($3.8 million).

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      A $1.00 increase (decrease) in the assumed initial public offering price of $          per share would increase (decrease) total consideration paid or to be paid by new investors and our option holders, total consideration paid by all stockholders and the average price per share paid by all stockholders by $           million, $           million, $          million and $          , respectively, assuming no change in the number of shares offered by us, as set forth on the cover page of this prospectus, and without deducting underwriting discounts and commissions and other expenses of the offering.
      As of December 31, 2005, there were 56,317,680 shares of our common stock outstanding, including 786,170 shares of restricted stock that are subject to forfeiture restrictions. Sales by the selling stockholders in this offering will reduce the number of shares of common stock held by existing stockholders to                     or approximately           % of the total number of shares of common stock outstanding after this offering and will increase the number of shares of common stock held by new investors to                      shares or approximately           % of the total number of shares of common stock outstanding after this offering.

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UNAUDITED PRO FORMA CONSOLIDATED FINANCIAL DATA
      On September 12, 2005, we completed the Combination transaction through which CES, IEM and IPS merged. To facilitate this transaction, we borrowed funds through our bank refinancing (the “Financing”), paid the Dividend to stockholders and recorded goodwill associated with the acquisition of minority interests (the “MI Acquisition”).
      The following summary unaudited pro forma consolidated statements of operations gives effect to the MI Acquisition, the Financing and the payment of the Dividend, assuming that the MI Acquisition, the Financing and the payment of the Dividend were effected on January 1, 2004. From a balance sheet perspective, these transactions have been reflected in our consolidated balance sheet as of December 31, 2005 included elsewhere in this prospectus.
      The historical statement of operations information for the years ended December 31, 2005 and 2004 are derived from our audited consolidated financial statements.
      The unaudited pro forma consolidated statements of operations represent management’s preliminary determination of purchase accounting adjustments and are based on available information and assumptions that management considers reasonable under the circumstances. The purchase accounting estimate is expected to be finalized within one year of the closing date of the Combination. Consequently, the amounts reflected in the unaudited pro forma consolidated statements of operations are subject to change. Management does not expect that the differences between the preliminary and final purchase price allocation will have a material impact on our consolidated financial position or results of operations.
      The unaudited pro forma consolidated statements of operations do not purport to be indicative of the results that would have been obtained had the transactions described above been completed on the indicated dates or that may be obtained in the future.
      The following information should be read together with our historical consolidated financial statements and related notes included within this prospectus.

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COMPLETE PRODUCTION SERVICES, INC.
Pro Forma Consolidated Statement of Operations
Year Ended December 31, 2005
                           
        Financing    
    Complete   Note 3   Consolidated
             
    (In thousands, except per share data)
    (Unaudited)
Revenue:
                       
 
Service
  $ 639,421     $     $ 639,421  
 
Product
    118,305             118,305  
                   
      757,726             757,726  
Service expenses
    393,856             393,856  
Product expenses
    87,538             87,538  
Selling, general and administrative expenses
    111,754             111,754  
Depreciation and amortization
    48,840             48,840  
Write-off of deferred financing fees
    3,315             3,315  
                   
 
Income before interest, taxes and minority interest
    112,423             112,423  
Interest expense
    24,461       7,660 (a)     32,121  
                   
 
Income before taxes and minority interest
    87,962       (7,660 )     80,302  
Taxes
    33,716       (2,681 )(b)     31,035  
                   
 
Income before minority interest
    54,246       (4,979 )     49,267  
Minority interest
    384             384  
                   
 
Net income
  $ 53,862     $ (4,979 )   $ 48,883  
                   
Earnings per share:
                       
 
Basic
  $ 1.16             $ 1.05  
                   
 
Diluted
  $ 1.06             $ 0.96  
                   
Weighted average shares:
                       
 
Basic
    46,603               46,603  
                   
 
Diluted
    50,656               50,656  
                   
See accompanying notes to the unaudited pro forma consolidated statements of operations.

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COMPLETE PRODUCTION SERVICES, INC.
Pro Forma Consolidated Statement of Operations
Year Ended December 31, 2004
                                   
        MI Acq.   Financing    
                 
    Complete   Note 2   Note 3   Consolidated
                 
    (In thousands, except per share data)
    (Unaudited)
Revenue:
                               
 
Service
  $ 239,427     $     $     $ 239,427  
 
Product
    81,320                   81,320  
                         
      320,747                   320,747  
Service expenses
    157,540                   157,540  
Product expenses
    58,633                   58,633  
Selling, general and administrative expenses
    46,077                   46,077  
Depreciation and amortization
    21,616                   21,616  
                         
 
Income before interest, taxes and minority interest
    36,881                   36,881  
Interest expense
    7,471             10,095 (a)     17,566  
                         
 
Income before taxes and minority interest
    29,410             (10,095 )     19,315  
Taxes
    10,821             (3,533 )(b)     7,288  
                         
 
Income before minority interest
    18,589             (6,562 )     12,027  
Minority interest (see note 2)
    4,705       (4,705 )            
                         
 
Net income
  $ 13,884     $ 4,705     $ (6,562 )   $ 12,027  
                         
Earnings per share:
                               
 
Basic
  $ 0.47                     $ 0.41  
                         
 
Diluted
  $ 0.46                     $ 0.40  
                         
Weighted average shares:
                               
 
Basic
    29,548                       29,548  
 
Diluted
    30,083                       30,083  
See accompanying notes to the unaudited pro forma consolidated statements of operations.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Unaudited Pro Forma Consolidated Statements of Operations
Years Ended December 31, 2005 and 2004 (unaudited)
(In thousands, except as noted)
1. Basis of Presentation:
      On September 12, 2005, Integrated Production Services, Inc. (“IPS”) acquired Complete Energy Services, Inc. (“CES”) and I.E. Miller Services, Inc. (“IEM”) for stock. We refer to this transaction as the “Combination.” The Combination was accounted for using the continuity of interest method as described in note 1 of the audited consolidated financial statements. Upon closing the Combination, IPS changed its name to Complete Production Services, Inc.
      The accompanying pro forma consolidated statements of operations for the years ended December 31, 2005 and 2004 have been prepared by management in accordance with accounting principles generally accepted in the United States for inclusion in a registration statement on Form S-1.
      These pro forma consolidated statements of operations are not necessarily indicative of the results that would have actually occurred if the events reflected herein had been in effect on the dates indicated or of the results that may occur in the future.
      These pro forma consolidated statements of operations are based on our historical audited and unaudited consolidated financial statements, and the pro forma adjustments and assumptions outlined below. Accordingly, these pro forma consolidated statements of operations should be read in conjunction with our audited and unaudited consolidated financial statements presented elsewhere in this prospectus.
      The accounting policies used in the preparation of the pro forma consolidated statements of operations are those disclosed in our audited consolidated financial statements for the year ended December 31, 2005.
      The purchase method of accounting was used to reflect the acquisition of the minority interests in CES and IEM as at September 12, 2005. The purchase price of $12.32 per share is intended to be the fair value of the shares owned by the minority interests, which purchase price was based on an estimate by a financial advisor engaged in connection with the Combination. The financial advisor was not engaged to, and did not, determine the actual value of such shares. Under this accounting method, the excess of the purchase price over the fair value of the assets and liabilities allocable to the minority interests acquired has been reflected as goodwill. The estimated fair values of the assets and liabilities are preliminary and subject to change. The unaudited pro forma consolidated statement of operations for the year ended December 31, 2004 has been adjusted for the effects of the purchase accounting, as described below.
2. Income Attributable to Minority Interests:
      Minority interest in income for the year ended December 31, 2004 was:
                         
    CES   IEM   Total
             
Year ended December 31, 2004
  $ 4,246     $ 459     $ 4,705  
      For a discussion of the purchase price allocation associated with the Combination, see note 2(a) of the consolidated financial statements at December 31, 2005.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Unaudited Pro Forma Consolidated Statements of Operations — (Continued)
Years Ended December 31, 2005 and 2004 (unaudited)
(In thousands, except as noted)
3. Financing:
      (a) To adjust interest expense for amounts related to borrowings of approximately $150 million to fund the payment of a stockholder dividend and to reflect the impact on deferred financing fees of our new term loan facility entered into on September 12, 2005. The net adjustments were as follows:
                   
    Pro Forma Results
    Year Ended
    December 31,
     
    2005   2004
         
Interest expense for new borrowings to fund dividend payment(1)
  $ 7,875     $ 10,500  
Add: amortization of term loan deferred financing fees(2)
    274       366  
Less: deferred financing fees associated with previous debt facilities(3)
    (489 )     (771 )
             
 
Adjustments to interest expense
  $ 7,660     $ 10,095  
             
 
(1)  To record additional interest expense associated with borrowings to fund our stockholder distribution of approximately $150 million, assuming the borrowing occurred on January 1, 2004. Interest was calculated at an assumed rate of 7% for each period presented.
 
(2)  To record amortization expense associated with deferred financing fees resulting from our term loan senior secured financing facility entered into on September 12, 2005, as if the new facility was entered into on January 1, 2004.
 
(3)  To add back amortization expense associated with deferred financing fees related to our previous debt facilities, assuming these facilities were retired with borrowings under our new term loan senior secured financing facility on January 1, 2004.
      Our historical results include a write-off of $3.3 million representing the unamortized portion of deferred financing fees associated with our previous debt facilities which were retired on September 12, 2005. These pro forma income statements were not adjusted to eliminate the impact of this non-recurring charge.
      (b) To record the tax benefit associated with the interest adjustments identified above at an assumed rate of 35%.

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SELECTED CONSOLIDATED FINANCIAL DATA
      The following table presents selected historical consolidated financial and operating data for the periods shown. The selected consolidated financial data as of December 31, 2001 and for the year ended December 31, 2001, have been derived from IPS’s consolidated financial statements for such date and period. The selected consolidated financial data as of December 31, 2002 and for the year ended December 31, 2002 have been derived from the audited consolidated financial statements of IPS for such date and period. In addition, the following selected consolidated financial data as of December 31, 2005, 2004 and 2003 and for the three-year period ended December 31, 2005 have been derived from our audited consolidated financial statements for those dates and periods. The following information should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our financial statements and related notes included in this prospectus.
      On December 29, 2005, we effected a 2-for-1 split of common stock. As a result, all common stock and per share data, as well as data related to other securities including stock warrants, restricted stock and stock options, have been adjusted retroactively to give effect to this stock split for all periods presented within this prospectus, except par value which remained at $0.01 per share, resulting in an insignificant reclassification between common stock and additional paid-in-capital.
                                             
    Year Ended December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands, except per share data)
Statement of Operations Data:
                                       
Revenue:
                                       
 
Completion and production services
  $ 5,855     $ 30,110     $ 65,025     $ 194,953     $ 510,304  
 
Drilling services
                2,707       44,474       129,117  
 
Products sales
          10,494       35,547       81,320       118,305  
                               
   
Total
    5,855       40,604       103,279       320,747       757,726  
Expenses:
                                       
 
Service and product expenses(1)
    3,528       28,531       73,124       216,173       481,394  
 
Selling, general and administrative
    1,563       7,764       16,591       46,077       111,754  
 
Depreciation and amortization
    402       4,187       7,648       21,616       48,840  
 
Write-off of deferred financing fees
                            3,315  
                               
   
Operating income
    362       122       5,916       36,881       112,423  
Interest expense
    176       1,260       2,687       7,471       24,461  
Taxes
    86       (477 )     1,506       10,821       33,716  
                               
 
Income (loss) before minority interest
    100       (661 )     1,723       18,589       54,246  
Minority interest
                247       4,705       384  
                               
 
Net income (loss)
  $ 100     $ (661 )   $ 1,476     $ 13,884     $ 53,862  
                               
Earnings (loss) per share – basic
  $ 0.03     $ (0.12 )   $ 0.11     $ 0.47     $ 1.16  
                               
Earnings (loss) per share – diluted
  $ 0.03     $ (0.12 )   $ 0.10     $ 0.46     $ 1.06  
                               
Weighted average shares – basic
    2,890       5,514       13,675       29,548       46,603  
Weighted average shares – diluted
    2,890       5,514       14,109       30,083       50,656  
 
(1)  Service and product expenses is the aggregate of service expenses and product expenses.

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    Year Ended December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands)
Other Financial Data:
                                       
EBITDA(2)
  $ 764     $ 4,309     $ 13,564     $ 58,497     $ 161,263  
Cash flows from operating activities
    1,683       (8 )     13,965       34,622       76,427  
Cash flows from financing activities
    33,320       36,279       55,281       157,630       112,139  
Cash flows from investing activities
    (32,538 )     (35,616 )     (66,214 )     (186,776 )     (188,358 )
Capital expenditures:
                                       
 
Acquisitions, net of cash acquired(3)
    9,860       27,851       54,798       139,362       67,689  
 
Property, plant and equipment
    2,678       6,799       11,084       46,904       127,215  
                                         
    As of December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands)
Balance Sheet Data:
                                       
Cash and cash equivalents
  $ 2,465     $ 3,120     $ 6,094     $ 11,547     $ 11,405  
Net property, plant and equipment
    7,110       47,808       95,217       235,211       384,580  
Total assets
    38,571       110,596       206,066       515,153       937,653  
Long-term debt, excluding current portion
    2,522       22,270       50,144       169,190       509,990  
Total stockholders’ equity
    34,550       65,262       97,956       172,080       250,761  
 
(2)  EBITDA consists of net income (loss) before interest expense, taxes, depreciation and amortization and minority interest. See “Non-GAAP Financial Measures.” EBITDA is included in this prospectus 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 EBITDA. In addition, we use EBITDA in evaluating acquisition targets. Management also believes that EBITDA is a useful tool for measuring our ability to meet our future debt service, capital expenditures and working capital requirements, and EBITDA is commonly used by us and our investors to measure our ability to service indebtedness. EBITDA is not a substitute for the GAAP measures of earnings or of 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 and minority interest. The following table reconciles EBITDA with our net income (loss).
 
(3)  Acquisitions, net of cash required, consists only of the cash component of acquisitions. It does not include common stock and notes issued for acquisitions, nor does it include other non-cash assets issued for acquisitions.
Reconciliation of EBITDA
                                         
    Year Ended December 31,
     
    2001   2002   2003   2004   2005
                     
    (In thousands)
Net income (loss)
  $ 100     $ (661 )   $ 1,476     $ 13,884     $ 53,862  
Plus: interest expense
    176       1,260       2,687       7,471       24,461  
Plus: tax expense
    86       (477 )     1,506       10,821       33,716  
Plus: depreciation and amortization
    402       4,187       7,648       21,616       48,840  
Plus: minority interest
                247       4,705       384  
                               
EBITDA
  $ 764     $ 4,309     $ 13,564     $ 58,497     $ 161,263  
                               

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MANAGEMENT’S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
      The following discussion and analysis should be read in conjunction with our consolidated financial statements and related notes included within this prospectus. This discussion contains forward-looking statements based on our current expectations, assumptions, estimates and projections about us and the oil and gas industry. These forward-looking statements involve risks and uncertainties that may be outside of our control. Our actual results could differ materially from those indicated in these 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, as well as those factors discussed below and elsewhere in this prospectus, particularly in “Risk Factors” and “Forward-Looking Statements.” In light of these risks, uncertainties and assumptions, the forward-looking events discussed below may not occur. Except to the extent 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.
Overview
      We provide specialized services and products focused on helping oil and gas companies develop hydrocarbon reserves, reduce 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 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 and Kansas, western Canada and Mexico.
      On September 12, 2005, we completed the Combination (see “Business – The Combination”) of Complete Energy Services, Inc. (“CES”), Integrated Production Services, Inc. (“IPS”) and I.E. Miller, Inc. (“IEM”). SCF-IV, L.P. (“SCF”) held a majority interest in each of CES, IPS and IEM prior to the Combination. Therefore, we accounted for the Combination using the continuity of interests method (see note 1 of the accompanying audited consolidated financial statements). The consolidated financial statements and the discussions herein, include the operating results of CES, IPS and IEM from the date that each became controlled by SCF (November 7, 2003, May 22, 2001 and August 26, 2004, respectively).
      We operate in three business segments:
  •  Completion and Production Services. Our completion and production services segment includes: (1) intervention services, which require the use of specialized equipment, such as coiled tubing units, pressure pumping units, nitrogen units, well service rigs and snubbing units, to perform various wellbore services, (2) downhole and wellsite services, such as wireline, production optimization, production testing and rental and fishing services, and (3) fluid handling services that are used to move, store and dispose of fluids that are involved in the development and production of oil and gas reservoirs.
 
  •  Drilling Services. Through our drilling services segment, we provide land drilling, specialized rig logistics and site preparation for oil and gas exploration and production companies.
 
  •  Product Sales. Through our product sales segment, we sell oil and gas field equipment, including completion, flow control and artificial lift equipment, as well as tubular goods.
      Substantially all of the service and rental revenue we earn is based upon a charge for a relatively short period of time (an hour, a day, a week) for the actual period of time the service or rental is provided to our customer. By contracting services on a short-term basis, we are exposed to the risks of a rapid reduction in market prices and utilization and volatility in our revenues. Product sales are recorded when

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the actual sale occurs and title or ownership passes to the customer and the product is shipped or delivered to the customer.
      Our customers include large multi-national and independent oil and gas producers, as well as smaller independent producers and the major land-based drilling contractors in North America (see “Business – Customers”). The primary factor influencing demand for our services and products is the level of drilling and workover activity of our customers, which in turn, depends on current and anticipated future oil and gas prices, production depletion rates and the resultant levels of cash flows generated and allocated by our customers to their drilling 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. The following tables summarize average North American drilling and well service rig activity, as measured by Baker Hughes Incorporated (“BHI”), and historical commodity prices as provided by Bloomberg:
AVERAGE RIG COUNTS
                                           
    Year Ended   Year Ended   Year Ended   Year Ended   Year Ended
BHI Rotary Rig Count:   12/31/05   12/31/04   12/31/03   12/31/02   12/31/01
                     
U.S. Land
    1,290       1,095       924       717       1,003  
U.S. Offshore
    93       97       108       113       153  
                               
 
Total U.S. 
    1,383       1,192       1,032       830       1,156  
Canada
    455       365       372       263       341  
Mexico
    107       110       92       65       54  
                               
 
Total North America
    1,945       1,667       1,496       1,158       1,551  
                               
BHI Workover Rig Count:
                                       
 
United States
    1,354       1,235       1,129       1,010       1,211  
Canada
    654       615       350       261       342  
                               
 
Total U.S. and Canada
    2,008       1,850       1,479       1,271       1,553  
                               
 
Source: BHI (www.BakerHughes.com)
AVERAGE OIL AND GAS PRICES
                 
 
    Average Daily Closing   Average Daily Closing
    Henry Hub Spot Natural   WTI Cushing Spot Oil
Period   Gas Prices ($/mcf)   Price ($/bbl)
 
1/1/99 - 12/31/99
  $ 2.27     $ 19.30  
1/1/00 - 12/31/00
    4.30       30.37  
1/1/01 - 12/31/01
    3.96       25.96  
1/1/02 - 12/31/02
    3.37       26.17  
1/1/03 - 12/31/03
    5.49       31.06  
1/1/04 - 12/31/04
    5.90       41.51  
1/1/05 - 12/31/05
    8.89       56.59  
1/1/05 - 3/1/06
    8.08       63.56  
 
 
Source: Bloomberg NYMEX prices.
      We consider the number of 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

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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 or are increasing. We evaluate the utilization of our assets as a measure of operating performance. This utilization can be impacted by these and other external and internal factors. See “Risk Factors.”
      We generally charge for our services on a dayrate basis. Depending on the specific service, a dayrate may include one or more of these components: (1) a set-up charge, (2) an hourly service rate based on equipment and labor, (3) an equipment rental charge, (4) a consumables charge, and (5) a mileage and fuel charge. We generally determine the rates charged through a competitive process on a job-by-job basis. Typically, work is performed on a “call out” basis, whereby the customer requests services on a job-specific basis, but does not guarantee work levels beyond the specific job bid. For contract drilling services, fees are charged based on standard dayrates or, to a lesser extent, as negotiated by footage or through turnkey contracts. Product sales are generated through our supply stores and through wholesale distributors, using a purchase order process and a pre-determined price book.
Outlook
      Our growth strategy includes a focus on internal growth in our current basins by adding additional like kind equipment, expanding service and product offerings and, to a lesser extent, by increasing equipment utilization. In addition, we identify new basins in which to replicate this approach. We also augment our internal growth through strategic acquisitions.
  •  Internal Capital Investment. Our internal expansion activities generally consist of adding equipment and qualified personnel in locations where we have established a presence. We expect to grow our operations in each of these locations by expanding services to current customers, attracting new customers and hiring local personnel with local basin-level expertise and leadership recognition. Depending on customer demand, we will consider adding equipment to further increase the capacity of services currently being provided and/or add equipment to expand the services we provide. We invested $185.2 million in equipment additions over the three-year period ended December 31, 2005, which included $120.6 million for the completion and production services segment, $53.0 million for the drilling services segment and $8.3 million for the product sales segment. We have invested $3.3 million related to general corporate operations over the same period.
 
  •  External Growth. We use strategic acquisitions as an integral part of our growth strategy. We consider acquisitions that will add to our service offerings in a current operating area or that will expand our geographical footprint into a targeted basin. We have completed several acquisitions in recent years. These acquisitions affect our operating performance period to period. Accordingly, comparisons of revenue and operating results are not necessarily comparable and should not be relied upon as indications of future performance. We have invested an aggregate of $370.8 million in acquisitions over the three-year period ended December 31, 2005, excluding the acquisition of minority interests in CES and IEM resulting from the Combination.
Significant Acquisitions
  •  Integrated Production Services Ltd. On July 3, 2002, we acquired Integrated Production Services Ltd., a western Canada-based integrated well service company providing wireline, production testing and production optimization services in western Canada. This acquisition was completed through a series of transactions, in which we paid $29.5 million in cash in July 2002 and an additional $20.0 million in cash in October 2002. This acquisition was an important addition to our completion and production services segment, as it provided a platform to expand our business into the Canadian oilfield services market. We recorded $28.7 million of goodwill related to this acquisition.
 
  •  BSI. On November 7, 2003, we acquired BSI Holdings Management, LLC and BSI Holdings, L.P. and related parties (“BSI”) for $50.1 million in cash, and issued common stock totaling $8.5 million. This acquisition provided us with a base of business in the Barnett Shale region of north Texas. BSI is an integrated provider of drilling, completion and production services in the oil

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  and gas industry and sells various products used in the production of oil and gas. We recorded $14.4 million of goodwill related to this acquisition.
 
  •  I.E. Miller. On August 31, 2004, we acquired all the outstanding membership interests of I.E. Miller of Eunice (Texas) No. 2, L.L.C. and certain related entities (“I.E. Miller”) for $13.6 million in cash and issued common stock totaling $12.5 million. This acquisition was an important addition to our drilling services business, as I.E. Miller specializes in rig logistics. We recorded $8.5 million of goodwill associated with this acquisition.
 
  •  Hyland Enterprises, Inc. On September 3, 2004, we acquired Hyland Enterprises, Inc., a Wyoming-based fluid-handling and oilfield equipment rental company, for $24.3 million in cash, including the repayment of debt. This acquisition expanded our completion and production services segment in the U.S. Rocky Mountain region. We recorded $5.5 million of goodwill related to this acquisition.
 
  •  Hamm Co. On October 14, 2004, we acquired Hamm and Phillips Service Company, Inc. and certain other entities (“Hamm Co.”), an Oklahoma-based fluid-handling, well-servicing and oilfield equipment rental company, for $48.1 million in cash, the issuance of common stock totaling $37.0 million and certain additional acquisition costs totaling $2.8 million. This acquisition expanded our completion and production services segment into the U.S. Mid-continent region and provided additional heavy equipment hauling capability for the drilling services segment. We recorded $33.8 million of goodwill related to this acquisition.
 
  •  Parchman Energy Group, Inc. On February 11, 2005, we acquired Parchman Energy Group, Inc. (“Parchman”) for $9.8 million in cash, the issuance of common stock totaling $16.9 million, the issuance of a subordinated note totaling $5.0 million and the potential issuance of 1,000,000 shares of our common stock based upon certain operating results. We expect that all 1,000,000 such shares of our common stock will be issued in the first quarter of 2006. In addition, we granted 344,664 shares of non-vested restricted stock to former Parchman employees, of which 153,736 shares vested on December 31, 2005. Parchman performs intervention services and downhole services including coiled tubing, production testing and wireline services, and operates from locations in Texas, Louisiana and Mexico. We recorded $20.3 million of goodwill related to this acquisition.
 
  •  Big Mac. On November 1, 2005, we acquired all of the outstanding equity interests of the Big Mac group of companies (Big Mac Transports, LLC, Big Mac Tank Trucks, LLC and Fugo Services, LLC) for $40.8 million in cash. The Big Mac group of companies (“Big Mac”) is based in McAlester, Oklahoma, and provides fluid handling services primarily to customers in eastern Oklahoma and western Arkansas. Big Mac’s principal assets consist of rolling stock and frac tanks. The purchase price, which is subject to a post-closing adjustment for actual working capital and reimbursable capital expenditures as of the closing date, has not yet been finalized. We recorded $23.7 million of goodwill in connection with this acquisition. We have included the operating results of Big Mac in the completion and production services business segment from the date of acquisition. This acquisition provides a platform to enter the eastern Oklahoma market and new Fayetteville Shale play in Arkansas.
      In addition, we completed several other smaller acquisitions during the years ended December 31, 2005, 2004 and 2003 each of which has contributed to the expansion of our business into new geographic regions or enhanced our service and product offerings.
      We have accounted for these acquisitions using the purchase method of accounting, whereby the purchase price is allocated to the fair value of net assets acquired, including intangibles and property, plant and equipment at depreciated replacement costs with the excess to goodwill, with the exception of the merger of Integrated Production Services Ltd., and another predecessor company in 2002, which was accounted for using the continuity of interest method of accounting, a treatment similar to a pooling of interests, and the Combination, which was also accounted for using the continuity of interest accounting

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method. Results of operations related to each of the acquired companies have been included in our combined operations as of the date of acquisition.
Marketing Environment
      We operate in a highly competitive industry. Our competition includes many large and small oilfield service companies. As such, we price our services and products to remain competitive in the markets in which we operate, adjusting our rates to reflect current market conditions as necessary. We examine the rate of utilization of our equipment as one measure of our ability to compete in the current market environment.
Seasonality
      We generally experience a decline in sales for our Canadian operations during the second quarter of each year due to seasonality, as weather conditions make oil and gas operations in this region difficult during this period. Our Canadian operations accounted for approximately 14% of total revenues during the year ended December 31, 2005.
Critical Accounting Policies and Estimates
      The preparation of our consolidated financial statements in conformity with 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.
      In the selection of our critical accounting policies, the objective is to properly reflect our financial position and results of operations for each reporting period in a consistent manner that can be understood by the reader of our financial statements. Our accounting policies and procedures are explained in note 1 of the notes to the consolidated financial statements contained elsewhere in this prospectus. We have identified the following as the most critical accounting policies which may have a significant effect on our reported financial results.
  •  Continuity of Interests Accounting. We applied the provisions of Statement of Financial Accounting Standards (“SFAS”) No. 141. “Business Combinations” to account for the formation of Complete. SFAS No. 141 permits us to account for the combination of several predecessor companies using a method similar to a pooling of interests if each is controlled by a common stockholder. In connection with the Combination, we paid a dividend to our stockholders of $2.62 per share and adjusted the number of shares subject to, and exercise price of, outstanding stock options and restricted shares in accordance with Financial Accounting Standards Board (“FASB”) Interpretation No. 44. “Accounting for Certain Transactions Involving Stock Compensation, an Interpretation of Accounting Principles Board (“APB”) Opinion No. 25.” On September 12, 2005, we completed the transaction, pursuant to which CES and IEM stockholders exchanged all of their common stock for common stock of IPS. CES stockholders received 19.704 shares of IPS common stock for each share of CES common stock, and IEM stockholders received 19.410 shares of IPS common stock for each share of IEM common stock. In connection with the Combination, IPS changed its name to Complete Production Services, Inc. We acquired the interests of the minority stockholders in these predecessor companies as of the date of the consummation and accounted for these transactions using the purchase method of accounting, resulting in goodwill of $93.8 million, which represented the excess of the purchase price over the carrying value of the net assets acquired.

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  •  Revenue Recognition. We recognize service revenue as services are performed and when realized or earned. Revenue is deemed to be realized or earned when we determine that the following criteria are met: (1) persuasive evidence of an arrangement exists; (2) delivery has occurred or services have been rendered; (3) the fee is fixed or determinable; and (4) collectibility is reasonably assured. These services are generally provided over a relatively short period of time pursuant to short-term contracts at pre-determined day-rate fees, or on a day-to-day basis. Revenue and costs related to drilling contracts are recognized as work progresses. Progress is measured as revenue is recognized based upon day rate charges. For certain contracts, we may receive lump-sum payments from our customers related to the mobilization of rigs and other drilling equipment. Under these arrangements, we defer revenues and the related cost of services and recognize them over the term of the drilling contract. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred. Revenues associated with product sales are recorded when product title is transferred to the customer.
 
  •  Impairment of Long-Lived Assets. We evaluate potential impairment of long-lived assets and intangibles, excluding goodwill and other intangible assets without defined services lives, when indicators of impairment are present, as defined in SFAS No. 144. If such indicators are present, we project the fair value of the assets by estimating the undiscounted future cash in-flows to be derived from the long-lived assets over their remaining estimated useful lives, as well as any salvage value. Then, we compare this fair value estimate to the carrying value of the assets and determine whether the assets are deemed to be impaired. For goodwill and other intangible assets without defined service lives, we apply the provisions of SFAS No. 142, which requires an annual impairment test, whereby we estimate the fair value of the asset by discounting future cash flows at our projected cost of capital rate. If the fair value estimate is less than the carrying value of the asset, an additional test is required whereby we apply a purchase price analysis consistent with that described in SFAS No. 141. If impairment is still indicated, we would record an impairment loss in the current reporting period for the amount by which the carrying value of the intangible asset exceeds its projected fair value. Our industry is highly cyclical and the estimate of future cash flows requires the use of assumptions and our judgment. Periods of prolonged down cycles in the industry could have a significant impact on the carrying value of these assets and may result in impairment charges.
 
  •  Stock Options. We have issued stock-based compensation to certain employees, officers and directors in the form of stock options. We account for these stock options by applying APB Opinion No. 25, “Accounting for Stock Issued to Employees,” which does not require us to recognize compensation expense related to these employee stock options when the exercise price of the option is at least equal to the market value of the stock on the date of grant. Accordingly, we have not recognized compensation expense related to our stock options issued. We have, however, included potential common shares associated with our stock option awards in the calculation of diluted shares outstanding in order to determine diluted earnings per share. For new stock-based compensation grants after January 1, 2006, we will be required to account for our stock-based compensation plans using the fair value recognition provision of SFAS No. 123R, “Share-Based Payments.” Accounting for these stock options using the fair value recognition provisions of SFAS No. 123R will negatively impact our financial position and results of operations, as it requires that the fair value of stock options issued be estimated using a pricing model, which requires the application of highly subjective assumptions that have an inherent degree of uncertainty, and requires us to expense the estimated fair value over the vesting period of the related options. SFAS No. 123R will require us to measure the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award, with limited exceptions. We expect to incur expenses related to our stock options for each reporting period beginning on or after January 1, 2006.
  The fair value of common stock for options granted was estimated by management and/or our controlling stockholder, SCF, using an internal valuation methodology. A market approach was

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generally used to estimate our enterprise value using estimates of EBITDA multiplied by relevant market multiples, adjusted to take into account particular characteristics of our businesses. We used market multiples of publicly traded energy service companies that we believed to be most comparable to our businesses. Prior to the Combination in September 2005, the valuation of common stock was based on the value of the common stock of the specific predecessor company, which had made a stock award. We did not obtain contemporaneous valuations by an unrelated valuation specialist because we were focused on internal growth and acquisitions and we had a good measure of fair value as a result of the numerous acquisitions negotiated at arms-length prices with third parties throughout the period, which included stock consideration. In addition, we believed that our management team and SCF had the appropriate expertise and experience to perform such analyses; and we utilized methodologies acknowledged in the applicable accounting literature.
  During the 12-month period ended December 31, 2005, we granted stock options with the exercise prices as follows:
                                 
            Weighted-Average   Weighted-Average
Grants Made   Number of   Weighted-Average   Fair Value   Intrinsic Value
During Quarter Ended   Options Granted   Exercise Price   per Share   per Share
                 
March 31, 2005
    454,861     $ 4.91     $ 4.91     $  
June 30, 2005
    777,868       6.25       6.25        
September 30, 2005
    65,536       9.19       9.19        
December 31, 2005
    448,044       11.66       11.66        
  Based on an assumed IPO price of $                    , the intrinsic value of all options outstanding as of December 31, 2005 would have been $           million.
 
  The principal reasons for the differences between the fair value per share at the option grant date and the assumed IPO price of $                    are as follows:
  •  The Combination, which closed on September 12, 2005, substantially increased our geographic scope and breadth of services, creating the potential for significant cross-selling opportunities and integration of the operations of the combined companies. Benefits of the Combination included increased market penetration resulting in part from expansion of proprietary production enhancement, product and service offerings into existing and new geographic regions and leveraging brand name and relationships in order to introduce additional products and services into core markets.
 
  •  Following the Combination, we believe we have been able successfully to demonstrate the execution of our strategy as a combined company.
 
  •  Prior to the Combination, our three predecessor companies were smaller private companies, the common stock of which was illiquid due in part to restrictions on the transferability of that stock, the lack of dividends and concentration of ownership. We believe that larger companies with broader product and service offerings generally trade at higher multiples of their EBITDA or other relevant performance measures.
 
  •  The financing completed in connection with the Combination has provided us improved liquidity for additional acquisitions and capital expenditures.
 
  •  Our operating results generally improved throughout the year in 2005 due to acquisitions, price increases and improved demand for our products and services.
 
  •  Our expectations for future performance for 2006 increased as compared to 2005 due to:
  •  acquisitions completed;
 
  •  increased forecasted demand from customers for drilling services and completion and production services, particularly in the Rocky Mountain and North Texas regions;

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  •  price increases in several of our business lines, including drilling services and intervention services; and
 
  •  improved forecasted operating results.
  •  We are realizing the benefits of the acquisitions we made in 2004 and 2005, including the acquisition of Hamm Co. in October 2004, Parchman Energy Group, Inc. in February 2005 and Big Mac in November 2005. These benefits include increased size, geographic scope and breadth of services.
 
  •  We are realizing the benefits of organic growth resulting from the capital expenditures of approximately $47 million in 2004 and approximately $127 million during 2005.
 
  •  We will use a substantial portion of the net proceeds from this offering to reduce existing outstanding debt. Please see “Use of Proceeds.”
 
  •  Market prices of publicly traded energy service companies have shown significant increases from January 1, 2005 due to increases in demand for energy services caused, in part, by increasing commodity prices. We believe that increased service sector demand and prices will remain strong in the foreseeable future. The Oil Service Sector Index increased from 119.38 at the beginning of 2005 to 169.56 at September 12, 2005, the date of the Combination, and to 190.59 at March 10, 2006. This represents an increase of approximately 12% since September 12, 2005 and an increase of approximately 60% since January 1, 2005.
  •  Allowance for Bad Debts and Inventory Obsolescence. We record trade accounts receivable at billed amounts, less an allowance for bad debts. Inventory is recorded at cost, less an allowance for obsolescence. To estimate these allowances, management reviews the underlying details of these assets as well as known trends in the marketplace, and applies historical factors as a basis for recording these allowances. If market conditions are less favorable than those projected by management, or if our historical experience is materially different from future experience, additional allowances may be required.
 
  •  Property, Plant and Equipment. We record property, plant and equipment at cost less accumulated depreciation. Major betterments to existing assets are capitalized, while repairs and maintenance costs that do not extend the service lives of our equipment are expensed. We determine the useful lives of our depreciable assets based upon historical experience and the judgment of our operating personnel. We generally depreciate the historical cost of assets, less an estimate of the applicable salvage value, on the straight-line basis over the applicable useful lives, except office furniture and computers, which are depreciated using the declining balance method. Upon disposition or retirement of an asset, we record a gain or loss if the proceeds from the transaction differ from the net book value of the asset at the time of the disposition or retirement. If our depreciation estimates are not correct, we may record a disproportionate amount of gains or losses upon disposition of these assets. We believe our estimates of useful lives are materially correct.
 
  •  Deferred Income Taxes. Our income tax expense includes income taxes related to the United States, Canada and other foreign countries, including local, state and provincial income taxes. We account for tax ramifications using SFAS No. 109, “Accounting for Income Taxes.” Under SFAS No. 109, we record deferred income tax assets and liabilities based upon temporary differences between the carrying amount and tax basis of our assets and liabilities and measure tax expense using enacted tax rates and laws that will be in effect when the differences are expected to reverse. The effect of a change in tax rates is recognized in income in the period of the change. Furthermore, SFAS No. 109 requires us to record a valuation allowance for any net deferred income tax assets which we believe are likely to not be used through future operations. As of December 31, 2005 and 2004, we had recorded a total valuation allowance of $0.9 million related to certain deferred tax assets in Canada. If our estimates and assumptions related to our deferred tax

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  position change in the future, we may be required to record additional valuation allowances against our deferred tax assets and our effective tax rate may increase, which could result in a material adverse effect on our financial position, results of operations and cash flows. As of December 31, 2005, no deferred U.S. income taxes have been provided on the approximately $1.7 million of undistributed earnings of foreign subsidiaries in which we intend to indefinitely reinvest. Upon distribution of these earnings in the form of dividends or otherwise, we may be subject to U.S. income taxes and foreign withholding taxes.
      The following table describes estimates, assumptions and methods regarding critical accounting policies used to prepare our consolidated financial statements. We consider an estimate to be critical if it is subjective and if changes in the estimate using different assumptions would result in a material impact on our financial position or results of operations:
             
            Historical Results/
Description   Estimates/Assumptions Used   Variability in Accounting   Sensitivity Analysis
             
Revenue Recognition   We recognize revenue when realizable and earned as services are performed or as risk of ownership and physical possession passes to the buyer. We defer unearned revenue until earned. Any reimbursements of mobilization charges are amortized over the contract involved.   There is a risk that we may not record revenue in the proper period.   We did not record material adjustments resulting from revenue recognition issues for the years ended December 31, 2005, 2004 and 2003.
Impairment of Long-lived Assets
  We evaluate the recoverability of assets periodically, but at least annually for goodwill and intangible assets with indefinite lives, by reviewing operational performance and expected cash flows. Our management estimates future cash flows for this purpose and for intangible assets, discounts these cash flows at an applicable rate.   There is a risk that management’s estimates of future performance may not approximate actual performance or that rates used for discounting cash flows are not consistent with the actual discount rates. Our assets could be overstated if impairment losses are not identified timely.   We tested goodwill for impairment for each of the years ended December 31, 2005, 2004, and 2003, and management determined that goodwill was not impaired. A significant decline in expected future cash flow as a result of lower sales, could result in an impairment charge. For example, an impairment of 10% of goodwill at December 31, 2005, would have resulted in a decrease in operating income of $29.8 million for the year ended December 31, 2005.

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            Historical Results/
Description   Estimates/Assumptions Used   Variability in Accounting   Sensitivity Analysis
             
Allowance for Bad Debts and Obsolete Inventory
  We estimate the recoverability of receivables and inventory on an individual basis based upon historical experience and management’s judgment.   There is a risk that management may not detect uncollectible accounts or unsalvageable inventory in the correct accounting period.   Bad debt expense has been less than 2% of sales for each of the years ended December 31, 2005, 2004 and 2003. If bad debt expense had increased by 1% of sales for the year ended December 31, 2005, net income would have declined by $4.7 million. Our obsolescence and other inventory reserves as of December 31, 2005, 2004 and 2003 have ranged from 4% to 13%. Our obsolescence and other inventory reserves were approximately 5% of inventory at December 31, 2005. A 1% increase, from 5% to 6%, in inventory reserves at December 31, 2005 would have decreased net income by approximately $254,000 for the year ended December 31, 2005.

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            Historical Results/
Description   Estimates/Assumptions Used   Variability in Accounting   Sensitivity Analysis
             
Property, Plant and Equipment
  Our management estimates useful lives of depreciable equipment and salvage values. The depreciation method used is generally the straight-line method, except for furniture and office equipment which is depreciated on an accelerated basis.   GAAP permits various depreciation methods to recognize the use of assets. Use of a different depreciation method or different depreciable lives could result in materially different results. The estimated useful lives are consistent with industry averages. There is a risk that the asset’s useful life used for our depreciation calculation will not approximate the actual useful life of the asset.   We evaluate property, plant and equipment for impairment when there are indicators of impairment. There have been no impairment charges related to our long-term assets during the years ended December 31, 2005, 2004 and 2003. Depreciation and amortization expense for the year ended December 31, 2005 represented 13% of the average depreciable asset base for that period. An increase in depreciation relative to the depreciable base of 1%, from 13% to 14%, would have reduced net income by approximately $2.2 million.
Valuation Allowance for Income Taxes
  We apply the provisions of SFAS No. 109 to account for income taxes. Differences between depreciation methods used for financial reporting purposes compared to tax purposes as well as other items, including loss carry forwards and valuation allowances against deferred tax assets, require management’s judgment related to the realizability of deferred tax accounts.   There is a risk that estimates related to the use of loss carry forwards and the realizability of deferred tax accounts may be incorrect, and that the result could materially impact our financial position and results of operations. In addition, future changes in tax laws could result in additional valuation allowances.   Historically, we have utilized net operating loss carry forwards to partially offset current tax expense, and we have recorded a valuation allowance to the extent we expect that our deferred tax assets will not be utilized through future operations. Deferred income tax assets totaled $5.3 million at December 31, 2005, against which we recorded a valuation allowance of $0.9 million, leaving a net deferred tax asset of $4.4 million deemed realizable. Changes in our valuation allowance would affect our net income on a dollar for dollar basis.

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            Historical Results/
Description   Estimates/Assumptions Used   Variability in Accounting   Sensitivity Analysis
             
Stock Options
  For years ended on or before December 31, 2005, we applied the provisions of APB No. 25 to account for stock options and estimate compensation expense that would be required to be recognized under SFAS No. 123 for pro forma footnote disclosures. The determination of the fair value of stock options required subjective estimates of variables used in a pricing model, including stock volatility, dividend rate, risk-free interest rate and expected term of options.   GAAP permits the use of various models to determine the fair value of stock options and the variables used for the model are highly subjective. The use of different assumptions or a different model may have a material impact on our financial disclosures.   For years ended on or before December 31, 2005, we determined the value of our stock options by applying the minimum value method permitted by APB No. 25 and, in connection with estimating compensation expense that would be required to be recognized under SFAS No. 123, we used a Black-Scholes model including assumptions for expected term (ranging from 3 to 4.5 years as of December 31, 2005), risk- free rate (based upon published rates for U.S. Treasury notes with a similar term), zero dividend rate and a volatility rate of zero.
Results of Operations
      The following tables set forth our results of operations, including amounts expressed as a percentage of total revenue, for the periods indicated (in thousands, except percentages).
                                                           
                    Percent       Percent
                Change   Change   Change   Change
                2005/   2005/   2004/   2004/
    2005   2004   2003   2004   2004   2003   2003
                             
Revenue:
                                                       
Completion and production services
  $ 510,304     $ 194,953     $ 65,025     $ 315,351       162 %   $ 129,928       200 %
Drilling services
    129,117       44,474       2,707       84,643       190 %     41,767       NM  
Product sales
    118,305       81,320       35,547       36,985       45 %     45,773       129 %
                                           
 
Total
  $ 757,726     $ 320,747     $ 103,279     $ 436,979       136 %   $ 217,468       211 %
                                           
EBITDA:
                                                       
Completion and production services
  $ 119,171     $ 38,349     $ 9,134     $ 80,822       211 %   $ 29,215       320 %
Drilling services
    44,393       10,093       712       34,300       340 %     9,381       NM  
Product sales
    18,444       12,924       4,951       5,520       43 %     7,973       161 %
Corporate
    (20,745 )     (2,869 )     (1,233 )     (17,876 )     NM       (1,636 )     133 %
                                           
 
Total
  $ 161,263     $ 58,497     $ 13,564     $ 102,766       176 %   $ 44,933       331 %
                                           

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“NM” denotes not meaningful.
“Corporate” includes amounts related to corporate personnel costs and other general expenses.
“EBITDA” consists of net income (loss) before interest expense, taxes, depreciation and amortization and minority interest. EBITDA is a non-cash measure of performance. We use EBITDA as the primary internal management measure for evaluating performance and allocating additional resources. See the discussion of EBITDA at note 2 to “Selected Consolidated Financial Data.”
      Our revenue and EBITDA results for the indicated periods generally increased due to the contribution of companies acquired and an increase in oilfield activity in North America as a result of higher commodity prices throughout the applicable periods.
      For a reconciliation of EBITDA, please see “Selected Consolidated Financial Data – Reconciliation of EBITDA.”
      Below is a more detailed discussion of our operating results by segment for these periods.
Year Ended December 31, 2005 Compared to the Year Ended December 31, 2004
Revenue
      Revenue for the year ended December 31, 2005 increased by 136%, or $437.0 million, to $757.7 million from $320.7 million for the year ended December 31, 2004. This increase by segment was as follows:
  •  Completion and Production Services. Segment revenue increased $315.4 million and resulted primarily from: (1) the acquisition of Hyland Enterprises, Inc. in September 2004, which contributed $62.4 million in 2005; (2) the acquisition of Hamm Co. in October 2004, which contributed incremental revenues of $69.9 million in 2005; (3) the acquisition of Parchman in February 2005, which contributed $59.6 million; (4) several other smaller acquisitions in 2005, including Big Mac, which contributed revenues to the 2005 results; and (5) an incremental increase in revenues earned as a result of additional capital investment in the well servicing, rental and fluid-handling businesses, as well as improved market conditions including favorable pricing for our services and products.
 
  •  Drilling Services. Segment revenue increased $84.6 million, primarily related to an increase associated with the acquisition of IEM in September 2004, which contributed $65.2 million in revenues for the year ended December 31, 2005 compared to $17.7 million in revenues for the period from the acquisition date through December 31, 2004. In addition, the segment benefited from increased prices for our services and increased oilfield activity, which provided incremental revenues of $37.1 million, achieved in part through additional investment in drilling rigs and drilling logistics equipment for operations located in the Barnett Shale region of north Texas.
 
  •  Product Sales. Segment revenue increased $37.0 million, fueled by an incremental increase in supply store sales of $24.2 million which includes the results of several newly opened supply stores, and two additional stores purchased during 2005, an increase in Canadian product sales, primarily surface production equipment, improved sales in other international locations and an increase in the sale of flow control products. These increased product sales reflect the overall improved market conditions.
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 123%, or $265.2 million, for the year ended December 31, 2005, to $481.4 million from $216.2 million for the same period in 2004. As a percentage of revenues, service and product expenses were 64% for 2005 compared to 67% for 2004. The decline in

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service and product expenses as a percentage of revenue reflected a favorable mix of services and products and improved prices, as more revenue was earned in 2005 from higher margin basins and related services in the United States, and increasing customer demand for our services. By segment, service and product expenses as a percentage of revenues for the years ended December 31, 2005 and 2004 were 63% and 65%, respectively, for the completion and production services segment; 55% and 70%, respectively, for the drilling services segment; and 74% and 72%, respectively, for the product sales segment.
Selling, General and Administrative Expenses
      Selling, general and administrative expenses consist primarily of salaries and other related expenses for our administrative, finance, information technology and human resource functions. Selling, general and administrative expenses increased 143%, or $65.7 million, for the year ended December 31, 2005, to $111.8 million from $46.1 million for the year ended December 31, 2004. This increase was primarily due to acquisitions, which provided additional headcount and general expenses. In addition, as a result of the Combination, we employed corporate officers and key members of management, paid an incentive bonus in connection with the Combination and expensed outside service costs related to the Combination of $1.4 million. Additional costs were incurred in 2005 for outside consulting services for accounting, tax and information technology, and higher performance-based incentive bonus accruals at December 31, 2005 compared to December 31, 2004. As a percentage of revenues, selling, general and administrative expenses were 15% and 14% for the years ended December 31, 2005 and 2004, respectively.
Write-off of Deferred Financing Fees
      We recorded a write-off of deferred financing fees of $3.3 million during 2005 to expense unamortized deferred costs associated with debt facilities which were repaid on September 12, 2005 with borrowings under the new $580.0 million term loan and revolving credit facility. Unamortized deferred financing fees at December 31, 2005 of $2.0 million related entirely to this new facility and are being amortized over the term of the facility.
Depreciation and Amortization
      Depreciation and amortization expense increased 126%, or $27.2 million, to $48.8 million for the year ended December 31, 2005, from $21.6 million during the same period in 2004. The increase in depreciation and amortization expense was the result of equipment and intangible assets acquired through capital expenditures and purchase acquisitions. As a percentage of revenue, depreciation and amortization expense was 6% and 7% for the years ended December 31, 2005 and 2004, respectively.
Interest Expense
      Interest expense was $24.5 million for the year ended December 31, 2005, compared to $7.5 million for the same period in 2004. The increase in interest expense was attributable to an increase in the average amount of debt outstanding as a result of acquisitions and capital expenditures completed in 2004 and 2005. The weighted-average interest rate outstanding increased from 6% at December 31, 2004 to 7% at December 31, 2005. This increase related to borrowings under variable interest rate facilities and a general increase in the prime interest rate during 2005.
Taxes
      Tax expense is comprised of three components: capital and franchise taxes, current income taxes and deferred income taxes. The capital and franchise tax component is generally based on our capital base and does not correlate to pretax income. The current and deferred taxes added together provide an indication of an effective rate of income tax.
      Tax expense was 38.5% and 43.8% of pretax income for the years ended December 31, 2005 and 2004, respectively.

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Year Ended December 31, 2004 Compared to the Year Ended December 31, 2003
Revenue
      Revenue for the year ended December 31, 2004 increased by 211%, or $217.5 million, to $320.7 million from $103.3 million for the year ended December 31, 2003. This increase by segment was as follows:
  •  Completion and Production Services. Segment revenue increased $129.9 million and resulted primarily from: (1) the acquisition of BSI in late 2003, which contributed $40.2 million of incremental revenues in 2004, of which $20.9 million was derived from a full-year’s operation in 2004 and $16.1 million was derived from investment in capital equipment; (2) the acquisition of eleven smaller companies throughout 2004 which contributed to 2004 revenue totals but did not contribute to operating results in 2003; and (3) a general increase in the use of our services attributable to more favorable oilfield activity levels associated with rising commodity prices.
 
  •  Drilling Services. Segment revenue increased $41.8 million. Of this increase, $18.9 million was provided through acquisitions, and more specifically, the acquisition of BSI in late 2003, which contributed $17.7 million of incremental revenues in 2004, and the Hamm Co. acquisition completed in late 2004, which provided an additional $1.2 million of drilling revenues. The remaining revenue increase in 2004 relative to 2003 was due to additional investment in drilling rigs for operations located in the Barnett Shale region of north Texas.
 
  •  Product Sales. Segment revenue increased $45.8 million, of which $31.2 million was derived from the product sales component of BSI’s acquisition and a general increase in product sales from existing operations as a result of improved market conditions in the oil and gas industry, including higher international sales and, in particular, sales of surface production equipment in Canada, and increased sales of flow control equipment.
Service and Product Expenses
      Service and product expenses increased by 196%, or $143.0 million, for the year ended December 31, 2004, to $216.2 million from $73.1 million for the year ended December 31, 2003. As a percentage of revenues, service and product expenses were 67% in 2004 compared to 71% in 2003. The decline in service and product expenses as a percentage of revenue reflected a favorable mix of products and strong prices, as more revenue was earned in 2004 from higher margin basins and related services in the United States, and increasing customer demand for oilfield service providers’ services. By segment, service and product expenses as a percentage of revenues for the years ended December 31, 2004 and 2003 were 65% and 70%, respectively, for the completion and production services segment; 70% and 70%, respectively, for the drilling services segment; and 72% and 73%, respectively, for the product sales segment. Overall declines in service and product expense as a percentage of revenues for the completion and production services and product sales segments yielded better operating margins.
Selling, General and Administrative Expenses
      Selling, general and administrative expense for the year ended December 31, 2004 increased by 178%, or $29.5 million, to $46.1 million from $16.6 million for the year ended December 31, 2003. This increase was primarily due to additional headcount and general expenses added as a result of acquisitions. Selling, general and administrative expense as a percentage of revenues was 14% in 2004 as compared to 16% in 2003.
Depreciation and Amortization
      Depreciation and amortization expense increased 183%, or $14.0 million, to $21.6 million, for the year ended December 31, 2004 compared to $7.6 million for the year ended December 31, 2003. We increased our property, plant and equipment through acquisitions and capital expenditures throughout the two years ended December 31, 2004, as gross book value increased to $268.8 million at December 31, 2004

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compared to $109.1 million at December 31, 2003. This higher depreciable base resulted in an increase in depreciation expense during these years. In addition, we acquired certain intangible assets that were amortized in 2004 after the date of acquisition. As a percentage of revenue, depreciation and amortization was 7% in 2004 and 2003.
Interest Expense
      Interest expense was $7.5 million for the year ended December 31, 2004 compared to $2.7 million for the year ended December 31, 2003. The increase in interest expense was consistent with increased levels of bank debt used to finance acquisitions and capital expenditures. We did not experience any significant changes in interest rates for the years ended December 31, 2004 and 2003.
Taxes
      Tax expense was 43.8% and 46.6% of pretax income for the years ended December 31, 2004 and 2003, respectively. These rates reflected the mix of tax rates in the jurisdictions in which we operated. In particular, in 2003 there was a Large Corporation’s Tax and Capital Tax of approximately $0.3 million that was payable under Canadian tax law.
Liquidity and Capital Resources
      Our primary liquidity needs are to fund capital expenditures, such as expanding our coiled tubing, wireline and production testing fleets, building new drilling rigs, increasing and replacing rental tool and well service rigs and snubbing units, funding new product development and funding general working capital needs. In addition, we need capital to fund strategic business acquisitions. Our primary sources of funds have historically been cash flow from operations, proceeds from borrowings under bank credit facilities and the issuance of equity securities, primarily associated with acquisitions. Upon completion of this offering, we anticipate that we will rely on cash generated from operations, borrowings under our revolving credit facility, future debt offerings and future public equity to satisfy our liquidity needs. We believe that funds from these sources should be sufficient to meet both our short-term working capital requirements and our long-term capital requirements. Our ability to fund planned capital expenditures and to make acquisitions will depend upon our future operating performance and, more broadly, on the availability of equity and debt financing, which will be affected by prevailing economic conditions in our industry, and general financial, business and other factors, some of which are beyond our control.
      The following table summarizes cash flows by type for the periods indicated (in thousands):
                           
    Year Ended December 31,
     
    2005   2004   2003
             
Cash flows provided by (used in):
                       
 
Operating activities
  $ 76,427     $ 34,622     $ 13,965  
 
Financing activities
    112,139       157,630       55,281  
 
Investing activities
    (188,358 )     (186,776 )     (66,214 )
      Net cash provided by operating activities increased $41.8 million for the year ended December 31, 2005, compared to the year ended December 31, 2004. This increase was primarily due to an increase in gross receipts as a result of increased revenues. Our gross receipts increased during 2005 as demand for our services grew, resulting in more billable hours and more favorable billing rates, while we expanded our current business and entered new markets through acquisitions and capital investment. For the years ended December 31, 2004 and 2003, cash flows from operating activities continued to trend higher on this basis, as a result of growing our business through acquisitions and investment in capital expenditures and general improvements in activity levels and pricing. We expect to continue to evaluate acquisition opportunities for the foreseeable future, and expect that new acquisitions will provide incremental operating cash flows.
      Net cash provided by financing activities declined $45.5 million for the year ended December 31, 2005 compared to the year ended December 31, 2004. This decline reflects the use of cash generated by

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operating activities to fund capital investment during 2005, rather than the use of debt financing, the primary source of funds for expansion during 2004 and 2003. Increases in borrowings under our new term loan facility were offset by repayments of long-term debt outstanding under prior facilities and the payment of a one-time dividend to stockholders of $146.9 million. For the years ended December 31, 2004 and 2003, net cash provided by financing activities increased as we borrowed under existing credit arrangements and through seller financing to finance our investment in capital expenditures and acquisitions. Our long-term debt balances, including current maturities, were $515.9 million, $201.8 million and $67.7 million as of December 31, 2005, 2004 and 2003, respectively.
      Net cash used in investing activities increased by $1.6 million for the year ended December 31, 2005, compared to the year ended December 31, 2004. We acquired several companies in 2004 for a total use of cash of $139.4 million, but fewer acquisitions during 2005 for a total use of cash of $67.7 million. This decrease in cash used for acquisitions was offset by an incremental increase in capital equipment expenditures of $80.3 million in 2005 compared to 2004. Significant capital equipment expenditures in 2005 included drilling rigs, well services rigs, fluid-handling equipment, rental equipment and coiled tubing equipment. For the years ended December 31, 2004 and 2003, cash used for investing activities continued to increase as we invested in long-term assets and made significant acquisitions. Significant capital equipment expenditures in 2004 included drilling rigs, well services rigs, fluid-handling equipment, rental equipment and coiled tubing equipment. For 2003, capital equipment expenditures primarily included drilling equipment and coiled tubing equipment for operations in Texas. Funds used for acquisitions totaled $139.4 million in 2004 and $54.8 million in 2003. See “– Significant Acquisitions” above.
      We expect to expend approximately $200 million for investment in capital expenditures, excluding acquisitions, during the year ended December 31, 2006. We believe that our operating cash flows and borrowing capacity will be sufficient to fund our operations for the next 12 months.
      In addition to making investments in capital expenditures, we also will continue to evaluate acquisitions of complementary companies. We evaluate each acquisition based upon the circumstances and our financing capabilities at that time.
Dividends
      On September 12, 2005, we paid a dividend of $2.62 per share for an aggregate payment of approximately $146.9 million to stockholders of record on that date. We are also obligated to issue up to an aggregate of approximately 1,200,000 shares of our common stock as contingent consideration based on certain operating results of the companies we have previously acquired, and we have agreed to make additional cash payments (up to $3.1 million) in respect of such contingent shares ultimately issued in the amount of the dividend that would have been paid on such shares if those shares had been issued prior to the payment of the dividend. We do not intend to pay dividends in the future, but rather plan to reinvest such funds in our business. Furthermore, our current term loan and revolving debt facility, which we entered into on September 12, 2005, contains restrictive debt covenants which preclude us from paying future dividends on our common stock.
Description of Our Indebtedness
      Our credit facilities as of December 31, 2005 are described in the accompanying audited consolidated financial statements (see notes 9 and 10 to the audited consolidated financial statements).
      On September 12, 2005, concurrently with the completion of the Combination, we entered into a senior secured credit facility (the “Credit Agreement”) with Wells Fargo Bank, National Association, as U.S. Administrative Agent, and certain other financial institutions. The Credit Agreement provides for a $130 million U.S. revolving credit facility that will mature in 2010, a $30 million Canadian revolving credit facility (with Integrated Production Services, Ltd. as the borrower thereof) that will mature in 2010 and a $420 million term loan credit facility that will mature in 2012. Subject to certain limitations, we have the ability to increase, decrease or reallocate the commitments under the various aforementioned credit

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facilities. In addition, certain portions of the credit facilities are available to be borrowed in U.S. Dollars, Canadian Dollars, Pounds Sterling, Euros and other currencies approved by the lenders.
      Subject to certain limitations, we have the ability to elect how interest under the Credit Agreement will be computed. Interest under the Credit Agreement may be determined by reference to (1) the London Interbank Offered Rate, or LIBOR, plus an applicable margin between 1.25% and 2.75% per annum (with the applicable margin depending upon our ratio of total debt to EBITDA (as defined below)) for revolving advances and 2.75% for term advances (or 2.5% if our debt ratings are upgraded by either Moody’s or Standard & Poor’s), or (2) the Canadian Base Rate (i.e., the higher of the Canadian bank’s prime rate or the CDOR rate plus 1.0%), in the case of Canadian loans or the greater of the prime rate and the federal funds rate plus 0.5%, in the case of U.S. loans, plus an applicable margin between 0.25% and 1.75% per annum for revolving advances and 1.75% for term advances (or 1.5% if our debt ratings are upgraded). Interest is payable quarterly for base rate loans and at the end of applicable interest periods for LIBOR loans, except that if the interest period for a LIBOR loan is six months, interest will be paid at the end of each three-month period.
      The Credit Agreement also contains various covenants that limit our and our subsidiaries’ ability to:
  •  grant certain liens;
 
  •  make certain loans and investments;
 
  •  make capital expenditures;
 
  •  make distributions;
 
  •  make acquisitions;
 
  •  enter into operating leases;
 
  •  enter into hedging transactions;
 
  •  merge or consolidate; or
 
  •  engage in certain asset dispositions.
      Additionally, the Credit Agreement limits our and our subsidiaries’ ability to incur additional indebtedness with certain exceptions, including purchase money indebtedness and indebtedness related to capital leases not to exceed 10% of our consolidated net worth (i.e., the excess of our assets over the sum of our liabilities plus the minority interests), unsecured indebtedness of less than $300 million, and indebtedness qualifying as permitted subordinated debt (e.g., certain existing promissory notes issued as consideration in some of our previous acquisitions).
      The Credit Agreement contains covenants which, among other things, require us and our subsidiaries, on a consolidated basis, to maintain specified ratios or conditions as follows (with such ratios tested at the end of each fiscal quarter):
  •  consolidated interest coverage ratio of not less than 3.0 to 1.0;
 
  •  total debt to EBITDA (i.e., consolidated net income plus interest expense, taxes, depreciation, amortization and other non-cash charges) of not more than 4.25 to 1.0 through September 30, 2006, 4.00 to 1.0 from December 31, 2006 through September 30, 2007, and 3.75 to 1.0 thereafter; and
 
  •  total senior secured debt to EBITDA of not more than 3.75 to 1.0 through March 31, 2006, 3.5 to 1.0 from June 30, 2006 through September 30, 2006, 3.25 to 1.0 from December 31, 2006 to September 30, 2007, 3.00 to 1.0 from December 31, 2007 through September 30, 2008, and 2.50 to 1.0 thereafter.
      Concurrently with the completion of the Combination, we borrowed approximately $450 million under the Credit Agreement as of the closing of the Combination to: (i) finance the Combination (including the

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payment of the Dividend) and (ii) repay in full indebtedness outstanding under our previous credit agreements. Future borrowings under the revolving credit facilities under the Credit Agreement are available for working capital and general corporate purposes. The revolving facilities under the Credit Agreement may be drawn on and repaid without restriction so long as we are in compliance with the terms of the Credit Agreement, including certain financial covenants, but the term credit facility under the Credit Agreement may not be reborrowed once repaid. We are required to repay the principal of the term facility in quarterly installments equal to 0.25% of the original principal amount thereof commencing December 31, 2005. The first required principal payment of $1.1 million was made as of December 31, 2005.
      Under the Credit Agreement, we are permitted to prepay certain of our borrowings. In addition, the Credit Agreement requires us to make prepayments in following situations:
  •  If the outstanding borrowings made under the U.S. revolver exceed the aggregate U.S. revolver commitments (the amounts the applicable lenders have agreed to loan to us), or if the outstanding borrowings made under the Canadian revolver exceed the aggregate Canadian revolver commitments, then we must prepay the excess amount(s), as applicable;
 
  •  Beginning on March 31, 2007, if our consolidated debt exceeds our consolidated EBITDA by a ratio of 3.0 to 1.0 during our fourth quarter, then on March 31 of the following year, we must prepay the outstanding borrowings made under the U.S. revolver and term loan. In addition, we must prepay an amount of our Canadian outstanding borrowings equal to 50% of our excess cash flow;
 
  •  We must make prepayments in the amount by which net condemnation or insurance proceeds in respect of assets received during any fiscal year exceed $3 million if these proceeds are not used to repair or replace (or have not been contractually committed to repair or replace) these assets within 365 days after the underlying or condemnation casualty event. However, if an event of default (as defined below) has occurred and is continuing, we are required to prepay 100% of the proceeds not used as described in the previous sentence;
 
  •  If there are outstanding borrowings under our term loan and we receive net proceeds for the sale of any debt (other than our permitted debt) that along with the net proceeds from the issuance of other debt exceed $5 million during any fiscal year, then we must prepay 50% of the excess amount;
 
  •  If we receive net proceeds for the sale or issuance of equity, subject to certain exceptions, that exceed $50 million during any fiscal year, then we must prepay 50% of the excess amount up to a maximum prepayment of $50 million in any given fiscal year; or
 
  •  If any of our outstanding borrowings under our U.S. revolving credit facility are denominated in a foreign currency that is not accepted under the Credit Agreement, then we must prepay (or convert the applicable advances into U.S. Dollars) these borrowings.
      All of the obligations under the U.S. portion of Credit Agreement are secured by first priority liens on substantially all of the assets of our U.S. subsidiaries as well as a pledge of approximately 66% of the stock of our first-tier foreign subsidiaries. Additionally, all of the obligations under the U.S. portion of the Credit Agreement are guaranteed by substantially all of our U.S. subsidiaries. All of the obligations under the Canadian portions of the Credit Agreement are secured by first priority liens on substantially all of the assets of all or certain of our subsidiaries. Additionally, all of the obligations under the Canadian portions of the Credit Agreement are guaranteed by us as well as all or certain of our subsidiaries.
      If an event of default exists under the Credit Agreement, the lenders may accelerate the maturity of the obligations outstanding under the Credit Agreement and exercise other rights and remedies. Each of the following is an event of default:
  •  failure to pay any principal when due or any interest, fees or other amount within certain grace periods;

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  •  breach of representations in the Credit Agreement or other loan documents;
 
  •  failure to perform or otherwise comply with the covenants in the Credit Agreement or other loan documents, subject, in certain instances, to certain grace periods;
 
  •  default by us and any of our subsidiaries on the payment of any other indebtedness in excess of $10.0 million, any other event or condition shall occur or exist with respect to such indebtedness beyond the applicable grace period if the effect of such event or condition is to permit or cause the acceleration of the indebtedness, or such indebtedness shall be declared due and payable prior to its scheduled maturity;
 
  •  bankruptcy or insolvency events involving us or our subsidiaries;
 
  •  the entry of one or more adverse judgments in excess of $10.0 million (excluding applicable insurance proceeds) against which enforcement proceedings are brought or that are not stayed pending appeal; and
 
  •  the occurrence of a change of control (as defined in the Credit Agreement).
      At December 31, 2005, we had $504.1 million outstanding under our term loan and revolving credit facility and an additional $5.5 million of outstanding letters of credit, leaving approximately $70.4 million available to be drawn under the facility. Our weighted average interest rate on outstanding borrowings at December 31, 2005 was approximately 7.2%. For the years ended December 31, 2005, 2004 and 2003, our weighted average interest rates on outstanding bank borrowings were approximately 6.7%, 6.0% and 6.0%, respectively. At February 28, 2006, we had $543.4 million outstanding under our term loan and revolving credit facility and an additional $10.2 million of outstanding letters of credit, leaving approximately $26.4 million available to be drawn under the facility.
Acquisitions
      On January 3, 2006, we acquired substantially all of the operating assets of Outpost Office Inc. (“Outpost”), a Grand Junction, Colorado, oilfield equipment rental company. On January 25, 2006, we acquired all the equity interests of The Rosel Company (“Rosel”), a cased-hole and open-hole electric-line business based in Liberal, Kansas, with operations in Kansas and Oklahoma. The Rosel acquisition extends our presence in the Mid-continent region and enhances our completion and production services business. The operating results of Outpost and Rosel will be included in the completion and production services segment from the respective dates of their acquisition. The aggregate purchase price for these two acquisitions was approximately $20.4 million.
Other Arrangements
      We entered into two separate agreements with customers of our contract drilling operation in north Texas whereby the customers advanced funds to us and we agreed to provide drilling services in the future to these customers. We received advance payments from these customers totaling $7.4 million. In connection with these customer prepayments, we entered into an agreement with a third party to construct two drilling rigs on our behalf to commit to these customers’ drilling programs. The first of the two rigs was completed in October 2005 for a total cost of approximately $4.0 million. The second rig was completed in January 2006 at a total cost of approximately $4.0 million. We are accounting for the construction of these rigs as capital expenditures and are depreciating the rigs in a manner consistent with depreciation of our other drilling rigs. The recognition of revenue commenced once the rigs began drilling for each customer. Revenue is recognized as it is earned based upon predetermined prices for each day the rig is employed by the customer and in a manner that is consistent with revenue recognition in our other contract drilling operations. The rates charged to the customers are equal to or greater than prevailing market rates. As revenues are earned, the prepayment liability is offset by our billings to those customers. The first rig began drilling operations in October 2005 and the second rig began drilling operations in January 2006. We earned and recognized approximately $1 million in revenues through December 31, 2005 related to such rigs resulting in a remaining current liability of approximately $6.4 million as of

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December 31, 2005. It is expected that the remaining portion of deferred revenue will be earned and recognized as revenue by December 31, 2006.
Outstanding Debt and Operating Lease Commitments
      The following table summarizes our known contractual obligations as of December 31, 2005 (in thousands):
                                             
    Payments Due by Period
     
Contractual Obligations   Total   2006   2007-2008   2009-2010   Thereafter
                     
Long-term debt, including capital (finance) lease obligations
  $ 505,892     $ 5,309     $ 9,121     $ 93,512     $ 397,950  
 
Purchase obligations(1)
    42,540       42,540                    
 
Operating lease obligations
    46,777       15,380       21,468       7,875       2,054  
 
Other long-term obligations(2)
    10,051       614       835       8,562       40  
                               
   
Total contractual obligations
  $ 605,260     $ 63,843     $ 31,424     $ 109,949     $ 400,044  
                               
 
(1)  Purchase obligations were pursuant to inventory and equipment purchase orders outstanding as of December 31, 2005. We have no significant purchase orders which extend beyond one year.
 
(2)  Other long-term obligations include amounts due under subordinated note arrangements with maturity dates beginning in 2009 and loans relating to equipment purchases which mature at various dates through December 2008.
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 five years. The terms of the light vehicle leases range from three to four years. The terms of the specialized equipment leases range from two to six years. Annual payments pursuant to these leases are included above in the table under “— Outstanding Debt and Operating Lease Commitments.”
      We have entered into purchase agreements with the former owners of Double Jack and MGM as described in note 2 of our audited consolidated financial statements. Pursuant to the Double Jack purchase agreement, we agreed to pay contingent consideration of up to $1.2 million based on certain operating results of Double Jack. As of December 31, 2005, we had paid $0.5 million of this contingent consideration to the former stockholders of Double Jack. We expect to pay $0.3 million of the contingent Double Jack consideration based on operating results for the year ended December 31, 2005 and have accrued a liability for such amount as of December 31, 2005. In addition, we may have to pay up to $0.3 million of the contingent Double Jack consideration based on operating results for the twelve months ending March 31, 2006 for which no accrual has been made. In addition, we have committed to issue 22,826 shares of our restricted stock and pay approximately $0.1 million to certain former employees of Double Jack who are now our employees.
      Pursuant to the MGM purchase agreement, we agreed to pay contingent consideration of up to $3.8 million and 214,132 shares of our common stock based on certain operating results of MGM. Based on operating results for the year ended December 31, 2005, we expect to pay approximately $2.9 million out of the potential $3.8 million contingent payment, and we have accrued a liability of approximately $2.9 million as of December 31, 2005. In addition, we expect to issue approximately 187,000 shares out of the maximum possible 214,132 shares. When these shares are issued, we will recognize additional goodwill associated with this acquisition in an amount equal to the then fair value of the shares issued and our stockholders’ equity will also increase by the same amount. We have also agreed to pay contingent consideration of up to $0.5 million based on operating results of MGM for the year ending December 31, 2006.
      On February 11, 2005, we entered into an agreement and plan of merger with Parchman, pursuant to which we purchased Parchman. This agreement and plan of merger contains provisions for the issuance of

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up to an additional 1,000,000 shares of our common stock on a contingent basis. In connection with the Combination, we have agreed to pay cash consideration of up to $2.6 million to the owners of these shares. We expect that we will issue all 1,000,000 shares in the first quarter of 2006 and pay the full $2.6 million to these owners and have recorded a liability of $2.6 million as of December 31, 2005. When these shares are issued, we will recognize additional goodwill associated with this acquisition in an amount equal to the then fair value of the shares issued and our stockholders’ equity will also increase by the same amount. See note 20(b) of the accompanying audited consolidated financial statements.
      Other than the normal operating leases described above and the contingent consideration that may be issued pursuant to purchase agreements, we do not have any off-balance sheet financing arrangements.
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. Expected trends in oil and gas production activities may not continue and demand for our services may not reflect the level of activity in the industry. Any prolonged substantial reduction in oil and gas prices would likely affect oil and gas production levels 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. Recently, demand for our services has been strong and we are currently electing to continue our past practice of committing our equipment on a short-term or day-to-day basis rather than entering into longer-term contracts.
      As of December 31, 2005, approximately 14% of our revenues and 12% of our long-term 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 impacts our revenues by approximately $1.0 million per year. We do not currently use hedges or forward contracts to offset this risk.
      Our Mexican operation uses the U.S. dollar as its functional currency and, as a result, all transactions and translation gains and losses are recorded currently in the financial statements. The balance sheet amounts are translated into U.S. dollars at the exchange rate at the end of the month and the income statement amounts are translated at the average exchange rate for the month. We estimate that a hypothetical one percentage point change in the value of the Mexican peso relative to the U.S. dollar would impact our revenues by approximately $0.2 million. Currently, we conduct a portion of our business in Mexico in the local currency, the Mexican peso. The effects of currency fluctuations on our Mexican operations are partly mitigated because the majority of our local expenses are also denominated in the Mexican peso.
      All of our bank debt is structured under floating rate terms and, as such, our interest expense is sensitive to fluctuations in the prime rates in the U.S. and Canada. Based on the debt structure in place as of December 31, 2005, a 1% increase in interest rates would increase interest expense by approximately $5.0 million per year and reduce operating cash flows by approximately $3.1 million.
Recent Accounting Pronouncements
      In November 2004, the FASB issued SFAS No. 151, “Inventory Costs.” SFAS No. 151 amends the guidance in Accounting Research Bulletin No. 43, Chapter 4, “Inventory Pricing,” to clarify the

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accounting for abnormal amounts of idle facility expense, freight, handling costs and wasted material (spoilage), and generally requires that these amounts be expensed in the period that the cost arises, rather than being included in the cost of inventory, thereby requiring that the allocation of fixed production overheads to the costs of conversion be based on normal capacity of the production facilities. SFAS No. 151 becomes effective for inventory costs incurred during fiscal years beginning after June 15, 2005, but earlier application is permitted. We adopted SFAS No. 151 as of January 1, 2006, with no material impact on our financial position, results of operations or cash flows.
      In December 2004, the FASB issued SFAS No. 153, “Exchanges of Nonmonetary Assets.” SFAS No. 153 amends current guidance related to the exchange of nonmonetary assets as per APB Opinion No. 29, “Accounting for Nonmonetary Transactions,” to eliminate an exception that allowed exchange of similar nonmonetary assets without determination of the fair value of those assets, and replaced this provision with a general exception for exchanges of nonmonetary assets that do not have commercial substance. A nonmonetary exchange has commercial substance if the future cash flows of the entity are expected to change significantly as a result of the exchange. SFAS No. 153 becomes effective for nonmonetary asset exchanges occurring in fiscal periods beginning after June 15, 2005. We adopted SFAS No. 153 as of January 1, 2006, with no material impact on our financial position, results of operations or cash flows.
      In December 2004, the FASB issued SFAS No. 123R, “Share-Based Payment,” which revises SFAS No. 123 and supercedes APB No. 25. SFAS No. 123R will require us to measure the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award, with limited exceptions. The fair value of the award will be remeasured at each reporting date through the settlement date, with changes in fair value recognized as compensation expense of the period. Entities should continue to use an option-pricing model, adjusted for the unique characteristics of those instruments, to determine fair value as of the grant date of the stock options. SFAS No. 123R became effective for public companies as of the beginning of the fiscal year after June 15, 2005. We adopted SFAS No. 123R on January 1, 2006. As permitted by SFAS No. 123R, we will continue to account for stock-based compensation grants issued prior to September 30, 2005, the date of our initial public filing with the SEC, pursuant to the minimum value method prescribed by APB No. 25 and will provide the required pro forma disclosures. For grants issued between October 1, 2005 and December 31, 2005 (prior to adoption of SFAS No. 123R), we will utilize the modified prospective transition method to record expense associated with these stock-based instruments and to provide the required pro forma disclosures. For grants awarded on or after January 1, 2006, we will utilize the prospective transition method, whereby we will recognize expense associated with new awards of stock-based compensation, as determined using a Black-Scholes pricing model over the expected term of the options. See note 12(e) of the accompanying audited consolidated financial statements for further discussion of the expected impact of adopting SFAS No. 123R on our financial position, results of operations and cash flows.
      In May 2005, the FASB issued SFAS No. 154, “Accounting Changes and Error Corrections, a Replacement of APB Opinion No. 20 and FASB Statement No. 3.” SFAS No. 154 requires retrospective application of changes in accounting principle to prior periods’ financial statements, rather than the use of the cumulative effect of a change in accounting principle, unless impracticable. If impracticable to determine the impact on prior periods, then the new accounting principle should be applied to the balances of assets and liabilities as of the beginning of the earliest period for which retrospective application is practicable, with a corresponding adjustment to equity, unless impracticable for all periods presented, in which case prospective treatment should be applied. SFAS No. 154 applies to all voluntary changes in accounting principle, as well as those required by the issuance of new accounting pronouncements if no specific transition guidance is provided. SFAS No. 154 does not change the previously-issued guidance for reporting a change in accounting estimate or correction of an error. SFAS No. 154 became effective for accounting changes and corrections of errors made in fiscal years beginning after December 15, 2005. We adopted SFAS No. 154 on January 1, 2006, and will apply its provisions, as applicable, to future reporting periods.

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BUSINESS
Our Company
      We provide specialized services and products focused on helping oil and gas companies develop hydrocarbon reserves, reduce 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 many needs of our customers at the wellsite, from drilling and completion through production and eventual abandonment. The following figure illustrates some of our services used during the lifecycle of a well.
(GRAPHIC)
      We seek to differentiate ourselves from our competitors through our local leadership, our basin-level expertise and the innovative application of proprietary and other technologies. We deliver solutions to our customers that we believe lower their costs and increase their production in a safe and environmentally friendly manner.
      We manage our operations from regional field service facilities located throughout the U.S. Rocky Mountain region, Texas, Oklahoma, Louisiana, Arkansas and Kansas, western Canada and Mexico.
      Our business is comprised of three 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. For example, in the Barnett Shale region of north Texas we operate advanced coiled tubing units that have electric-line conductors within the units’ coiled tubing string. These specially configured units can deploy perforating guns, logging tools and plugs, without a separate electric-line unit in high inclination and “horizontal” wells that are prevalent throughout that basin.
 
  •  Downhole and Wellsite Services. Our downhole and wellsite services include electric-line, slickline, production optimization, production testing, rental and fishing services. We also offer several proprietary services and products that we believe create significant value for our customers. Examples of these proprietary services and products include: (1) our Green Flowback system, which permits the flow of gas to our customers while performing drill-outs and flowback operations, increasing production, accelerating time to production and eliminating the need to flare gas, and (2) our patented plunger lift system that, when combined with our diagnostic and installation

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  services, removes fluids from gas wells resulting in increased production and the extension of the life of the well.
 
  •  Fluid Handling. We provide a variety of services to help our customers obtain, move, store and dispose of fluids that are involved in the development and production of their reservoirs. Through our fleet of specialized trucks, frac tanks and other assets, we provide fluid transportation, heating, pumping and disposal services for our customers.
      Drilling Services. Through our drilling services segment, we provide services and equipment that initiate or stimulate oil and gas production by providing land drilling, specialized rig logistics and site preparation. Through this segment, we also provide pressure control, drill string, pipe handling and other equipment. Our drilling rigs currently operate exclusively in the Barnett Shale region of north Texas.
      Product Sales. Through our product sales segment, we provide a variety of equipment used by oil and gas companies throughout the lifecycle of their wells. Our current product offering includes completion, flow control and artificial lift equipment as well as tubular goods. We sell products throughout North America primarily through our supply stores and through distributors on a wholesale basis. We also sell products through agents in markets outside of North America.
Our Industry
      Our business depends on the level of exploration, development and production expenditures made by our customers. These expenditures are driven by the current and expected future prices for oil and gas, and the perceived stability and sustainability of those prices. Our business is primarily driven by natural gas drilling activity in North America. We believe the following two principal economic factors will positively affect our industry in the coming years:
  •  Higher demand for natural gas in North America. We believe that natural gas will be in high demand in North America over the next several years because of the growing popularity of this clean-burning fuel. According to the International Energy Association’s 2004 World Energy Outlook, natural gas demand in North America (United States, Canada and Mexico) is projected to grow by approximately 45% from 2002 to 2030.
 
  •  Constrained North American gas supply. Although the demand for natural gas is projected to increase, supply is likely to be constrained as North American natural gas basins are becoming more mature and experiencing increased decline rates. Even though the number of wells drilled in North America has increased significantly in recent years, a corresponding increase in domestic production has not occurred. As a result, producers are required to increase drilling just to maintain flat production. To supply the growing demand for natural gas, the primary alternatives are to increase drilling, enhance recovery rates or import LNG from overseas. To date minimal increases have occurred, although many forecasts anticipate a material increase of LNG imports.
      As a result of the above factors, we expect that there will continue to be a tight supply of, and high demand for, natural gas in North America. We believe this will continue to support high natural gas prices and high levels of drilling activity.

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      As illustrated in the table below, 2005 marked the third consecutive year of gas price increases and the fourth consecutive year of oil price increases, with a 2005 average daily closing Henry Hub spot price for natural gas of $8.89 per mcf and a 2005 average daily closing WTI Cushing spot oil price of $56.59 per bbl. Until recently, these prices have generally been at historically high levels. Gas prices have recently declined substantially. The Henry Hub natural gas spot price on March 1, 2006 was $6.62 per mcf. Oil prices have also declined. The WTI Cushing crude oil spot price on March 1, 2006 was $61.97. The number of drilling rigs under contract in the United States and Canada has increased from 1,181 as of January 3, 2003 to 2,222 as of March 10, 2006, according to BHI. The number of well service rigs has increased from 1,478 at the end of January 2003 to 2,356 at the end of February 2006. The table below sets forth average daily closing prices for the WTI Cushing spot oil price and the average daily closing prices for the Henry Hub price for natural gas since 1999:
                 
    Average Daily Closing   Average Daily Closing
    Henry Hub Spot Natural   WTI Cushing Spot Oil
Period   Gas Prices ($/mcf)   Price ($/bbl)
         
1/1/99 - 12/31/99
  $ 2.27     $ 19.30  
1/1/00 - 12/31/00
    4.30       30.37  
1/1/01 - 12/31/01
    3.96       25.96  
1/1/02 - 12/31/02
    3.37       26.17  
1/1/03 - 12/31/03
    5.49       31.06  
1/1/04 - 12/31/04
    5.90       41.51  
1/1/05 - 12/31/05
    8.89       56.59  
1/1/06 - 3/1/06
    8.08       63.56  
 
Source: Bloomberg NYMEX prices.
      Higher demand for natural gas and a constrained gas supply have resulted in higher prices and increased drilling activity. The increase in prices and drilling activity are driving three additional trends that we believe will benefit us:
        Trend toward drilling and developing unconventional North American natural gas resources. Due to the maturity of conventional North American oil and gas reservoirs and their accelerating production decline rates, unconventional oil and gas resources will comprise an increasing proportion of future North American oil and gas production. Unconventional resources include tight sands, shales and coalbed methane. These resources require more wells to be drilled and maintained, frequently on tighter acreage spacing. The appropriate technology to recover unconventional gas resources varies from region to region; therefore, knowledge of local conditions and operating procedures, and selection of the right technologies is key to providing customers with appropriate solutions.
 
        The advent of the resource play. A “resource play” is a term used to describe an accumulation of hydrocarbons known to exist over a large area which, when compared to a conventional play, has lower commercial development risks and a lower average decline rate. Once identified, resource plays have the potential to make a material impact because of their size and low decline rates. The application of appropriate technology and program execution are important to obtain value from resource plays. Resource play developments occur over long periods of time, well by well, in large-scale developments that repeat common tasks in an assembly-line fashion and capture economies of scale to drive down costs.
 
        Increasingly complex technologies. Increasing prices and the development of unconventional oil and gas resources are driving the need for complex, new technologies to help increase recovery rates, lower production costs and accelerate field development. We believe that the increasing complexity of technology used in the oil and gas development process coupled with limited engineering resources will require production companies to increase their reliance on service companies to assist them in developing and applying these technologies.

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Our Business Strategy
      Our goal is to build the leading oilfield services company focused on the completion and production phases in the life of an oil and gas well. We intend to capitalize on the emerging trends in the North American marketplace through the execution of a growth strategy that consists of the following components:
      Expand and capitalize on local leadership and basin-level expertise. A key component of our strategy is to build upon our base of strong local leadership and basin-level expertise. We have a significant presence in most of the key onshore continental U.S. and Canadian gas plays we believe have the potential for long-term growth. Our position in these basins capitalizes on our strong local leadership that has accumulated a valuable knowledge base and strong customer relationships. We intend to leverage our existing market presence, expertise and customer relationships to expand our business within these gas plays. We also intend to replicate this approach in new regions by building and acquiring new businesses that have strong regional management with extensive local knowledge.
      Develop and deploy technical and operational solutions. We are focused on developing and deploying technical services, equipment and expertise that lower our customers’ costs.
      Capitalize on organic and acquisition-related growth opportunities. We believe there are numerous opportunities to sell new services and products to customers in our current geographic areas and to sell our current services and products to customers in new geographic areas. We have a proven track record of organic growth and successful acquisitions, and we intend to continue using capital investments and acquisitions to strategically expand our business. We employ a rigorous acquisition screening process and have developed comprehensive post-acquisition integration capabilities designed to ensure each acquisition is effectively assimilated. We use a returns method for evaluating capital investment opportunities, and we apply a disciplined approach to adding new equipment.
      Focus on execution and performance. We have established and intend to develop further a culture of performance and accountability. Senior management spends a significant portion of its time ensuring that our customers receive the highest quality of service by focusing on the following:
  •  clear business direction;
 
  •  thorough planning process;
 
  •  clearly defined targets and accountabilities;
 
  •  close performance monitoring;
 
  •  strong performance incentives for management and employees; and
 
  •  effective communication.
Our Competitive Strengths
      We believe that we are well positioned to execute our strategy and capitalize on opportunities in the North American oil and gas market based on the following competitive strengths:
      Strong local leadership and basin-level expertise. We operate our business with a focus on each regional basin complemented by our local reputations. We believe our local and regional businesses, some of which have been operating for more than 50 years, provide us with a significant advantage over many of our competitors. Our managers, sales engineers and field operators have extensive expertise in their local geological basins and understand the regional challenges our customers face. We have long-term relationships with many customers, and most of the services and products we offer are sold or contracted at a local level, allowing our operations personnel to bring their expertise to bear while selling services and products to our customers. We strive to leverage this basin-level expertise to establish ourselves as the preferred provider of our services in the basins in which we operate.

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      Significant presence in major North American basins. We operate in major oil and gas producing regions of the U.S. Rocky Mountains, Texas, Louisiana and Oklahoma, western Canada and Mexico, with concentrations in key “resource play” and unconventional basins. Resource plays are expected to become increasingly important in future North American oil and gas production as more conventional resources enter later stages of the exploration cycle. We believe we have an excellent position in highly active markets such as the Barnett Shale region of north Texas. Each of these markets is among the most active areas for exploration and development of onshore oil and gas. Accelerating production and driving down development and production costs are key goals for oil and gas operators in these areas, resulting in strong demand for our services and products. In addition, our strong presence in these regions allows us to build solid customer relationships and take advantage of cross-selling opportunities.
      Focus on complementary production and field development services. Our breadth of service and product offerings well positions us relative to our competitors. Our services encompass the entire lifecycle of a well from drilling and completion, through production and eventual abandonment. We deliver complementary services and products, which we may provide in tandem or sequentially over the life of the well. This suite of services and products gives us the opportunity to cross-sell to our customer base and throughout our geographic regions. Leveraging our strong local leadership and basin-level expertise, we are able to offer expanded services and products to existing customers or current services and products to new customers.
      Innovative approach to technical and operational solutions. We develop and deploy services and products that enable our customers to increase production rates, stem production declines and reduce the costs of drilling, completion and production. The significant expertise we have developed in our areas of operation offers our customers customized operational solutions to meet their particular needs. For example, our Canadian operation provides highly skilled personnel and a combination of heliportable and specialized equipment that includes wireline (electric-line and slickline) and production testing services that can work together and be deployed quickly and efficiently in the harsh environment of the Northwest Territories of Canada. Our ability to develop these technical and operational solutions is possible due to our understanding of applicable technology, our basin-level expertise and our close local relationships with customers.
      Modern and active asset base. We have a modern and well-maintained fleet of coiled tubing units, pressure pumping equipment, wireline units, well service rigs, snubbing units, fluid transports, frac tanks and other specialized equipment. We believe our ongoing investment in our equipment allows us to better serve the diverse and increasingly challenging needs of our customer base. New equipment is generally less costly to maintain and operate on an annual basis and is more efficient for our customers. Modern equipment reduces the downtime and associated expenditures and enables the increased utilization of our assets. Our fleet is active with high utilization. We believe our future expenditures will be used to capitalize on growth opportunities within the areas we currently operate and to build out new platforms obtained through targeted acquisitions.
      Experienced management team with proven track record. Each member of our operating management team has over 20 years of experience in the oilfield services industry. We believe that their considerable knowledge of and experience in our industry enhances our ability to operate effectively throughout industry cycles. Our management also has substantial experience in identifying, completing and integrating acquisitions. In addition, our management supports local leadership by developing corporate strategy, implementing corporate governance procedures and overseeing a company-wide safety program.
The Combination
      Prior to 2001, SCF Partners, a private equity firm that focuses on investments in the oilfield services segment of the energy industry, began to target investment opportunities in service oriented companies in the North American natural gas market with specific focus on the production phase of the exploration and production cycle. On May 22, 2001, SCF Partners through SCF formed Saber, a new company, in connection with its acquisition of two companies primarily focused on completion and production related

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services in Louisiana. In July 2002, SCF became the controlling stockholder of Integrated Production Services, Ltd., a production enhancement company that, at the time, focused its operation in Canada. In September 2002, Saber acquired this company and changed its name to Integrated Production Services, Inc. Subsequently, IPS began to grow organically and through several acquisitions, with the ultimate objective of creating a technical leader in the enhancement of natural gas production. In November 2003, SCF formed another production services company, CES, establishing a platform from which to grow in the Barnett Shale region of north Texas. Subsequently, through organic growth and several acquisitions, CES extended its presence to the U.S. Rocky Mountain and the Mid-continent regions. In the summer of 2004, SCF formed IEM, which at the time had a presence in Louisiana and Texas. During 2004, IPS and IEM independently began to execute strategic initiatives to establish a presence in both the Barnett Shale and U.S. Rocky Mountain regions.
      On September 12, 2005, IPS, CES and IEM were combined and became Complete Production Services, Inc. in a transaction we refer to as the “Combination.” In the Combination, IPS served as the acquirer. Immediately after the Combination, SCF held approximately 70% of our outstanding common stock, the former CES stockholders (other than SCF) in the aggregate held approximately 18.8% of our outstanding common stock, the former IEM stockholders (other than SCF) in the aggregate held approximately 2.4% of our outstanding common stock and the former IPS stockholders (other than SCF) in the aggregate held approximately 8.4% of our outstanding common stock.
      We believe that operational and financial benefits realized through the Combination enhance the growth potential and establish the foundation for long-term growth for the combined company.
Overview of Our Segments
      We manage our business through three primary segments: completion and production services, drilling services and product sales. Within each of these segments, we perform services and deliver products, as detailed in the table below. However, significant regional growth opportunities remain. We constantly monitor the North American market for opportunities to expand our business by building our presence in existing regions and expanding our services and products into attractive, new regions.
                                                                                                   
        Gulf                                       Western
        Coast/               Central &   Eastern   DJ   Western       North   Canadian
        South   South   East   North   Western   Oklahoma &   Basin   Slope       Rockies   Sedimentary
Product/Service Offering   Mexico   Louisiana   Texas   Texas   Texas   Oklahoma   Arkansas   (CO)   (CO & UT)   Wyoming   (MT & ND)   Basin
                                                 
Completion and Production Services:
                                                                                               
 
Coiled Tubing
    ü       ü       ü       ü       ü                                       ü       ü          
 
Well Servicing
                            ü       ü       ü               ü       ü       ü                  
 
Snubbing
                    ü               ü                                       ü                  
 
Electric-line
            ü                       ü       ü                                               ü  
 
Slickline
    ü               ü       ü       ü                                                       ü  
 
Production Optimization
                    ü       ü       ü       ü                       ü       ü               ü  
 
Production Testing
    ü               ü       ü       ü                               ü       ü               ü  
 
Rental Equipment
                            ü       ü                       ü       ü               ü          
 
Pressure Testing
                                                                    ü       ü                  
 
Fluid Handling
                            ü       ü       ü       ü       ü       ü       ü       ü          
 
Drilling Services:
                                                                                               
 
Contract Drilling
                                    ü                                                          
 
Drilling Logistics
            ü       ü       ü       ü       ü                               ü       ü          
 
Product Sales:
                                                                                               
 
Supply Stores
                            ü       ü                               ü                          
 
Production Enhancement Products
                    ü               ü                                                       ü  
 
ü”  denotes a service or product currently offered by us in this area.
Completion and Production Services (67% of Revenue for the Year Ended December 31, 2005)
      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 intervention services, downhole and wellsite services and fluid handling.

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Intervention Services
      We use our intervention assets, which include coiled tubing units, pressure pumping equipment, nitrogen units, well service rigs and snubbing units to perform three major types of services for our customers:
  •  Completion Services. As newly drilled oil and gas wells are prepared for production, our operations may include selectively perforating the well casing to access producing zones, stimulating and testing these zones and installing downhole equipment. We provide intervention services and products to assist in the performance of these services. The completion process typically lasts from a few days to several weeks, depending on the nature and type of the completion. Oil and gas producers use our intervention services to complete their wells because we have well trained employees, the experience necessary to perform such services and a strong record for safety and reliability.
 
  •  Workover Services. Producing oil and gas wells occasionally require major repairs or modifications, called “workovers.” These services include extensions of existing wells to drain new formations either through deepening wellbores to new zones or by drilling horizontal lateral wellbores to improve reservoir drainage patterns. In less extensive workovers, we provide services and products to seal off depleted zones in existing wellbores and access previously bypassed productive zones. Other workover services which we provide include: major subsurface repairs, such as casing repair or replacement; recovery of tubing and removal of foreign objects in the wellbore; repairing downhole equipment failures; plugging back the bottom of a well to reduce the amount of water being produced; cleaning out and recompleting a well if production has declined; and repairing leaks in the tubing and casing.
 
  •  Maintenance Services. Maintenance services are required throughout the life of most producing oil and gas wells to ensure efficient and continuous operation. We provide services that include mechanical repairs necessary to maintain production from the well, such as repairing inoperable pumping equipment or replacing defective tubing, and removing debris from the well. Other services include pulling rods, tubing, pumps and other downhole equipment out of the wellbore to identify and repair a production problem.
      The key intervention assets we use to perform the above services are as follows:
Coiled Tubing and Pressure Pumping Units
      We are one of the leading providers of coiled tubing services in North America. As of February 15, 2006, we operated a fleet of 32 coiled tubing units and 31 pressure pumping units, as well as 18 nitrogen units. We use these assets to perform a variety of wellbore applications, including foam washing, acidizing, displacing, cementing, gravel packing, plug drilling, fishing and jetting. Coiled tubing is a key segment of the well service industry today, which allows operators to continue production during service operations without shutting down the well, reducing the risk of formation damage. The growth in deep well and horizontal drilling has increased the market for coiled tubing. We have developed innovative equipment configurations to capitalize on emerging market opportunities. For example, in the Barnett Shale region of north Texas, we have introduced advanced coiled tubing units that have electric-line conductors within the units’ coiled tubing string. These specially configured units provide electric-line and coiled tubing controls in one fully integrated package, and allow us to deploy perforating guns, logging tools and plugs in high inclination wells for our customers. We provide coiled tubing and pressure pumping services primarily in Wyoming, Colorado, Oklahoma, Texas, Louisiana, Mexico and offshore in the Gulf of Mexico.
Well Service Rigs
      As of February 15, 2006, we owned and operated a fleet of 112 well service rigs, including 63 units that are either recently constructed or have been rebuilt over the past five years. We believe we have a leading market position in the Barnett Shale region of north Texas and in some of the most active regions

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of the U.S. Rocky Mountains. As of February 15, 2006, we also operated 33 swabbing units, 11 of which are highly customized hydraulic units which we use to diagnose and remediate gas well production problems. We provide well service rig operations in Wyoming, Colorado, Utah, Montana, North Dakota, Oklahoma and Texas. These rigs are used to perform a variety of completion, workover and maintenance services, such as installations, completions, assisting with perforating, removing defective equipment and sidetracking wells.
Snubbing Units
      As of February 15, 2006, we operated a fleet of 10 snubbing units, four of which are rig assist units. Snubbing services use specialized hydraulic well service units that permit an operator to repair damaged casing, production tubing and downhole production equipment in high-pressure, “live-well” environments. A snubbing unit makes it possible to remove and replace downhole equipment while maintaining pressure in the well. Applications for snubbing units include “live-well” completions and workovers, underground blowout control, underbalanced completions, underbalanced drilling and the snubbing of tubing, casing or drillpipe into or out of the wellbore. Our snubbing units operate primarily in Texas, Oklahoma, and Wyoming.
Downhole and Wellsite Services
      We provide an array of complementary downhole and wellsite services that we classify into four groups: wireline services; production optimization services; production testing services; and rental, fishing and pressure testing services.
      Wireline Services. As of February 15, 2006, we owned and operated a fleet of 89 wireline units in North America and provided both electric-line and slickline services. Truck and skid mounted wireline services are used to evaluate downhole well conditions, to initiate production from a formation by perforating a well’s casing, and to provide mechanical services such as setting equipment in the well, or fishing lost equipment out of a well. We provide wireline services in the western Canadian Sedimentary Basin, Oklahoma, Texas, Kansas, Louisiana and offshore in the Gulf of Mexico. Of our fleet of 89 wireline units, we have 53 electric-line units, nine of which are offshore skids, and 36 slickline units.
      With our fleet of wireline equipment we provide the following services:
  •  Perforating Services. Perforating involves positioning a perforating gun that contains explosive jet charges down the wellbore next to a productive zone. A detonator is fired and primer cord is ignited, which then detonates the jet charges. The resulting explosion burns a hole through the wellbore casing and cement and into the formation, thus allowing the formation fluid to flow into the wellbore and be produced to the surface. The perforating gun may be deployed in a number of ways. The gun can be conveyed by a conventional wireline cable if the wellbore geometry allows, it may be conveyed on coiled tubing, it may be conveyed on conventional tubing or the gun may be “pumped-down” to the correct depth in the wellbore.
 
  •  Logging Services. Logging requires the use of a single or multi-conductor, braided steel cable (electric-line), mounted on a hydraulically operated drum, and a specialized logging truck. Electronic instruments are attached to the end of the cable and lowered to the bottom of the well and the line is slowly pulled out of the well transmitting wellbore data up the cable to the surface where the information is processed by a surface computer system and displayed on a paper graph in a logging format. This information is used by customers to analyze different downhole formation structures, to detect the presence of oil, gas and water and to check the integrity of the casing or the cement behind the pipe. Logs are also run to detect gas or fluid migration between zones or to the surface.
 
  •  Slickline Services. Slickline services are used primarily for well maintenance. The line used for this application is generally a small single steel line. Typical applications of this service would include bottom hole pressure surveys, running temperature gradients, setting tubing plugs, opening

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  and closing sliding sleeves, fishing operations, plunger lift installations, gas lift installations and other maintenance services that the well would require during its lifecycle.
      Production Optimization Services. Our production optimization services provide customers with technical solutions to stem declining production that result from liquid loading, reduced bottom-hole pressures or improper wellsite designs. We assist in identifying candidates, designing solutions, executing on-site and following up to ensure continued performance. We have developed proprietary technologies that allow us to enhance recovery for our customers and provide on-going service. Specific services we provide include:
  •  Plunger Lift Services and Products. We provide plunger lift candidate selection, installation and maintenance services which may incorporate the use of our patented Pacemaker Plunger Lift System. Plunger lift systems facilitate the removal of fluids that restrict the production of natural gas wells. Removing fluids that accumulate in wells increases production and in many cases slows decline rates. The proprietary design of our Pacemaker Plunger Lift System incorporates a large bypass area which allows it to make more trips per day and remove more wellbore fluids, versus other plunger lift designs, in wells with certain characteristics.
 
  •  Acoustic Pressure Surveys. We provide acoustic pressure surveys which are an analytical technique that assists our customers in determining static reservoir pressure and the existence of near wellbore formation damage.
 
  •  Dynamometer Analysis. Our dynamometer analysis services include the analysis of reciprocating rod pumping systems (pumpjacks) to determine pump performance and provide our customers with critical information for well performance used to optimize the production and recovery of oil and gas.
 
  •  Fluid Level Analysis. We provide fluid level analysis services which record an acoustic pulse as it travels down the wellbore in order to determine the fluid depth.
      We offer production optimization services to customers across the United States and in Canada. We provide production optimization services in Canada through our 50% joint venture with Premier Production Services Ltd.
      Production Testing Services. Production testing is a service required by exploration and production companies to evaluate and clean out new and existing wells. We use a proprietary technology and service approach and are a leading independent provider in North America. We provide production testing services throughout the western Canadian Sedimentary Basin and also provide production testing services in Wyoming, Utah, Colorado, Texas and Mexico. As of February 15, 2006, we operated a total of 78 production testing units.
Production testing has the following primary applications:
  •  Well clean-ups or flowbacks are done shortly after completing or stimulating a well and are designed to remove damaging drilling fluids, completion fluids, sand and other debris. This “clean-up” prevents damage to the permanent production facilities and flowlines, thereby improving production. Our clean-up offering includes our Green Flowback services, which permit the flow of gas to our customers while performing drill- outs and flowback operations, increasing production, accelerating time to production and eliminating the need to flare gas;
 
  •  Exploration well testing measures how a reservoir performs under various flow conditions. These measurements allow reservoir and production engineers, and geologists to understand a well’s or reservoir’s production capability. Exploration testing jobs can last from a few days to several months; and
 
  •  In-line production testing measures a well’s flow rates, oil, gas and water composition, pressure and temperature. These measurements are used by engineers to identify and solve well and reservoir

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  problems. In-line production testing is performed after a well has been completed and is already producing. In-line tests can run from several hours to more than several months.
      Rental Equipment, Fishing and Pressure Testing Services. Oil and gas producers and drilling contractors often find it uneconomical to maintain complete inventories of tools, drillpipe, pressure testing equipment and other specialized equipment and to retain the qualified personnel to operate this equipment. We provide the following services and products:
  •  Rental Equipment and Services. We rent specialized tools, equipment and tubular goods for the drilling, completion and workover of oil and gas wells. Items rented include pressure control equipment, drill string equipment, pipe handling equipment, fishing and downhole tools, and other equipment, including stabilizers, power swivels and bottom-hole assemblies.
 
  •  Fishing Services. We provide highly skilled downhole services, including fishing, milling and cutting services, which consist of removing or otherwise eliminating “fish” or “junk” (a piece of equipment, a tool, a part of the drill string or debris) in a well that is causing an obstruction. We also install whipstocks to sidetrack wells, provide plugging and abandonment services, pipe recovery and wireline recovery services, foam services and casing patch installation.
 
  •  Pressure Testing Services. We provide specialized pressure testing services which involve the use of truck mounted equipment designed to carry small fluid volumes with high pressure pumps and hydraulic torque equipment. This equipment is primarily used to perform pressure tests on flow line, pressure vessels, lubricators, well heads, casings and tubing strings. The units are also used to assemble and disassemble BOPs for the drilling and work over sector. We have developed specialized, multi-service pressure testing units that enable one or two employees to complete multiple services simultaneously. As of February 15, 2006, we had 35 multi-service pressure testing units that we operated in Colorado, Utah and Wyoming.
Fluid Handling
      Oil and gas operations use and produce significant quantities of fluids. We provide a variety of services to assist our customers to obtain, move, store and dispose of fluids that are involved in the development and production of their reservoirs. We provide fluid handling services in Texas, Oklahoma, Colorado, Wyoming, North Dakota and Montana.
  •  Fluid Transportation. As of February 15, 2006, we operated over 600 specialized transport trucks to deliver, transport and dispose of fluids safely and efficiently. We transport fresh water, completion fluids, produced water, drilling mud and other fluids to and from our customers’ wellsites. Our assets include U.S. Department of Transportation certified equipment for transportation of hazardous waste.
 
  •  Frac Tank Rental. As of February 15, 2006, we operated a fleet of over 2,058 frac tanks, of which 227 were rented, that are often used during hydraulic fracturing operations. We use our fleet of fluid transport assets to fill and empty these tanks and we deliver and remove these tanks from the wellsite with our fleet of winch trucks.
 
  •  Fluid Disposal. As of February 15, 2006, we owned 24 salt water disposal wells in Oklahoma and Texas and one produced water evaporation facility in Wyoming. These facilities are used to dispose of water from fracturing operations and from fluids produced during the routine production of oil and gas. In addition, we also operated two mud disposal facilities that are used to store and ultimately dispose of drilling mud.
 
  •  Other Services. We own and operate a fleet of hot oilers and superheaters, which are assets capable of heating high volumes of fluids. We also sell fluids used during well completions, such as fresh water and potassium chloride, and drilling mud, which we move to our customers’ wellsites using our fluid transportation services.

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Drilling Services (17% of Revenue for the Year Ended December 31, 2005)
      Through our drilling services segment, we deliver services that initiate or stimulate oil and gas production by providing land drilling, specialized rig logistics and site preparation. Through this segment, we also provide pressure control, drill string, pipe handling and downhole tools and equipment. Our drilling rigs currently operate exclusively in the Barnett Shale region of north Texas.
Contract Drilling
      We provide contract drilling services to major oil companies and independent oil and gas producers in north Texas. Contract drilling services are primarily provided under standard day rate, and, to a lesser extent, footage or turnkey contracts. Drilling rigs vary in size and capability and may include specialized equipment. As of February 15, 2006, the majority of our drilling rig fleet of 14 drilling rigs was equipped with mechanical power systems and had depth ratings ranging from approximately 8,000 to 15,000 feet. We also had three land drilling rigs under construction as of February 15, 2006 which we expect to be operational by the end of 2006.
Drilling Logistics
We provide a variety of drilling logistic services as follows:
  •  Drilling Rig Moving. Through our owned and operated fleet of over 200 specialized trucks as of February 15, 2006, we provide drilling rig mobilization services primarily in Louisiana, Texas, Oklahoma, Arkansas and Wyoming. Our capabilities allow us to move the largest rigs in the United States. Our operations are strategically located in regions where approximately 50% of the land drilling rigs in the United States are located. We believe we have a leading market position in the Gulf Coast region of Texas and Louisiana. We believe our highly skilled personnel position us as one of the leading rig moving companies in the industry.
 
  •  Wellsite Preparation and Remediation. We provide equipment and services to build and reclaim drilling wellsites before and after the drilling operations take place. We build roads, dig pits, clear land, move earth and provide a host of construction services to drilling contractors and to oil and gas producers. Our wellsite preparation and remediation services are in Texas, Colorado and Wyoming.
Product Sales (16% of Revenue for the Year Ended December 31, 2005)
      Through our product sales segment, we provide a variety of equipment used by oil and gas companies throughout the lifecycle of their wells. Our current product offering includes completion, flow control and artificial lift equipment as well as tubular goods. We sell products throughout North America primarily through our supply stores and through distributors on a wholesale basis. We also sell products through agents in markets outside of North America.
Supply Stores
      We own and operate supply stores that provide products and services to the oil and gas industry. As of February 15, 2006, we had a total of 15 supply stores and two sales offices in Texas, Colorado, Louisiana and Oklahoma. We market tubular products, drill pipe, flow control and completion equipment, valves, fittings and other oilfield products.
Production Enhancement Products
      Our production enhancement products group designs, assembles and distributes flow control, well completion and artificial lift products primarily in North America.
  •  Flow Control Products. We are a leading independent supplier of subsurface flow control equipment to the North American oil and gas market. Our product line includes downhole blanking

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  plugs, landing nipples, sliding sleeves, flapper valves and bottom-hole chokes. Through our flow control business, we also provide a proprietary thermo chemical metal treatment process known as HARD KOTEtm that increases the useful life of downhole equipment by providing enhanced resistance to abrasion, adhesion, erosion and corrosion.
 
  •  Well Completion Products. We offer a comprehensive line of well completion products, which include packers, tubing anchors, plugs, retainers and other completion accessories.
 
  •  Artificial Lift Systems. Our line of artificial lift system accessories is designed to optimize the performance of rod pump and progressive cavity (“PC”) or screw pump systems. We are a leader in tools designed to prevent the counter rotation of PC pumps, particularly during high-volume operation, and we hold eight patents in this area. Other accessories include tubing centralizers and downhole gas separators installed below the pump. Downhole gas separators remove the natural gas from the reservoir fluid before it enters the pump, thus improving pump efficiency.
      Our production enhancement products are sold throughout North America primarily through distributors on a wholesale basis, through our supply stores and through agents in international markets.
Manufacturing
      Our manufacturing business produces a number of wellsite production processing facility components. Products include pressure vessels, separators, line heaters, dehydration units, header packages and metering skids. Our equipment is designed to comply with the standards of the American Society of Mechanical Engineers National Board “U” stamp and the Alberta Boilers Safety Association. Customers for our manufactured products are predominantly gas producing companies in Canada; however, the business does provide equipment throughout North America and may periodically ship products into international markets, including India and South America.
Overseas Operations
      We operate an oilfield sales service and rental business based in Singapore. This business sells new and reconditioned equipment used in the construction and upgrade of offshore drilling rigs; rents mud coolers, tubular handling equipment, BOPs and other service tools; and provides machining and repair services.
Properties
      As of February 15, 2006, we own 45 offices, facilities and yards, of which eight are in Texas, 19 are in Oklahoma, one is in Arkansas, one is in North Dakota, one is in Montana, six are in Wyoming, three are in Colorado, three are in Louisiana, two are in Alberta, Canada, and one is in Poza Rica, Mexico. As of February 15, 2006, we own 25 salt water disposal wells, of which four are in Texas, 19 are in Oklahoma and two in Arkansas. As of February 15, 2006, we own one drilling mud disposal facility in Oklahoma and one produced water evaporation facility in Wyoming.
      In addition, as of February 15, 2006, we lease 153 offices, facilities and yards, of which 46 are in Texas, 12 are in Oklahoma, 19 are in Wyoming, 27 are in Colorado, four are in Louisiana, one is in Arkansas, two are in Kansas, two are in Utah, 27 are in Alberta, Canada, one is in British Columbia, Canada, five are in Mexico and seven are in Singapore. As of February 15, 2006, we lease one drilling mud disposal facility in Oklahoma and we lease two salt water disposal wells in Texas.
Sales and Marketing
      Most sales and marketing activities are performed through our local operations in each geographical region. We believe our local field sales personnel have an excellent understanding of basin-specific issues and customer operating procedures and, therefore, can effectively target marketing activities. We also have a small corporate sales team located in Houston, Texas that supplements our field sales efforts and focuses on large accounts and selling technical services.

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Customers
      Our customers consist of large multi-national and independent oil and gas producers, as well as smaller independent producers and virtually all of the major land-based drilling contractors in North America. Our top ten customers accounted for approximately 34% of our revenue for the year ended December 31, 2005, with no one customer representing more than 10% of our revenue in this period. We believe we have a broad customer base and wide geographic coverage of operations, which somewhat insulates us from regional or customer specific circumstances that might cause a significant erosion in revenue.
Operating Risk and Insurance
      Our operations are subject to hazards inherent in the oil and gas industry, such as accidents, blowouts, explosions, fires and oil spills that can cause:
  •  personal injury or loss of life;
 
  •  damage or destruction of property, equipment and the environment; and
 
  •  suspension of operations.
      In addition, claims for loss of oil and gas production and damage to formations can occur in the well services industry. If a serious accident were to occur at a location where our equipment and services are being used, it could result in our being named as a defendant in lawsuits asserting large claims.
      Because our business involves the transportation of heavy equipment and materials, we may also experience traffic accidents which may result in spills, property damage and personal injury.
      Despite our efforts to maintain high safety standards, we from time to time have suffered accidents in the past and anticipate that we could experience accidents in the future. In addition to the property and personal losses from these accidents, the frequency and severity of these incidents affect our operating costs and insurability and our relationships with customers, employees and regulatory agencies. Any significant increase in the frequency or severity of these incidents, or the general level of compensation awards, could adversely affect the cost of, or our ability to obtain, workers’ compensation and other forms of insurance, and could have other material adverse effects on our financial condition and results of operations.
      Although we maintain insurance coverage of types and amounts that we believe to be customary in the industry, we are not fully insured against all risks, either because insurance is not available or because of the high premium costs. We do maintain commercial general liability, workers’ compensation, business auto, excess auto liability, commercial property, rig physical damage and contractor’s equipment, motor truck cargo, umbrella liability and excess liability, non-owned aircraft liability, directors and officers, employment practices liability, fiduciary, commercial crime and kidnap and ransom insurance policies. However, any insurance obtained by us may not be adequate to cover any losses or liabilities and this insurance may not continue to be available or available on terms which are acceptable to us. Liabilities for which we are not insured, or which exceed the policy limits of our applicable insurance, could have a material adverse effect on us.
Competition
      The markets in which we operate are highly competitive. To be successful, a company must provide services and products that meet the specific needs of oil and gas exploration and production companies and drilling services contractors at competitive prices.
      We provide our services and products across North America, and we compete against different companies in each service and product line we offer. Our competition includes many large and small oilfield service companies, including the largest integrated oilfield services companies.

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      Our major competitors for our completion and production services segment include Schlumberger Ltd., BJ Services Company, Halliburton Company, Weatherford International Ltd., Baker Hughes Inc., Key Energy Services, Inc., Basic Energy Services, Inc., Superior Energy Services, Inc., Tetra Technologies, Inc. and a significant number of locally oriented businesses. In our drilling services segment, our primary competitors include Nabors Industries Ltd., Patterson-UTI Energy, Inc., Unit Corporation and Helmerich & Payne, Grey Wolf Inc. Our principal competitors in our product sales segment include National Oilwell Varco, Inc., Baker Hughes Inc., Weatherford International Ltd., Halliburton Company, Smith International, Inc., and various smaller providers of equipment. We believe that the principal competitive factors in the market areas that we serve are quality of service and products, reputation for safety and technical proficiency, availability and price. While we must be competitive in our pricing, we believe our customers select our services and products based on local leadership and basin-expertise that our personnel use to deliver quality services and products.
Government Regulation
      We operate under the jurisdiction of a number of regulatory bodies that regulate worker safety standards, the handling of hazardous materials, the transportation of explosives, the protection of the environment and driving standards of operation. Regulations concerning equipment certification create an ongoing need for regular maintenance which is incorporated into our daily operating procedures. The oil and gas industry is subject to environmental regulation pursuant to local, state and federal legislation.
      Among the services we provide, we operate as a motor carrier and therefore are subject to regulation by the U.S. Department of Transportation and by various state agencies. These regulatory authorities exercise broad powers, governing activities such as the authorization to engage in motor carrier operations, and regulatory safety, financial reporting and certain mergers, consolidations and acquisitions. There are additional regulations specifically relating to the trucking industry, including testing and specification of equipment and product handling requirements. The trucking industry is subject to possible regulatory and legislative changes that may affect the economics of the industry by requiring changes in operating practices or by changing the demand for common or contract carrier services or the cost of providing truckload services. Some of these possible changes include increasingly stringent environmental regulations, changes in the hours of service regulations which govern the amount of time a driver may drive in any specific period, onboard black box recorder devices or limits on vehicle weight and size.
      Interstate motor carrier operations are subject to safety requirements prescribed by the Department of Transportation. To a large degree, intrastate motor carrier operations are subject to safety regulations that mirror federal regulations. Such matters as weight and dimension of equipment are also subject to federal and state regulations. Department of Transportation regulations mandate drug testing of drivers.
      From time to time, various legislative proposals are introduced, including proposals to increase federal, state, or local taxes, including taxes on motor fuels, which may increase our costs or adversely impact the recruitment of drivers. We cannot predict whether, or in what form, any increase in such taxes applicable to us will be enacted.
Environmental Matters
      Our operations are subject to numerous foreign, federal, state and local environmental laws and regulations governing the release and/or discharge of materials into the environment or otherwise relating to environmental protection. Numerous governmental agencies issue regulations to implement and enforce these laws, for which compliance is often costly and difficult. The violation of these laws and regulations may result in the denial or revocation of permits, issuance of corrective action orders, assessment of administrative and civil penalties, and even criminal prosecution. We believe that we are in substantial compliance with applicable environmental laws and regulations. Further, we do not anticipate that compliance with existing environmental laws and regulations will have a material effect on our consolidated financial statements. However, it is possible that substantial costs for compliance may be incurred in the future. Moreover, it is possible that other developments, such as the adoption of stricter

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environmental laws, regulations, and enforcement policies, could result in additional costs or liabilities that we cannot currently quantify.
      We generate wastes, including hazardous wastes, that are subject to the federal Resource Conservation and Recovery Act, or RCRA, and comparable state statutes. The U.S. Environmental Protection Agency, or EPA, and state agencies have limited the approved methods of disposal for some types of hazardous and nonhazardous wastes. Some wastes handled by us in our field service activities that currently are exempt from treatment as hazardous wastes may in the future be designated as “hazardous wastes” under RCRA or other applicable statutes. If this were to occur, we would become subject to more rigorous and costly operating and disposal requirements.
      The federal Comprehensive Environmental Response, Compensation, and Liability Act, CERCLA or the “Superfund” law, and comparable state statutes impose liability, without regard to fault or legality of the original conduct, on classes of persons that are considered to have contributed to the release of a hazardous substance into the environment. Such classes of persons include the current and past owners or operators of sites where a hazardous substance was released, and companies that disposed or arranged for disposal of hazardous substances at offsite locations such as landfills. Under CERCLA, these persons may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment and for damages to natural resources, and it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment. We currently own, lease, or operate numerous properties and facilities that for many years have been used for industrial activities, including oil and gas production operations. Hazardous substances, wastes, or hydrocarbons may have been released on or under the properties owned or leased by us, or on or under other locations where such substances have been taken for disposal. In addition, some of these properties have been operated by third parties or by previous owners whose treatment and disposal or release of hazardous substances, wastes, or hydrocarbons, was not under our control. These properties and the substances disposed or released on them may be subject to CERCLA, RCRA and analogous state laws. Under such laws, we could be required to remove previously disposed substances and wastes (including substances disposed of or released by prior owners or operators), remediate contaminated property (including groundwater contamination, whether from prior owners or operators or other historic activities or spills), or perform remedial plugging or pit closure operations to prevent future contamination. These laws and regulations may also expose us to liability for our acts that were in compliance with applicable laws at the time the acts were performed.
      In the course of our operations, some of our equipment may be exposed to naturally occurring radiation associated with oil and gas deposits, and this exposure may result in the generation of wastes containing naturally occurring radioactive materials or “NORM.” NORM wastes exhibiting trace levels of naturally occurring radiation in excess of established state standards are subject to special handling and disposal requirements, and any storage vessels, piping, and work area affected by NORM may be subject to remediation or restoration requirements. Because many of the properties presently or previously owned, operated, or occupied by us have been used for oil and gas production operations for many years, it is possible that we may incur costs or liabilities associated with elevated levels of NORM.
      The Federal Water Pollution Control Act, also known as the Clean Water Act, and analogous state laws impose restrictions and strict controls regarding the discharge of pollutants into state waters or waters of the United States. The discharge of pollutants into jurisdictional waters is prohibited unless the discharge is permitted by the EPA or applicable state agencies. Many of our properties and operations require permits for discharges of wastewater and/or stormwater, and we have a system for securing and maintaining these permits. In addition, the Oil Pollution Act of 1990 imposes a variety of requirements on responsible parties related to the prevention of oil spills and liability for damages, including natural resource damages, resulting from such spills in waters of the United States. A responsible party includes the owner or operator of a facility. The Federal Water Pollution Control Act and analogous state laws provide for administrative, civil and criminal penalties for unauthorized discharges and, together with the Oil Pollution Act, impose rigorous requirements for spill prevention and response planning, as well as

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substantial potential liability for the costs of removal, remediation, and damages in connection with any unauthorized discharges.
      Our underground injection operations are subject to the federal Safe Drinking Water Act, as well as analogous state and local laws and regulations. Under Part C of the Safe Drinking Water Act, the EPA established the Underground Injection Control program, which established the minimum program requirements for state and local programs regulating underground injection activities. The Underground Injection Control program includes requirements for permitting, testing, monitoring, record keeping and reporting of injection well activities, as well as a prohibition against the migration of fluid containing any contaminant into underground sources of drinking water. State regulations require us to obtain a permit from the applicable regulatory agencies to operate our underground injection wells. We believe that we have obtained the necessary permits from these agencies for our underground injection wells and that we are in substantial compliance with permit conditions and state rules. Nevertheless, these regulatory agencies have the general authority to suspend or modify one or more of these permits if continued operation of one of our underground injection wells is likely to result in pollution of freshwater, substantial violation of permit conditions or applicable rules, or leaks to the environment. Although we monitor the injection process of our wells, any leakage from the subsurface portions of the injection wells could cause degradation of fresh groundwater resources, potentially resulting in cancellation of operations of a well, issuance of fines and penalties from governmental agencies, incurrence of expenditures for remediation of the affected resource and imposition of liability by third parties for property damages and personal injuries. In addition, our sales of residual crude oil collected as part of the saltwater injection process could impose liability on us in the event that the entity to which the oil was transferred fails to manage the residual crude oil in accordance with applicable environmental health and safety laws.
      Some of our operations also result in emissions of regulated air pollutants. The federal Clean Air Act and analogous state laws require permits for facilities that have the potential to emit substances into the atmosphere that could adversely affect environmental quality. Failure to obtain a permit or to comply with permit requirements could result in the imposition of substantial administrative, civil and even criminal penalties.
      We are also subject to the requirements of the federal Occupational Safety and Health Act (OSHA) and comparable state statutes that regulate the protection of the health and safety of workers. In addition, the OSHA hazard communication standard requires that information be maintained about hazardous materials used or produced in operations and that this information be provided to employees, state and local government authorities and the public. We believe that our operations are in substantial compliance with the OSHA requirements, including general industry standards, record keeping requirements, and monitoring of occupational exposure to regulated substances.
Employees
      As of January 31, 2006, we had 4,485 employees. Of our total employees, 3,717 were in the United States, 534 were in Canada, 177 were in Mexico and 57 were in Singapore and other locations in the Far East. We are a party to certain collective bargaining agreements in Mexico. Other than these agreements in Mexico, we are not a party to any collective bargaining agreements, and we consider our relations with our employees to be satisfactory.

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Legal Proceedings
      We operate in a dangerous business. We are 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 that 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 businesses.
      Although we cannot know the outcome of pending legal proceedings and the effect such outcomes may have on us, we believe that any ultimate liability resulting from the outcome of such proceedings, 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.

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MANAGEMENT
      Our directors, executive officers and other key operational management employees, their ages and their positions as of February 28, 2006 are as follows:
             
Name   Age   Position
         
Andrew L. Waite
    45     Chairman of the Board
Joseph C. Winkler
    54     Director, President and Chief Executive Officer
J. Michael Mayer
    49     Senior Vice President and Chief Financial Officer
James F. Maroney, III
    54     Vice President, Secretary and General Counsel
Kenneth L. Nibling
    55     Vice President – Human Resources and Administration
Robert L. Weisgarber
    53     Vice President – Accounting and Controller
David C. Baldwin
    43     Director
Robert S. Boswell
    56     Director
Harold G. Hamm
    60     Director
W. Matt Ralls
    56     Director
R. Graham Whaling
    51     Director
James D. Woods
    74     Director
Ronald Boyd
    49     President Mid-Continent Division
Lee Daniel, III
    59     President Rockies Division
Brian K. Moore
    49     President IPS Operations
John D. Schmitz
    45     President Texas Division
      Andrew L. Waite. Mr. Waite has served as Chairman of our board of directors since the date of the Combination. Mr. Waite is a Managing Director of L.E. Simmons and Associates, Incorporated, a private equity firm and has been an officer of that company since October 1995. He was previously Vice President of Simmons & Company International, an investment banking firm specializing in the energy industry where he served from August 1993 to September 1995. From 1984 to 1991, Mr. Waite held a number of engineering and management positions with the Royal Dutch/ Shell Group, an integrated energy company. From November 2003 to June 2005, he served as Chairman, President and Chief Executive Officer of CES. He served as Chairman of CES prior to the Combination and currently serves as a director of Oil States International, Inc., a provider of products and services to oil and gas drilling and production companies, and as a director of Hornbeck Offshore Services, Inc., an operator of offshore supply vessels and other marine assets. He received an M.B.A. degree from the Harvard University Graduate School of Business Administration and an M.S. degree from the California Institute of Technology.
      Joseph C. Winkler. Mr. Winkler has served as our President and Chief Executive Officer since the date of the Combination and a director since June 2005. On June 20, 2005, Mr. Winkler assumed his duties as President and Chief Executive Officer of CES and a director of CES, IEM and IPS. Mr. Winkler served as the Executive Vice President and Chief Operating Officer of National Oilwell Varco, Inc., an oilfield capital equipment and services company, from March 2005 until June 2005 and the company’s predecessor, Varco International, Inc.’s President and Chief Operating Officer from May 2003 until March 2005. From April 1996 until May 2003, Mr. Winkler served in various other capacities with Varco and its predecessor including Executive Vice President and Chief Financial Officer. From 1993 to April 1996, Mr. Winkler served as the Chief Financial Officer of D.O.S., Ltd., a privately held provider of solids control equipment and services and coil tubing equipment to the oil and gas industry, which was acquired by Varco in April 1996. Prior to joining D.O.S., Ltd., he was Chief Financial Officer of Baker Hughes INTEQ, and served in a similar role for various companies owned by Baker Hughes Incorporated including Eastman/ Teleco and Milpark Drilling Fluids. Mr. Winkler received a Bachelor of Science degree from Louisiana State University.

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      J. Michael Mayer. Mr. Mayer has served as our Senior Vice President and Chief Financial Officer since the date of the Combination. He joined CES as Vice President and Chief Financial Officer in May 2004. Prior to joining CES, Mr. Mayer served as the Chief Financial Officer of Tri-Point Energy Services, Inc., a Houston based private company providing repair and refurbishment services to the drilling industry, from March 2003 until May 2004. Before joining Tri-Point, Mr. Mayer was the Chief Financial Officer of NATCO Group Inc., an NYSE-listed provider of process and production equipment to the oil and gas industry, from September 1999 to March 2003. At NATCO, Mr. Mayer was active in taking the company public in 2000 and completed a number of acquisitions while in that role. He has served as Chief Financial Officer in a number of private entities engaged in various facets of the oilfield service industry, as well as approximately 10 years in various financial management positions at Baker Hughes Incorporated, an international oilfield service company. Mr. Mayer received a Bachelor of Business Administration degree from Texas A&M University and is a certified public accountant.
      James F. Maroney, III. Mr. Maroney has served as our Vice President, Secretary and General Counsel since October 2005. From August 2005 until October 2005, Mr. Maroney surveyed various opportunities until accepting employment with us. Mr. Maroney served as Of Counsel to National Oilwell Varco, Inc. from March 2005 to August 2005. He served as Vice President, Secretary and General Counsel of Varco International, Inc. from May 2000 until March 2005. Prior to that time, Mr. Maroney served as Vice President, Secretary and General Counsel of Tuboscope, Inc., Varco’s predecessor.
      Kenneth L. Nibling. Mr. Nibling has served as our Vice President – Human Resources and Administration since October 2005. From July 2005 to October 2005, Mr. Nibling surveyed various opportunities until accepting employment with us. He served as Vice President, Human Resources of National Oilwell Varco, Inc. from March through July 2005. He served as Varco International, Inc.’s Vice President – Human Resources and Administration of Varco International, Inc. from May 2000 until March 2005. Prior to that time, Mr. Nibling served as Vice President – Human Resources and Administration of Tuboscope, Inc.
      Robert L. Weisgarber. Mr. Weisgarber has served as our Vice President – Accounting and Controller since September 2005. From April 2004 until September 2005, he served as the Vice President – Accounting of CES. From October 2003 until April 2004, Mr. Weisgarber served as CFO Partner for Tatum Partners, an executive services and consulting firm. Prior to joining Tatum Partners, Mr. Weisgarber served as Chief Financial Officer of DSI Toys, Inc., a publicly owned manufacturer of toys that has since liquidated pursuant to Chapter 7 of the Bankruptcy Code, from March 1999 until October 2003.
      David C. Baldwin. Mr. Baldwin has served as a director since September 2002. From September 2002 to April 2004, Mr. Baldwin occupied the positions of President and Chief Executive Officer of IPS. Mr. Baldwin is a Managing Director of L.E. Simmons and Associates, Incorporated, which he joined 1991. He served as Chairman of the board of directors of IPS and IEM prior to the Combination. Prior to joining SCF, Mr. Baldwin was a drilling and production engineer with Union Pacific Resources, an independent exploration and production company that has since been acquired. He received both a B.S. degree in Petroleum Engineering and an M.B.A. degree from the University of Texas at Austin.
      Robert S. Boswell. Mr. Boswell has served as a director since the date of the Combination. He serves as Chairman and Chief Executive Officer of Laramie Energy, LLC, a Denver-based privately held oil and gas exploration and production company he founded in September 2003. Prior to his time at Laramie, Mr. Boswell served as Chairman of the board of directors of Forest Oil Corporation, an independent exploration and production company, from March 2000 until September 2003. He served as Chief Executive Officer of Forest Oil from December 1995 until September 2003. Mr. Boswell served as Forest Oil’s President from November 1993 to March 2000 and Chief Financial Officer from May 1991 until December 1995, having served as a member of the board of directors of Forest Oil from 1986 until September 2003. He has also served as a director of C.E. Franklin Ltd., a provider of products and services to the oilfield industry, specifically completion products.

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      Harold G. Hamm. Mr. Hamm has served as a director since the date of the Combination. Mr. Hamm was elected Chairman of the board of directors of Hiland Partners’ general partner in October 2004. Hiland Partners is a NASDAQ publicly traded midstream master limited partnership. Mr. Hamm has served as President and Chief Executive Officer and as a director of Continental Gas, Inc., a midstream natural gas gathering company since December 1994 and then served as Chief Executive Officer and a director to 2004. Since its inception in 1967, Mr. Hamm has served as President and Chief Executive Officer and a director of Continental Resources, Inc. and currently serves as Chairman of its board of directors. Continental Resources, Inc. is an independent exploration and production company. Mr. Hamm is the chairman of the Oklahoma Independent Petroleum Association. He is the founder and served as Chairman of the board of directors of Save Domestic Oil, Inc. Currently, Mr. Hamm is President of the National Stripper Well Association, and serves on the executive boards of the Oklahoma Independent Petroleum Association and the Oklahoma Energy Explorers.
      W. Matt Ralls. Mr. Ralls joined our board of directors on December 2, 2005. Mr. Ralls serves as Senior Vice President and Chief Operating Officer for GlobalSantaFe Corporation, an international contract drilling company, a position he has held since June 2005. Mr. Ralls also serves as a director, Chairman of the Audit Committee and member of the Governance Committee of the general partner of Enterprise Products Partners L.P., a publicly traded provider of midstream energy services, having been elected director in September 2004. He had previously served as Senior Vice President and Chief Financial Officer for GlobalSantaFe. Previously, he was Global Marine Inc.’s Senior Vice President, Chief Financial Officer and Treasurer from January 1999 to November 2001 when Global Marine merged to become GlobalSantaFe. He served as Global Marine’s Vice President and Treasurer from 1997 to January 1999. Mr. Ralls served as Vice President of Capital Markets and Corporate Development for The Meridian Resource Corporation, an independent exploration and production company, before joining Global Marine. Prior to joining The Meridian Resource Corporation, Mr. Ralls served as Executive Vice President, Chief Financial Officer and a director of Kelley Oil Corporation, an independent exploration and production company, from 1990 until 1996. Mr. Ralls spent the first 17 years of his career in commercial banking, mostly at the senior loan management level, with three large Texas banks, including NationsBank in San Antonio, Texas.
      R. Graham Whaling. Mr. Whaling has served as a director since the date of the Combination. In addition, he has served as a director of Brigham Exploration Company, an independent exploration and production company, since June 2001. Mr. Whaling is currently Chairman and Chief Executive Officer of Laredo Energy, LP, a privately owned partnership engaged in the acquisition and development of natural gas reserves in south Texas, and has spent his entire career in the energy industry, as a petroleum engineer, an energy investment banker, a chief financial officer and a chief executive officer of energy companies. Mr. Whaling worked as a petroleum engineer for nine years in the beginning of his career primarily with Ryder Scott Company, an oil and gas consulting firm. Mr. Whaling then spent seven years as an investment banker focusing on the energy industry with Lazard Freres & Co. and Credit Suisse First Boston. Mr. Whaling then became the Chief Financial Officer for Santa Fe Energy, an independent exploration and production company, where he managed the initial public offering and the spin-off of Santa Fe’s western division, Monterey Resources. Mr. Whaling was Chairman and Chief Executive Officer of Monterey Resources from its inception until it was acquired by Texaco in 1997. From May 1999 to May 2001, Mr. Whaling was a Managing Director with Credit Suisse First Boston’s Global Energy Partners, which specializes in private equity investments in energy businesses world-wide. Immediately prior to joining Laredo Energy, LP, Mr. Whaling was Chairman of Michael Petroleum Corporation, an independent exploration and production company that no longer exists.
      James D. Woods. Mr. Woods has served as a director since June 2001. During the period beginning in 1988 and ending in March 2005, Mr. Woods served as director of Varco at various times. Mr. Woods is the Chairman Emeritus and retired Chief Executive Officer of Baker Hughes Incorporated. Mr. Woods was Chief Executive Officer of Baker Hughes from April 1987, and Chairman from January 1989, in each case until January 1997. Mr. Woods is also a director of National Oilwell Varco, Inc. and ESCO Technologies, an NYSE-listed supplier of engineered filtration precuts to the process, healthcare and

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transportation markets; Foster Wheeler Ltd., an OTC-traded holding company of various subsidiaries which provides a broad range of engineering, design, construction and environmental services; OMI Corporation, an NYSE-listed bulk shipping company providing seaborne transportation services primarily of crude oil and refined petroleum products; and USEC Inc., an NYSE-listed supplier of enriched uranium.
Key Operational Management
      Ronald Boyd – President, Mid-Continent Division. Mr. Boyd served as the President of the Mid-Continent Division of CES from October 2004 until the date of the Combination. He currently serves in this capacity with us. Mr. Boyd joined the Hamm Group of Companies in 1988 where he served as President until the group was acquired by CES in October 2004. From 1982 to 1988, he served as Vice President for MB Oilfield Services, an oilfield services company. He received his drilling fluid engineer certification and was Regional Engineer Supervisor for Milchem, Inc., a drilling fluids company until 1982. Mr. Boyd began his career in western Oklahoma in 1973 working on drilling rigs.
      Lee Daniel, III – President, Rockies Division. Mr. Daniel served as the President of the Rockies Division of CES from February 2004 until the date of the Combination. Mr. Daniel currently serves in this capacity with us. Mr. Daniel founded LEED Energy Services, a Colorado-based provider of oilfield services, in February 1990 and served as President and Chief Executive Officer of LEED until it was acquired by CES in February 2004. Prior to founding LEED, Mr. Daniel was the President and Chief Operating Officer of Oil Field Rental Service Company (“OFRS”) in Houston, Texas. OFRS was a subsidiary of Enterra Corporation, which has since merged with Weatherford International. Mr. Daniel received a Bachelor of Business Administration degree from the University of Oklahoma.
      Brian K. Moore – President, IPS Operations. From April 2004 through September 12, 2005, Mr. Moore served as President and Chief Executive Officer and a director of IPS. From January 2001 through April 2004, Mr. Moore served as General Manager – Oilfield Services, U.S. Land Central Region, at Schlumberger Ltd., an international oilfield and information services company. Prior to serving as General Manager – Oilfield Services, Mr. Moore served as Pressure Pumping Manager for Schlumberger’s Eastern Region from July 1999 to January 2001. Mr. Moore has over 24 years of oilfield service experience including 15 years with Camco International where he served in various management and engineering positions including General Manager – Coiled Tubing Operations.
      John D. Schmitz – President, Texas Division. Mr. Schmitz served as the President of the Texas Division of CES from November 2003 until the date of the Combination. Mr. Schmitz currently serves in this capacity with us. In 1983, Mr. Schmitz founded Brammer Supply and spent the next 20 years growing Brammer Supply, both organically and through acquisitions, into BSI, an integrated wellsite service provider with over 16 locations in North and East Texas, Oklahoma and Louisiana, which was acquired by CES in November 2003. Mr. Schmitz began his career as a sales representative for Fluid Packed Pumps in 1979.
      There are no family relationships among any of our directors, executive officers or key operational management employees. The address of each director, executive officer and key operational management employee is: c/o Complete Production Services, Inc., 11700 Old Katy Road, Suite 300, Houston, Texas 77079.
Board of Directors
      Our board of directors currently consists of eight members, including four independent members – Messrs. Boswell, Ralls, Whaling and Woods. The listing requirements of the NYSE require that our board of directors be composed of a majority of independent directors within one year of the listing of our common stock on the NYSE. Accordingly, we intend to appoint additional independent directors to our board of directors following the completion of this offering.

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      Our board of directors is divided into three classes. The directors serve staggered three-year terms. The initial terms of the directors of each class will expire at the annual meetings of stockholders to be held in 2006 (Class I), 2007 (Class II) and 2008 (Class III). At each annual meeting of stockholders, one class of directors will be elected for a full term of three years to succeed that class of directors whose terms are expiring. The classification of directors are as follows:
  •  Class I – Messrs. Joseph C. Winkler, Andrew L. Waite and R. Graham Whaling;
 
  •  Class II – Messrs. Harold G. Hamm, James D. Woods and R. Matt Ralls; and
 
  •  Class III – Messrs. David C. Baldwin and Robert S. Boswell.
      SCF has certain rights to designate up to two members of our board of directors. See “Description of Our Capital Stock – Stockholders Agreement – Management Rights.”
Audit Committee
      Our audit committee is currently comprised of Messrs. Ralls, Whaling and Boswell. Our board has determined that Messrs. Ralls, Whaling and Boswell are independent directors as defined under and required by the Securities Exchange Act of 1934, or the Exchange Act, and the listing requirements of the NYSE. Rule 10A-3 under the Exchange Act and the listing requirements of the NYSE require that our audit committee be composed of a minimum of three members and that it be composed of a majority of independent directors within 90 days of the effectiveness of the registration statement of which this prospectus is a part and that it be composed solely of independent directors within one year of such date. Mr. Ralls has been designated as the audit committee financial expert, as defined by Item 401(h) of Regulation S-K of the Exchange Act. The principal duties of the audit committee, which is chaired by Mr. Ralls, will be as follows:
  •  to review our external financial reporting;
 
  •  to engage our independent auditors; and
 
  •  to review our procedures for internal auditing and the adequacy of our internal accounting controls.
      Our board of directors has adopted a written charter for the audit committee that will be available on our website after the completion of this offering.
Nominating and Corporate Governance Committee
      Our nominating and corporate governance committee is currently comprised of Messrs. Woods and Hamm. Our board has determined that Mr. Woods is independent as required by the listing requirements of the NYSE. The listing requirements of the NYSE require that our nominating and corporate governance committee be composed of a majority of independent directors within 90 days of the listing of our common stock on the NYSE and that it be composed solely of independent directors within one year of such date. The principal duties of the nominating and corporate governance committee will be as follows:
  •  to recommend to the board of directors proposed nominees for election to the board of directors by the stockholders at annual meetings, including an annual review as to the renominations of incumbents and proposed nominees for election by the board of directors to fill vacancies that occur between stockholder meetings; and
 
  •  to make recommendations to the board of directors regarding corporate governance matters and practices.
      Our board of directors has adopted a written charter for the corporate governance and nominating committee that will be available on our website after the closing of this offering.

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Compensation Committee
      Our compensation committee is currently comprised of Messrs. Woods and Whaling. Our board has determined that Messrs. Woods and Whaling are independent as required by the listing requirements of the NYSE. The principal duties of the compensation committee will be as follows:
  •  to administer our stock plans and incentive compensation plans, including our stock incentive plans, and in this capacity, make all option grants or awards to our directors and employees under such plans;
 
  •  to make recommendations to the board of directors with respect to the compensation of our chief executive officer and our other executive officers; and
 
  •  to review key employee compensation policies, plans and programs.
      Our board of directors has adopted a written charter for the compensation committee that will be available on our website after the completion of this offering.
Compensation of Directors
      Directors who are also employees do not receive a retainer or fees for service on our board of directors or any committees. Directors who are not employees will receive an annual fee of $27,500 and fees of $1,500 for attendance at each meeting of our board of directors or $750 for each meeting of our board of directors attended telephonically. In addition, the chairman of the audit committee will receive an annual fee of $15,000 and each director who serves as committee chairmen (other than chairman of the audit committee) will receive an annual fee of $7,500 for each committee on which he serves as chairman. Directors who are not employees will receive options to purchase 5,000 shares of our common stock in connection with their election to the board of directors and options to purchase 5,000 shares of our common stock at each annual meeting after which they continue to serve. These options will be granted under our 2001 Stock Incentive Plan, will vest in four annual installments and will expire ten years from the date of grant. In the event of a change of control, the options will vest in accordance with the plan. The exercise price of these options will be the fair market value at the date of grant. In addition, directors who are not employees will receive an annual grant of restricted stock valued at $50,000. The restricted stock will vest on the anniversary of the date of grant. Directors must retain 65% of the restricted stock so long as they are a director of the Company. All of our directors are reimbursed for reasonable out-of-pocket expenses incurred in attending meetings of our board of directors or committees and for other reasonable expenses related to the performance of their duties as directors.
Web Access
      We will provide access through our website at www.completeproduction.com to current information relating to governance, including a copy of each board committee charter, our code of conduct, our corporate governance guidelines and other matters impacting our governance principles. You may also contact our Chief Financial Officer for paper copies of these documents free of charge.
Compensation Committee Interlocks and Insider Participation
      None of our executive officers serve as a member of the board of directors or compensation committee of any entity that has one or more of its executive officers serving as a member of our board of directors or compensation committee.

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Compensation of Executive Officers
      The following table summarizes all compensation earned by each person who served as Chief Executive Officer and our four other most highly compensated executive officers during the year ended December 31, 2005, to whom we refer in this prospectus as our named executive officers.
Summary Compensation Table
                                                           
                    Long-Term    
            Compensation Awards    
        Annual Compensation        
            Restricted   Securities    
            Other Annual   Stock   Underlying   All Other
Name and Principal Position   Year   Salary   Bonus   Compensation   Awards   Options   Compensation(1)
                             
Joseph C. Winkler(2)
    2005     $ 213,846     $ 318,904     $ 5,160     $ 1,000,136       597,600        
  President and Chief     2004                                      
  Executive Officer     2003                                      
J. Michael Mayer(3)
    2005     $ 174,714     $ 355,000           $ 239,994           $ 8,951  
  Senior Vice President and     2004       106,298       89,186                   125,144        
  Chief Financial Officer     2003                                      
James F. Maroney, III(4)
    2005     $ 56,250     $ 42,072     $ 2,400     $ 175,058       52,000        
  Vice President, Secretary     2004                                      
  and General Counsel     2003                                      
Kenneth L. Nibling(5)
    2005     $ 51,250     $ 38,332     $ 2,400     $ 175,058       52,000        
  Vice President –     2004                                      
  Human Resources and     2003                                      
  Administration                                                        
Robert L. Weisgarber(6)
    2005     $ 155,208     $ 246,257                       $ 9,888  
  Vice President – Accounting     2004       141,667       13,513                   93,858        
  and Controller     2003                                      
Andrew L. Waite(7)
    2005                       $ 50,021              
  Chairman of the Board     2004                                      
  and Former Chief     2003                                      
  Executive Officer                                                        
 
(1)  These amounts consist of matching contributions made by us under our 401(k) plans in which the executive officer participates.
 
(2)  Upon the completion of the Combination, Mr. Winkler became our Chief Executive Officer, President and director. See “– Employment Agreements” below for a description of the terms of Mr. Winkler’s employment. Mr. Winkler was employed by CES as Chief Executive Officer and President and appointed as a director of CES in June 2005. The stockholders of CES prior to the Combination held a majority ownership in us following the Combination. In addition, former directors of CES represent a majority of the directors of our board of directors.
 
(3)  Upon the completion of the Combination, Mr. Mayer became our Senior Vice President and Chief Financial Officer. Mr. Mayer was employed by CES as Vice President and Chief Financial Officer in May 2004.
 
(4)  On October 3, 2005, Mr. Maroney became our Vice President, Secretary and General Counsel.
 
(5)  On October 3, 2005, Mr. Nibling became our Vice President – Human Resources and Administration.
 
(6)  Upon the completion of the Combination, Mr. Weisgarber became our Vice President – Accounting and Controller. Mr. Weisgarber was employed by CES as Vice President – Accounting in April 2004.
 
(7)  Mr. Waite is the Chairman of our board of directors and served as the Chief Executive Officer of CES prior to the hiring of Mr. Winkler in June 2005. Mr. Waite served as the Chief Executive Officer of CES from November 7, 2003 until June 20, 2005. Mr. Waite did not receive compensation from CES for his services as Chief Executive Officer. Mr. Waite is a Managing Director of L.E. Simmons and Associates, Incorporated. L.E. Simmons and Associates, Incorporated received certain consideration from CES in connection with its provision of support services to CES. For a description of these services, see “Certain Relationships and Related Party Transactions.”

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Equity Grants
      The following table summarizes the option grants made to the Chief Executive Officer and the other named executive officers during 2005:
                                                   
                    Potential Realizable
                    Value at Assumed Annual
                    Rates of Stock Price
    Appreciation for Options
Individual Grants   Term
     
    Number of   Percent of        
    Securities   Total Options        
    Underlying   Granted to   Exercise or        
    Option   Employees in   Base Price   Expiration    
Name   Granted   Fiscal Year   Per Share(1)   Date   5%   10%
                         
Joseph C. Winkler
    597,660       34.2%     $ 6.69       06/2015     $ 2,516,149     $ 6,371,056  
  President and Chief                                                
  Executive Officer                                                
J. Michael Mayer
                                   
  Senior Vice President and                                                
  Chief Financial Officer                                                
James F. Maroney, III
    52,000       3.0%     $ 11.66       11/2015     $ 381,160     $ 966,160  
  Vice President, Secretary                                                
  and General Counsel                                                
Kenneth L. Nibling
    52,000       3.0%     $ 11.66       11/2015     $ 381,160     $ 966,160  
  Vice President – Human                                                
  Resources and Administration                                                
Robert L. Weisgarber
                                   
  Vice President –                                                
  Accounting and Controller                                                
Andrew L. Waite
    5,000       0.3%     $ 11.66       10/2015       36,650       92,900  
  Chairman of the Board                                                
  Former Chief Executive                                                
  Officer                                                
 
(1)  Option exercise prices for options granted prior to September 12, 2005 have been adjusted pursuant to FIN 44 to take into account the impact of the approximate $147.0 million Dividend paid to our stockholders following the Combination.
Aggregated Option Exercises in 2005 and Fiscal Year-End Option Values
      The following table sets forth information concerning options exercised during the last fiscal year and held as of December 31, 2005 by each of the named executive officers. None of the named executive officers exercised options during the year ended December 31, 2005. Because there was no public market for our common stock as of December 31, 2005, amounts described in the following table under the heading “Value of Unexercised In-the-Money Options at December 31, 2005” are determined by multiplying the number of shares issued or issuable upon the exercise of the option by the difference between the assumed initial public offering price of $           per share and the per share option exercise price.
                                 
    Number of Shares Underlying   Value of Unexercised
    Unexercised Options at   In-the-Money Options at
    December 31, 2005   December 31, 2005
         
    Exercisable   Unexercisable   Exercisable   Unexercisable
                 
Joseph C. Winkler
          597,660           $    
J. Michael Mayer
    41,714       83,430     $       $    
James F. Maroney, III
          52,000           $    
Kenneth L. Nibling
          52,000           $    
Robert L. Weisgarber
    31,286       62,572     $       $    
Andrew L. Waite
          5,000           $    

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Stock Incentive Plans
2001 Stock Incentive Plan
      In 2001 we adopted a stock incentive plan, which we refer to as the 2001 Stock Incentive Plan, for our and our affiliates’ officers, directors, consultants and employees. The 2001 Stock Incentive Plan amended and restated in its entirety our predecessor’s 2001 Stock Incentive Plan. Under the 2001 Stock Incentive Plan, eligible participants may receive incentive and nonqualified options to purchase shares of our common stock and/or an award of shares of our restricted stock. Under the 2001 Stock Incentive Plan, options to purchase up to 2,540,364 shares of our common stock may be granted to eligible participants. The terms of each incentive and non-qualified option will be determined by a committee of, and established by, our board of directors (the “Committee”). The Committee will determine the exercise price for both incentive and non-qualified options. Generally, these shares vest equally over a three-year period and have a five-year or ten-year life. As of December 31, 2005, under the 2001 Stock Incentive Plan, options for approximately                      shares of our common stock were outstanding.
      In the case of employees, options granted under the 2001 Stock Incentive Plan generally expire on the earlier of (i) 5 or 10 years from the date of grant; (ii) 90 days from the employee’s termination date or (iii) one year from the employee’s termination date due to death or disability. In the case of non-employee directors, all options granted under the 2001 Stock Incentive Plan expire on the earlier of (i) 5 years from the date of grant or (ii) one year from the date of termination of director’s service on our board of directors due to death or disability.
      Our restricted stock that is granted under the 2001 Stock Incentive Plan is subject to certain restrictions on disposition by the holder and an obligation of the holder to forfeit and surrender the shares of our restricted stock to us under certain circumstances. These forfeiture restrictions are determined by the Committee and may lapse upon the occurrence of the following: (i) the attainment of certain performance targets established by the Committee, (ii) the holder’s continued employment with our company or an affiliate of our company or continued service as a consultant to or director of our company for a specified period of time, (iii) any event or the satisfaction of any condition specified by the Committee or (iv) a combination of the foregoing. As of December 31, 2005,                      shares of our restricted stock granted under the 2001 Stock Incentive Plan were unvested.
2003 Stock Incentive Plan
      In connection with the Combination, we assumed CES’s 2003 Stock Incentive Plan, which we refer to as the 2003 Stock Incentive Plan, for certain officers, directors, consultants and employees. Under the 2003 Stock Incentive Plan, as amended, eligible participants received incentive and nonqualified options to purchase shares of CES common stock and/or an award of CES restricted stock, which options and shares were converted, respectively, to options for, and shares of, our common stock pursuant to the terms and conditions of the Combination. Generally, these shares vest equally over a three-year or four-year period, have a five-year life and may be exercised only if the holder is one of our employees, directors or consultants. As of December 31, 2005, under the 2003 Stock Incentive Plan, options for approximately                      shares of our common stock were outstanding. All options (other than options granted to Mr. Winkler) expire on the earlier of (i) 5 years from the date of grant; (ii) 90 days from the employee’s termination date; or (iii) one year from the employee’s termination due to death or disability.
      The restricted stock granted under the 2003 Stock Incentive Plan is subject to certain restrictions on disposition by the holder and an obligation of the holder to forfeit and surrender the shares of the restricted stock to us under certain circumstances. These forfeiture restrictions were determined by the CES board of directors and may lapse upon the occurrence of the following: (i) the attainment of certain performance targets established by the CES board of directors, (ii) the holder’s continued employment with our company or an affiliate of our company or continued service as a consultant to or director of our company for a specified period of time, (iii) any event or the satisfaction of any condition specified by the

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CES board of directors or (iv) a combination of the foregoing. As of December 31, 2005, 144,232 shares of our restricted stock granted under the 2003 Stock Incentive Plan were unvested.
      The 2003 Stock Incentive Plan shall continue to govern the existing options and restricted stock granted thereunder; however, no future awards will be made under the 2003 Stock Incentive Plan.
2004 Stock Incentive Plan
      In connection with the Combination, we assumed IEM’s 2004 Stock Incentive Plan, which we refer to as the 2004 Stock Incentive Plan, for certain officers, directors, consultants and employees. Under the 2004 Stock Incentive Plan, eligible participants received incentive and nonqualified options to purchase shares of IEM common stock and/or an award of IEM restricted stock, which options and shares were converted, respectively, to options for, and shares of, our common stock pursuant to the terms and conditions of the Combination. Generally, these shares vest equally over a three-year or four-year period, have a five-year life and may be exercised only if the holder is one of our employees, directors or consultants. As of December 31, 2005, under the 2004 Stock Incentive Plan, options for                      shares of our common stock were outstanding. No options were granted to employees of IEM. All options (other than options granted to Mr. Winkler) expire on the earlier of (i) 5 years from the date of grant; (ii) 90 days from the employee’s termination date; or (iii) one year from the employee’s termination due to death or disability.
      The restricted stock granted under the 2004 Stock Incentive Plan is subject to certain restrictions on disposition by the holder and an obligation of the holder to forfeit and surrender the shares of the restricted stock to us under certain circumstances. These forfeiture restrictions were determined by the IEM board of directors and may lapse upon the occurrence of the following: (i) the attainment of certain performance targets established by the IEM board of directors, (ii) the holder’s continued employment with our company or an affiliate of our company or continued service as a consultant to or director of our company for a specified period of time, (iii) any event or the satisfaction of any condition specified by the IEM board of directors or (iv) a combination of the foregoing. As of December 31, 2005,                      shares of our restricted stock granted under the 2004 Stock Incentive Plan were unvested.
      The 2004 Stock Incentive Plan will continue to govern the existing options and restricted stock granted thereunder; however, no future awards will be made under the 2004 Stock Incentive Plan.
Parchman Stock Incentive Plan
      In connection with our acquisition of Parchman Energy Group, Inc. in February 2005, we assumed Parchman’s 2003 Restricted Stock Plan, which we refer to as the Parchman Plan, for certain of our employees. Under the Parchman Plan, eligible participants received an award of our restricted stock subject to the restrictions described below. The restricted stock granted under the Parchman Plan is subject to certain restrictions on disposition by the holder and an obligation of the holder to forfeit and surrender the shares of restricted stock to us under certain circumstances. These forfeiture restrictions were determined by the former compensation committee of Parchman and may lapse upon the occurrence of the following: (i) the attainment of certain performance targets established by the former compensation committee of Parchman, (ii) the holder’s continued employment with our company or an affiliate of our company or continued service as a consultant to our company for a specified period of time, or (iii) a combination of the foregoing. As of December 31, 2005,                      shares of our restricted stock granted under the Parchman Plan were unvested.
      The Parchman Plan will continue to govern the existing restricted stock granted thereunder; however, no future awards will be granted under the Parchman Plan.
Employment Agreements
      We have entered into an employment agreement with Mr. Winkler, the initial term of which terminates on June 20, 2008. Unless either party gives notice of its intention not to renew prior to May 6,

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2007, the term will be automatically extended for successive one-year periods until notice is given by either party prior to May 6 of any subsequent year that the term of employment will expire on June 20 of the following year. Mr. Winkler’s annual base salary is $400,000, subject to increase at the discretion of our board of directors, and he will be eligible to receive annual bonuses of at least 100% of his annual base salary assuming the Company satisfies performance criteria established by our board of directors. For 2005, Mr. Winkler’s bonus was to be an amount of up to 150% of the annual base salary if certain performance targets were met, which was to be prorated to cover the period beginning June 20, 2005, the effective date of Mr. Winkler’s employment, to December 31, 2005. Mr. Winkler earned the prorated amount of the maximum 2005 bonus. Mr. Winkler is also entitled to an annual car allowance equal to $9,600.
      Under the employment agreement, if Mr. Winkler’s employment is terminated prior to his attainment of age 63 (and not during the two-year period following any Change of Control (as such term is defined in the employment agreement)) by Mr. Winkler for Good Reason (as defined in the employment agreement) or by us for any reason other than for Cause (as such term is defined in the employment agreement), or the disability or death of Mr. Winkler, Mr. Winkler will be entitled to receive the following benefits:
        (A) his base salary when otherwise due through the date of the termination,
 
        (B) a bonus, in an amount determined in good faith by our board of directors in accordance with the performance criteria established under the employment agreement, prorated through and including the date of termination,
 
        (C) an amount equal to two times the sum of his base salary and average annual bonus (deemed to be 100% of his base salary for this purpose), payable in a lump-sum within 30 days following the date of termination,
 
        (D) all restricted shares, restricted stock units, performance shares, and performance units and stock options held by Mr. Winkler will vest immediately at the time of the termination, and
 
        (E) additional benefits, such as health and disability coverage, outplacement services and an automobile allowance, for up to two years.
      Under the employment agreement, if during the two-year period commencing on the effective date of any Change of Control, Mr. Winkler’s employment is terminated by Mr. Winkler for Good Reason or by us for any reason other than for Cause, or the disability or death of Mr. Winkler, Mr. Winkler will be entitled to receive the following benefits:
        (A) his base salary when otherwise due through the date of the termination,
 
        (B) a bonus, in an amount determined in good faith by our board of directors in accordance with the performance criteria established under the employment agreement, prorated through and including the date of termination,
 
        (C) an amount equal to three times the sum of his base salary and average annual bonus (deemed to be 100% of his base salary for this purpose), payable in a lump-sum within 30 days following the date of termination,
 
        (D) all restricted shares, restricted stock units, performance shares, performance units and stock options held by Mr. Winkler will vest immediately at the time of the termination,
 
        (E) Mr. Winkler will become fully vested in accrued benefits under benefit plans maintained by us; provided, that, if such acceleration is prohibited by law or would require accelerated vesting for all participants in such plans, we will instead make a lump-sum payment to Mr. Winker equal to the present value of such unvested accrued benefits, and
 
        (F) additional benefits, such as health and disability coverage and benefits, outplacement services and an automobile allowance, for up to three years.
      Under the terms of the agreement, subject to certain exceptions, Mr. Winkler may not compete in the market in which we and our affiliates engage in business during his employment with us and for 18 months following the termination of his employment. Also under the agreement, subject to certain

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exceptions, we have agreed to pay a gross-up payment to Mr. Winkler so as to cover any excise tax imposed on benefits provided to Mr. Winkler by us.
      In connection with Mr. Winkler’s employment with us, we granted Mr. Winkler options to purchase 597,660 shares of our common stock. The options are subject to option agreements, which provide that the options vest 25% per year. Mr. Winkler’s options may not be exercised after June 20, 2015, the date of expiration of such options. Furthermore, Mr. Winkler purchased 117,654 shares of our common stock and was granted an additional 117,654 shares of restricted common stock in connection with his stock purchase. The shares of restricted stock are subject to restricted stock agreements between Mr. Winkler and us. These agreements provide that all of the shares of restricted stock will vest on the fourth anniversary of the date of grant.
      We have also entered into an employment agreement with J. Michael Mayer, our Senior Vice President and Chief Financial Officer. Under the agreement, Mr. Mayer will receive an annual base salary equal to $250,000, subject to increase at the discretion of our board of directors, and a bonus of up to 90% of his base salary per year. Mr. Mayer is also entitled to an annual car allowance equal to $9,600. In addition, if we terminate Mr. Mayer’s employment for reasons other than for Cause (as such term is defined in the employment agreement) Mr. Mayer may be entitled to receive the following:
  •  a severance payment equal to 160% of his annual base salary;
 
  •  all unvested stock options and restricted stock will immediately vest; and
 
  •  a bonus for the year during which his employment is terminated, prorated for the days served.
      We have also entered into an employment agreement with James F. Maroney, III, our Vice President, Secretary and General Counsel. Under the agreement, Mr. Maroney will receive an annual base salary equal to $225,000, subject to increase at the discretion of our board of directors, and a bonus of up to 75% of his base salary per year. The bonus earned during 2005 was prorated based on the number of days Mr. Maroney has been employed by us. In addition, if we terminate Mr. Maroney’s employment for reasons other than for Cause (as such term is defined in the employment agreement) Mr. Maroney may be entitled to receive the following:
  •  a severance payment equal to 150% of his annual base salary;
 
  •  all unvested stock options and restricted stock will immediately vest; and
 
  •  a bonus for the year during which his employment is terminated, prorated for the days served.
      In connection with Mr. Maroney’s employment with us, we granted Mr. Maroney options to purchase 52,000 shares of our common stock. The options are subject to an option agreement, which provides that the options vest 331/3% per year. Mr. Maroney’s options may not be exercised after October 3, 2015, the date of expiration of such options. Furthermore, Mr. Maroney purchased 42,900 shares of our common stock and was granted an additional 15,020 shares of restricted common stock in connection with his stock purchase. The shares of restricted stock are subject to a restricted stock agreement between Mr. Maroney and us. The agreement provides that the restricted stock vests 25% per year. Mr. Maroney is also entitled to an annual car allowance equal to $9,600.
      We have also entered into an employment agreement with Kenneth L. Nibling, our Vice President — Human Resources and Administration. Under the agreement, Mr. Nibling will receive an annual base salary equal to $205,000, subject to increase at the discretion of our board of directors, and a bonus of up to 75% of his base salary per year. The bonus earned during 2005 was prorated based on the number of days Mr. Nibling has been employed by us. In addition, if we terminate Mr. Nibling’s employment for reasons other than for Cause (as such term is defined in the employment agreement) Mr. Nibling may be entitled to receive the following:
  •  a severance payment equal to 150% of his annual base salary;
 
  •  all unvested stock options and restricted stock will immediately vest; and
 
  •  a bonus for the year during which his employment is terminated, prorated for the days served.

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      In connection with Mr. Nibling’s employment with us, we granted Mr. Nibling options to purchase 52,000 shares of our common stock. The options are subject to an option agreement, which provides that the options vest 331/3% per year. Mr. Nibling’s options may not be exercised after October 3, 2015, the date of expiration of such options. Furthermore, Mr. Nibling purchased 42,900 shares of our common stock and was granted an additional 15,020 shares of restricted common stock in connection with his stock purchase. The shares of restricted stock are subject to a restricted stock agreement between Mr. Nibling and us. The agreement provides that the restricted stock vests 25% per year. Mr. Nibling is also entitled to an annual car allowance equal to $9,600.
Indemnification Agreements
      Our directors and our executive officers have entered into customary indemnification agreements with us, pursuant to which we have agreed to indemnify our directors and our executive officers to the fullest extent permitted by law.

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CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
      The descriptions set forth below are qualified in their entirety by reference to the applicable agreements.
Offering By Selling Stockholders
      We are paying the expenses of the offering by the selling stockholders, other than the underwriting discounts, commissions and transfer taxes with respect to shares of stock sold by the selling stockholders and the fees and expenses of any attorneys, accountants and other advisors separately retained by them.
The Combination
      The Combination closed on September 12, 2005. Immediately prior to the Combination, SCF owned 13,840,356 shares or 69.9% of the outstanding shares of common stock of IPS; 1,100,000 shares or 67.2% of the outstanding shares of common stock of CES; and 200,000 shares or 75.2% of the outstanding shares of common stock of IEM. As a result of the Combination, as of September 12, 2005, SCF held a total of 39,396,756 shares or approximately 70% of our total shares outstanding. For a discussion of the Combination, please see “Business – The Combination.”
Transactions with Our Significant Stockholder Prior to the Combination
      IPS was party to that certain Services Agreement dated as of December 1, 2002 with L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF, pursuant to which IPS paid L.E. Simmons and Associates, Incorporated $20,000 per month for the services of David C. Baldwin in his capacity as its former Chief Executive Officer and certain administrative staff. David C. Baldwin serves as one of our directors and is a Managing Director of L.E. Simmons and Associates, Incorporated. In March 2004, this agreement was terminated by the parties and is no longer in effect.
      CES was a party to that certain Financial Advisory Agreement dated as of November 7, 2003 with L.E. Simmons and Associates, Incorporated, pursuant to which CES paid L.E. Simmons and Associates, Incorporated fees totaling $1,970,000 for the provision of support services during 2003 and 2004. In addition, L.E. Simmons and Associates, Incorporated provided certain management services, including the services of Andrew L. Waite in his capacity as its former Chief Executive Officer, to CES in exchange for $50,000 in the first quarter in 2004, $87,500 in each of the second and third quarters of 2004 and $125,000 in the fourth quarter of 2004 and the first and second quarters of 2005. This agreement has been terminated by the parties and is no longer in effect.
      IEM was party to that Financial Advisory Agreement dated as of August 14, 2004, with L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF, pursuant to which IEM paid L.E. Simmons and Associates, Incorporated an upfront fee of $250,000 and subsequent to that $31,250 per quarter for management services. This agreement has been terminated by the parties and is no longer in effect.
Transactions with our Directors, Officers and Key Operational Managers
      Andrew L. Waite, the Chairman of our board of directors, is also a Managing Director and an officer of L.E. Simmons and Associates, Incorporated. David C. Baldwin, one of our directors, is also a Managing Director and an officer of L.E. Simmons and Associates, Incorporated.
      We provide services to Laramie Energy, an exploration and production company. Robert S. Boswell is a principal of Laramie as well as the Chairman and Chief Executive Officer. Mr. Boswell is a member of our board of directors. Laramie paid us approximately $1.9 million and $205,000 for such services for the years ended December 31, 2005 and 2004, respectively.
      In connection with CES’s acquisition of Hamm Co. in 2004, CES entered into that certain Strategic Customer Relationship Agreement with Continental Resources. By virtue of the Combination, through a

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subsidiary, we are now a party to such agreement. The agreement provides Continental Resources the option to engage a limited amount of our assets into a long-term contract at market rates. Mr. Hamm is a majority owner of Continental Resources and serves as a member of our board of directors.
      We sell services and products to Continental Resources, Inc. and its subsidiaries. Revenues attributable to these sales totaled approximately $3.3 million from October 14, 2004, the date of CES’s acquisition of Hamm Co., through December 31, 2004 and approximately $21.3 million for the year ended December 31, 2005. Harold G. Hamm is a majority owner of Continental Resources, Inc. and serves as a member of our board of directors.
      We lease offices and an oilfield yard from Continental Management Co. and Mr. Hamm for an aggregate of approximately $8,000 per month. These leases expire between 2009 and 2010. Harold G. Hamm is the owner of Continental Management Co. and serves as a member of our board of directors.
      We are obligated to pay Lee Daniel, III an aggregate principal amount of $2.2 million pursuant to a subordinated promissory note due March 31, 2009 that was issued by CES in connection with the acquisition of LEED Energy Services in 2004. Mr. Daniel is a member of our key operational management.
      We sell products and services to HEP Oil Company and its subsidiaries. Revenues attributable to these sales totaled approximately $7.8 and $8.4 million for the years ended December 31, 2005 and 2004, respectively. John D. Schmitz is a majority owner of HEP Oil Company and is a member of our key operational management.
      We lease various oilfield yards, office buildings and other locations from G-ville Properties and B-29 Investments for approximately $132,000 per month. These leases expire between 2008 and 2016. Mr. Schmitz is a majority owner of G-ville Properties and B-29 Investments.
      On September 29, 2005, we entered into an Asset Purchase Agreement with Spindletop Production Services, Ltd. and Mr. Schmitz. Pursuant to the agreement, we purchased the assets of Spindletop in exchange for approximately $0.2 million cash and 90,364 shares of our common stock.
      We believe that all of these related party transactions were either on terms at least as favorable to us as could have been obtained through arm’s-length negotiations with unaffiliated third parties or were negotiated in connection with acquisitions, the overall terms of which were as favorable to us as could have been obtained through arm’s-length negotiations with unaffiliated third parties. We intend to address future material transactions with our affiliates by having the transactions approved by a committee of disinterested directors.

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PRINCIPAL AND SELLING STOCKHOLDERS
      The following table1 sets forth information with respect to the beneficial ownership of our common stock as of February 28, 2006 by:
  •  each person who is known by us to own beneficially 5% or more of our outstanding common stock;
 
  •  each of our named executive officers;
 
  •  each of our directors;
 
  •  all of our executive officers and directors as a group (12 persons); and
 
  •  each selling stockholder.
      Except as otherwise indicated, the person or entities listed below have sole voting and investment power with respect to all shares of our common stock beneficially owned by them, except to the extent this power may be shared with a spouse. Unless otherwise indicated, the address of each stockholder listed below is 11700 Old Katy Road, Suite 300, Houston, Texas 77079.
                                                                 
                    Shares   Shares
                    Beneficially   Beneficially
                    Owned After   Owned After
                    Offering   Offering
            Maximum Number   (Assuming No   (Assuming
    Shares Beneficially       of Shares to   Exercise of Over-   Exercise of Over-
    Owned Prior       be Sold Upon   Allotment   Allotment Option
    to this Offering   Number of Shares   Exercise of   Option)   in Full)
        to be Sold in   Over-Allotment        
    Number   Percent   Offering   Option(1)   Number   Percent   Number   Percent
                                 
SCF-IV, L.P.(2)
    39,396,756       70.0 %                                                
Andrew L. Waite(3)(7)
    4,290       *                                                  
Joseph C. Winkler(7)
    235,308       *                                                  
J. Michael Mayer(4)(7)
    138,522       *                                                  
James F. Maroney, III(7)
    57,920       *                                                  
Kenneth L. Nibling(7)
    57,920       *                                                  
Robert L. Weisgarber(4)
    57,890       *                                                  
David C. Baldwin(5)(7)
    4,290       *                                                  
Robert S. Boswell(4)(7)
    28,164       *                                                  
Harold G. Hamm(6)(7)
    4,058,266       7.3 %                                                
W. Matt Ralls
          *                                                  
R. Graham Whaling(4)(7)
    26,166       *                                                  
James D. Woods(4)(7)
    11,710       *                                                  
Directors and Executive Officers as a Group (12 persons) (3)(4)(5)(6)(7)
    4,680,446       8.3 %                                                
 
1  We will add the selling stockholders to the table once they have been determined.

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  * Less than one percent.
(1)  Assuming the over-allotment option is exercised in full.
 
(2)  L.E. Simmons is the natural person who has voting and investment control over the securities owned by SCF-IV, L.P. Mr. Simmons serves as chairman of the Board and President of L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF-IV, L.P.
(3)  Mr. Waite serves as Managing Director of L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF-IV, L.P. As such, Mr. Waite may be deemed to have voting and dispositive power over the shares beneficially owned by SCF-IV, L.P. Mr. Waite disclaims beneficial ownership of the shares owned by SCF-IV, L.P.
(4)  Includes shares that may be acquired within 60 days through the exercise of options to purchase shares of our common stock as follows: Messrs. Mayer – 41,714; Weisgarber – 31,286; Boswell – 4,170; Whaling – 2,466; and Woods – 7,420.
 
(5)  Mr. Baldwin serves as Managing Director of L.E. Simmons and Associates, Incorporated, the ultimate general partner of SCF-IV, L.P. As such, Mr. Baldwin may be deemed to have voting and dispositive power over the shares beneficially owned by SCF-IV, L.P. Mr. Baldwin disclaims beneficial ownership of the shares owned by SCF-IV, L.P.
 
(6)  Includes an aggregate of 4,053,976 shares owned by Harold G. Hamm GRAT 4, Harold G. Hamm GRAT 6, and Harold G. Hamm GRAT 8, each of which is an estate planning trust (collectively, the “Hamm Trusts”). Mr. Hamm serves as the trustee of each of the Hamm Trusts. As such, Mr. Hamm may be deemed to have voting and dispositive power over the shares beneficially owned by the Hamm Trusts.
 
(7)  Includes restricted common stock as follows: Waite – 4,290; Winkler – 117,654; Mayer – 39,408; Maroney – 15,020; Nibling – 15,020; Baldwin – 4,290; Boswell – 4,290; Hamm – 4,290; Whaling – 4,290; Woods – 4,290.
Registration Rights
      For a discussion of our stockholder agreement, please see “Description of Our Capital Stock – Stockholders Agreement.”

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DESCRIPTION OF OUR CAPITAL STOCK
      Our authorized capital stock consists of 200,000,000 shares of common stock, par value $.01 per share, and 5,000,000 shares of preferred stock, par value $.01 per share. As of February 28, 2006, we had 56,317,680 shares of common stock outstanding, including 786,170 shares of restricted stock. The shares of restricted stock have voting rights, rights to receive dividends and are subject to certain forfeiture restrictions.
Common Stock
      As of February 28, 2006, there were approximately 140 holders of our common stock. Holders of our common stock are entitled to one vote per share on all matters to be voted upon by our stockholders. Because holders of our common stock do not have cumulative voting rights, the holders of a majority of the shares of our common stock can elect all of the members of the board of directors standing for election, subject to the rights, powers and preferences of any outstanding series of preferred stock. Subject to the rights and preferences of any preferred stock that we may issue in the future, the holders of our common stock are entitled to receive:
  •  dividends as may be declared by our board of directors; and
 
  •  all of our assets available for distribution to holders of our common stock in liquidation, pro rata, based on the number of shares held.
      There are no redemption or sinking fund provisions applicable to our common stock. All outstanding shares of our common stock are fully paid and non-assessable.
Preferred Stock
      Subject to the provisions of our certificate of incorporation and legal limitations, our board of directors has the authority, without further vote or action by our stockholders:
  •  to issue up to 5,000,000 shares of preferred stock in one or more series; and
 
  •  to fix the rights, preferences, privileges and restrictions of our preferred stock, including provisions related to dividends, conversion, voting, redemption, liquidation and the number of shares constituting the series or the designation of that series, which may be superior to those of our common stock.
      There were no shares of preferred stock outstanding as of February 28, 2006, and we have no present plans to issue any preferred stock.
      The issuance of shares of preferred stock by our board of directors as described above may adversely affect the rights of the holders of our common stock. For example, preferred stock may rank prior to our common stock as to dividend rights, liquidation preference or both, may have full or limited voting rights and may be convertible into shares of our common stock. The issuance of shares of preferred stock may discourage third-party bids for our common stock or may otherwise adversely affect the market price of our common stock. In addition, the preferred stock may enable our board of directors to make more difficult or to discourage attempts to obtain control of our company through a hostile tender offer, proxy contest, merger or otherwise, or to make changes in our management.
Anti-Takeover Provisions of Our Certificate of Incorporation and Bylaws
      Our certificate of incorporation and bylaws contain several provisions that could delay or make more difficult the acquisition of us through a hostile tender offer, open market purchases, proxy contest, merger or other takeover attempt that a stockholder might consider in his or her best interest, including those attempts that might result in a premium over the market price of our common stock.

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Written Consent of Stockholders
      Our certificate of incorporation provides that, on and after the date when SCF ceases to own a majority of the shares of our outstanding securities entitled to vote in the election of directors, any action by our stockholders must be taken at an annual or special meeting of stockholders, and stockholders cannot act by written consent. Until that date, any action required or permitted to be taken by our stockholders may be taken at a duly called meeting of stockholders or by the written consent of stockholders owning the minimum number of shares required to approve the action.
Special Meetings of Stockholders
      Subject to the rights of the holders of any series of preferred stock, our bylaws provide that special meetings of the stockholders may only be called by the chairman of the board of directors or by the resolution of our board of directors approved by a majority of the total number of authorized directors. No business other than that stated in our notice may be transacted at any special meeting.
Advance Notice Procedure for Director Nominations and Stockholder Proposals
      Our bylaws provide that adequate notice must be given to nominate candidates for election as directors or to make proposals for consideration at annual meetings of our stockholders. For nominations or other business to be properly brought before an annual meeting by a stockholder, the stockholder must have delivered a written notice to the secretary of our company at our principal executive offices not earlier than the close of business on the 120th calendar day prior to the first anniversary of the date of the preceding year’s annual meeting nor later than the close of business on the 90th calendar day prior to the first anniversary of the date of the preceding year’s annual meeting; provided, however, that in the event that the date of the annual meeting is more than 30 calendar days before or more than 70 calendar days after such anniversary date, notice by the stockholder to be timely must be so delivered not earlier than the close of business on the 120th calendar day prior to such annual meeting nor later than the close of business on the later of the 90th calendar day prior to such annual meeting or the 10th calendar day following the calendar day on which public announcement, if any, of the date of such meeting is first made by us.
      Nominations of persons for election to our board of directors may be made at a special meeting of stockholders at which directors are to be elected pursuant to our notice of meeting (i) by or at the direction of our board of directors, or (ii) by any stockholder of our company who is a stockholder of record at the time of the giving of notice of the meeting, who is entitled to vote at the meeting and who complies with the notice procedures set forth in our bylaws. In the event we call a special meeting of stockholders for the purpose of electing one or more directors to our board of directors, any stockholder may nominate a person or persons (as the case may be) for election to such position(s) if the stockholder provides written notice to the secretary of our company at our principal executive offices not earlier than the close of business on the 120th calendar day prior to such special meeting, nor later than the close of business on the later of the 90th calendar day prior to such special meeting or the 10th calendar day following the day on which public announcement, if any, is first made of the date of the special meeting and of the nominees proposed by our board of directors to be elected at such meeting.
      These procedures may operate to limit the ability of stockholders to bring business before a stockholders meeting, including the nomination of directors and the consideration of any transaction that could result in a change in control and that may result in a premium to our stockholders.
Classified Board of Directors
      Our certificate of incorporation divides our directors into three classes serving staggered three-year terms. As a result, stockholders will elect approximately one-third of the board of directors each year. This provision, when coupled with the provision of our restated certificate of incorporation authorizing only the board of directors to fill vacant or newly created directorships or increase the size of the board of directors and the provision providing that directors may only be removed for cause, may deter a stockholder from

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gaining control of our board of directors by removing incumbent directors or increasing the number of directorships and simultaneously filling the vacancies or newly created directorships with its own nominees.
Renouncement of Business Opportunities
      SCF has investments in other oilfield service companies that may compete with us, and SCF and its affiliates, other than us, may invest in other such companies in the future. We refer to SCF, its other affiliates and its portfolio companies as the SCF group. Our certificate of incorporation provides that, so long as we have a director or officer that is affiliated with SCF (an “SCF Nominee”), we renounce any interest or expectancy in any business opportunity in which any member of the SCF group participates or desires or seeks to participate in and that involves any aspect of the energy equipment or services business or industry, other than:
  •  any business opportunity that is brought to the attention of an SCF Nominee solely in such person’s capacity as a director or officer of our company and with respect to which no other member of the SCF group independently receives notice or otherwise identifies such opportunity; or
 
  •  any business opportunity that is identified by the SCF group solely through the disclosure of information by or on behalf of us.
      Thus, for example, members of the SCF group may pursue opportunities in the oilfield services industry for their own account or present such opportunities to SCF’s other portfolio companies. Our certificate of incorporation provides that the SCF group has no obligation to offer such opportunities to us, even if the failure to provide such opportunity would have a competitive impact on us. We are not prohibited from pursuing any business opportunity with respect to which we have renounced any interest.
Amendment of the Bylaws
      Our board of directors may amend or repeal the bylaws and adopt new bylaws by the affirmative vote of a majority of the total number of authorized directors. The holders of common stock may amend or repeal the bylaws and adopt new bylaws by a majority vote at any annual meeting or special meeting for which notice of the proposed amendment, repeal or adoption was contained in the notice for such special meeting.
Limitation of Liability of Directors
      Our directors will not be personally liable to us or our stockholders for monetary damages for breach of fiduciary duty as a director, except, if required by Delaware law, for liability:
  •  for any breach of the duty of loyalty to us or our stockholders;
 
  •  for acts or omissions not in good faith or involving intentional misconduct or a knowing violation of law;
 
  •  for unlawful payment of a dividend or unlawful stock purchases or redemptions; or
 
  •  for any transaction from which the director derived an improper personal benefit.
      As a result, neither we nor our stockholders have the right, through stockholders’ derivative suits on our behalf, to recover monetary damages against a director for breach of fiduciary duty as a director, including breaches resulting from grossly negligent behavior, except in the situations described above.
Delaware Takeover Statute
      Under the terms of our certificate of incorporation and as permitted under Delaware law, we have elected not to be subject to Delaware’s anti-takeover law in order to give our significant stockholders, including SCF, greater flexibility in transferring their shares of our common stock. This law provides that specified persons who, together with affiliates and associates, own, or within three years did own, 15% or more of the outstanding voting stock of a corporation could not engage in specified business combinations with the corporation for a period of three years after the date on which the person became an interested stockholder. The law defines the term “business combination” to encompass a wide variety of transactions with or caused by an interested stockholder, including mergers, asset sales and other transactions in which

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the interested stockholder receives or could receive a benefit on other than a pro rata basis with other stockholders. With the approval of our stockholders, we may amend our certificate of incorporation in the future to become governed by the anti-takeover law. This provision would then have an anti-takeover effect for transactions not approved in advance by our board of directors, including discouraging takeover attempts that might result in a premium over the market price for the shares of our common stock. By opting out of the Delaware anti-takeover law, a transferee of SCF could pursue a takeover transaction that was not approved by our board of directors.
Stockholders Agreement
      Complete and the existing stockholders are parties to that certain Stockholders Agreement dated September 12, 2005 (the “Stockholders Agreement”).
Management Rights
      As long as SCF owns 20% or more of our outstanding common stock, we have agreed to take all action within our power required to cause the board of directors at all times to include at least two members designated by SCF and so long as SCF owns 5% or more, at least one member designated by SCF.
Demand Registration Rights
      Under the Stockholders Agreement, from and after 180 days following this offering, SCF has the right to demand on five occasions, and Non-SCF stockholders holding at least 50% of our unregistered common stock not held by SCF have the right to demand on one occasion, that we register all or any portion of their registrable securities so long as the registrable securities proposed to be sold on an individual registration statement have an aggregate gross offering price of at least $20 million, unless we otherwise agree to a lesser amount (a “Demand Registration”). Holders of registrable securities may not require us to effect more than one Demand Registration in any six-month period. After such time that we become eligible to use Form S-3 (or comparable form) for the registration under the Securities Act of any of its securities, any demand request by SCF with a reasonably anticipated aggregate offering price of $100 million may be for a “shelf” registration statement pursuant to Rule 415 under the Securities Act.
Piggyback Registration Rights
      If we propose to file a registration statement under the Securities Act relating to an offering of our common stock, subject to certain exceptions, upon the written request of holders of registrable securities, we will use our commercially reasonable efforts to include in such registration, and any related underwriting, all of the registrable securities included in such requests, subject to customary cutback provisions.
Registration Procedures and Expenses
      The Stockholders Agreement contains customary procedures relating to underwritten offerings and the filing of registration statements. We have agreed to pay all registration expenses incurred in connection with any registration, including all registration, qualification and filings fees, printing expenses, accounting fees, escrow fees, legal fees of our company, reasonable fees of one counsel to the holders of registrable securities, blue sky fees and expenses and the expense of any special audits incident to or required by any such registration. All underwriting discounts and selling commissions and stock transfer taxes applicable to securities registered by holders and fees of counsel to any such holder (other than as described above) will be payable by holders of registrable securities.
Transfer Agent and Registrar
      The transfer agent and registrar for the common stock is Wells Fargo Shareowner Services.
Listing
      Our common stock has been approved for listing on the NYSE under the symbol “CPX.”

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SHARES ELIGIBLE FOR FUTURE SALE
      Prior to this offering, there has been no public market for our common stock. The market price of our common stock could drop due to sales of a large number of shares of our common stock or the perception that these sales could occur. These factors also could make it more difficult to raise funds through future offerings of common stock.
      After this offering,                      shares of common stock will be outstanding. Of these shares, the shares sold in this offering, including any shares sold pursuant to the underwriters’ over-allotment option, will be freely tradable without restriction under the Securities Act of 1933, as amended (“Securities Act”), except for any shares purchased by one of our “affiliates” as defined in Rule 144 under the Securities Act. All of our other outstanding shares of common stock will be “restricted securities” within the meaning of Rule 144 under the Securities Act or subject to lock-up arrangements.
      The restricted securities generally may not be sold unless they are registered under the Securities Act or are sold under an exemption from registration, such as the exemption provided by Rule 144 under the Securities Act. After this offering, the holders of shares of our common stock prior to this offering will have rights, subject to some limited conditions, to demand that we include their shares in registration statements that we file on their behalf, on our behalf or on behalf of other stockholders. By exercising their registration rights and selling a large number of shares, these holders could cause the price of our common stock to decline. Furthermore, if we file a registration statement to offer additional shares of our common stock and have to include shares held by those holders, it could impair our ability to raise needed capital by depressing the price at which we could sell our common stock. For a description of the registration rights held by our stockholders, please see “Description of Our Capital Stock – Stockholders Agreement.”
      Our officers and directors and the selling stockholders will enter into lock-up agreements described in “Underwriting.”
      As restrictions on resale end, the market price of our common stock could drop significantly if the holders of these restricted shares sell them, or are perceived by the market as intending to sell them.
      As soon as practicable after this offering, we intend to file one or more registration statements with the SEC on Form S-8 providing for the registration of shares of our common stock issued or reserved for issuance under our stock incentive plans. Subject to the exercise of unexercised options or the expiration or waiver of vesting conditions for restricted stock and the expiration of lock-ups that we and our stockholders have entered into, shares registered under these registration statements on Form S-8 will be available for resale immediately in the public market without restriction.
Rule 144
      In general, beginning 90 days after the date of this prospectus, under Rule 144 as currently in effect, any person (or persons whose shares are aggregated), including an affiliate, who has beneficially owned shares for a period of at least one year is entitled to sell, within any three-month period, a number of shares that does not exceed the greater of:
  •  1% of the then outstanding shares of common stock; and
 
  •  the average weekly trading volume in the common stock on the NYSE during the four calendar weeks immediately preceding the date on which the notice of the sale on Form 144 is filed with the SEC.
      Sales under Rule 144 are also subject to other provisions relating to notice and manner of sale and the availability of current public information about us.

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Rule 144(k)
      Under Rule 144(k), a person who is not deemed to have been one of our affiliates at any time during the 90 days preceding a sale, and who has beneficially owned the shares proposed to be sold for at least two years, including the holding period of any prior owner other than an “affiliate,” is entitled to sell the shares without complying with the manner of sale, public information, volume limitation or notice provision of Rule 144.
Rule 701
      In general, under Rule 701 under the Securities Act as currently in effect, any of our employees, consultants or advisors who purchased or received shares from us in connection with a compensatory stock or option plan or other written agreement in a transaction that was completed in reliance on Rule 701 and complied with the requirements of Rule 701 is eligible to resell such shares beginning 90 days after the date of this prospectus in reliance on Rule 144, but without compliance with most of its restrictions, including the holding period, contained in Rule 144.

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PRINCIPAL U.S. FEDERAL TAX CONSEQUENCES
TO NON-U.S. HOLDERS OF COMMON STOCK
      The following is a general discussion of the principal U.S. federal income and estate tax consequences of the ownership and disposition of our common stock applicable to Non-U.S. Holders. For purposes of this discussion, a “Non-U.S. Holder” is any beneficial owner of our common stock that is not:
  •  an individual who is a citizen or resident of the United States;
 
  •  a corporation (or other entity taxed as a corporation for U.S. federal income tax purposes) created or organized in the United States or under the laws of the United States, any state thereof or the District of Columbia;
 
  •  an estate whose income is subject to U.S. federal income taxation regardless of its source; or
 
  •  a trust whose administration is subject to the primary supervision of a U.S. court and which has one or more U.S. persons who have the authority to control all substantial decisions of the trust, or a trust in existence on August 20, 1996 that has elected to continue to be treated as a “United States person” (as defined for U.S. federal income tax purposes).
      In the case of shares of our common stock held by a partnership (or any other entity treated as a partnership for U.S. federal income tax purposes), the tax treatment of a partner generally will depend upon the status of the partner as a Non-U.S. Holder and the activities of the partnership. An individual may be treated as a resident of the United States for federal income tax purposes with respect to a calendar year if the individual is present in the United States on at least 31 days in that calendar year and at least 183 days during that calendar year and the two preceding calendar years (counting, for this purpose, each day present in the first preceding year as 1/3 of a day and each day present in the second preceding year as 1/6 of a day). Residents are taxed for U.S. federal income tax purposes as if they were U.S. citizens.
      This discussion is based on current provisions of the Internal Revenue Code, Treasury Regulations promulgated under the Internal Revenue Code, judicial opinions, published positions of the Internal Revenue Service, and other applicable authorities, all of which are subject to change, possibly with retroactive effect. This discussion does not address all aspects of U.S. federal income and estate taxation or any aspects of state, local, or non-U.S. taxation, nor does it consider any specific facts or circumstances that may apply to particular Non-U.S. Holders that may be subject to special treatment under the U.S. federal tax laws, such as insurance companies, tax-exempt organizations, financial institutions, brokers, dealers in securities, regulated investment companies, real estate investment trusts, and certain former citizens or former long-term residents of the United States. This discussion does not address special tax rules that may apply to a Non-U.S. Holder that holds our common stock as part of a “straddle,” “hedge,” “conversion transaction,” “synthetic security” or other integrated investment, and assumes that a Non-U.S. Holder holds our common stock as a capital asset.
      Each Non-U.S Holder is urged to consult a tax advisor regarding the U.S. federal, state, local and non-U.S. income and other tax considerations of acquiring, holding and disposing of shares of our common stock.
Dividends
      Distributions on our common stock generally will constitute dividends for U.S. federal income tax purposes to the extent paid from our current or accumulated earnings and profits, as determined under U.S. federal income tax principles. In general, dividends paid to a Non-U.S. Holder of our common stock that are not effectively connected with the conduct of a trade or business in the United States will be subject to U.S. withholding tax at a rate of 30% of the gross amount, or a lower rate prescribed by an applicable income tax treaty. In order to claim a reduced rate of withholding tax under an applicable income tax treaty, a Non-U.S. Holder must certify its eligibility by filing Internal Revenue Service Form W-8BEN. In the case of common stock held by a foreign partnership, the certification generally is

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applied to the partners of the partnership, unless the partnership agrees to become a “withholding foreign partnership” and to provide eligibility information to the Internal Revenue Service.
      Dividends that are effectively connected with a Non-U.S. Holder’s conduct of a trade or business in the United States (and, if an income tax treaty applies, that are attributable to the Non-U.S. Holder’s permanent establishment in the United States) are taxed on a net income basis at the regular graduated rates generally in the manner applicable to U.S. persons. Such dividends are not subject to U.S. withholding tax if the Non-U.S. Holder files Internal Revenue Service Form W-8ECI. A Non-U.S. Holder that is a corporation also may be subject to a branch profits tax at a rate of 30%, or such lower rate as may be specified by an applicable income tax treaty, on the repatriation from the United States of its earnings and profits effectively connected with its U.S. trade or business.
      A Non-U.S. Holder of our common stock that is eligible for a reduced rate of U.S. withholding tax under a tax treaty may obtain a refund of any excess amounts withheld by filing an appropriate claim for refund with the Internal Revenue Service.
Gain on Disposition of Common Stock
      In general, a Non-U.S. Holder will not be subject to U.S. federal income tax on any gain realized upon the sale, exchange, redemption, retirement or other disposition of shares of our common stock so long as:
  •  the gain is not effectively connected with the conduct of a trade or business in the United States by the Non-U.S. Holder (or, if an income tax treaty applies, is not attributable to the Non-U.S. Holder’s permanent establishment in the United States);
 
  •  if the Non-U.S. Holder is an individual, the Non-U.S. Holder either is not present in the United States for 183 days or more in the taxable year of disposition or does not have a “tax home” in the United States for U.S. federal income tax purposes and meets certain other requirements;
 
  •  the Non-U.S. Holder is not subject to tax under the provisions of the Internal Revenue Code regarding the taxation of certain former citizens or former long-term residents of the United States; and
 
  •  we are not and have not been a U.S. real property holding corporation for U.S. federal income tax purposes at any time during the shorter of the Non-U.S. Holder’s holding period of our common stock and the five-year period ending on the date of disposition.
      Generally, a corporation is a U.S. real property holding corporation if the fair market value of its U.S. real property interests equals or exceeds 50% of the fair market value of its worldwide real property and its other assets used or held for use in a trade or business. We believe that we are not currently, and we do not anticipate becoming in the future, a U.S. real property holding corporation.
Certain U.S. Federal Estate Tax Consequences
      Common stock owned or treated as owned by an individual who is not a citizen or resident (as defined for U.S. federal estate tax purposes) of the United States at the time of death will be includible in the individual’s gross estate for U.S. federal estate tax purposes and therefore may be subject to U.S. federal estate tax, unless an applicable estate tax treaty provides otherwise.
Information Reporting and Backup Withholding
      Dividends paid to you may be subject to information reporting and U.S. backup withholding tax (at a rate of 28%). If you are a Non-U.S. Holder you will be exempt from backup withholding if you provide a Form W-8BEN certifying that you are a Non-U.S. Holder or you otherwise meet documentary evidence requirements for establishing that you are a Non-U.S. Holder, or you otherwise establish an exemption.

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      The gross proceeds from the disposition of our common stock may be subject to information reporting and U.S. backup withholding tax. If you sell your common stock outside the United States through a non-U.S. office of a non-U.S. broker and the sales proceeds are paid to you outside the United States, information reporting and backup withholding generally will not apply to that payment. However, information reporting, but not backup withholding, will generally apply to a payment of sales proceeds, even if that payment is made outside the United States, if you sell your common stock through a non-U.S. office of a broker that is:
  •  a U.S. person;
 
  •  a “controlled foreign corporation” for U.S. federal income tax purposes;
 
  •  a foreign person 50% or more of whose gross income from a specified period is effectively connected with the conduct of a U.S. trade or business; or
 
  •  a foreign partnership if at any time during its tax year either (i) one or more of its partners are U.S. persons who in the aggregate hold more than 50% of the income or capital interests in the partnership, or (ii) the foreign partnership is engaged in a U.S. trade or business,
unless the broker has documentary evidence in its files that you are a Non-U.S. Holder and certain other conditions are met, or you otherwise establish an exemption.
      If you receive payments of the proceeds of a sale of our common stock to or through a U.S. office of a broker, the payment is subject to both U.S. backup withholding tax and information reporting unless you provide a Form W-8BEN certifying that you are a Non-U.S. Holder, or you otherwise establish an exemption.
      Backup withholding is not an additional tax. You generally may obtain a refund of any amounts withheld under the backup withholding rules that exceed your U.S. federal income tax liability by timely filing a properly completed refund claim with the U.S. Internal Revenue Service.

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UNDERWRITING
      Under the terms and subject to the conditions contained in an underwriting agreement dated                     , 2006, we and the selling stockholders have agreed to sell to the underwriters named below, for whom Credit Suisse Securities (USA) LLC and UBS Securities LLC are acting as representatives, the following respective number of shares of our common stock:
           
    Number of
Underwriter   Shares
     
Credit Suisse Securities (USA) LLC
       
UBS Securities LLC
       
Banc of America Securities LLC
       
Jefferies & Company, Inc. 
       
Johnson Rice & Company L.L.C. 
       
Raymond James & Associates, Inc. 
       
Simmons & Company International
       
Pickering Energy Partners, Inc. 
       
       
 
Total
       
       
      The underwriting agreement provides that the underwriters are obligated to purchase all of the shares of our common stock in this offering if any are purchased, other than those shares covered by the over-allotment option described below. The underwriting agreement also provides that if an underwriter defaults, the purchase commitments of the non-defaulting underwriters may be increased or this offering may be terminated.
      The selling stockholders have granted to the underwriters a 30-day option to purchase on a pro rata basis up to                     additional outstanding shares from the selling stockholders at the initial public offering price less the underwriting discounts and commissions. The option may be exercised only to cover any over-allotments of common stock.
      The underwriters propose to offer the shares of common stock initially at the public offering price on the cover page of this prospectus and to selling group members at that price less a selling concession of $           per share. The underwriters and selling group members may allow a discount of $           per share on sales to other broker/ dealers. After the initial public offering, the representatives may change the public offering price and concession and discount to broker/ dealers.
      The following table summarizes the compensation and estimated expenses we and the selling stockholders will pay:
                                 
    Per Share   Total
         
    Without   With   Without   With
    Over-allotment   Over-allotment   Over-allotment   Over-allotment
                 
Underwriting discounts and commissions paid by us
  $       $       $       $    
Expenses payable by us
  $       $       $       $    
Underwriting discounts and commissions paid by selling stockholders
  $       $       $       $    
      We estimate that our out-of-pocket expenses for this offering will be approximately $          .
      The representatives have informed us that the underwriters do not expect sales to accounts over which the underwriters have discretionary authority to exceed 5% of the shares of common stock being offered.
      We have agreed that we will not offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, or file with the SEC a registration statement under the Securities Act relating to, any shares of

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our common stock or securities convertible into or exchangeable or exercisable for any shares of our common stock, or publicly disclose the intention to make any offer, sale, pledge, disposition or filing, without the prior written consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC for a period of 180 days after the date of this prospectus, except with respect to common stock issued or issuable pursuant to stock options outstanding on the date of this prospectus, common stock contingently issuable under existing acquisition contracts, common stock, not to exceed            shares, issued in connection with future acquisitions subject to the same 180-day restriction on resales and common stock and other stock-based awards issued or issuable pursuant to our stock incentive plans. However, in the event that either (1) during the last 17 days of the “lock-up” period, we release earnings results or material news or a material event relating to us occurs or (2) prior to the expiration of the “lock-up” period, we announce that we will release earnings results during the 16-day period beginning on the last day of the “lock-up” period, then in either case the expiration of the “lock-up” will be extended until the expiration of the 18-day period beginning on the date of the release of the earnings results or the occurrence of the material news or event, as applicable, unless Credit Suisse Securities (USA) LLC and UBS Securities LLC waive, in writing, such an extension.
      Our officers and directors, the selling stockholders and certain other persons have agreed that they will not offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, any shares of our common stock or securities convertible into or exchangeable or exercisable for any shares of our common stock, enter into a transaction that would have the same effect, or enter into any swap, hedge or other arrangement that transfers, in whole or in part, any of the economic consequences of ownership of our common stock, whether any of these transactions are to be settled by delivery of our common stock or other securities, in cash or otherwise, or publicly disclose the intention to make any offer, sale, pledge or disposition, or to enter into any transaction, swap, hedge or other arrangement, without, in each case, the prior written consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC for a period of 180 days after the date of this prospectus. However, in the event that either (1) during the last 17 days of the “lock-up” period, we release earnings results or material news or a material event relating to us occurs or (2) prior to the expiration of the “lock-up” period, we announce that we will release earnings results during the 16-day period beginning on the last day of the “lock-up” period, then in either case the expiration of the “lock-up” will be extended until the expiration of the 18-day period beginning on the date of the release of the earnings results or the occurrence of the material news or event, as applicable, unless Credit Suisse Securities (USA) LLC and UBS Securities LLC waive, in writing, such an extension.
      The underwriters have reserved for sale at the initial public offering price up to 5% of the total shares of our common stock offered hereby (excluding any shares to be sold pursuant to the over-allotment option)for employees, directors and other persons associated with us who have expressed an interest in purchasing common stock in the offering. The number of shares available for sale to the general public in the offering will be reduced to the extent these persons purchase the reserved shares. Any reserved shares not so purchased will be offered by the underwriters to the general public on the same terms as the other shares.
      We and the selling stockholders have agreed to indemnify the underwriters against liabilities under the Securities Act, or contribute to payments that the underwriters may be required to make in that respect.
      Our common stock has been approved for listing on the New York Stock Exchange under the symbol “CPX”.
      Some of the underwriters and their affiliates have engaged in transactions with, and performed commercial and investment banking financial advisor or lending services for, us and our affiliates from time to time, for which they have received customary compensation and may do so in the future. Affiliates of UBS Securities LLC are arrangers and agents under our credit facility and receive fees customary for performing these services and interest on such. In addition, a portion of the net proceeds from this offering may be used to repay a portion of our revolving credit facility and term loan facility, in which case lenders

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under such facilities, including affiliates of some of the underwriters, will receive their proportionate share of the net proceeds (consisting of less than 10% of such proceeds) used to repay such debt.
      Prior to this offering, there has been no public market for our common stock. The initial public offering price for our common stock will be determined by negotiation between us and the underwriters. The principal factors to be considered in determining the initial public offering price include the following:
  •  the information included in this prospectus and otherwise available to the underwriters;
 
  •  market conditions for initial public offerings;
 
  •  the history of and prospects for our business and our past and present operations;
 
  •  the history of and prospects for the industry in which we compete;
 
  •  our past and present earnings and current financial position;
 
  •  an assessment of our management;
 
  •  the market of securities of companies in businesses similar to ours; and
 
  •  the general condition of the securities markets.
      The initial public offering price may not correspond to the price at which our common stock will trade in the public market subsequent to this offering, and an active trading market may not develop and continue after this offering.
      In connection with the offering, the underwriters may engage in stabilizing transactions, over-allotment transactions, syndicate covering transactions and penalty bids in accordance with Regulation M under the Exchange Act.
  •  Stabilizing transactions permit bids to purchase the underlying security so long as the stabilizing bids do not exceed a specified maximum.
 
  •  Over-allotment involves sales by the underwriters of shares in excess of the number of shares the underwriters are obligated to purchase, which creates a syndicate short position. The short position may be either a covered short position or a naked short position. In a covered short position, the number of shares over-allotted by the underwriters is not greater than the number of shares that they may purchase in the over-allotment option. In a naked short position, the number of shares involved is greater than the number of shares in the over-allotment option. The underwriters may close out any covered short position by either exercising their over-allotment option and/or purchasing shares in the open market.
 
  •  Syndicate covering transactions involve purchases of the common stock in the open market after the distribution has been completed in order to cover syndicate short positions. In determining the source of shares to close out the short position, the underwriters will consider, among other things, the price of shares available for purchase in the open market as compared to the price at which they may purchase shares through the over-allotment option. If the underwriters sell more shares than could be covered by the over- allotment option, a naked short position, the position can only be closed out by buying shares in the open market. A naked short position is more likely to be created if the underwriters are concerned that there could be downward pressure on the price of the shares in the open market after pricing that could adversely affect investors who purchase in the offering.

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  •  Penalty bids permit the representatives to reclaim a selling concession from a syndicate member when the common stock originally sold by the syndicate member is purchased in a stabilizing or syndicate covering transaction to cover syndicate short positions.
      These stabilizing transactions, syndicate covering transactions and penalty bids may have the effect of raising or maintaining the market price of our common stock or preventing or retarding a decline in the market price of the common stock. As a result, the price of our common stock may be higher than the price that might otherwise exist in the open market. These transactions may be effected on the New York Stock Exchange or otherwise and, if commenced, may be discontinued at any time.
      A prospectus in electronic format may be made available on the websites maintained by one or more of the underwriters, or selling group members, if any, participating in this offering and one or more of the underwriters participating in this offering may distribute prospectuses electronically. The representatives may agree to allocate a number of shares to underwriters and selling group members for sale to their online brokerage account holders. Internet distributions will be allocated by the underwriters and selling group members that will make Internet distributions on the same basis as other allocations.

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NOTICE TO CANADIAN RESIDENTS
Resale Restrictions
      The distribution of our common stock in Canada is being made only on a private placement basis exempt from the requirement that we and the selling stockholders prepare and file a prospectus with the securities regulatory authorities in each province where trades of common stock are made. Any resale of the common stock in Canada must be made under applicable securities laws which will vary depending on the relevant jurisdiction, and which may require resales to be made under available statutory exemptions or under a discretionary exemption granted by the applicable Canadian securities regulatory authority. Purchasers are advised to seek legal advice prior to any resale of the common stock.
Representations of Purchasers
      By purchasing common stock in Canada and accepting a purchase confirmation, a purchaser is representing to us, the selling stockholders and the dealer from whom the purchase confirmation is received that:
  •  the purchaser is entitled under applicable provincial securities laws to purchase the common stock without the benefit of a prospectus qualified under those securities laws;
 
  •  where required by law, that the purchaser is purchasing as principal and not as agent; and
 
  •  the purchaser has reviewed the text above under “– Resale Restrictions.”
Rights of Action – Ontario Purchasers Only
      Under Ontario securities legislation, a purchaser who purchases a security offered by this prospectus during the period of distribution will have a statutory right of action for damages, or while still the owner of the common stock, for rescission against us and the selling stockholders in the event that this prospectus contains a misrepresentation. A purchaser will be deemed to have relied on the misrepresentation. The right of action for damages is exercisable not later than the earlier of 180 days from the date the purchaser first had knowledge of the facts giving rise to the cause of action and three years from the date on which payment is made for the common stock. The right of action for rescission is exercisable not later than 180 days from the date on which payment is made for the common stock. If a purchaser elects to exercise the right of action for rescission, the purchaser will have no right of action for damages against us or the selling stockholders. In no case will the amount recoverable in any action exceed the price at which the common stock was offered to the purchaser and if the purchaser is shown to have purchased the securities with knowledge of the misrepresentation, we and the selling stockholders will have no liability. In the case of an action for damages, we and the selling stockholders will not be liable for all or any portion of the damages that are proven to not represent the depreciation in value of the common stock as a result of the misrepresentation relied upon. These rights are in addition to, and without derogation from, any other rights or remedies available at law to an Ontario purchaser. The foregoing is a summary of the rights available to an Ontario purchaser. Ontario purchasers should refer to the complete text of the relevant statutory provisions.
Enforcement of Legal Rights
      All of our directors and officers as well as the experts named herein and the selling stockholders may be located outside of Canada and, as a result, it may not be possible for Canadian purchasers to effect service of process within Canada upon us or those persons. All or a substantial portion of our assets and the assets of those persons may be located outside of Canada and, as a result, it may not be possible to satisfy a judgment against us or those persons in Canada or to enforce a judgment obtained in Canadian courts against us or those persons outside of Canada.

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Taxation and Eligibility for Investment
      Canadian purchasers of common stock should consult their own legal and tax advisors with respect to the tax consequences of an investment in the common stock in their particular circumstances and about the eligibility of the common stock for investment by the purchaser under relevant Canadian legislation.
LEGAL MATTERS
      The validity of the shares of common stock offered by this prospectus will be passed upon for us by Vinson & Elkins L.L.P., Houston, Texas and certain legal matters in connection with this offering will be passed upon for the underwriters by Baker Botts L.L.P., Houston, Texas.
EXPERTS
      The consolidated financial statements of Complete Production Services, Inc. and subsidiaries as of December 31, 2005 and 2004 and for the years then ended included in this prospectus and elsewhere in the registration statement have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their report with respect thereto, and are included herein in reliance upon the authority of said firm as experts in accounting and auditing.
      The consolidated financial statements of Complete Production Services, Inc. and subsidiaries for the year ended December 31, 2003, have been included herein and in the registration statement in reliance upon the report of KPMG LLP (“KPMG”), independent registered public accounting firm, appearing elsewhere herein, and upon the authority of said firm as experts in accounting and auditing.
      Complete Production Services, Inc. has agreed to indemnify and hold KPMG harmless against and from any and all legal costs and expenses incurred by KPMG in the successful defense of any legal action or proceeding that arises as a result of KPMG’s consent to the inclusion of its audit reports on the Company’s past financial statements included in this registration statement.
      The combined financial statements of BSI Companies, a predecessor of Complete Production Services, Inc., as of November 6, 2003 and December 31, 2002 and for the period from January 1, 2003 through November 6, 2003 and for the year ended December 31, 2002, included in this prospectus and elsewhere in the registration statement have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their report with respect thereto, and are included herein in reliance upon the authority of said firm as experts in accounting and auditing.
      The combined financial statements of I.E. Miller Companies, a predecessor of Complete Production Services, Inc., as of August 31, 2004 and for the eleven month period ended August 31, 2004 included in this prospectus and elsewhere in the registration statement have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their report with respect thereto, and are included herein in reliance upon the authority of said firm as experts in accounting and auditing.
      The combined financial statements of I.E. Miller Companies, a predecessor of Complete Production Services, Inc., as of September 30, 2003 and for the year ended September 30, 2003 have been included herein and in the registration statement in reliance upon the report of Darnall, Sikes & Frederick, independent public accounting firm, appearing elsewhere herein, and upon the authority of said firm as experts in accounting and auditing.
      The financial statements of Oil Tool Rentals, Inc., an acquired entity of a predecessor of Complete Production Services, Inc., as of September 30, 2004, December 31, 2003 and December 31, 2002 and for the periods then ended, and the financial statements of Hamm Co., an acquired entity of a predecessor of Complete Production Services, Inc., as of September 30, 2004 and December 31, 2003 and for the respective nine-month and year periods then ended, have been included herein and in the registration

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statement in reliance upon the reports of BKD LLP, independent registered public accountants, appearing elsewhere in this prospectus, given upon the authority of said firm as experts in accounting and auditing.
      The financial statements of Big Mac Tank Trucks LLC, an acquired entity of Complete Production Services, Inc., as of October 31, 2005 and December 31, 2004 and for the ten months and year then ended, included in this prospectus and elsewhere in the registration statement have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their report with respect thereto, and are included herein in reliance upon the authority of said firm as experts in accounting and auditing.
      The financial statements of Hyland Enterprises Inc., an acquired entity of Complete Production Services, Inc., as of August 31, 2004 and February 29, 2004, and for the six months ended August 31, 2004 and the year ended February 29, 2004, included in this prospectus and elsewhere in the registration statement have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their report with respect thereto, and are included herein in reliance upon the authority of said firm as experts in accounting and auditing.
      The financial statements of Monument Well Service, Inc., an acquired entity of Complete Production Services, Inc., as of April 30, 2004 and December 31, 2003, and for the four months ended April 30, 2004 and the year ended December 31, 2003, included in this prospectus and elsewhere in the registration statement have been audited by Grant Thornton LLP, independent registered public accountants, as indicated in their report with respect thereto, and are included herein in reliance upon the authority of said firm as experts in accounting and auditing.
WHERE YOU CAN FIND MORE INFORMATION
      We have filed with the SEC a registration statement on Form S-1 regarding the common stock offered by this prospectus. This prospectus does not contain all of the information found in the registration statement. For further information regarding us and the common stock offered in this prospectus, you may desire to review the full registration statement, including its exhibits. The registration statement, including the exhibits, may be inspected and copied at the public reference facilities maintained by the SEC at 100 F Street, N.E., Washington D.C. 20549. Copies of this material can also be obtained upon written request from the Public Reference Section of the SEC at prescribed rates, or accessed at the SEC’s website on the Internet at www.sec.gov. Please call the SEC at 1-800-SEC-0330 for further information on its public reference room. In addition, our future public filings can also be inspected and copied at the offices of the New York Stock Exchange, Inc., 20 Broad Street, New York, New York 10005.
      We are not, and the underwriters are not, making an offer to sell these securities in any jurisdiction where an offer or sale is not permitted. You should assume that the information appearing in this prospectus is accurate as of the date on the front cover of this prospectus only. Our business, financial condition, results of operations and prospects may have changed since that date.
      Following the completion of this offering, we will file with or furnish to the SEC periodic reports and other information. These reports and other information may be inspected and copied at the public reference facilities maintained by the SEC or obtained from the SEC’s website as provided above. Our website on the Internet is located at www.completeproduction.com, and we expect to make our periodic reports and other information filed with or furnished to the SEC available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC. Information on our website or any other website is not incorporated by reference into this prospectus and does not constitute a part of this prospectus. You may also request a copy of these filings at no cost, by writing or telephoning us at the following address: Complete Production Services, Inc., Attention: Chief Financial Officer, 11700 Old Katy Road, Suite 300, Houston, Texas 77079, (281) 372-2300.
      We intend to furnish or make available to our stockholders annual reports containing our audited financial statements prepared in accordance with GAAP. We also intend to furnish or make available to our stockholders quarterly reports containing our unaudited interim financial information, including the information required on a Quarterly Report on Form 10-Q, for the first three fiscal quarters of each fiscal year.

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INDEX TO FINANCIAL STATEMENTS
Complete Production Services, Inc.
           
    Page
     
Audited Consolidated Financial Statements
       
 
Report of Independent Registered Public Accounting Firm
    F-3  
 
Report of Independent Registered Public Accounting Firm
    F-4  
 
Report of Independent Registered Public Accounting Firm
    F-5  
 
Report of Independent Registered Public Accounting Firm
    F-6  
 
Consolidated Balance Sheets as of December 31, 2005 and 2004
    F-7  
 
Consolidated Statements of Operations and Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2005, 2004 and 2003
    F-8  
 
Consolidated Statements of Stockholders’ Equity for the Years Ended
December 31, 2005, 2004 and 2003
    F-9  
 
Consolidated Statements of Cash Flows for the Years Ended December 31, 2005, 2004 and 2003
    F-10  
 
Notes to Consolidated Financial Statements
    F-11  
Audited Combined Financial Statements — BSI Companies (Predecessor)
       
 
Report of Independent Registered Public Accounting Firm
    F-44  
 
Combined Balance Sheets as of November 6, 2003 and December 31, 2002
    F-45  
 
Combined Statements of Earnings for the Period from January 1, 2003 through November 6, 2003 and for the Year Ended December 31, 2002
    F-46  
 
Combined Statement of Owners’ Equity for the Year Ended December 31, 2002 and for the Period from January 1, 2003 through November 6, 2003
    F-47  
 
Combined Statements of Cash Flows for the Period from January 1, 2003 through November 6, 2003 and for the Year Ended December 31, 2002
    F-48  
 
Notes to Combined Financial Statements
    F-49  
Audited Combined Financial Statements — I.E. Miller Companies (Predecessor)
       
 
Report of Independent Registered Public Accounting Firm
    F-55  
 
Combined Balance Sheet as of August 31, 2004
    F-56  
 
Combined Statement of Operations and Owners’ Equity for the Eleven Month Period Ended August 31, 2004
    F-57  
 
Combined Statement of Cash Flows for the Eleven Month Period Ended August 31, 2004
    F-58  
 
Notes to Combined Financial Statements
    F-59  
 
Independent Auditors’ Report
    F-63  
 
Combined Balance Sheet as of September 30, 2003
    F-64  
 
Combined Statement of Operations for the Year Ended September 30, 2003
    F-65  
 
Combined Statement of Stockholders’ and Members’ Equity for the Year Ended September 30, 2003
    F-66  
 
Combined Statement of Cash Flows for the Year Ended September 30, 2003
    F-67  
 
Notes to Combined Financial Statements
    F-68  
Audited Consolidated Financial Statements — Hamm Co. (Acquired Entity of a Predecessor)
       
 
Independent Accountants’ Report
    F-72  
 
Consolidated Balance Sheet as of September 30, 2004
    F-73  
 
Consolidated Statement of Income for the Nine Months Ended September 30, 2004
    F-74  
 
Consolidated Statement of Stockholders’ Equity for the Nine Months Ended September 30, 2004
    F-75  
 
Consolidated Statement of Cash Flows for the Nine Months Ended September 30, 2004
    F-76  
 
Notes to Consolidated Financial Statements
    F-77  

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Table of Contents

           
    Page
     
 
Independent Accountants’ Report
    F-83  
 
Consolidated Balance Sheet as of December 31, 2003
    F-84  
 
Consolidated Statement of Income for the Year Ended December 31, 2003
    F-85  
 
Consolidated Statement of Stockholders’ Equity for the Year Ended December 31, 2003
    F-86  
 
Consolidated Statement of Cash Flows for the Year Ended December 31, 2003
    F-87  
 
Notes to Consolidated Financial Statements
    F-88  
Audited Financial Statements — Oil Tool Rentals, Inc. (Acquired Entity of a Predecessor)
       
 
Independent Accountants’ Report
    F-94  
 
Balance Sheets as of September 30, 2004 and December 31, 2003 and 2002
    F-95  
 
Statements of Income for the Nine Months Ended September 30, 2004 and the Years Ended December 31, 2003 and 2002
    F-96  
 
Statements of Stockholders’ Equity for the Nine Months Ended September 30, 2004 and the Years Ended December 31, 2003 and 2002
    F-97  
 
Statements of Cash Flows for the Nine Months Ended September 30, 2004 and the Years Ended December 31, 2003 and 2002
    F-98  
 
Notes to Financial Statements
    F-99  
Audited Consolidated Financial Statements — Big Mac Tank Trucks, Inc. and Affiliates (Acquired Entity)
       
 
Report of Independent Registered Public Accounting Firm
    F-103  
 
Consolidated Balance Sheets as of October 31, 2005 and December 31, 2004
    F-104  
 
Consolidated Statements of Operations for the Ten Months Ended October 31, 2005 and the Year Ended December 31, 2004
    F-105  
 
Consolidated Statements of Shareholders’ Equity for the Ten Months Ended October 31, 2005 and the Year Ended December 31, 2004
    F-106  
 
Consolidated Statements of Cash Flows for the Ten Months Ended October 31, 2005 and the Year Ended December 31, 2004
    F-107  
 
Notes to Consolidated Financial Statements
    F-108  
Audited Consolidated Financial Statements — Hyland Enterprises, Inc. (Acquired Entity of a Predecessor)
       
 
Independent Accountants’ Report
    F-112  
 
Balance Sheets as of August 31, 2004 and February 29, 2004
    F-113  
 
Statements of Earnings for the Six Months Ended August 31, 2004 and the Twelve Months Ended February 29, 2004
    F-114  
 
Statement of Shareholders’ Equity for the Six Months Ended August 31, 2004 and the Twelve Months Ended February 29, 2004
    F-115  
 
Statements of Cash Flows for the Six Months Ended August 31, 2004 and the Twelve Months Ended February 29, 2004
    F-116  
 
Notes to Financial Statements
    F-117  
Audited Consolidated Financial Statements — Monument Well Service Company and Affiliates (Acquired Entity of a Predecessor)
       
 
Independent Accountants’ Report
    F-123  
 
Combined Balance Sheets as of April 30, 2004 and December 31, 2003
    F-124  
 
Combined Statements of Earnings for the Four Months Ended April 30, 2004 and the Twelve Months Ended December 31, 2003
    F-125  
 
Combined Statements of Stockholders’ Equity for the Four Months Ended April 30, 2004 and the Twelve Months Ended December 31, 2003
    F-126  
 
Combined Statements of Cash Flows for the Four Months Ended April 30, 2004 and the Twelve Months Ended December 31, 2003
    F-127  
 
Notes to Combined Financial Statements
    F-128  

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors
Complete Production Services, Inc.:
      We have audited the accompanying consolidated balance sheets of Complete Production Services, Inc. and subsidiaries as of December 31, 2005 and 2004, and the related consolidated statements of operations, comprehensive income, stockholders’ equity and cash flows for the years then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We did not audit the consolidated financial statements of Integrated Production Services, Inc., which financial statements reflect total assets constituting 35 percent as of December 31, 2004 and total revenues constituting 38 percent for the year ended December 31, 2004 of the related consolidated totals. Those consolidated financial statements were audited by other auditors whose report has been furnished to us, and our opinion, insofar as it relates to the amounts included for Integrated Production Services, Inc., is based solely on the accompanying report of the other auditors.
      We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits and the report of other auditors provide a reasonable basis for our opinion.
      In our opinion, based on our audits and the report of other auditors, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Complete Production Services, Inc. and subsidiaries as of December 31, 2005 and 2004, and the results of their operations and their cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.
/s/ Grant Thornton LLP
Houston, Texas
March 17, 2006

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors
Complete Energy Services, Inc.:
      We have audited the accompanying consolidated balance sheet of Complete Energy Services, Inc. and subsidiaries as of December 31, 2003, and the related consolidated statements of earnings, shareholder’s equity and cash flows for the period from inception (November 7, 2003) through December 31, 2003 (not presented separately herein). These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.
      We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall consolidated financial statement presentation. We believe that our audit provide a reasonable basis for our opinion.
      In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Complete Energy Services, Inc. and subsidiaries as of December 31, 2003, and the consolidated results of their operations and their consolidated cash flows for the period from inception (November 7, 2003) through December 31, 2003, in conformity with accounting principles generally accepted in the United States of America.
/s/ Grant Thornton LLP
Houston, Texas
September 28, 2005

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Table of Contents

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors
Complete Production Services, Inc.:
      We have audited the accompanying consolidated statements of operations, comprehensive income (loss), stockholders’ equity and cash flows of Complete Production Services, Inc. and subsidiaries for the year ended December 31, 2003. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit. We did not audit the consolidated financial statements of Complete Energy Services, Inc., which financial statements reflect total revenues constituting 10 percent for the period from its formation on November 7, 2003 to December 31, 2003 of the consolidated total. Those consolidated financial statements were audited by other auditors whose report has been furnished to us, and our opinion, insofar as it relates to the amounts included for Complete Energy Services, Inc., is based solely on the accompanying report of the other auditors.
      We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit and the report of other auditors provide a reasonable basis for our opinion.
      In our opinion, based on our audit and the report of other auditors, the consolidated financial statements referred to above present fairly, in all material respects, the results of operations and cash flows of Complete Production Services, Inc. and subsidiaries for the year ended December 31, 2003, in conformity with U.S. generally accepted accounting principles.
/s/ KPMG LLP
Calgary, Canada
September 30, 2005
(except as to notes 1 and 12(b),
which are as of January 17, 2006)

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors
Integrated Production Services, Inc.:
      We have audited the consolidated balance sheet of Integrated Production Services, Inc. and subsidiaries as of December 31, 2004, and the related consolidated statements of earnings, comprehensive income, stockholders’ equity and cash flows for the year then ended (not presented separately herein). These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.
      We conducted our audit in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
      In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Integrated Production Services, Inc. and subsidiaries as of December 31, 2004, and the results of their operations and their cash flows for the year then ended in conformity with U.S. generally accepted accounting principles.
/s/ KPMG LLP
Calgary, Canada
April 8, 2005
(except as to note 18, which is as
of August 19, 2005)

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COMPLETE PRODUCTION SERVICES, INC.
Consolidated Balance Sheets
December 31, 2005 and 2004
                     
    2005   2004
         
    (In thousands, except
    share data)
ASSETS
Current assets:
               
 
Cash and cash equivalents
  $ 11,405     $ 11,547  
 
Trade accounts receivable, net
    167,395       85,801  
 
Inventory
    41,290       21,910  
 
Prepaid expenses
    25,404       5,825  
 
Deferred tax asset
    1,992       870  
             
   
Total current assets
    247,486       125,953  
Property, plant and equipment, net
    384,580       235,211  
Intangible assets, net
    4,967       4,073  
Deferred financing costs, net
    2,048       4,467  
Goodwill
    298,297       145,449  
Other long-term assets
    275        
             
   
Total assets
  $ 937,653     $ 515,153  
             
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 
Current liabilities:
               
 
Bank operating loans
  $     $ 21,745  
 
Current maturities of long-term debt
    5,953       28,493  
 
Convertible debentures
          4,150  
 
Accounts payable
    50,693       27,688  
 
Accrued liabilities
    40,972       18,848  
 
Unearned revenue
    6,407        
 
Notes payable
    14,985       2,735  
 
Taxes payable
    1,193       1,081  
             
   
Total current liabilities
    120,203       104,740  
Long-term debt
    509,990       169,190  
Deferred income taxes
    54,334       26,225  
Minority interest
    2,365       42,918  
             
   
Total liabilities
    686,892       343,073  
Commitments and contingencies
               
Stockholders’ equity:
               
 
Common stock, $0.01 par value per share, 200,000,000 shares authorized, 55,531,510 issued (2004 - 38,895,220 issued to controlling stockholders)
    555       389  
 
Treasury stock, at cost
    (202 )      
 
Additional paid-in capital
    220,786       143,147  
 
Retained earnings
    16,885       14,799  
 
Deferred compensation
    (3,803 )     (752 )
 
Accumulated other comprehensive income
    16,540       14,497  
             
   
Total stockholders’ equity
    250,761       172,080  
             
Total liabilities and stockholders’ equity
  $ 937,653     $ 515,153  
             
See accompanying notes to consolidated financial statements.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Consolidated Statements of Operations
Years Ended December 31, 2005, 2004 and 2003
                           
    2005   2004   2003
             
    (In thousands, except per share data)
Revenue:
                       
 
Service
  $ 639,421     $ 239,427     $ 67,732  
 
Product
    118,305       81,320       35,547  
                   
      757,726       320,747       103,279  
Service expenses
    393,856       157,540       47,329  
Product expenses
    87,538       58,633       25,795  
Selling, general and administrative expenses
    111,754       46,077       16,591  
Depreciation and amortization
    48,840       21,616       7,648  
Write-off of deferred financing fees
    3,315              
                   
 
Income before interest, taxes and minority interest
    112,423       36,881       5,916  
Interest expense
    24,461       7,471       2,687  
                   
 
Income before taxes and minority interest
    87,962       29,410       3,229  
Taxes
    33,716       10,821       1,506  
                   
 
Income before minority interest
    54,246       18,589       1,723  
Minority interest
    384       4,705       247  
                   
 
Net income
  $ 53,862     $ 13,884     $ 1,476  
                   
Earnings per share:
                       
 
Basic
  $ 1.16     $ 0.47     $ 0.11  
 
Diluted
  $ 1.06     $ 0.46     $ 0.10  
Weighted average shares:
                       
 
Basic
    46,603       29,548       13,675  
 
Diluted
    50,656       30,083       14,109  
Consolidated Statements of Comprehensive Income
Years Ended December 31, 2005, 2004 and 2003
                           
    2005   2004   2003
             
    (In thousands)
Net income
  $ 53,862     $ 13,884     $ 1,476  
Change in cumulative translation adjustment
    2,043       4,034       10,143  
                   
 
Comprehensive income
  $ 55,905     $ 17,918     $ 11,619  
                   
See accompanying notes to consolidated financial statements.

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COMPLETE PRODUCTION SERVICES, INC.
Consolidated Statements of Stockholders’ Equity
Years Ended December 31, 2005, 2004 and 2003
                                                                   
                            Accumulated    
            Additional               Other    
    No. of   Common   Paid-In   Treasury   Retained   Deferred   Comprehensive    
    Shares   Stock   Capital   Stock   Earnings   Compensation   Income   Total
                                 
    (In thousands, except share amounts)
Balance at December 31, 2002
    12,278,020     $ 123     $ 65,380           $ (561 )         $ 320     $ 65,262  
Net income
                            1,476                   1,476  
Cumulative translation adjustment
                                        10,143       10,143  
Issuance of common stock:
                                                               
 
Acquisition of CES
    7,881,600       79       19,921                               20,000  
 
Other acquisitions
    147,498       1       839                               840  
 
Exercise of options
    56,190             320                               320  
 
For cash
    12,866             73                               73  
Repurchase of common stock
    (27,774 )           (158 )                             (158 )
                                                 
Balance at December 31, 2003
    20,348,400       203       86,375             915             10,463       97,956  
Net income
                            13,884                   13,884  
Cumulative translation adjustment
                                        4,034       4,034  
Issuance of common stock:
                                                               
 
Acquisition of IEM
    3,882,000       39       9,961                               10,000  
 
Other acquisitions
    533,454       5       3,036                               3,041  
 
Exercise of options
    81,180       1       184                               185  
 
For cash
    656,568       7       1,753                               1,760  
 
Exercise of warrants
    13,393,618       134       40,861                               40,995  
Issuance of restricted stock
                977                   (977 )            
Amortization of deferred compensation
                                  225             225  
                                                 
Balance at December 31, 2004
    38,895,220       389       143,147             14,799       (752 )     14,497       172,080  
Net income
                            53,862                   53,862  
Cumulative translation adjustment
                                        2,043       2,043  
Issuance of common stock:
                                                               
 
Acquisition of Parchman
    2,655,336       27       16,861                               16,888  
 
Acquisition of Spindletop
    90,364             1,053                               1,053  
 
Exercise of warrants
    2,048,526       20       9,980                               10,000  
 
For cash
    136,376       1       1,403                               1,404  
 
Exercise of stock options
    15,082             79                               79  
Purchase of warrants
                (256 )                             (256 )
Stock compensation
    16,096             187                               187  
Noncash compensation-options
                230                               230  
Issuance of restricted stock
    153,736       2       4,616                   (4,618 )            
Amortization of deferred compensation
                                  1,747             1,747  
Purchase of minority interest
    11,556,344       116       138,604                   (180 )           138,540  
Dividend paid
                (95,118 )           (51,776 )                 (146,894 )
Repurchase of common stock
    (35,570 )                 (202 )                       (202 )
                                                 
Balance at December 31, 2005
    55,531,510     $ 555     $ 220,786     $ (202 )   $ 16,885     $ (3,803 )   $ 16,540     $ 250,761  
                                                 
See accompanying notes to consolidated financial statements.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Consolidated Statements of Cash Flows
Years Ended December 31, 2005, 2004 and 2003
                             
    2005   2004   2003
             
    (In thousands)
Cash provided by (used in):
                       
Operating activities:
                       
 
Net income (loss)
  $ 53,862     $ 13,884     $ 1,476  
 
Items not affecting cash:
                       
   
Depreciation and amortization
    48,840       21,616       7,648  
   
Deferred income taxes (benefit)
    17,993       9,267       728  
   
Write-off of deferred financing fees
    3,315              
   
Minority interest
    384       4,705       247  
   
Noncash compensation expense
    1,984              
   
Other noncash items
    2,451       (44 )     125  
 
Net change in working capital
    (52,402 )     (14,806 )     3,741  
                   
      76,427       34,622       13,965  
Financing activities:
                       
 
Issuances of long-term debt
    741,599       121,639       35,878  
 
Repayments of long-term debt
    (464,605 )     (9,859 )     (7,275 )
 
Net borrowings (repayments) under lines of credit
    (19,603 )     32,500       6,429  
 
Proceeds from issuances of common stock
    12,267       16,611       21,075  
 
Repayment of convertible debenture
    (4,069 )            
 
Repurchase of common stock/warrants
    (458 )            
 
Issuances (repayments) of notes payable
    (1,690 )     376       (18 )
 
Dividends paid
    (146,894 )            
 
Deferred financing costs
    (4,408 )     (3,637 )     (808 )
                   
      112,139       157,630       55,281  
Investing activities:
                       
 
Business acquisitions, net of cash acquired
    (67,689 )     (139,362 )     (54,798 )
 
Additions to property, plant and equipment
    (125,142 )     (46,904 )     (11,084 )
 
Proceeds on disposal of other assets
    4,473       489       652  
 
Additions to intangible assets
          (999 )     (984 )
                   
      (188,358 )     (186,776 )     (66,214 )
Effect of exchange rate changes on cash
    (350 )     (23 )     (58 )
                   
Change in cash and cash equivalents
    (142 )     5,453       2,974  
Cash and cash equivalents, beginning of year
    11,547       6,094       3,120  
                   
Cash and cash equivalents, end of year
  $ 11,405     $ 11,547     $ 6,094  
                   
See accompanying notes to consolidated financial statements.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
1.     Significant accounting policies:
      Complete Production Services, Inc. (“Complete” or the “Company”) is a provider of specialized services and products focused on developing hydrocarbon reserves, reducing operating costs and enhancing production for oil and gas companies. The Company focuses on basins within North America and delivers targeted services and products required by its customers within each specific basin. The Company manages its operations from regional field service facilities located throughout the U.S. Rocky Mountain region, Texas, Oklahoma, Louisiana, western Canada and Mexico. The Company also has offices in Southeast Asia from which it delivers products to international oil and gas customers. Complete’s business depends, to a large degree, on the level of spending by oil and gas companies for exploration, development and production activities. Therefore, a sustained increase or decrease in the price of natural gas or oil, which could have a material impact on exploration, development and production activities, also could materially affect our financial position, results of operations and cash flows.
      On September 12, 2005, the Company completed the combination (“Combination”) of Complete Energy Services, Inc. (“CES”), Integrated Production Services, Inc. (“IPS”) and I.E. Miller Services, Inc. (“IEM”) pursuant to which the CES and IEM shareholders exchanged all of their common stock for common stock of IPS. CES shareholders received 19.704 shares of IPS for each share of CES, and IEM shareholders received 19.410 shares of IPS for each share of IEM. Subsequent to the combination, IPS changed its name to Complete Production Services, Inc. The former CES shareholders owned 57.6% of Complete common shares, IPS shareholders owned 33.2% and the former IEM shareholders owned 9.2%.
      The consolidated financial statements include the activities of CES, IPS and IEM for the respective periods and have been prepared using the continuity of interests accounting method, which yields results similar to the pooling of interests method, under which the Company combined entities which were under common control and majority ownership of SCF-IV, L.P. (“SCF”), a private equity fund that focuses on investments in the energy services segment of the energy industry. Under this method of accounting, the historical financial statements of CES, IPS and IEM were combined for the period January 1, 2005 through September 12, 2005, and for the years ended December 31, 2004 and 2003, in each case from the date each became controlled by SCF (IPS – May 22, 2001, CES – November 7, 2003, and IEM – August 26, 2004). The accounting policies adopted by the Company were the same policies that the predecessor companies employed. IPS was the legal acquirer in the Combination. The minority interest ownership in net income for each year is calculated based upon the percentage of equity ownership not held by SCF in each of CES and IEM. The consolidated financial statements have been adjusted to reduce net income and stockholders’ equity by the interest of minority stockholders in CES and IEM, as applicable.
      The consolidated financial statements of the Company are expressed in U.S. dollars and have been prepared by management in accordance with accounting principles generally accepted in the United States. The preparation of financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires management to make estimates and assumptions that affect amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates. The financial statements have, in management’s opinion, been properly prepared using careful judgment with reasonable limits of materiality and within the framework of the significant accounting policies summarized below.
Complete Energy Services, Inc.
      CES, a Delaware corporation, was formed on November 7, 2003. CES is an integrated wellsite services provider with operations in north and east Texas as well as in the Mid-continent and the Rocky

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
Mountain regions of the United States. CES provides a wide range of services to the oil and gas exploration industry, including contract drilling, well servicing, fluid handling, wellsite rentals, materials and supplies and other support services.
      These consolidated financial statements include the operations of CES from the date of its incorporation on November 7, 2003.
Integrated Production Services, Inc. (formerly Saber Energy Services, Inc. (“Saber”))
      IPS, a Delaware corporation, was formerly named Saber Energy Services, Inc. On September 18, 2002, an amendment to the certificate of incorporation for Saber was filed with the State of Delaware to change the name of the company from Saber to IPS. Saber was incorporated on May 22, 2001 at which date SCF was its controlling shareholder. Saber entered into a combination agreement with Integrated Production Services Ltd. (“IPSL”) on September 20, 2002. SCF held an equity interest in IPSL from October 16, 2000 and became the controlling shareholder of IPSL on July 3, 2002. IPS provides a wide range of services and products to the oil and gas industry designed to reduce customers’ operating costs and increase production from customers’ hydrocarbon reserves. Services provided include coiled tubing, wireline, production testing and production optimization. Operations are located in western Canada, Texas, Louisiana and Southeast Asia.
      These consolidated financial statements include the operations of Saber from the date of its incorporation on May 22, 2001 and the operations of Integrated Productions Services Ltd. (“IPSL”) from the date of an initial investment by SCF on October 16, 2000, following the continuity of interest method of accounting based on common ownership by SCF.
I.E. Miller Services, Inc.
      IEM, a Delaware corporation, was formed on August 26, 2004 to acquire certain businesses that perform land rig moving services in Louisiana and Texas and vacuum truck services in south Louisiana.
      These consolidated financial statements include the operations of IEM from the date of its incorporation on August 26, 2004.
(a) Basis of preparation:
      The consolidated financial statements include the accounts of the legal entities discussed above and their wholly owned subsidiaries. All material inter-company balances and transactions have been eliminated.
(b) Foreign currency translation:
      Assets and liabilities of foreign subsidiaries, whose functional currencies are the local currency, are translated from their respective functional currencies to U.S. dollars at the balance sheet date exchange rates. Income and expense items are translated at the average rates of exchange prevailing during the year. Foreign exchange gains and losses resulting from translation of account balances are included in income or loss in the year in which they occur. The adjustment resulting from translating the financial statements of such foreign subsidiaries into U.S. dollars is reflected as a separate component of stockholders’ equity.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(c) Revenue recognition:
      The Company recognizes service revenue when it is realized and earned. The Company considers revenue to be realized and earned when the services have been provided to the customer, the product has been delivered, the sales price has been fixed or determinable and collectibility is reasonably assured. Generally services are provided over a relatively short time.
      Revenue and costs on drilling contracts are recognized as work progresses. Progress is measured and revenues recognized based upon agreed day-rate charges. For certain contracts, the Company receives additional lump-sum payments for the mobilization of rigs and other drilling equipment. Consistent with the drilling contract day-rate revenues and charges, revenues and related direct costs incurred for the mobilization are deferred and recognized over the term of the related drilling contract. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred.
      The Company recognizes revenue under service contracts as services are performed. For the year ended December 31, 2005, the Company entered into two separate agreements whereby customers advanced funds totaling $7,400, and the Company agreed to provide contract drilling services. This amount was recorded as a current liability when received. Under this arrangement, a third-party constructed two drilling rigs on the Company’s behalf for these customers. The first rig was completed in October 2005, and the second was completed in January 2006. The Company recognizes revenue under this arrangement when the rigs drill for the customers. Revenue is recognized as it is earned based upon predetermined prices for each day the rig is employed by the customer and in a manner that is consistent with Complete’s revenue recognition policy. The rates charged to the customers are equal to or greater than prevailing marking rates. As revenues are earned, the prepayment liability is offset by billings to the customers. One rig began operating in October 2005, and Complete has recognized revenues totaling $993 under this arrangement in 2005. The other rig began operating in January 2006. Unearned revenue totaled $6,407 at December 31, 2005. The Company expects that the entire portion of the deferred revenue will be earned and recognized by December 31, 2006. The Company had no unearned revenues associated with long-term service contracts as of December 31, 2004 and 2003.
(d) Cash and cash equivalents:
      Short-term investments with maturities less than three months are considered to be cash equivalents and are recorded at cost, which approximates fair market value. The Company considers all investments in highly liquid debt instruments with original maturities of three months or less to be cash equivalents.
(e) Trade accounts receivable:
      Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts is the Company’s best estimate of the amount of probable credit losses in the Company’s existing accounts receivable. The Company determines the allowance based on historical write-off experience, account aging and management’s assumptions about the oil and gas industry economic cycle. The Company reviews its allowance for doubtful accounts monthly. Past due balances over 90 days and over a specified amount are reviewed individually for collectibility. All other balances are reviewed on a pooled basis. Account balances are charged off against the allowance after all appropriate means of collection have been exhausted and the potential for recovery is considered remote. Based on its customer base, the Company does not believe that it has any significant concentrations of credit risk other than its concentration in the oil and gas industry. The Company does not have any off balance-sheet credit exposure related to its customers.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(f) Inventory:
      Inventory consisting of finished goods and materials and supplies held for resale is carried at the lower of cost or market. Market is defined as net realizable value for finished goods and as replacement cost for manufacturing parts and materials. Cost, which includes the cost of raw materials and labor for finished goods, is determined on a first-in first-out basis for refurbished parts and an average cost basis for all other inventories.
(g) Property, plant and equipment:
      Property, plant and equipment are carried at cost less accumulated depreciation. Major betterments are capitalized. Repairs and maintenance that do not extend the useful life of equipment are expensed.
      Depreciation is provided over the estimated useful life of each asset as follows:
           
Asset   Basis   Rate
         
Buildings
  straight-line   39 years
Field Equipment
       
 
Wireline, optimization and coiled tubing equipment
  straight-line   10 years
 
Gas testing equipment
  straight-line   15 years
 
Drilling rigs
  straight-line   20 years
 
Well-servicing rigs
  straight-line   25 years
Office furniture and computers
  declining balance   30%
Leasehold improvements
  straight-line   5 years
Vehicles and other equipment
  straight-line   3 to 10 years
(h) Intangible assets:
      Intangible assets, consisting of acquired customer relationships, service marks, non-compete agreements, acquired patents and technology, are carried at cost less accumulated amortization, which is calculated on a straight-line basis over a period of 2 to 10 years depending on the asset’s estimated useful life. The weighted average remaining amortization period was approximately 4 years as of December 31, 2005.
(i) Impairment of long-lived assets:
      In accordance with SFAS 144, long-lived assets, such as property, plant and equipment, and purchased intangibles subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated future cash flows, an impairment charge is recognized in the amount by which the carrying amount of the asset exceeds the fair value of the asset. Assets to be disposed of would be separately presented in the balance sheet and reported at the lower of the carrying amount or fair value less costs to sell, and are no longer depreciated.
      The assets and liabilities of a disposal group classified as held for sale would be presented separately in the appropriate asset and liability sections of the balance sheet.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(j) Asset retirement obligations:
      In June 2001, SFAS 143, Accounting for Asset Retirement Obligations, was issued. SFAS 143 requires the Company to record the fair value of an asset retirement obligation as a liability in the period in which it incurs a legal obligation associated with the retirement of tangible long-lived assets that result from the acquisition, construction, development, and/or normal use of the assets. The Company also would record a corresponding asset that is depreciated over the life of the asset. Subsequent to the initial measurement of the asset retirement obligation, the obligation would be adjusted at the end of each period to reflect the passage of time and changes in the estimated future cash flows underlying the obligation. The Company was required to adopt SFAS 143 on January 1, 2003. The adoption of SFAS 143 did not affect the Company’s financial statements.
(k) Deferred financing costs:
      Deferred financing costs associated with long-term debt are carried at cost and are expensed over the term of the relevant long-term debt.
(l) Goodwill:
      Goodwill represents the excess of costs over fair value of assets of businesses acquired. Goodwill acquired in a business combination is not amortized, but instead tested for impairment at least annually in the fourth quarter. Under this goodwill impairment test, if the fair value of a reporting unit does not exceed its carrying value, the excess of fair value of a reporting unit over the fair value of its net assets is considered to be the implied fair value of goodwill. If the carrying value of goodwill exceeds its implied fair value, the difference is recognized as an impairment loss. Goodwill was evaluated for impairment at December 31, 2005. Management determined that goodwill was not impaired, and thus no impairment charge has been recorded related to goodwill for the year ended December 31, 2005.
(m) Deferred income taxes:
      The Company follows the liability method of accounting for income taxes. Under this method, deferred income tax assets and liabilities are determined based upon temporary differences between the carrying amount and tax basis of the Company’s assets and liabilities and measured using enacted tax rates and laws that will be in effect when the differences are expected to reverse. The effect on deferred tax assets and liabilities of a change in the tax rates is recognized in income in the period in which the change occurs. The Company records a valuation reserve in each reporting period when management believes that it is more likely than not that any deferred tax asset created will not be realized.
(n) Financial instruments:
      The financial instruments recognized in the balance sheet consist of cash and cash equivalents, trade accounts receivable, bank operating loans, accounts payable and accrued liabilities, long-term debt and convertible debentures. The fair value of all financial instruments approximates their carrying amounts due to their current maturities or market rates of interest.
(o) Per share amounts:
      The treasury stock method of calculating diluted per share amounts is utilized. This method assumes that any proceeds from the exercise of options and other dilutive instruments where the fair value exceeds the exercise price would be used to purchase common stock at the average fair value during the period.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(p) Stock-based compensation:
      The Company has stock-based compensation plans for its employees, officers and directors to acquire common stock. Options are issued with an exercise price equal to fair value of the stock on the date of grant; consequently, under Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees, no compensation expense is recorded. Consideration paid on the exercise of stock options is credited to share capital and additional paid-in capital. Pro forma information required by Statement of Financial Accounting Standard (“SFAS”) No. 123, Accounting for Stock-Based Compensation, is noted below. The Company adopted SFAS No. 123R on January 1, 2006. See note 12(e). Restricted shares are awarded at a price equal to fair value and the related compensation expense is charged to income over the vesting period of the restricted stock.
      The Company applied the minimum value method prescribed in APB No. 25 in accounting for its stock-based compensation plans. If compensation cost for the Company’s stock-based compensation plans had been determined using the fair value approach set forth in SFAS No. 123, the Company’s results of operations for the years ended December 31, 2005, 2004 and 2003 would approximate the pro forma amounts below:
                           
    2005   2004   2003
             
Net income:
                       
 
As reported
  $ 53,862     $ 13,884     $ 1,476  
 
Add: Compensation expense related to stock-based compensation, net of tax
    1,318       42        
 
Deduct: Impact of stock-based compensation expense determined under fair value method, net of tax
    (1,645 )     (340 )     (202 )
                   
 
Pro forma net income
  $ 53,535     $ 13,586     $ 1,274  
                   
Basic earnings per share:
                       
 
As reported
  $ 1.16     $ 0.47     $ 0.11  
 
Pro forma
  $ 1.15     $ 0.46     $ 0.09  
Diluted earnings per share:
                       
 
As reported
  $ 1.06     $ 0.46     $ 0.10  
 
Pro forma
  $ 1.06     $ 0.45     $ 0.09  
      The fair value of each stock option award on the grant date was estimated using the minimum value option pricing model with the following fair values and assumptions:
                           
    2005   2004   2003
             
Weighted average fair value
  $ 1.36     $ 0.76     $ 0.92  
Assumptions:
                       
 
Risk free interest rate
    3.8% to 4.9 %     4.9 %     6 %
 
Dividend yield
                 
 
Expected life (in years)
    3.0 to 4.5       3.0       3.0  

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(q) Research and development:
      Research and development costs are charged to income as period costs when incurred.
(r) Contingencies:
      Liabilities for loss contingencies, including environmental remediation costs not within the scope of SFAS No. 143 arising from claims, assessments, litigation, fines, and penalties and other sources, are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated.
(s) Measurement uncertainty:
      The Company’s consolidated financial statements are prepared in accordance with U.S. GAAP. The preparation of the consolidated financial statements in accordance with U.S. GAAP necessarily requires the Company to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. The Company evaluates its estimates including those related to bad debts, inventory obsolescence, property plant and equipment useful lives, goodwill, intangible assets, income taxes, contingencies and litigation on an ongoing basis. The Company bases its estimates on historical experience and on various other assumptions that are believed at the time to be reasonable under the circumstances. Under different assumptions or conditions, the actual results could differ, possibly materially, from those previously estimated. Many of the conditions impacting these assumptions are estimates outside of the Company’s control.
(t) Comparative figures:
      Certain prior year figures have been reclassified to conform to the current year’s presentation.
2. Business combinations:
(a) The Combination:
      On September 12, 2005, IPS, later renamed Complete Production Services, Inc., acquired all of the interest of the minority stockholders in CES and IEM in conjunction with the “Combination.” The Combination was accounted for using the continuity of interest method as described in Note 1. The purchase of the interest of the minority stockholders by IPS was accounted for using the purchase method of accounting. The purchase resulted in goodwill of $93,792, which represented the excess of the purchase price over the carrying value of the net assets acquired.
      The following table summarizes the acquisition of the interest of minority stockholders of CES and IEM in exchange for shares of the Company’s common stock and the elimination of the historical amounts reflected in the combined group:
                           
    CES   IEM   Total
             
Common stock to minority interest
  $ 129,718     $ 13,167     $ 142,885  
Minority interest in fair value of net assets acquired
    44,565       4,528       49,093  
                   
 
Amount recorded as goodwill
  $ 85,153     $ 8,639     $ 93,792  
                   
      Since this transaction represents the purchase of a minority interest in the combined entity, assets and liabilities were deemed to be recorded at historical cost which approximated fair value. Therefore, the Company recorded an increase in additional paid-in capital with a similar increase in goodwill, with no

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
other changes to asset or liability accounts.
(b) Post-Combination Acquisitions (After September 12, 2005):
(i) Spindletop Production Services, Ltd. (“Spindletop”):
      On September 29, 2005, the Company acquired all of the assets of Spindletop, an entity owned by a related party, in a transaction accounted for as a purchase. This business consists of a manufacturing and equipment repair operation located in Gainsville, Texas, which produces completion products to be sold through our supply stores, distributors and direct sales force, with a primary service area of the Barnett Shale region of north Texas. The results of operations for this business were included in the accounts of the Company from the date of acquisition. Goodwill of $613 resulted from the acquisition and was allocated entirely to the product sales segment.
      The following table summarizes the preliminary purchase price allocation:
           
Net assets acquired:
       
 
Non-cash working capital
  $ (9 )
 
Property, plant and equipment
    686  
 
Goodwill
    613  
       
Net assets acquired
  $ 1,290  
       
Consideration:
       
 
Cash, net of cash and cash equivalents acquired
  $ 237  
 
Issuance of common stock (90,364 shares)
    1,053  
       
Consideration
  $ 1,290  
       
      The price for common shares was based on internal calculations of the fair value for such shares. The purchase price allocation is preliminary and certain items such as acquisition costs, final tax basis and fair values of asset and liabilities as of the acquisition date have not yet been finalized.
(ii) Big Mac Tank Trucks, Inc. and Affiliates (“Big Mac”):
      On November 1, 2005, the Company acquired all of the outstanding equity interests of the Big Mac group of companies (Big Mac Transports, LLC, Big Mac Tank Trucks, LLC and Fugo Services, LLC) for $40,800 in cash. Big Mac is based in McAlester, Oklahoma, and provides fluid handling services primarily to customers in eastern Oklahoma and western Arkansas. The purchase price, which is subject to a post-closing adjustment for actual working capital and reimbursable capital expenditures as of the closing date, has not yet been finalized. Goodwill of $23,724 resulted from this transaction and was allocated entirely to the completion and production services business segment. The Company has included the operating results of Big Mac in the completion and production services business segment from the date of acquisition. The Company believes that this acquisition provides a platform to enter the eastern Oklahoma market and new Fayetteville Shale play in Arkansas.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The following table summarizes the preliminary purchase price allocation:
           
Net assets acquired:
       
 
Non-cash working capital
  $ 4,833  
 
Property, plant and equipment
    11,715  
 
Goodwill
    23,724  
       
Net assets acquired
  $ 40,272  
       
Consideration:
       
 
Cash, net of cash and cash equivalents acquired
  $ 40,272  
       
(iii) Wolsey Well Service, LP (“Wolsey”):
      On December 15, 2005, the Company acquired the well servicing assets of Wolsey, a well operating company with a fleet of five well servicing rigs based in Bowie, Texas, for $6,500 in cash. Of the total purchase price, $3,500 was allocated to property, plant and equipment. This purchase price allocation has not yet been finalized. Goodwill of $3,000 resulted from this transaction and has been allocated entirely to the completion and production services business segment. The results of operations of Wolsey were included in the completion and production services business segment since the date of acquisition.
      The following table provides pro forma information related to the acquisitions of Spindletop, Big Mac and Wolsey, assuming each acquisition occurred on January 1, 2004:
                   
    Pro Forma Results
    Year Ended
    December 31,
     
    2005   2004
         
    (unaudited)
Revenues
  $ 782,344     $ 350,277  
Income before taxes and minority interest
  $ 93,752     $ 36,167  
Net income
  $ 57,322     $ 17,921  
Earnings per share:
               
 
Basic
  $ 1.23     $ 0.61  
 
Diluted
  $ 1.13     $ 0.60  
      To calculate pro forma amounts, the Company used the audited financial statements of Big Mac for the ten months ended October 31, 2005 and year ended December 31, 2004, and assumed 7% debt service costs to finance the transaction, net of tax effect calculated at the statutory tax rate of 35%. Results for the Spindletop and Wolsey transactions were calculated by annualizing results obtained during the period the assets were held by the Company in 2005 and based on certain management assumptions, adjusted for debt service costs and related tax effect, as described above, for each of the years ended December 31, 2005 and 2004. Although the accounting policies and procedures used to prepare the pro forma results are deemed reasonable by the Company, these pro forma results do not purport to be indicative of the actual results which would have been achieved had the acquisitions been consummated on January 1, of the respective year, and are not intended to be a projection of future results.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(c) Pre-Combination 2005 Acquisitions (Before September 12, 2005):
(i) Parchman Energy Group, Inc. (“Parchman”):
      On February 11, 2005, the Company acquired all of the common shares of Parchman in a business combination accounted for as a purchase. Parchman performs coiled tubing services, well testing services, snubbing services and wireline services in Louisiana, Texas, Wyoming and Mexico. The results of operations for Parchman were included in the accounts of the Company from the date of acquisition. In addition, the purchase agreement provides for the issuance of up to 1,000,000 shares of common stock of the Company as contingent consideration over the period from the date of acquisition to December 31, 2005 based on certain operating results of the Company’s operations in the United States. See note 20(b). Goodwill of $20,255 resulted from the acquisition and was allocated entirely to the completion and production services segment. Intangible assets included customer relationships and patents that are being amortized over a 3-to-5 year period. The Company awarded 344,664 shares of non-vested restricted common stock to certain former Parchman employees, which will vest over a three-year term. Of these restricted shares, 153,736 shares vested on December 31, 2005. The Company recorded deferred compensation associated with these shares totaling $2,192, of which $731 was expensed during the year ended December 31, 2005.
      The following table summarizes the preliminary purchase price allocation:
           
Net assets acquired:
       
 
Non-cash working capital
  $ 1,657  
 
Property, plant and equipment
    49,975  
 
Intangible assets
    459  
 
Goodwill (no tax basis)
    20,255  
 
Long-term debt
    (32,017 )
 
Deferred income taxes
    (8,608 )
       
Net assets acquired
  $ 31,721  
       
Consideration:
       
 
Cash, net of cash and cash equivalents acquired
  $ 9,833  
 
Subordinated note
    5,000  
 
Issuance of common stock (2,655,336 shares)
    16,888  
       
Consideration
  $ 31,721  
       
      The price for common shares was based on internal calculations of the fair value for such shares and consultations with the seller. The purchase price allocation is preliminary and certain items such as acquisition costs, final tax basis and fair values of asset and liabilities as of the acquisition date have not yet been finalized.
(ii) Premier Integrated Technologies (“Premier”):
      On January 1, 2005, the Company acquired a 50% interest in Premier in a business combination accounted for as a purchase. Premier provides optimization services in Alberta, British Columbia and Saskatchewan. The Company consolidates Premier, including results of operations, in the accounts of the Company from the date of acquisition and has recorded the minority interest ownership. Goodwill of $997 resulted from this acquisition and was allocated entirely to the completion and production services segment.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The following table summarizes the preliminary purchase price allocated to the Company’s 50% interest:
           
Net assets acquired:
       
 
Non-cash working capital
  $ 2,390  
 
Property, plant and equipment
    2,164  
 
Goodwill
    997  
 
Long-term debt
    (750 )
 
Minority interest
    (1,902 )
       
Net assets acquired
  $ 2,899  
       
Consideration:
       
 
Non-cash working capital
  $ 1,559  
 
Property, plant and equipment
    1,340  
       
Consideration
  $ 2,899  
       
      The purchase price allocation is preliminary and certain items such as fair value of assets and liabilities as of the acquisition date have not yet been finalized.
(iii) Roustabout Specialties Inc. (“RSI”):
      On July 7, 2005, the Company acquired all of the common shares of RSI in a business combination accounted for as a purchase. RSI is a field services and rental company headquartered in Grand Junction, Colorado, with a primary service area of operation in the Piceance Basin of western Colorado. The results of operations for RSI were included in the accounts of the Company from the date of acquisition. Goodwill of $3,073 resulted from the acquisition and was allocated entirely to the completion and production services segment.
      The following table summarizes the preliminary purchase price allocation:
             
Net assets acquired:
       
 
Non-cash working capital
  $ 1,843  
 
Property, plant and equipment
    4,900  
 
Goodwill
    3,073  
       
Net assets acquired
  $ 9,816  
       
Cash consideration, net of cash and cash equivalents acquired
  $ 8,656  
Issuance of common stock to minority interest (136,444 shares)
    1,160  
       
   
Total
  $ 9,816  
       
      The price for common shares was based on internal calculations of the fair value for such shares. The purchase price allocation is preliminary and certain items such as acquisition costs, final tax basis and fair values of asset and liabilities as of the acquisition date have not yet been finalized.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(d) IPS 2004 Acquisitions:
      During 2004, the Company acquired all of the interests of the following entities in transactions accounted for as a purchase. The businesses acquired included Double Jack Testing and Services, Inc. (“Double Jack”), Nortex Perforating Group, Inc. (“Nortex”), and MGM Well Service, Inc. (“MGM”).
      The following table summarizes the purchase price allocation in millions of dollars:
                                   
    Double Jack   Nortex   MGM   Total
                 
Non-cash working capital
  $ 0.8     $     $ 2.6     $ 3.4  
Property, plant and equipment
    2.5       0.8       0.9       4.2  
Goodwill
    7.5       1.0       5.2       13.7  
Deferred income taxes
    (0.6 )           (0.8 )     (1.4 )
                         
Net assets acquired
  $ 10.2     $ 1.8     $ 7.9     $ 19.9  
                         
Consideration:
                               
 
Cash
  $ 8.0     $ 1.8     $ 6.7     $ 16.5  
 
Issuance of common stock
    1.9             1.2       3.1  
 
Cash contingent consideration
    0.3                   0.3  
                         
Total consideration
  $ 10.2     $ 1.8     $ 7.9     $ 19.9  
                         
      There were 533,454 common shares issued as consideration on these acquisitions. The share price of $5.70 per share was determined based on an internal valuation using a market multiple methodology and approved by the Company’s Board of Directors. These acquisitions provide platforms for the provision of the Company’s services in the Barnett Shale and Rocky Mountain regions. In addition, MGM operates an optimization and swabbing business in Texas, and through distributors in Wyoming and Canada, provides the Company with expertise, personnel, and a platform to expand its optimization business in North America. The results of operations are included in the accounts from the date of acquisition. The purchase agreement for Double Jack provides for up to $1,200 of contingent consideration over the period from the date of acquisition to December 31, 2005 based on operating results of the acquired business. Contingent consideration will be accounted for as an adjustment to the purchase price in the period earned. At December 31, 2004, $300 of the contingent consideration was earned. The purchase agreement for MGM provides for contingent consideration of up to $3,430 of cash and 214,132 common shares over the period from the date of acquisition to December 31, 2006 based on certain operating results of the acquired MGM business. Contingent consideration will be accounted for as an adjustment to the purchase price in the period earned. See note 20(b). The goodwill for these acquisitions was allocated entirely to the completion and production services segment. Of the total goodwill recorded of $13,700, $12,700 is without tax basis.
(e) CES 2004 Acquisitions:
      During 2004, the Company acquired all of the interests (except as noted) of the following entities in a combination accounted for as a purchase. The businesses acquired included LEED Energy Services (“LEED”), Salmon Drilling (“Salmon”), A&W Water Service (“A&W”), Monument Well Service and R&W Rentals (“MWS”), Hyland Enterprises (“Hyland”), Hamm Co. Companies (Hamm Management Co., Hamm and Phillips Service Co., Stride Well Service Company, Inc., Rigmovers, Co., Guard Drilling Mud Disposal, Inc., and Oil Tool Rentals, Co.) (collectively, “Hamm”), and the remaining 50% interest in Price Pipeline (“Price”).

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The following table summarizes the purchase price allocation associated with these transactions in millions of dollars:
                                                                   
    LEED   Salmon   A&W   MWS   Hyland   Hamm   Price   Total
                                 
Current assets
  $ 6.9     $ 0.5     $ 1.4     $ 0.8     $ 7.1     $ 7.4     $ 0.4     $ 24.5  
Property, plant and equipment
    14.4       3.6       5.5       7.0       21.9       48.7       0.7       101.8  
Other assets
    0.6       0.2       0.5       0.3       0.4       0.1       0.3       2.4  
Intangible assets
    0.3             0.2       0.3       0.3       0.4             1.5  
Goodwill
    5.5       0.4       8.8       5.7       5.5       33.8       1.2       60.9  
Liabilities
    (6.8 )           (1.4 )     (0.4 )     (9.7 )     (2.5 )     (1.2 )     (22.0 )
                                                 
Net assets acquired
  $ 20.9     $ 4.7     $ 15.0     $ 13.7     $ 25.5     $ 87.9     $ 1.4     $ 169.1  
                                                 
Cash consideration and seller notes
  $ 14.4     $ 4.0     $ 6.6     $ 6.6     $ 17.7     $ 48.1     $ 0.2     $ 97.6  
Issuance of common stock
    5.9       0.5       7.9       6.6       6.6       37.0       1.2       65.7  
Acquisition costs
    0.6       0.2       0.5       0.5       1.2       2.8             5.8  
                                                 
 
Total
  $ 20.9     $ 4.7     $ 15.0     $ 13.7     $ 25.5     $ 87.9     $ 1.4     $ 169.1  
                                                 
      There were 6,568,332 common shares issued to minority interest as consideration in connection with these acquisitions. The share price of $2.54 or $6.09 per share was determined based on an internal valuation using a market multiple methodology and approved by the Company’s board of directors. These acquisitions provide the Company with a presence in the completion and production services and drilling services segments to the oil and gas industry in the Mid-continent and Rocky Mountain and Barnett Shale regions. The results of operations have been included in the accounts of Complete from the dates of the respective acquisitions. Goodwill associated with these acquisitions was allocated as follows: $1,549 to the drilling services segment and $59,386 to the completion and production services segment. Intangible assets are comprised of customer relationships, service marks and non-compete agreements and are being amortized over a 3 to 5 year period.
(f) I.E. Miller 2004 Acquisitions:
      On August 31, 2004, the Company acquired all of the stock of I.E. Miller of Eunice (Texas) No. 2, L.L.C., I.E. Miller – Fowler Trucking (Texas) No. 2, L.L.C. and I.E. Miller – Heldt Brothers Trucking (Texas) No. 2, L.L.C. in a combination accounted for as a purchase. The results of operations were included in the accounts of Complete from the date of acquisition. Goodwill associated with these acquisitions was entirely allocated to the drilling services segment. The price per common share of $2.58 was a negotiated price with the seller.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The following table summarizes the purchase price allocation:
           
Net assets acquired:
       
 
Current assets
  $ 8,641  
 
Property, plant and equipment
    12,250  
 
Goodwill (no tax basis)
    8,543  
 
Current liabilities
    (3,361 )
       
Net assets acquired
  $ 26,073  
       
 
Cash consideration
  $ 13,573  
 
Issuance of common stock to minority interest (4,852,500 common shares)
    12,500  
       
Total consideration
  $ 26,073  
       
(g) CES 2003 Acquisitions:
      On November 7, 2003, the Company acquired all of the interests (except as noted) of BSI in a combination accounted for as a purchase. BSI included Basin Tool, Bell Supply I, LP, Felderhoff Drilling, Mercer Well Service, Price Pipeline (50% interest acquired), Shale Tank Truck, L.P., Tejas Oilfield Services, LLC, and Western Bentonite. BSI provided the Company with a platform business in the Barnett Shale region of north Texas. The results of operations of these acquired companies have been included in the accounts of Complete from the date of acquisition. Goodwill associated with these acquisitions was allocated $9,471 to the completion and production services segment and $4,940 to the drilling services segment. The price for common stock, of $2.54 per share, issued pursuant to the transaction was based on a negotiated price with the seller. Intangible assets acquired were comprised of customer relationships, service marks and non-compete agreements and are being amortized over a 3-to-5 year period.
      The following table summarizes the purchase price allocation:
           
Current assets
  $ 12,226  
Property, plant and equipment
    36,160  
Intangible assets
    1,048  
Goodwill
    14,411  
Current liabilities
    (5,252 )
       
Net assets acquired
  $ 58,593  
       
Cash consideration
  $ 50,093  
Issuance of common stock to minority interest (3,377,896 common shares)
    8,500  
       
 
Total
  $ 58,593  
       
(h) IPS 2003 Acquisitions:
      On April 30, 2003, the Company acquired all of the stock of Ess-Ell Tool Co. Ltd., 852592 Alberta Ltd. and Sentry Oil Tools LLC as well as related holding companies in a business combination accounted for as a purchase. The companies operate a flow control products business in Canada and Texas providing the Company with an expanded line of production enhancement products and geographic platforms from

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
which to expand. The results of operations of these acquired companies have been included in the accounts of Complete from the date of acquisition. Goodwill associated with these acquisitions was entirely allocated to the product sales segment. The price for common stock of $5.70 per share issued pursuant to the transaction was based on the fair value estimated by the financial advisor engaged in connection with the September 20, 2002 combination as described in note 2(f) and updated with an internally-prepared valuation using a market-multiple approach.
      The following table summarizes the purchase price allocation:
           
Net assets acquired:
       
 
Non-cash working capital
  $ 528  
 
Property, plant and equipment
    167  
 
Goodwill (no tax basis)
    4,062  
 
Long-term debt
    (54 )
       
Net assets acquired
  $ 4,703  
       
Consideration:
       
 
Cash, net of cash acquired
  $ 3,863  
 
Issuance of common stock (147,498 common shares)
    840  
       
Total consideration
  $ 4,703  
       
3. Accounts receivable:
                 
    2005   2004
         
Trade
  $ 158,585     $ 80,980  
Unbilled revenue
    9,636       4,152  
Notes receivable
    193       183  
Other
    883       1,029  
             
      169,297       86,344  
Allowance for doubtful accounts
    1,902       543  
             
    $ 167,395     $ 85,801  
             
4. Inventory:
                 
    2005   2004
         
Finished goods
  $ 30,306     $ 19,929  
Manufacturing parts and materials
    12,966       3,344  
Bulk fuel
    88        
             
    $ 43,360     $ 23,273  
Inventory reserves
    2,070       1,363  
             
    $ 41,290     $ 21,910  
             

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
5. Property, plant and equipment:
                         
        Accumulated    
        Depreciation    
        and   Net
December 31, 2005   Cost   Amortization   Book Value
             
Land
  $ 4,906     $     $ 4,906  
Building
    6,798       609       6,189  
Field equipment
    376,979       64,272       312,707  
Vehicles
    37,848       8,692       29,156  
Office furniture and computers
    5,667       1,374       4,293  
Leasehold improvements
    4,083       507       3,576  
Construction in progress
    23,753             23,753  
                   
    $ 460,034     $ 75,454     $ 384,580  
                   
                         
December 31, 2004            
             
Land
  $ 848     $     $ 848  
Building
    6,577       340       6,237  
Field equipment
    238,948       29,314       209,634  
Vehicles
    18,610       2,232       16,378  
Office furniture and computers
    2,254       775       1,479  
Leasehold improvements
    1,556       921       635  
                   
    $ 268,793     $ 33,582     $ 235,211  
                   
6. Intangible assets:
                                                           
    As of December 31, 2005   As of December 31, 2004
         
    Term   Historical   Accumulated   Net Book   Historical   Accumulated   Net Book
Description   (in months)   Cost   Amortization   Value   Cost   Amortization   Value
                             
Patents and trademarks
    60     $ 2,619     $ 810     $ 1,809     $ 2,049     $ 461     $ 1,588  
Contractual agreements
    24 to 120       3,489       1,381       2,108       3,031       546       2,485  
Customer lists and other
    36 to 60       1,346       296       1,050                    
                                           
 
Totals
          $ 7,454     $ 2,487     $ 4,967     $ 5,080     $ 1,007     $ 4,073  
                                           
      The Company recorded amortization expense associated with intangible assets of $1,493, $740 and $212 for the years ended December 31, 2005, 2004 and 2003, respectively. The Company expects to record amortization expense associated with these intangible assets for the next five years approximating: 2006 - $1,633; 2007 - $1,323; 2008 - $844; 2009 - $572; and 2010 - $231.
7. Deferred financing costs:
                         
        Accumulated   Net
December 31, 2005   Cost   Amortization   Book Value
             
Deferred financing costs
  $ 2,144     $ 96     $ 2,048  
                   
                         
December 31, 2004            
             
Deferred financing costs
  $ 5,763     $ 1,296     $ 4,467  
                   

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The Company expensed unamortized deferred financing fees totaling $3,315 associated with debt facilities which were retired on September 12, 2005 with the proceeds from the Company’s new $580.0 million term loan and revolving credit facilities.
8. Taxes:
      Tax expense (benefit) consisted of:
                           
    2005   2004   2003
             
Domestic:
                       
 
Franchise taxes
  $     $ 171     $ 172  
 
Current income taxes
    11,653       218        
 
Deferred income taxes (benefit)
    18,557       8,015       (594 )
                   
      30,210       8,404       (422 )
Foreign:
                       
 
Capital taxes
          197       344  
 
Current income taxes
    4,070       968       262  
 
Deferred income taxes (benefit)
    (564 )     1,252       1,322  
                   
      3,506       2,417       1,928  
                   
Tax expense (benefit)
  $ 33,716     $ 10,821     $ 1,506  
                   
      The Company operates in several tax jurisdictions. A reconciliation of the U.S. federal income tax rate of 35% (2004 and 2003–34%) to the Company’s effective income tax rate follows:
                           
    2005   2004   2003
             
Expected provision (benefit) for taxes:
  $ 30,787     $ 9,999     $ 1,098  
Increase (decrease) resulting from
                       
 
Foreign tax rate differential
    (698 )     (396 )     (297 )
 
Foreign capital taxes
          197       344  
 
State taxes, net of federal benefit
    2,190       631       172  
 
Non-deductible expenses
    1,169       200       122  
 
Other, net
    268       190       67  
                   
Tax expense (benefit)
  $ 33,716     $ 10,821     $ 1,506  
                   

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The net deferred income tax liability was comprised of the tax effect of the following temporary differences:
                   
    2005   2004
         
Deferred income tax assets:
               
 
Net operating loss
  $ 909     $ 11,062  
 
Intangible assets
    2,781       443  
 
Research and development credits
    1,490       344  
 
Restricted stock compensation costs
    79       18  
             
      5,259       11,867  
 
Less valuation allowance
    (877 )     (877 )
             
      4,382       10,990  
             
Deferred income tax liabilities:
               
 
Property, plant and equipment
    (48,888 )     (33,159 )
 
Goodwill
    (3,243 )     (2,432 )
 
Other
    (4,593 )     (754 )
             
      (56,724 )     (36,345 )
             
Net deferred income tax liability
  $ (52,342 )   $ (25,355 )
             
The net deferred income tax liability consisted of:
                 
    2005   2004
         
Domestic
  $ (45,766 )   $ (18,566 )
Foreign
    (6,576 )     (6,789 )
             
    $ (52,342 )   $ (25,355 )
             
      In assessing the realizability of deferred income tax assets, management considers whether it is more likely than not that some portion or all of the deferred income tax assets will not be realized. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. In order to fully realize the deferred tax asset, the Company will need to generate future taxable income of approximately $15,000 prior to the expiration of the net operating loss carryforwards in 2024.
      The Company has U.S. loss carryforwards of $1,599 at December 31, 2005, compared to $26,023 at December 31, 2004. The Company has a $1,163 foreign non-capital loss carryforward at December 31, 2005, compared to $3,772 at December 31, 2004.
      In 2003, the Company completed a review of the tax basis arising from certain acquisitions which resulted in a reduction to the valuation allowance by $1,400. The reduction in the valuation allowance resulted in a reduction in goodwill attributable to the completion and production services segment.
      No deferred income taxes were provided on approximately $1,700 of undistributed earnings of foreign subsidiaries as of December 31, 2005, as the Company intends to indefinitely reinvest these funds. Upon distribution of these earnings in the form of dividends or otherwise, the Company may be subject to U.S. income taxes and foreign withholding taxes. It is not practical, however, to estimate the amount of

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
taxes that may be payable on the eventual distribution of these earnings after consideration of available foreign tax credits.
9. Bank operating loans:
      At December 31, 2004, the Company had Canadian– and U.S. dollar–syndicated revolving operating credit facilities (see note 10(b)) in place. The Canadian operating facility provided up to C$10,000. The U.S. operating facility line provided a revolving credit facility up to $10,000. Interest was on a grid based on certain financial ratios and ranged from prime–to–prime plus 1.25% per annum. At December 31, 2004, Canadian and U.S. prime were 4.25% and 5.25%, respectively. The facilities were secured by a general security agreement providing a first charge against the Company’s assets. The Canadian and U.S. credit facilities included a commitment fee of 0.25% and 0.375% per annum, respectively, on the average unused portion of the revolving credit facilities.
      The maximum amounts available under these credit facilities were subject to a borrowing base formula based upon trade accounts receivable and inventory. As at December 31, 2004, the maximum available under these combined facilities was limited by the borrowing base formula to $20,536.
      At December 31, 2004, the Company had drawn $15,745 on these operating lines and an additional amount of $6,000 outstanding pursuant to an overnight facility in the United States offset by a corresponding $6,000 of cash on deposit in Canada. As at December 31, 2004, $48 of letters of credit were outstanding.
      On September 12, 2005, the Company retired all amounts outstanding under these bank operating loans with proceeds from borrowings under the new $580,000 term loan and revolving credit facilities, as further described in note 10(a).
10. Long-term debt:
                 
    2005   2004
         
U.S. term loan facility(a)
  $ 418,950     $  
U.S. revolving credit facility(a)
    58,096        
Canadian revolving credit facility(a)
    27,016        
Reducing Canadian term facility(b)
          22,552  
Reducing U.S. term facility(b)
          17,168  
Term loan(c)
          120,650  
Revolving line of credit(c)
          19,850  
Subordinated seller notes(d)
    8,450       3,450  
Term loan(e)
          9,274  
Subordinated note(f)
          4,383  
Capital leases(g)
    1,830       356  
Other(h)
    1,601        
             
      515,943       197,683  
Less: current maturities of long-term debt and capital leases
    (5,953 )     (28,493 )
             
    $ 509,990     $ 169,190  
             

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
 
(a) Concurrent with the consummation of the Combination on September 12, 2005, the Company entered into a syndicated senior secured credit facility (the “Credit Facility”) pursuant to which all bank debt held by each of IPS, CES and IEM was repaid and replaced with the proceeds from the Credit Facility. The Credit Facility was comprised of a $420,000 term loan credit facility that will mature in September 2012, a U.S. revolving credit facility of $130,000 that will mature in September 2010, and a Canadian revolving credit facility of $30,000 that will mature in September 2010. Interest on the Credit Facility is determined by reference to LIBOR plus a margin of 1.25% to 2.75% (dependent on the ratio of total debt to EBITDA, as defined in the agreement) for revolving advances and a margin of 2.75% for term loan advances. Interest on advances under the Canadian revolving facility was calculated at the Canadian Prime Rate plus a margin of 0.25% to 1.75%. Quarterly principal repayments of 0.25% of the original principal amount are required for the term loans commencing December 2005. The Credit Facility contains covenants restricting the levels of certain transactions including: entering into certain loans, the granting of certain liens, capital expenditures, acquisitions, distributions to stockholders, certain asset dispositions and operating leases. The Company was in compliance with all debt covenants under the Credit Facility at December 31, 2005. The Credit Facility is secured by substantially all of the assets of the Company. As of December 31, 2005, the Company had borrowings of $418,950 outstanding under the term loan portion of this facility, which bore interest at 7.28%, with no borrowing capacity available under the term loan. Borrowings outstanding under the U.S. revolving and Canadian revolving portions of this facility at December 31, 2005 were $58,096 and $27,016, respectively, and bore interest at 7.23% and 6.5%, respectively. In addition, there were letters of credit outstanding which totaled $5,519 under the U.S. revolving portion of the facility that further reduced the available borrowing capacity at December 31, 2005.
 
(b) At December 31, 2004, the Company had a syndicated credit facility which included four separate facilities secured by a common security package. The two operating facilities are described in Note 9. The agreement also included a Canadian reducing term facility (“CTF”) and a U.S. reducing term facility (“UTF”). The CTF had been fully drawn and was repayable in equal quarterly installments of C$1,370 and $175. The UTF had also been fully drawn and was repayable in equal quarterly installments of C$954. The facilities were to mature on June 30, 2007 and bore interest from prime plus 0.25% to prime plus 1.50% per annum on a grid based on certain financial ratios. At December 31, 2004, Canadian and U.S. prime were 4.25% and 5.25% (2003 – 4.5% and 4.0%, 2002 – 4.5% and 4.25%), respectively. The Company was in compliance with all of the terms of these facilities at December 31, 2004.
 
Effective February 11, 2005, in conjunction with the acquisition of Parchman Energy Group, Inc., the Company and a group of banks entered into a new credit facility replacing the current credit facility. The new credit facility was comprised of five separate facilities secured by a common security package including a first charge against the Company’s assets. There are two operating facilities ($20,000 and C$15,000), each of which was to mature on February 10, 2008, which replaced the existing operating facilities. There were two reducing term facilities ($20,000 and C$30,000) which were to mature on February 10, 2010 and which required quarterly payments of $1,000 and C$1,500 respectively. Each of these four facilities bore interest from prime plus 0.25% to prime plus 1.50% per annum on a grid based on certain financial ratios. The fifth term facility was in the amount of $35,000, was to mature on February 10, 2011, required quarterly payments of $88, and bore interest at LIBOR plus 3.5%. Each of the three term facilities were drawn in full on February 11, 2005. The credit facilities required maintenance of certain financial ratios and other covenants and were secured by substantially all of the assets of IPS. This facility was retired on September 12, 2005.
 
(c) In November 2003, the Company established a secured $30,600 term loan and an $8,000 secured revolving line of credit. During 2004, the Company amended the term loan and revolving line of credit several times to facilitate the acquisitions described in note 2, which resulted in increasing the Company’s total borrowing capacity to $120,650 and $30,000, respectively, and extension of the

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
maturity dates. At December 31, 2004, the Company did not have any remaining borrowing capacity on the term loan and $10,200 of remaining capacity on the revolving line of credit.
 
Substantially all of CES’s real and personal property and a pledge of the ownership interest of present and future subsidiaries secure both the term loan and the revolving line of credit. The term loan and revolving line of credit bore interest at either the lead bank’s prime rate plus a margin of 1.75% to 2.25% or the LIBOR plus a margin of 2.75% to 3.25%, depending on the Company’s leverage ratio, as defined. The interest rate on the term loan in 2004 averaged 5.75%. The interest rate on the revolving loan in 2004 averaged 6.13%.
 
There are quarterly principal payments on the term loan in the amount of $4,350 with final maturity on August 31, 2009. The revolving line of credit was due on August 31, 2007. The Company must pay a commitment fee in the amount of 0.50% on the unused revolving line of credit capacity.
 
The Company was required to maintain certain financial ratios and other financial conditions. In addition, the Company was prohibited from making certain investments, advances or loans. The term loan and credit agreements restrict substantial asset sales, capital expenditures and cash dividends. The Company was in compliance with all covenants and conditions as of December 31, 2004.
 
During the first quarter of 2005, the Company amended the term loan and revolving loans described above several times which resulted in increased total borrowing capacity and the extension of the maturity dates of the term loan to February 2012 and the revolving line of credit to February 2009. Quarterly principal payments of $350 were required on the term loan. All borrowings under these facilities were retired on September 12, 2005.
 
(d) On February 11, 2005, the Company issued subordinated notes to certain sellers of Parchman common shares. These notes are unsecured, subordinated to all present and future senior debt and bear interest at 6.0% during the first three years of the note, 8.0% during year four and 10.0% thereafter. The notes mature on the earliest of February 11, 2010 or ten days after an initial public offering or change of control. The Company, at its option, may repay the notes at anytime so long as such payment does not result in an event of default under any loan agreement. These subordinated notes, recorded as long-term debt at December 31, 2005, included notes totaling $4,765 which were beneficially held by directors or employees of the Company. In addition, the Company issued subordinated seller notes totaling $3,450 in 2004 related to certain business acquisitions. These notes bear interest at 6% and mature in March 2009.
 
(e) In August 2004, the Company entered into a Senior Secured Agreement (“the Agreement”) with a group of financial institutions with a maximum commitment of $12,000 and a maturity date of August 31, 2008. Quarterly principal payments of $464 are required under the facility. As part of the Agreement, the Company entered into a Revolving Note Agreement (“Revolver”) providing for borrowings of up to $8,000 with a maturity date of August 31, 2007. At December 31, 2004, there were no outstanding borrowings under the Revolver. Pursuant to the Agreement, interest on the borrowings was calculated using a variable base rate plus a margin. The margin ranges from 0.25% to 1.25% for base rate advances and from 2.50% to 3.50% for LIBOR loans depending on IEM’s leverage ratio. The interest rate averaged approximately 5.18% for the four months ended December 31, 2004. In addition to interest, the banks receive various fees, including a commitment fee. The commitment fee varies from 0.375% to 0.50% of average unused commitment amount on the Revolver, depending on IEM’s leverage ratio. The note was subject to restrictive covenants. The Company was in compliance with all covenants during 2004. The Agreement was secured by substantially all of IEM’s assets. This facility was retired on September 12, 2005.
 
(f) On August 31, 2004, the Company entered into a Subordinate Credit Agreement with a maximum term commitment of $20,000 and maturity of August 31, 2009. Principal plus accrued interest was to be due at maturity. Pursuant to the credit agreement, interest on borrowings was calculated using a variable base rate equal to the greater of the agent bank’s Prime Rate or the Federal Funds Rate plus

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
  0.5% plus a margin. The margin ranges from 2.0% to 4.0% depending on IEM’s leverage ratio. The interest rate for the four months ended December 31, 2004 was approximately 7.25%. The note was subject to restrictive covenants. The Company was in compliance with all covenants during 2004. This facility was retired on September 12, 2005.
(g) At December 31, 2005, the Company’s capital leases are collateralized by specific assets and bear interest at various rates averaging 10.30% (2004 – 10.29%).
 
(h) Other includes: (1) a mortgage loan totaling $320 at December 31, 2005 related to property in Wyoming, which requires annual principal payments of approximately $56, accrues interest at 6% and matures in 2012; and (2) loans totaling $1,281 at December 31, 2005 related to equipment purchases with terms of 12 to 36 months and extend through December 2008.
      At December 31, 2005, principal maturities under the Company’s long-term debt facilities (including capital leases) for the next five years were:
         
2006
  $ 5,953  
2007
    5,422  
2008
    4,534  
2009
    7,706  
2010
    94,368  
11. Convertible debentures:
      On May 31, 2000, IPSL, a wholly-owned subsidiary of the Company, issued convertible debentures of C$5,000 maturing June 30, 2005 and convertible into 627,408 shares of common stock at the holders’ option at C$7.97 per share at any time prior to maturity. The debentures were secured by a general security agreement providing a charge against IPSL’s assets, subordinated to any other senior indebtedness, and bore interest at 9% per annum. The chief executive officer of the debenture holder was a director of the Company. The debenture was repaid in full on June 30, 2005.
12. Share capital:
      On September 12, 2005, the Company completed the Combination of CES, IPS and IEM pursuant to which CES and IEM stockholders exchanged all of their common stock for common stock of IPS. The CES stockholders received 19.704 shares of IPS common stock for each share of CES, and the IEM received 19.410 shares of IPS common stock for each share of IEM. Subsequent to the combination, IPS changed its name to Complete Production Services, Inc. In the Combination, the former CES stock was converted into approximately 57.6% of the Company’s common stock, the IPS stock remained outstanding and represented approximately 33.2% of the Company’s common stock and the former IEM stock was converted into approximately 9.2% of the Company’s common shares. The amounts of authorized and issued stock, warrants and options of CES have been adjusted to reflect the exchange ratio of 19.704 per share pursuant to the Combination. The amounts of authorized and issued stock, warrants and options of IEM have been adjusted to reflect the exchange ratio of 19.410 per share pursuant to the Combination.
(a) Authorized:
      On September 12, 2005, the authorized share capital of the Company was increased to 200,000,000 shares of common stock from 24,000,000 shares of common stock with par value of $0.01 per share and to 5,000,000 shares of preferred stock from 1,000 shares of preferred stock with a par value of $0.01 per share.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
(b) Stock Split:
      On December 29, 2005, the Company effected a 2-for-1 split of common stock. As a result, all common stock and per share data, as well as data related to other securities including stock warrants, restricted stock and stock options, have been adjusted retroactively to give effect to this stock split for all periods presented within the accompanying financial statements, except par value which remained at $0.01 per share, resulting in an insignificant reclassification between common stock and additional paid-in capital.
(c) Dividend:
      On September 12, 2005, the Company paid a dividend of $2.62 per share for an aggregate payment of approximately $146,900 to stockholders of record on that date. We are also obligated to issue up to an aggregate of approximately 1,200,000 shares of our common stock as contingent consideration based on certain operating results of the companies we have previously acquired, and we have agreed to make additional cash payments (up to $3,100) in respect of such contingent shares ultimately issued in the amount of the dividend that would have been paid on such shares if those shares had been issued prior to the payment of the dividend.
(d) Warrants:
      On May 23, 2001, the Company issued a warrant to its major shareholder, SCF-IV, L.P. (“SCF”), to purchase up to 4,000,000 shares of the Company’s common stock at an exercise price of $5.00 per share any time through May 23, 2011. The warrant was issued as a source of future financing for the Company’s growth. In 2001 and 2004, SCF purchased 740,000 shares and 400,000 shares, respectively, under the warrant. On February 9, 2005, SCF purchased another 2,000,000 shares under the warrant. The warrant was cancelled on September 12, 2005.
      In November 2003, the Company issued a warrant to SCF to purchase up to 13,792,800 shares of the Company’s common stock at an exercise price of $2.54 per share. This warrant was exercised in full during 2004.
      In August 2004, the Company issued a warrant to SCF to purchase up to 6,211,200 shares of the Company’s common stock at an exercise price of $2.58 per share at any time through August 31, 2007 and a warrant to one of the Company’s minority stockholders to purchase up to 970,500 shares of the Company’s common stock at an exercise price of $2.58 per share at any time through August 31, 2007. These warrants were cancelled on September 12, 2005.
      Pursuant to the Subordinate Credit Agreement (note 10(f)), the Company issued detachable warrants to the lenders to purchase up to 71,818 shares of the Company’s common stock at $2.58 per share at any time through August 31, 2007. These warrants were cancelled on September 12, 2005.
      Also pursuant to the Subordinate Credit Agreement (note 10(f)), the Company issued detachable warrants to the lenders to purchase up to 48,526 shares of the Company’s common stock at $0.01 per share at any time through August 31, 2007. The fair value of these warrants, $125,000, was recorded as additional paid-in capital and as a discount on the liability under the subordinate credit agreement. These warrants were exercised on September 12, 2005.
(e) Employee stock incentive plan:
      Following the Combination, the Company maintains each of the options plans previously maintained by IPS, CES and IEM. Under the three option plans, the options could be granted to employees, officers

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
and directors to purchase up to 3,000,000 common shares, 1,477,800 common shares (increased to 2,364,480 during 2005) and 776,400 common shares, respectively. The exercise price of each option is based on the fair value of the individual company’s stock at the date of grant. Options may be exercised over a 5-year period and generally a third of the options vest on each of the first three anniversaries from the grant date.
                 
    Options Outstanding
     
        Weighted
        Average
        Exercise
    Number   Price
         
Balance at December 31, 2002
    659,888       5.39  
Granted
    196,414       3.95  
Exercised
    (56,190 )     5.70  
Cancelled
    (43,064 )     5.70  
             
Balance at December 31, 2003
    757,048       4.97  
Granted
    1,118,856       4.14  
Exercised
    (81,180 )     2.29  
Cancelled
    (16,012 )     5.70  
             
Balance at December 31, 2004
    1,778,712     $ 4.58  
             
      Pursuant to the Combination, upon payment of the dividend of $2.62 per share as described above at (c), the terms of all options outstanding at that time were adjusted to offset the decrease in the Company’s per share price attributable to the dividend. The result of this adjustment was applied to the options outstanding at December 31, 2004, resulting in an increase in the number of options outstanding to 2,259,396 and a reduction of the average exercise price to $3.60.
                 
    Options Outstanding
     
        Weighted
        Average
        Exercise
    Number   Price
         
Balance at December 31, 2004, adjusted for dividend
    2,259,396     $ 3.60  
Granted
    1,746,309       7.39  
Exercised
    (15,082 )     4.11  
Cancelled
    (478,179 )     4.15  
             
Balance at December 31, 2005
    3,512,444     $ 5.42  
             

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
                                         
    Options Outstanding   Options Exercisable
         
        Weighted   Weighted       Weighted
    Outstanding at   Average   Average   Exercisable at   Average
    December 31,   Remaining   Exercise   December 31,   Exercise
Range of Exercise Price   2005   Life (months)   Price   2005   Price
                     
$2.00-2.20
    763,154       40     $ 2.04       304,443     $ 2.06  
$3.94
    85,782       12       3.94       85,782       3.94  
$4.49-4.80
    1,328,100       41       4.67       536,622       4.57  
$5.01
    223,944       48       5.01       70,414       5.01  
$6.59-6.69
    630,196       111       6.68              
$11.66
    481,268       117       11.66              
                               
      3,512,444       64     $ 5.42       997,261     $ 3.78  
                               
      The Company adopted SFAS No. 123R on January 1, 2006. This pronouncement requires the Company to measure the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award, with limited exceptions, by using an option-pricing model to determine fair value. As permitted by SFAS No. 123R, the Company will continue to account for stock-based compensation for grants prior to September 30, 2005, the date of the Company’s initial public filing with the SEC, using the minimum value method prescribed by APB No. 25, and will provide the required pro forma disclosures. For grants issued between October 1, 2005 and December 31, 2005 (prior to adoption of SFAS No. 123R), the Company will utilize the modified prospective transition method to record expense associated with these stock-based instruments and to provide the required pro forma disclosures. For grants awarded on or after January 1, 2006, the Company will utilize the prospective transition method, whereby the Company will recognize expense associated with new awards of stock-based compensation, as determined using a Black-Scholes pricing model over the expected term of the options. For stock options outstanding as of December 31, 2005, the Company expects to record compensation expense of $844 over the remaining term of the options, of which $307 would be recognized in 2006. Future stock option grants will result in additional compensation expense.
(f) Per share amounts:
      The weighted average number of common shares outstanding used in calculating basic and diluted earnings per share at December 31, 2005 were 46,602,504 (2004 – 29,548,312; 2003 – 13,675,096) and 50,655,930 (2004 – 30,083,490; 2003 – 14,109,094), respectively. The reconciling items between basic and diluted weighted average common shares outstanding included the dilutive impact of outstanding restricted stock, stock options, convertible debt and warrants. The Company excluded the impact of anti-dilutive potential common shares from the calculation of diluted weighted average shares for the years ended December 31, 2005 and 2004. If these potential common shares were included in the calculation, diluted weighted average shares would have been 50,775,802 and 30,318,802 for the years ended December 31, 2005 and 2004, respectively, with no impact on diluted earnings per share as presented. The Company had no anti-dilutive potential common shares for the year ended December 31, 2003 except as related to convertible debentures discussed below.
      In 2004, interest expense, net of tax, of $234 (2003 – $209) on the convertible debentures (see note 11) was added back to the numerator in calculating diluted earning per share when the impact, if converted, is dilutive. In 2004 and 2003, the impact of conversion of the convertible debentures would have been anti-dilutive.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
13. Supplemental cash flow information:
                         
    2005   2004   2003
             
Change in:
                       
Trade accounts receivable
  $ (69,755 )   $ (20,585 )   $ (687 )
Inventory
    (18,346 )     (7,936 )     (1,959 )
Prepaid expenses and other current assets
    (4,903 )     (3,480 )     (614 )
Accounts payable
    18,647       5,032       1,635  
Accrued liabilities
    21,955       11,094       5,366  
Notes payable
          1,069        
                   
    $ (52,402 )   $ (14,806 )   $ 3,741  
                   
Cash interest paid
  $ 23,718     $ 6,756     $ 2,415  
Cash taxes paid
  $ 15,138     $ 1,136     $ 778  
Common stock issued by controlling stockholder for acquisitions
  $ 20,118     $ 3,041     $ 840  
Acquisition of minority interest
  $ 93,792              
Notes issued for acquisitions
  $ 5,000     $ 4,510        
Notes issued for equipment
  $ 1,281              
Additional acquisition consideration accrued
  $ 5,800              
Capital expenditures in accounts payable
  $ 792              
Non-cash assets as acquisition consideration
  $ 2,899              
14. Segment information:
      SFAS No. 131, Disclosure About Segments of an Enterprise and Related Information, establishes standards for the reporting of information about operating segments, products and services, geographic areas, and major customers. The method of determining what information to report is based on the way management organizes the operating segments within the Company for making operational decisions and assessments of financial performance. The Company evaluates performance and allocates resources based on net income (loss) before interest expense, taxes, depreciation and amortization and minority interest (“EBITDA”). The calculation of EBITDA should not be viewed as a substitute to calculations under U.S. GAAP, in particular not net earnings. EBITDA calculated by the Company may not be comparable to another company.
      The Company has three reportable operating segments: completion and production services (“C&PS”), drilling services and product sales, and three geographic regions: the United States, Canada and International. The accounting policies of the segments are the same as those described in note 1. Inter-segment transactions are accounted for on a cost-recovery basis.

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Table of Contents

COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
Operational segments:
                                         
        Drilling   Product        
Year Ended December 31, 2005   C&PS   Services   Sales   Corporate   Total
                     
Revenue from external customers
  $ 510,304     $ 129,117     $ 118,305     $     $ 757,726  
EBITDA, as defined
  $ 119,171     $ 44,393     $ 18,444     $ (20,745 )   $ 161,263  
Depreciation and amortization
  $ 40,149     $ 5,666     $ 1,580     $ 1,445     $ 48,840  
                               
Operating income (loss)
  $ 79,022     $ 38,727     $ 16,864     $ (22,190 )   $ 112,423  
Capital expenditures
  $ 81,086     $ 38,574     $ 4,382     $ 3,173     $ 127,215  
December 31, 2005
                                       
Segment assets
  $ 639,856     $ 118,751     $ 65,636     $ 113,410     $ 937,653  
                                         
        Drilling   Product        
Year Ended December 31, 2004   C&PS   Services   Sales   Corporate   Total
                     
Revenue from external customers
  $ 194,953     $ 44,474     $ 81,320     $     $ 320,747  
EBITDA, as defined
  $ 38,349     $ 10,093     $ 12,924     $ (2,869 )   $ 58,497  
Depreciation and amortization
  $ 16,750     $ 2,737     $ 907     $ 1,222     $ 21,616  
                               
Operating income (loss)
  $ 21,599     $ 7,356     $ 12,017     $ (4,091 )   $ 36,881  
Capital expenditures
  $ 32,004     $ 11,840     $ 2,944     $ 116     $ 46,904  
                                         
December 31, 2004                    
                     
Segment assets
  $ 384,014     $ 72,839     $ 53,751     $ 4,549     $ 515,153  
                                         
        Drilling   Product        
Year Ended December 31, 2003   C&PS   Services   Sales   Corporate   Total
                     
Revenue from external customers
  $ 65,025     $ 2,707     $ 35,547     $     $ 103,279  
EBITDA, as defined
  $ 9,134     $ 712     $ 4,951     $ (1,233 )   $ 13,564  
Depreciation and amortization
  $ 6,147     $ 130     $ 644     $ 727     $ 7,648  
                               
Operating income (loss)
  $ 2,987     $ 582     $ 4,307     $ (1,960 )   $ 5,916  
Capital expenditures
  $ 7,474     $ 2,623     $ 987     $     $ 11,084  

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      The following table summarizes the changes in the carrying amount of goodwill by segment for the three-year period ended December 31, 2005:
                                         
        Drilling   Product        
    C&PS   Services   Sales   Corporate   Total
                     
Balance at December 31, 2002
  $ 33,870     $     $ 1,814     $     $ 35,684  
Acquisitions
    9,471       4,940       4,062             18,473  
Tax valuation adjustment
    (1,400 )                       (1,400 )
Foreign currency translation
    6,515             24             6,539  
                               
Balance at December 31, 2003
    48,456       4,940       5,900             59,296  
Acquisitions
    73,101       10,082                   83,183  
Contingency adjustment
    250                         250  
Foreign currency translation
    2,390             330             2,720  
                               
Balance at December 31, 2004
    124,197       15,022       6,230             145,449  
Acquisitions
    50,089             1,610             51,699  
Purchase of minority interest
                      93,792       93,792  
Accrue contingent consideration
    5,800                         5,800  
Contingency adjustment and other
    263                         263  
Foreign currency translation
    1,164             130             1,294  
                               
Balance at December 31, 2005
  $ 181,513     $ 15,022     $ 7,970     $ 93,792     $ 298,297  
                               
      The tax valuations adjustment of $1,400 was recorded to properly reflect management’s estimate of the net realizable deferred tax assets associated with acquisitions made prior to December 31, 2003, based upon a review of the tax provision as of that date.
Geographic information:
                                 
    United       Other    
Year Ended December 31, 2005   States   Canada   International   Total
                 
Revenue by sale origin to external customers
  $ 609,939     $ 106,261     $ 41,526     $ 757,726  
Income before taxes and minority interest
  $ 74,946     $ 7,173     $ 5,843     $ 87,962  
December 31, 2005
                               
Long-lived assets
  $ 597,834     $ 85,685     $ 6,648     $ 690,167  
                                 
    United       Other    
Year Ended December 31, 2004   States   Canada   International   Total
                 
Revenue by sale origin to external customers
  $ 231,509     $ 73,743     $ 15,495     $ 320,747  
Income before taxes and minority interest
  $ 22,786     $ 4,048     $ 2,576     $ 29,410  
                                 
December 31, 2004                
                 
Long-lived assets
  $ 306,140     $ 79,662     $ 3,398     $ 389,200  

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
                                 
    United       Other    
Year Ended December 31, 2003   States   Canada   International   Total
                 
Revenue by sale origin to external customers
  $ 28,129     $ 62,376     $ 12,774     $ 103,279  
Income (loss) before taxes and minority interest
  $ (771 )   $ 2,211     $ 1,789     $ 3,229  
      The Company does not have revenue from any single customer which amounts to 10% or more of the Company’s total revenue.
15. Financial instruments:
(a) Interest rate risk:
      The Company manages its exposure to interest rate risks through a combination of fixed and floating rate borrowings. At December 31, 2005, 98% of long-term debt was in floating rate borrowings.
(b) Foreign currency rate risk:
      The Company is exposed to foreign currency fluctuations in relation to its foreign operations. In 2005, approximately 14% of the Company’s operations were conducted in Canadian dollars and the related balance sheet accounts were denominated in Canadian dollars.
(c) Credit risk:
      A significant portion of the Company’s trade accounts receivable are from companies in the oil and gas industry, and as such, the Company is exposed to normal industry credit risks. The Company evaluates the credit-worthiness of its major new and existing customers’ financial condition and generally does not require collateral.
16. Commitment and contingences:
      The Company has non-cancelable operating lease commitments for equipment and office space. These commitments for the next five years were as follows at December 31, 2005:
         
2006
  $ 15,380  
2007
    12,859  
2008
    8,609  
2009
    4,766  
2010
    3,109  
       
    $ 44,723  
       
      In 2005, operating lease payments expensed were approximately $10,110 (2004 – $6,585; 2003 – $4,031).
      The Company is subject to legal procedures and claims, either asserted or unasserted, in the ordinary course of business. While the outcome of these claims cannot be predicted with certainty, management does not believe that the outcome of any of these legal matters will have a material adverse effect on its combined financial position, results of operations or cash flows.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
17. Related party transactions:
      The Company believes all transactions with related parties have the terms and conditions no less favorable to the Company as transactions with unaffiliated parties.
      The Company has entered into lease agreements for properties owned by employees and directors of the Company. The leases expire at different times through December 2016. In 2005, the total lease expense pursuant to these leases was $2,976 (2004 – $1,439; 2003 – $151).
      In connection with CES’ acquisition of Hamm Co. in 2004, CES entered into that certain Strategic Customer Relationship Agreement with Continental Resources, Inc. (“CRI”). By virtue of the Combination, through a subsidiary, the Company is now party to such agreement. The agreement provides CRI the option to engage a limited amount of the Company’s assets into a long-term contract at market rates. Mr. Hamm is a majority owner of CRI and serves as a member of the Company’s board of directors.
      The Company provided services to companies that are majority-owned by directors of the Company during 2005 which aggregate $21,724, of which $21,255 was sold to CRI (2004 – $2,680; 2003 – $620) and $469 was sold to other companies. The Company purchased services from companies that are majority-owned by its directors during 2005 totaling $2,164, of which $2,034 was purchased from CRI and $130 was purchased from other companies. At December 31, 2005, the Company’s trade receivables and trade payables included amounts from CRI of $3,544 and $130, respectively.
      The Company provided services totaling $8,794 in 2005 to companies majority-owned by officers of the Company or its subsidiaries, of which $7,804 was sold to HEP Oil (“HEP”) and $990 was sold to other companies. Purchases of services from companies majority-owned by these officers totaled $5,149, of which $598 related to HEP, $1,390 related to other companies owned by the same officer, $2,805 related to companies owned by an officer of Parchman and $356 related to other companies. At December 31, 2005, the Company’s trade receivables included amounts from HEP of $859. There were no amounts due to HEP at December 31, 2005.
      The Company provided services totaling $1,910 in 2005 to Laramie Energy LLC (“Laramie”), a company for which one of the Company’s directors serves as an officer. At December 31, 2005, the Company’s trade receivables included $457 due from Laramie.
      In addition, the Company provided services totaling $1,423 and purchased services totaling $2,576 from companies that formerly employed current officers of Complete or for which certain directors of the Company currently serve on the customer’s board of directors.
      Effective December 1, 2002, the Company entered into a management services agreement with an affiliate of its major shareholder. This agreement provides for monthly payments of $20 for services rendered. In 2004, $60 (2003 – $240) was expensed pursuant to this agreement. This agreement was terminated March 31, 2004. Effective November 7, 2003, the Company entered into a financial advisory services agreement with an affiliate of its major shareholder, which provided for an upfront fee of $250 and quarterly payments of $31. This agreement was cancelled effective September 12, 2005. Effective August 14, 2004, the Company entered into a financial advisory services agreement with an affiliate of its major shareholder pursuant to which it paid fees of $1,600 in conjunction with the Company’s 2004 acquisitions, and management fees of $350 during 2004. This agreement was cancelled effective September 12, 2005.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      In 2003, the Company purchased equipment with aggregate value of $2,378 from a company in which the Company’s major shareholder has an equity interest. The Company’s major shareholder no longer holds an equity interest in this equipment supplier.
      The Company is obligated to pay employees an aggregate principal amount of $8,450 pursuant to subordinated promissory notes issued in connection with acquisitions in 2005 and 2004 (see note 10(d)). Certain of these employees are officers of the Company’s subsidiaries.
      On December 1, 2001, Bison Oilfield Tools, Ltd. (“Bison”), and PEG, a subsidiary of IPS, entered into a lease agreement pursuant to which PEG leases real property from Bison. A former director of IPS controls Bison as the president of its two general partners. IPS is required to pay Bison $4 per month until December 2006, the date on which the lease terminates.
      Premier Integrated Technologies Ltd. (“PIT”), a subsidiary of IPS, purchased $819 of machining services from a company controlled by employees of PIT during the year ended December 31, 2005.
      On September 29, 2005, the Company entered into an Asset Purchase Agreement with Spindletop and Mr. Schmitz. Pursuant to the agreement, the Company purchased the assets of Spindletop in exchange for approximately $200 cash and 90,364 shares of the Company’s common stock. Mr. Schmitz is a member of our key operational management.
18. Retirement plans:
      The Company maintains defined contribution retirement plans for substantially all of its U.S. and Canadian employees who have completed six months of service. Employees may voluntarily contribute up to a maximum percentage of their salaries to these plans subject to certain statutory maximum dollar values. The maximums range from 20% to 60%, depending on the plan. The Company makes matching contributions at 25% – 50% of the first 6% or 7% of the employee’s contributions, depending on the plan. The employer contributions vest immediately with respect to the Canadian RRSP plan and vest at varying rates under the U.S. 401(k) plans. Vesting ranges from immediately to a graduated scale with 100% vesting after five years of service.
      In 2005, the Company recognized an expense of $2,039 (2004 – $853; 2003 – $331) related to its various defined contribution plans.
      The Company provides a seniority premium benefit to substantially all of its Mexican employees, through a subsidiary, in accordance with Mexican law. The benefit consists of a one-time payment equivalent to 12-days wages for each year of service (calculated at the employee’s current wage rate but not exceeding twice the minimum wage), payable upon voluntary termination after fifteen years of service, involuntary termination or death. In addition, Complete provides statutory mandated severance benefits to substantially all Mexican employees, which includes a one-time payment of three months wages, plus 20-days wages for each year of service, payable upon involuntary termination without cause and charged to income as incurred. The Company’s liability pursuant to these benefit arrangements in Mexico for 2005 was approximately $280.
19. Recent accounting pronouncements:
      In November 2004, the FASB issued SFAS No. 151, “Inventory Costs.” SFAS No. 151 amends the guidance in Accounting Research Bulletin No. 43, Chapter 4, “Inventory Pricing,” to clarify the accounting for abnormal amounts of idle facility expense, freight, handling costs and wasted material (spoilage), and generally requires that these amounts be expensed in the period that the cost arises, rather than being included in the cost of inventory, thereby requiring that the allocation of fixed production overheads to the costs of conversion be based on normal capacity of the production facilities. SFAS

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
No. 151 becomes effective for inventory costs incurred during fiscal years beginning after June 15, 2005, but earlier application is permitted. The Company adopted SFAS No. 151 as of January 1, 2006, with no material impact on its financial position, results of operations or cash flows.
      In December 2004, the FASB issued SFAS No. 153, “Exchanges of Nonmonetary Assets.” SFAS No. 153 amends current guidance related to the exchange on nonmonetary assets as per APB Opinion No. 29, “Accounting for Nonmonetary Transactions,” to eliminate an exception that allowed exchange of similar nonmonetary assets without determination of the fair value of those assets, and replaced this provision with a general exception for exchanges of nonmonetary assets that do not have commercial substance. A nonmonetary exchange has commercial substance if the future cash flows of the entity are expected to change significantly as a result of the exchange. SFAS No. 153 becomes effective for nonmonetary asset exchanges occurring in fiscal periods beginning after June 15, 2005. The Company adopted SFAS No. 153 as of January 1, 2006, with no material impact on its financial position, results of operations or cash flows.
      In December 2004, the FASB issued SFAS No. 123R, “Share-Based Payment,” which revises SFAS No. 123 and supercedes APB No. 25. SFAS No. 123R will require the Company to measure the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award, with limited exceptions. The fair value of the award will be remeasured at each reporting date through the settlement date, with changes in fair value recognized as compensation expense of the period. Entities should continue to use an option-pricing model, adjusted for the unique characteristics of those instruments, to determine fair value as of the grant date of the stock options. SFAS No. 123R became effective for public companies as of the beginning of the fiscal year after June 15, 2005. The Company adopted SFAS No. 123R on January 1, 2006. See note 12(e) for discussion of the impact of adopting SFAS No. 123R on the Company’s financial position, results of operations and cash flows.
      In May 2005, the FASB issued SFAS No. 154, “Accounting Changes and Error Corrections, a Replacement of APB Opinion No. 20 and FASB Statement No. 3.” SFAS No. 154 requires retrospective application of changes in accounting principle to prior periods’ financial statements, rather than the use of the cumulative effect of a change in accounting principle, unless impracticable. If impracticable to determine the impact on prior periods, then the new accounting principle should be applied to the balances of assets and liabilities as of the beginning of the earliest period for which retrospective application is practicable, with a corresponding adjustment to equity, unless impracticable for all periods presented, in which case prospective treatment should be applied. SFAS No. 154 applies to all voluntary changes in accounting principle, as well as those required by the issuance of new accounting pronouncements if no specific transition guidance is provided. SFAS No. 154 does not change the previously-issued guidance for reporting a change in accounting estimate or correction of an error. SFAS No. 154 became effective for accounting changes and corrections of errors made in fiscal years beginning after December 15, 2005. The Company adopted SFAS No. 154 on January 1, 2006, and will apply its provisions, as applicable, to future reporting periods.
20. Subsequent events:
(a) Acquisitions:
      On January 3, 2006, the Company acquired substantially all of the operating assets of Outpost Office Inc. (“Outpost”), a Grand Junction, Colorado oilfield equipment rental company, for $6,535 in cash. The purchase price allocation has not yet been finalized. The Company will include the operating results of Outpost in the completion and production services segment from the date of acquisition.

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COMPLETE PRODUCTION SERVICES, INC.
Notes to Consolidated Financial Statements — (Continued)
Years Ended December 31, 2005, 2004 and 2003
(In thousands, except share and per share data)
      On January 25, 2006, the Company acquired all the equity interests of The Rosel Company (“Rosel”), a cased-hole and open-hole electric-line business based in Liberal, Kansas, with operations in Kansas and Oklahoma, for approximately $13,900 in cash. The purchase price allocation has not yet been finalized. The Company expects this acquisition to extend its presence in the Mid-continent region and enhance its completion and production services business. Rosel’s operating results will be included in the completion and production services segment from the date of acquisition.
  (b) Earn-out Agreements:
      Pursuant to earn-out agreement with the former owners and employees of Double Jack, MGM and Parchman, the Company expects to issue approximately 1,200,000 shares of its common stock during the first quarter of 2006. The underlying agreements state that the shares are issuable based upon financial results, a specified number of days following an audit by the Company’s independent registered public accountants. If the shares were issued at December 31, 2005, the Company would record additional goodwill associated with these earn-out provisions totaling approximately $24,300, with an offsetting credit to additional paid-in capital. In addition, the recipients would be entitled to approximately $3,200 associated with the dividend paid to all stockholders at the date of the Combination, or $2.62 per share, as well as cash consideration of approximately $2,600. The Company has accrued $5,800 related to these cash commitments at December 31, 2005, with an offsetting adjustment to goodwill.
(c) Financing of Insurance Premiums:
      On January 5, 2006, the Company entered into a note agreement with its insurance broker to finance annual insurance premiums for the policy year beginning December 1, 2005 through November 31, 2006. As of December 31, 2005, the Company has recorded a note payable totaling $14,584 and an offsetting prepaid asset which includes a broker’s fee of $600. The prepaid asset will be amortized to expense over the policy term. In addition, the Company expects to incur finance charges totaling $268 as interest expense related to this arrangement over the policy term.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors and Owners
BSI Companies:
      We have audited the combined balance sheets of BSI Companies (the “Company”) as of November 6, 2003 and December 31, 2002, and the related statements of earnings, owners’ equity and cash flows for the period from January 1, 2003 through November 6, 2003 and for the year ended December 31, 2002. These combined financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.
      We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
      In our opinion, the combined financial statements referred to above present fairly, in all material respects, the financial position of BSI Companies as of November 6, 2003 and December 31, 2004, and the results of their operations and their cash flows for the period from January 1, 2003 through November 6, 2003 and for the year ended December 31, 2002, in conformity with accounting principles generally accepted in the United States of America.
  /s/ Grant Thornton LLP
 
 
Houston, Texas
February 1, 2005

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BSI COMPANIES
Combined Balance Sheets
                     
    November 6,   December 31,
    2003   2002
         
ASSETS
CURRENT ASSETS
               
 
Cash and cash equivalents
  $ 22,124     $ 369,224  
 
Accounts receivable, net of allowance for doubtful accounts of $157,218 and $110,606
    7,245,632       5,351,266  
 
Notes receivable
    534,886       803,525  
 
Investment in partnership
          294,669  
 
Inventory
    4,413,285       4,691,575  
 
Prepaid expenses
    49,479       166,499  
             
   
Total current assets
    12,265,406       11,676,758  
PROPERTY, PLANT AND EQUIPMENT, net
    23,950,811       10,232,776  
GOODWILL
    375,555        
             
   
TOTAL ASSETS
  $ 36,591,772     $ 21,909,534  
             
 
LIABILITIES AND OWNERS’ EQUITY
CURRENT LIABILITIES
               
 
Current maturities of long-term debt
  $ 72,538     $ 255,560  
 
Accounts payable
    3,700,569       3,164,249  
 
Accrued liabilities
    1,254,799       569,201  
 
Note payable – shareholder
           
 
Lines of credit
    3,190,000       2,785,000  
             
   
Total current liabilities
    8,217,906       6,774,010  
LONG-TERM DEBT, less current maturities
          252,334  
MINORITY INTEREST IN SUBSIDIARY
    171,888       9,675  
COMMITMENTS AND CONTINGENCIES
           
OWNERS’ EQUITY
               
 
Paid-in capital
    11,757,909       8,207,336  
 
Retained earnings
    16,444,069       6,666,179  
             
   
Total owners’ equity
    28,201,978       14,873,515  
             
   
TOTAL LIABILITIES AND OWNERS’ EQUITY
  $ 36,591,772     $ 21,909,534  
             
The accompanying notes are an integral part of these statements.

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BSI COMPANIES
Combined Statements of Earnings
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
                     
    2003   2002
         
REVENUES
  $ 49,119,656     $ 33,962,689  
 
OPERATING EXPENSES
               
 
Costs of goods and services
    30,188,568       22,963,942  
 
General and administrative expenses
    2,035,329       1,643,842  
 
Taxes and insurance
    327,315       356,284  
 
Depreciation
    1,525,022       726,937  
 
Salaries and employee benefits
    3,962,819       3,982,169  
 
Shop and automobile expenses
    1,040,867       1,740,998  
             
   
Total operating expenses
    8,891,352       8,450,230  
             
OPERATING INCOME
    10,039,736       2,548,517  
OTHER INCOME, net
    39,523       81,462  
INTEREST EXPENSE
    (139,156 )     (47,668 )
MINORITY INTEREST IN NET EARNINGS OF SUBSIDIARY
    (162,213 )     (9,675 )
             
   
NET EARNINGS
  $ 9,777,890     $ 2,572,636  
             
The accompanying notes are an integral part of these statements.

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BSI COMPANIES
Combined Statement of Owners’ Equity
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
                           
    Paid-in        
    capital   Retained earnings   Total owners’ equity
             
Balance at January 1, 2002
  $ 5,880,320     $ 4,093,543     $ 9,973,863  
Capital contributions:
                       
 
Bell Supply I, LP
    266,015             266,015  
 
Shale Tank Truck, LP
    2,061,001             2,061,001  
Net earnings
          2,572,636       2,572,636  
                   
Balance at December 31, 2002
    8,207,336       6,666,179       14,873,515  
Capital contributions:
                       
 
BSI Holdings, L.P. and BSI Holdings Management LLC
    3,376,983             3,376,983  
 
Acquire New Tejas, L.L.C. (50% Interest)
    173,590             173,590  
Net earnings
          9,777,890       9,777,890  
                   
Balance at November 6, 2003
  $ 11,757,909     $ 16,444,069     $ 28,201,978  
                   
The accompanying notes are an integral part of these statements.

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BSI COMPANIES
Combined Statements of Cash Flows
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
                       
    2003   2002
         
Cash flows from operating activities
               
 
Net earnings
  $ 9,777,890     $ 2,572,636  
 
Adjustments to reconcile net earnings to net cash used in operating activities
               
   
Minority interest in net earnings of subsidiaries
    162,213       9,675  
   
Equity earnings in investment
          (26,291 )
   
Depreciation
    1,525,022       726,937  
   
Gain on sale of equipment
    16,268       3,884  
   
Change in assets and liabilities
               
     
Increase in accounts receivable
    (1,894,366 )     (790,379 )
     
Decrease in prepaid expenses and other
    117,020       320,305  
     
Decrease (increase) in notes receivable
    268,639       (372,927 )
     
Decrease (increase) in inventory
    278,290       (1,787,879 )
     
Increase in accounts payable and accrued expenses
    1,221,918       978,555  
             
     
Net cash provided by operating activities
    11,472,894       1,634,516  
Cash flows from investing activities
               
 
Acquisition of Western Bentonite, net of cash acquired
    (375,555 )      
 
Purchase of equipment and improvements
    (15,209,054 )     (5,897,181 )
 
Proceeds from sale of equipment and improvements
    244,398       59,789  
 
Investment in partnership
          (29,295 )
             
   
Net cash used in investing activities
    (15,340,211 )     (5,866,687 )
Cash flows from financing activities
               
 
Net advances in lines of credit
    405,000       1,285,000  
 
Proceeds on long-term debt
    2,156,629       388,800  
 
Payments on long-term debt
    (2,591,985 )     (307,133 )
 
Contributions from partners
    3,550,573       2,327,016  
             
   
Net cash provided by financing activities
    3,520,217       3,693,683  
             
Net decrease in cash and cash equivalents
    (347,100 )     (538,488 )
Cash and cash equivalents at beginning of period
    369,224       907,712  
             
Cash and cash equivalents at end of period
  $ 22,124     $ 369,224  
             
The accompanying notes are an integral part of these statements.

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BSI COMPANIES
Notes to Combined Financial Statements
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
NOTE A – NATURE OF OPERATIONS
      BSI Companies (“BSI”) is an integrated well site services provider with operations in north and east Texas. BSI provides a wide range of services to the oil and gas exploration industry, including contract drilling, well servicing, fluid handling, well site rentals, materials and supplies and other support services.
      BSI’s business depends, to a large degree, on the level of spending by oil and gas companies for exploration, development and production activities. Therefore, a sustained increase or decrease in the price of natural gas or oil, which could have a material impact on exploration, development and production activities, also could materially affect our financial position, results of operations and cash flows.
NOTE B – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
1.     Basis of Presentation
      The combined financial statements of BSI include entities under common control that were acquired by SCF-IV, L.P. through its majority-ownership interest in Complete Energy Services, Inc. on November 7, 2003. At November 6, 2003, BSI includes the following entities:
  •  BSI Holdings, LP
 
  •  BSI Holdings Management, LLC
 
  •  Bell Supply I, LP
 
  •  Red River Well Service Ltd. (dba’s Mercer Well Service, Brammer Supply, Basin Tool)
 
  •  Shale Tank Truck, L.P.
 
  •  New Tejas, L.L.C.
 
  •  Price Pipeline Construction, Ltd. (50% interest)
      As of January 1, 2003, a common group of individuals and related entities owned 100% of BSI Holdings, LP and BSI Holdings Management, LLC (the “Controlling Entities”). For the period January 1, 2003 through November 6, 2003, the Controlling Entities owned 100% of Bell Supply I, LP; Red River Well Service Ltd. and Shale Tank Truck, L.P. Operations of Brammer Supply, Inc. were transferred to Bell Supply I, LP on January 1, 2003. The Controlling Entities acquired the assets of Felderhoff Drilling and the accounts of Western Bentonite as of January 1, 2003, and acquired a remaining 50% ownership in New Tejas, L.L.C., an entity that was accounted for under the equity method in 2002. Price Pipeline Construction, Ltd. was consolidated in 2003, with a 50% ownership interest held by a related party shown as minority interest.
      For the year ended December 31, 2002; Bell Supply I, LP; Red River Well Service Ltd. and Shale Tank Truck, L.P., as well as an equity investment in New Tejas, L.L.C. and a 50% ownership interest in Price Pipeline Construction, Ltd. were managed by an individual with a significant equity interest in each. The operations of these entities were combined for the year ended December 31, 2002 for comparative presentation with 2003 results.
      All intercompany accounts among the entities in BSI were eliminated for the year ended December 31, 2002 and the period January 1, 2003 through November 6, 2003.

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BSI COMPANIES
Notes to Combined Financial Statements – (Continued)
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
2. Use of Estimates
      The preparation of financial statements in conformity with accounting principles generally accepted in the U.S. requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.
3.            Cash and Cash Equivalents
      BSI considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
4.            Inventory
      Inventory, which is stated at the lower of average cost or market, consists primarily of materials and supplies held for resale.
5.            Property, Plant and Equipment
      Property, plant and equipment, including renewals and betterments, are stated at cost, while maintenance and repairs are expensed currently. Depreciation on our buildings, drilling rigs, well-servicing rigs, oilfield hauling and mobile equipment, and other machinery and equipment is computed using the straight-line method over the estimated useful life of the asset after provision for salvage value (buildings – 20 years; drilling rigs – 20 years; well-servicing rigs – 25 years; oilfield hauling and mobile equipment and other machinery and equipment – 3 to 10 years). Upon retirement or other disposal of fixed assets, the cost and related accumulated depreciation are removed from the respective accounts and any gains or losses are included in our results of operations.
      BSI reviews our assets for impairment when events or changes in circumstances indicate that the net book value of property, plant and equipment may not be recovered over its remaining service life. Provisions for asset impairment are charged to income when the sum of estimated future cash flows, on an undiscounted basis, is less than the asset’s net book value. Actual impairment charges are recorded using an estimate of discounted future cash flows. The determination of future cash flows requires us to estimate day rates and utilization in future periods, and such estimates can change based on market conditions, technological advances in the industry or changes in regulations governing the industry. There was no impairment recorded in 2003.
6.            Goodwill
      Goodwill represents the cost in excess of fair value of the net assets of companies acquired. Statement of Financial Accounting Standards (SFAS) No. 142, “Goodwill and Other Intangible Assets,” presumes that all goodwill will not be subject to amortization, but rather will be tested at least annually for impairment. In addition, the standard provides specific guidance on how to determine and measure goodwill impairment.
7.            Revenue Recognition
      BSI recognizes revenues and costs on drilling contracts as the work progresses. For certain contracts, we receive lump-sum payments for the mobilization of rigs and other drilling equipment. Revenues and the related direct costs incurred for the mobilization are deferred and recognized over the term of the related

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BSI COMPANIES
Notes to Combined Financial Statements – (Continued)
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
drilling contract. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred.
      BSI recognizes revenues on service contracts (service rigs, hauling, etc.) in the period in which the service is provided. BSI recognizes revenue on the sale of materials and supplies when products have been shipped, title and risk of loss have been transferred and collectibility is probable.
NOTE C – PROPERTY, PLANT AND EQUIPMENT
      The major components of our property, plant and equipment as of November 6, 2003 and December 31, 2002 are as follows:
                   
    2003   2002
         
Drilling and service rigs
  $ 23,527,831     $ 9,765,282  
Automobiles
    2,997,672       1,782,770  
Buildings
    20,000       70,722  
Leasehold improvements
    530,854       233,981  
Land
    127,609       75,000  
Office equipment
    138,044       75,867  
             
 
Total property, plant and equipment
    27,342,010       12,003,622  
Accumulated depreciation
    (3,391,199 )     (1,770,846 )
             
 
Net property, plant and equipment
  $ 23,950,811     $ 10,232,776  
             
NOTE D – INVENTORY
      The major components of inventory as of November 6, 2003 and December 31, 2002 are as follows:
                   
    2003   2002
         
Tubular products
  $ 1,123,399     $ 595,633  
Hardware
    1,455,878       1,874,942  
Plumbing and fittings
    879,675       747,094  
Other
    954,333       1,473,906  
             
 
Net inventory
  $ 4,413,285     $ 4,691,575  
             
NOTE E – FAIR VALUE INSTRUMENTS
      The fair values of our cash equivalents, trade receivables and trade payables approximate their carrying values due to the short-term nature of these instruments. The fair value of our long-term debt approximates its carrying value as the stated variable interest rate approximates the market rate at November 6, 2003.

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BSI COMPANIES
Notes to Combined Financial Statements – (Continued)
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
NOTE F – DEBT
      Long-term debt consists of the following at November 6, 2003 and December 31, 2002:
                 
    2003   2002
         
Note payable to a finance company with interest payable monthly at a rate of 2.9% per annum; payments of $882 payable monthly with the last payment due May 12, 2003; collateralized by truck
  $     $ 1,391  
Note payable to a finance company with no interest; principal payments of $811 payable monthly with the last payment due December 9, 2004; collateralized by truck
          18,662  
Note payable to a finance company with no interest; principal payments of $811 payable monthly with the last payment due December 9, 2004; collateralized by truck
          18,662  
Note payable to a finance company with no interest; principal payments of $811 payable monthly with the last payment due December 9, 2004; collateralized by truck
          18,662  
Note payable to a finance company with no interest; principal payments of $811 payable monthly with the last payment due October 16, 2004; collateralized by truck
          18,662  
Note payable to a finance company with interest payable monthly at a rate of 8.75% per annum; principal payments of $1,057 payable monthly with the last payment due September 19, 2003; collateralized by truck
          8,042  
Note payable to a finance company with no interest; principal payments of $3,410 payable monthly with the last payment due April 6, 2006; collateralized by equipment
          109,133  
Note payable to a finance company with interest payable monthly at a rate of 6.53% per annum; principal payments of $5,420 payable monthly with the last payment due April 20, 2005; collateralized by equipment
          136,129  
Note payable to a finance company with interest payable monthly at a rate of 4.80% per annum; principal payments of $5,279 payable monthly with the last payment due September 29, 2004; collateralized by equipment
          100,310  
Note payable to a finance company with no interest; principal payments of $670 payable monthly with the last payment due February 3, 2005; collateralized by truck
          16,741  
Note payable to a finance company with no interest; principal payments of $630 payable monthly with the last payment due January 12, 2005; collateralized by truck
          15,117  
Note payable to a finance company with no interest; principal payments of $670 payable monthly with the last payment due February 3, 2005; collateralized by truck
          16,741  
Note payable to a finance company with no interest; principal payments of $593 payable monthly with the last payment due December 9, 2004; collateralized by truck
          14,819  
Note payable to a finance company with no interest; principal payments of $593 payable monthly with the last payment due December 9, 2004; collateralized by truck
          14,823  

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BSI COMPANIES
Notes to Combined Financial Statements – (Continued)
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
                     
    2003   2002
         
Note payable to a finance company with no interest; principal payments of $3,384 payable monthly with the last payment due September 5, 2004; collateralized by truck
    72,538        
             
 
Total debt
    72,538       507,894  
 
Less current portion
    72,538       255,560  
             
   
Long-term debt
  $     $ 252,334  
             
      In addition to its long-term debt, BSI has the following lines of credit at November 6, 2003 and December 31, 2002:
                 
    2003   2002
         
$1,500,000 revolving line of credit, secured, with interest rate of 4.0%; due December 2003
  $ 1,500,000     $ 1,385,000  
$1,500,000 revolving line of credit, secured, with interest rate of 4.0%; due December 2003
          1,400,000  
$750,000 revolving line of credit, secured, with interest rate of 4.25% ; due January 2004
    190,000        
$1,500,000 revolving line of credit, secured, with interest rate of 5.25%; due June 2004
    1,500,000        
             
    $ 3,190,000     $ 2,785,000  
             
NOTE G – RELATED PARTY TRANSACTIONS
      In the normal course of business, BSI provides and receives goods and services with various entities in which an officer of BSI has an ownership interest. BSI believes that all transactions with related parties were on terms at least as favorable to BSI as could have been obtained through arm’s-length negotiations with unaffiliated third parties.
NOTE H – COMMITMENTS AND CONTINGENCIES
      BSI and its subsidiaries occupy various facilities and lease certain equipment under various lease agreements. The minimum rental commitments under non-cancelable operating leases, with lease terms in excess of one year subsequent to November 6, 2003, are as follows:
           
2004
  $ 477,894  
2005
    471,684  
2006
    436,560  
2007
    436,560  
2008
    401,060  
       
 
Total
  $ 2,223,758  
       
      Rental expense with operating lease terms greater than 30 days amounted to $520,577 for the period ended November 6, 2003.

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BSI COMPANIES
Notes to Combined Financial Statements – (Continued)
Period from January 1, 2003 through November 6, 2003
and Year Ended December 31, 2002
      Bell Supply I, LP and Shale Tank Truck, L.P., two entities of BSI, are defendants in litigation involving the death of an employee that occurred prior to November 6, 2003. BSI believes that any exposure in connection with this litigation would not exceed applicable insurance coverage. Depositions in this case are continuing, and BSI’s management and counsel believe it is too early to predict the amount of any settlement. In addition, in connection with its acquisition of BSI, Complete Energy Services, Inc. is indemnified for any contingent liabilities existing at the acquisition date in excess of $250,000.
      BSI is also subject to various other legal proceedings and claims that arise in the ordinary course of business. In the opinion of management, the amount of any liability with respect to these actions is either too early to determine or will not materially affect BSI’s consolidated financial statements or results of operations.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Owners
I.E. Miller Companies:
      We have audited the accompanying combined balance sheet of I.E. Miller Companies (defined in Note A1) as of August 31, 2004, and the related combined statements of operations, owners’ equity and cash flows for the eleven month period then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.
      We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
      In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of I.E. Miller Companies as of August 31, 2004, and the results of their operations and their cash flows for the eleven month period then ended, in conformity with accounting principles generally accepted in the United States of America.
  /s/ Grant Thornton LLP
 
 
Houston, Texas
January 27, 2005

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I. E. MILLER COMPANIES
Combined Balance Sheet
             
    August 31,
    2004
     
ASSETS
CURRENT ASSETS
       
 
Cash and cash equivalents
  $ 1,035,929  
 
Accounts receivable – trade, net of allowance for doubtful accounts of $103,354
    6,948,834  
 
Prepaid assets
    1,569,830  
 
Other current assets
    323,562  
       
   
Total current assets
    9,878,155  
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation and amortization
    6,968,954  
GOODWILL, net of accumulated amortization of $73,210
    161,508  
       
    $ 17,008,617  
       
 
LIABILITIES AND OWNERS’ EQUITY
CURRENT LIABILITIES
       
 
Accounts payable
  $ 1,252,475  
 
Accrued liabilities
    2,103,745  
 
Payable to affiliates
    164,077  
       
   
Total current liabilities
    3,520,297  
COMMITMENTS AND CONTINGENCIES
       
OWNERS’ EQUITY
    13,488,320  
       
    $ 17,008,617  
       
The accompanying notes are an integral part of this statement.

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I. E. MILLER COMPANIES
Combined Statement of Operations and Owners’ Equity
           
    Eleven Month
    Period Ended
    August 31,
    2004
     
OPERATING REVENUE
  $ 41,507,522  
OPERATING EXPENSES
    30,057,266  
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES
    4,779,669  
       
 
OPERATING INCOME
    6,670,587  
INTEREST EXPENSE
    84,856  
OTHER EXPENSE
    183,774  
       
 
NET INCOME
  $ 6,401,957  
BALANCE OF OWNERS’ EQUITY AS OF OCTOBER 1, 2003
    10,925,363  
DISTRIBUTION TO OWNERS DURING THE PERIOD
    (3,839,000 )
       
BALANCE OF OWNERS’ EQUITY AS OF AUGUST 31, 2004
  $ 13,488,320  
       
The accompanying notes are an integral part of these statements.

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I. E. MILLER COMPANIES
Combined Statement of Cash Flows
               
    Eleven
    Month
    Period Ended
    August 31,
    2004
     
CASH FLOWS FROM OPERATING ACTIVITIES
       
 
Net income
  $ 6,401,957  
 
Adjustments to reconcile net income to net cash provided by operating activities
       
   
Depreciation
    1,567,075  
   
Change in assets and liabilities
       
   
Decrease in accounts receivable
    107,691  
   
Increase in prepaid assets
    (347,891 )
   
Increase in other current assets
    (105,250 )
   
Increase in accounts payable
    340,405  
   
Increase in accrued liabilities
    440,638  
   
Increase in payable to affiliates
    164,077  
       
     
Net cash provided by operating activities
    8,568,702  
CASH FLOWS FROM INVESTING ACTIVITIES
       
 
Fixed asset additions
    (2,022,020 )
 
CASH FLOWS FROM FINANCING ACTIVITIES
       
 
Repayment of affiliated debt
    (2,144,431 )
 
Distributions to owners
    (3,839,000 )
       
     
Net cash used in financial activities
    (5,983,431 )
       
INCREASE IN CASH
    563,251  
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD
    472,678  
       
CASH AND CASH EQUIVALENTS AT END OF PERIOD
  $ 1,035,929  
       
Supplemental cash flow information:
       
 
Interest paid during the period
  $ 84,856  
The accompanying notes are an integral part of these statements.

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements
NOTE A – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
1.            Financial Statement Presentation
      The combined financial statements include the accounts of I. E. Miller of Eunice, L.L.C.; I. E. Miller – Fowler Trucking, L.L.C.; and I. E. Miller – Heldt Brothers Trucking, L.L.C, collectively referred to as the “I. E. Miller Companies.” These entities were 100% owned by an individual through personal ownership and affiliated persons or companies. The financial statements of these entities were combined with no adjustments to the balance sheet or statement of owners’ equity. All significant intercompany balances and transactions have been eliminated.
2.            Nature of Operations
      The I. E. Miller Companies’ principal business activity consists of land rig moving, line hauling, and vacuum truck service in Louisiana and southeast Texas.
3.            Cash and Cash Equivalents
      For purpose of the combined statement of cash flows, the I. E. Miller Companies consider all highly liquid debt instruments purchased with a maturity of three months or less to be cash equivalents. There were no cash equivalents at August 31, 2004.
4.            Depreciation
      Fixed assets are recorded at cost. Depreciation is provided by the straight-line method and declining balance method for financial statement and tax purposes, respectively, over the estimated useful lives of the assets as follows:
     
Buildings and improvements
  25-39 years
Furniture and fixtures
  1-5 years
Shop equipment
  2-5 years
Vehicles
  3 years
Revenue equipment
  2-10 years
5.            Intangible Assets
      The I. E. Miller Companies have adopted Statement of Financial Accounting Standards (SFAS) 142, Goodwill and Other Intangible Assets. As a result of this pronouncement, goodwill is no longer subject to amortization. Rather, goodwill is tested for impairment on an annual basis, or more frequently if an event occurs or circumstances change that would indicate an impairment is possible. Prior to adoption of SFAS 142, the accumulated balance of amortized goodwill was $73,210. For the period ended August 31, 2004, management of the I. E. Miller Companies have concluded that there is no impairment of goodwill.
6.            Income Taxes
      I. E. Miller of Eunice, L.L.C. was formed and all the assets I. E. Miller of Eunice, Inc. were transferred to the L.L.C. effective October 1, 2002. Earnings and losses after that date are included in the income tax return of the owners. Accordingly, the L.L.C. will not incur additional income tax obligations, and the financial statements do not include a provision for income taxes.
      I.E. Miller – Heldt Brothers Trucking L.L.C. and I. E. Miller – Fowler Trucking, L.L.C., with the consent of their owners, elected to be taxed as partnerships. In lieu of company level income taxes, the owners are taxed on their proportionate share of the net income from their operations. Accordingly, no

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements — (Continued)
NOTE A – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES — (Continued)
provision or liability for income taxes is included in the accompanying combined financial statements for their operations.
7.            Revenue recognition
      Revenue is recognized when the service is rendered.
8.            Use of Estimates
      The preparation of combined financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the combined financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
NOTE B – ACCOUNTS RECEIVABLE
      The I. E. Miller Companies provide for doubtful accounts using the allowance method. Accounts estimated to be uncollectible total $103,354 as of August 31, 2004.
NOTE C – PROPERTY, PLANT AND EQUIPMENT
      The following is a summary of property, plant and equipment – at cost, less accumulated depreciation and amortization at August 31, 2004:
           
Land
  $ 265,732  
Buildings and improvements
    512,608  
Furniture and fixtures
    372,593  
Shop equipment
    59,213  
Vehicles
    1,120,180  
Revenue equipment
    11,611,855  
       
      13,942,181  
 
Less accumulated depreciation and amortization
    6,973,227  
       
    $ 6,968,954  
       

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements — (Continued)
NOTE D – RELATED PARTY TRANSACTIONS
      Related parties of the I. E. Miller Companies include the following entities: Sunland Construction, Inc., Sunland-Kori Services, L.L.C., I. E. Miller and Company, L.L.C., Gulfgate Construction, L.L.C., Andre Land and Cattle and Progressive Tractor & Implement Co., Inc. Related party transactions are as follows:
             
Accounts receivable from:
       
 
Sunland Construction, Inc. 
  $ 60,730  
 
Progressive Tractor and Implement Co., Inc. 
    105  
       
    $ 60,835  
       
Accounts payable to:
       
 
Sunland Construction, Inc. 
  $ 3,423  
 
Purchases of services from:
       
   
Sunland Construction, Inc. 
  $ 896,494  
   
Sunland-Kori Services, L.L.C
    213,388  
       
    $ 1,109,882  
       
Sales of services to:
       
 
Sunland Construction, Inc. 
  $ 175,431  
 
Progressive Tractor and Implement Co., Inc. 
    1,515  
       
    $ 176,946  
       
      During the eleven months ended August 31, 2004, the I. E. Miller Companies rented property from Andre Land and Cattle for $33,000. The I. E. Miller Companies sold assets to Sunland Construction, Inc. for $59,000 and repaid debts of $2,144,431 and paid $9,063 in interest to Sunland.
NOTE E – RETIREMENT PLAN
      For the period ended August 31, 2004, the employees of I. E. Miller Companies were allowed to participate in the I. E. Miller Companies Profit Sharing 401(k) Plan. The Plan covers all full-time employees of I. E. Miller Companies who have one year of service and are age eighteen or older. The Plan is subject to the provisions of the Employee Retirement Income Security Act of 1974 (ERISA).
      Each year (at the option of I. E. Miller Companies’ management) the employer may make contributions. Participants may contribute up to 15 percent of their annual wages before bonuses and overtime. Employer contributions to the Plan were $17,978.17 for the period ended August 31, 2004.
NOTE F – CONCENTRATION OF CREDIT RISK
      The I. E. Miller Companies provide services to a diversified group of customers in the petroleum industry, including major oil companies, located primarily in the Southern United States. Credit is extended based on a evaluation of each customer’s financial condition. Credit losses, upon occurrence, are provided for within the financial statements.
      The I. E. Miller Companies maintain their cash in bank deposit accounts at high credit quality financial institutions. The balances, at times, may exceed federally insured limits.

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements — (Continued)
NOTE G – SALES TO MAJOR CUSTOMERS
      The customer base for the I. E. Miller Companies is primarily concentrated in the oil and gas industry. The revenue earned for each customer varies from year to year based on the services provided. Sales to customers exceeding 10 percent or more of the I. E. Miller Companies’ total revenue during the period comprised one customer at 13%.
NOTE H – COMMITMENTS AND CONTINGENCIES
      The I. E. Miller Companies are involved in various claims and lawsuits in the normal course of business. Management does not believe that any accruals are necessary in accordance with Statement of Financial Accounting Standards (SFAS) No. 5, Accounting for Contingencies.
      The I. E. Miller Companies lease equipment under various operating lease agreements. Total minimum rental commitments at August 31, 2004 are as follows:
         
Year Ended August 31,   Amount
     
2005
  $ 398,400  
2006
    200,575  
       
    $ 598,975  
       
NOTE I – SUBSEQUENT EVENTS
      On August 31, 2004, the I. E. Miller Companies were purchased by I. E. Miller Services, Inc. in an asset acquisition.

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LOGO   Eugene H. Darnall, CPA, Retired 1990
Paula D. Bihm, CPA, Deceased 2002

E. Larry Sikes, CPA, CVA, CFP
Danny P. Frederick, CPA
Clayton E. Darnall, CPA,CVA
Eugene H. Darnall, III, CPA

Stephanie M. Higginbotham, CPA
John P. Armato, CPA
Jennifer S. Ziegler, CPA, CFP
Chris A. Miller, CPA,CVA
Stephen R. Dischler, MBA, CPA
Steven G. Moosa, CPA

Erich G. Loewer, Jr. CPA, CVA

Kathleen T. Darnall, CPA
Erich G. Loewer, III, MTX, CPA
Tamera T. Landry, CPA
Raegan D. Maggio, CPA
Julie Templet DeVillier, CPA

Barbara A. Clark, CPA
Lauren F. Verrett, CPA
Michelle B. Borrello, CPA
Jeremy C. Meaux, CPA
Kevin S. Young, CPA

Other Locations:

1231 E. Laurel Avenue
Eunice, LA 70535
337.457.4146

1201 Brashear Avenue
Suite 301
Morgan City, LA 70380
985.384.6264

404 Pere Megret
Abbeville, LA 70510
337.893.5470
INDEPENDENT AUDITOR’S REPORT
Mr. John E. Soileau
I. E. Miller Companies
Eunice, Louisiana
      We have audited the accompanying combined balance sheet of I.E. Miller Companies as of September 30, 2003, and the related combined statement of operations, stockholders’ and members’ equity and cash flows for the year then ended. These combined financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these combined financial statements based on our audit.
      We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the combined financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform an audit of its internal control over financing reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the combined financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
      In our opinion, the combined financial statements referred to above present fairly, in all material respects, the financial position of I.E. Miller Companies as of September 30, 2003, and the results of its operations and its cash flows for the year then ended in conformity with accounting principles generally accepted in the United States of America.
/s/ DARNALL, SIKES & FREDERICK
A Corporation of Certified Public Accountants
     
Eunice, Louisiana
November 10, 2003
  Member of:

American Institute of
Certified Public Accountants

Society of Louisiana
Certified Public Accountants

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I. E. MILLER COMPANIES
Combined Balance Sheet
September 30, 2003
             
ASSETS
CURRENT ASSETS
       
 
Cash
  $ 621,528  
 
Accounts receivable – trade – net
    7,116,525  
 
Other receivables
    191,091  
 
Prepaid expenses
    1,206,555  
       
   
Total current assets
    9,135,699  
       
PROPERTY AND EQUIPMENT
       
 
Land and improvements
    314,475  
 
Buildings and improvements
    399,714  
 
Furniture and fixtures
    377,555  
 
Shop equipment
    56,625  
 
Vehicles
    1,000,356  
 
Revenue equipment
    12,837,793  
 
Leasehold improvements
    64,151  
 
Construction in progress
    31,398  
       
      15,082,067  
 
Less accumulated depreciation
    8,568,031  
       
      6,514,036  
       
OTHER ASSETS
       
 
Goodwill – net
    161,509  
 
Deposits
    27,192  
       
      188,701  
       
   
TOTAL ASSETS
  $ 15,838,436  
       
 
LIABILITIES AND STOCKHOLDERS’ AND MEMBERS’ EQUITY
 
LIABILITIES
       
 
Bank overdrafts
  $ 133,467  
 
Accounts payable
    1,021,172  
 
Accrued expenses
    1,367,537  
 
Note payable – insurance
    246,467  
 
Due to related parties
    2,144,431  
       
   
Total current liabilities
    4,913,074  
       
MINORITY INTEREST
    355,572  
       
STOCKHOLDERS’ AND MEMBERS’ EQUITY
       
 
Common stock
    1,000  
 
Members’ equity
    8,564,759  
 
Retained earnings
    2,004,031  
       
      10,569,790  
       
   
TOTAL LIABILITIES AND STOCKHOLDERS’ AND MEMBERS’ EQUITY
  $ 15,838,436  
       
See independent auditor’s report and notes to combined financial statements.

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I. E. MILLER COMPANIES
Combined Statement of Operations
Year Ended September 30, 2003
           
OPERATING REVENUE
  $ 30,186,155  
OPERATING EXPENSES
       
 
Direct expenses
    17,295,775  
 
Indirect expenses
    12,628,516  
       
      29,924,291  
       
OPERATING INCOME
    261,864  
       
OTHER INCOME
       
 
Gain on sale of assets
    36,088  
 
Interest
    7,676  
 
Miscellaneous
    175,001  
       
      218,765  
       
NET INCOME
  $ 480,629  
       
See independent auditor’s report and notes to combined financial statements.

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I. E. MILLER COMPANIES
Combined Statement of Stockholders’ and Members’ Equity
Year Ended September 30, 2003
                                           
    Common   Members’   Retained   Minority    
    Stock   Equity   Earnings   Interest   Total Equity
                     
Balances, September 30, 2002
  $ 576,000     $ (149,683 )   $ 10,381,565     $ 248,412     $ 11,056,294  
 
Conversion of corporation to L.L.C. 
    (575,000 )     8,783,005       (8,145,859 )           62,146  
 
Net income (loss)
          605,144       (231,675 )     107,160       480,629  
 
Gain on liquidation of parent
          214,468                   214,468  
 
Distributions
          (888,175 )                 (888,175 )
                               
Balances, September 30, 2003
  $ 1,000     $ 8,564,759     $ 2,004,031     $ 355,572     $ 10,925,362  
                               
See independent auditor’s report and notes to combined financial statements.

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I. E. MILLER COMPANIES
Combined Statement of Cash Flows
Year Ended September 30, 2003
               
CASH FLOWS FROM OPERATING ACTIVITIES
       
 
Net income
  $ 480,629  
       
 
Adjustments to reconcile net income to net cash provided by operating activities Depreciation
    1,817,037  
   
Gain on disposal of assets
    (36,088 )
 
(Increase) decrease in:
       
   
Accounts receivable
    (3,010,184 )
   
Other receivables
    15,280  
   
Prepaid assets
    947,774  
   
Interest receivable
    100,513  
   
Deposits
    (16,131 )
 
Increase (decrease) in:
       
   
Accounts payable
    132,904  
   
Accrued expenses
    (63,223 )
   
Deferred expenses
    (62,146 )
       
     
Total adjustments
    (174,264 )
       
     
Net cash provided by operating activities
    306,635  
       
CASH FLOWS FROM INVESTING ACTIVITIES
       
 
Proceeds from disposal of fixed assets
    195,432  
 
Purchase of fixed assets
    (839,196 )
       
     
Net cash used by investing activities
    (643,764 )
       
CASH FLOWS FROM FINANCING ACTIVITIES
       
 
Proceeds from bank overdraft. 
    133,467  
 
Net proceeds to affiliates
    1,458,862  
 
Net payments to member
    (122,447 )
 
Net decrease in short-term debt
    (120,137 )
 
Deferred compensation payments
    (162,195 )
 
Repayment of long-term debt
    (1,404,454 )
       
     
Net cash used by financing activities
    (216,904 )
       
DECREASE IN CASH AND CASH EQUIVALENTS
    (554,303 )
CASH AND CASH EQUIVALENTS, beginning of year
    1,175,831  
       
CASH AND CASH EQUIVALENTS, end of year
  $ 621,528  
       
Supplemental disclosures
       
Interest paid
  $ 131,360  
       
Income taxes paid
  $ 70,656  
       
See independent auditor’s report and notes to combined financial statements.

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements
NOTE 1 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Combination
      The combined financial statements include the accounts of I. E. Miller of Eunice, L.L.C. (wholly owned by I. E. Miller & Company, L.L.C.), I. E. Miller Holding Co., Inc. and its subsidiary, I. E. Miller – Fowler Trucking, L.L.C., and I. E. Miller – Heldt Brothers Trucking, L.L.C. collectively referred to as the “I. E. Miller Companies.” During the year ended September 30, 2003, with the shareholder’s consent, I. E. Miller of Eunice, Inc. transferred all of its operating assets to I. E. Miller of Eunice, L.L.C. in exchange for 100% ownership in the L.L.C. Subsequent to this transaction, I. E. Miller & Company, L.L.C. elected to liquidate I. E. Miller of Eunice, Inc., which resulted in I. E. Miller of Eunice, LLC. being 100% owned by I. E. Miller & Company, L.L.C. The I. E. Miller Companies were 100% owned by an individual through personal ownership and affiliated persons or companies. The financial statements of the I. E. Miller Companies were combined with no adjustments to the balance sheet or statement of owners’ equity. All significant intercompany transactions have been eliminated in the combination.
Nature of Operations
      The I. E. Miller Companies’ principal business activity consists of land rig moving, line hauling, and vacuum truck service in Louisiana and southeast Texas.
Cash and Cash Equivalents
      For purposes of the Combined Statement of Cash Flows, the I. E. Miller Companies consider all highly liquid debt instruments purchased with a maturity of three months or less to be cash equivalents. There were no cash equivalents at September 30, 2003.
Depreciation
      Fixed assets are recorded at cost. Depreciation, for financial statement purposes, is provided by the straight-line method and declining balance method over the estimated useful lives of the assets as follows:
         
Building and improvements
    25  
Furniture and fixtures
    1-5  
Shop equipment
    2-5  
Vehicles
    3  
Revenue equipment
    2-10  
Intangible Assets
      Goodwill represents the excess of the cost of the I. E. Miller Companies over the fair value of its net assets at the date of acquisition. In prior periods goodwill was being amortized on the straight-line basis over 40 years. For the year ended September 30, 2003 the I. E. Miller Companies have adopted SFAS No. 142, “Goodwill and Other Intangible Assets,” which changes the accounting for goodwill and other intangible assets. Goodwill is no longer amortized using the straight-line method over 40 years. Instead, SFAS No. 142 requires the Company to test for any impairment of goodwill. The I. E. Miller Companies have concluded that there has been no impairment of goodwill during the current year and therefore has not charged any expense to the income statement for the year ended September 30, 2003. Amortization expense charged to operations for 2002 was $6,682.

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements – (Continued)
Income Taxes
I. E. Miller of Eunice, L.L.C.
      I. E. Miller of Eunice, L.L.C. was formed and all the assets of I. E. Miller of Eunice, Inc. were transferred to the L.L.C. effective October 1, 2002. Earnings and losses after that date will be included in the income tax return of the member. Accordingly, the L.L.C. will not incur additional income tax obligations, and future financial statements will not include a provision for income taxes. Prior to the change, income taxes currently payable and deferred income taxes based on differences between the financial basis of assets and liabilities and their tax basis were recorded in the financial statements.
I. E. Miller Holding Co., Inc. & Subsidiary/ I.E. Miller – Heldt Brothers Trucking, L.L.C.
      I. E. Miller Holding Co., Inc. and Subsidiary and I. E. Miller – Heldt Brothers Trucking, L.L.C., with the consent of their stockholders (members), elected to be taxed as an S corporation and a partnership, respectively. In lieu of company level income taxes, the stockholders (members) are taxed on their proportionate share of the net income from their operations. Accordingly, no provision or liability for income taxes is included in the accompanying combined financial statement for their operations.
Uses of Estimates
      The preparation of combined financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the combined financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
NOTE 2 ACCOUNTS RECEIVABLE
      The I. E. Miller Companies provide for doubtful accounts using the allowance method. Accounts estimated to be uncollectible total $124,153 as of September 30, 2003.
NOTE 3 NOTE PAYABLE
         
Note payable to Canonwill, Inc., dated March 14, 2003, original amount of $864,476, with a downpayment of $216,119, bearing interest at 5% per annum, payable in 9 monthly installments of $73,549, collateralized by insurance policies
  $ 213,172  
Note payable to Hibernia Insurance, dated March 17, 2003, original amount of $131,537, with a downpayment of $32,884, bearing interest at 5% per annum, payable in 9 monthly installments of $11,191, collateralized by insurance policies
    33,295  
       
    $ 246,467  
       
NOTE 4 DEFERRED COMPENSATION
      The I. E. Miller Companies had established a deferred compensation agreement with a key employee. Additional compensation, if any, was earned based on profitability of the I. E. Miller Companies through a formula set forth in the plan. The plan also included a vesting schedule and withdrawal options of amounts earned and vested. Included in long-term liabilities is the deferred compensation payable earned as of September 30, 2002 in the amount of $162,195. During the year ended September 30, 2003, the covered individual discontinued employment with the I. E. Miller Companies and was paid all amounts owed as of that date.

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements – (Continued)
NOTE 5 RELATED PARTY TRANSACTIONS
      Related parties of the I. E. Miller Companies include the following entities: Sunland Construction, Inc., Sunland-Kori Services, L.L.C., I. E. Miller and Company, L.L.C., Gulfgate Construction, L.L.C., and Progressive Tractor & Implement Co., Inc. Related party transactions are as follows:
         
Accounts Receivable
       
Sunland Construction, Inc. 
  $ 262  
       
Accounts Payable/ Accrued Expenses
       
Sunland-Kori Services, L.L.C
  $ 10,102  
       
Due (to) from Affiliates/ Stockholders
       
Due to Sunland Construction, Inc. 
  $ 2,144,431  
       
Sales
       
Sunland Construction, Inc. 
  $ 27,940  
Gulfgate Construction, L.L.C
    1,306  
Progressive Tractor & Implement Co., Inc. 
    317  
       
    $ 29,563  
       
Purchases
       
Sunland Construction, Inc. 
  $ 2,899  
Sunland-Kori Services, L.L.C
    18,144  
Progressive Tractor & Implement Co., Inc. 
    2,573  
       
    $ 23,616  
       
NOTE 6 RETIREMENT PLAN
      For the year ended September 30, 2002, the employees of the I. E. Miller Companies were allowed to participate in the Sunland Construction, Inc. Profit Sharing 401(k) Plan. For the year ended September 30, 2003, the employees of the I. E. Miller Companies are allowed to participate in the I. E. Miller Companies Profit Sharing 401(k) Plan. The Plans cover all full-time employees of the I. E. Miller Companies who have one year of service and are age eighteen or older. They are subject to the provisions of the Employee Retirement Income Security Act of 1974 (ERISA).
      Each year (at the option of the I. E. Miller Companies’ management) the employer may make contributions. Participants may contribute up to 15 percent of their annual wages before bonuses and overtime. Employer contributions to the plans were $21,100 for the year ended September 30, 2003.
NOTE 7 BENEFIT TRUST
      The I. E. Miller Companies participate in the “Voluntary Employee’s Benefit Association Plan of Sunland Construction, Inc. and Affiliated Companies.” The Plan provides health benefits and life insurance coverage to full-time participants and to their beneficiaries and covered dependents. Funding of the Plan is provided monthly by contributions from both employers for employee coverage and employees for spouse and dependent coverage.

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I. E. MILLER COMPANIES
Notes to Combined Financial Statements – (Continued)
NOTE 8 CONCENTRATION OF CREDIT RISK
      The I. E. Miller Companies provide services to a diversified group of customers in the petroleum industry, including major oil companies, located primarily in the Southern United States. Credit is extended based on an evaluation of each customer’s financial condition. Credit losses, upon occurrence, are provided for within the financial statements.
      The I. E. Miller Companies maintain its cash in bank deposit accounts at high credit quality financial institutions. The balances, at times, may exceed federally insured limits.
NOTE 9 STOCK RESTRICTIONS
      The Articles of Incorporation do not allow any unit of I. E. Miller – Heldt Brothers Trucking, L.L.C. to be transferred by any member to any person not already a member of I. E. Miller – Heldt Brothers Trucking, L.L.C. unless the unit has been first offered for sale to the other members and the other members fail or refuse to accept the offer. The other members shall have an option to purchase the unit to be transferred at the same price and on the same terms and conditions as the offer or shall have been offered by a third person in an arm’s length transaction, acting in good faith. The offer shall be in writing and open for a period of 60 days. After the offer period has expired, the member may transfer his units at a price not less than the amount offered to the other members. The right of first refusal shall not apply to a gift or donation; however, a donation shall require the consent of the members.
NOTE 10 CONTINGENCIES
      The I. E. Miller Companies are guarantors on a line-of-credit of $30,000,000 for Sunland Construction, Inc. (a commonly owned affiliate). The outstanding balance was $4,995,814 at September 30, 2003. Also, the I. E. Miller Companies are guarantors on a term note for Sunland Construction, Inc. The balance on the note was $1,671,911 at September 30, 2003.
      The I. E. Miller Companies have outstanding four letters of credit with Bank One for a total of $2,120,978. At September, 30, 2003, no amounts were drawn on the letters of credit.
NOTE 11 SALES TO MAJOR CUSTOMERS
      The customer base for the I. E. Miller Companies is primarily concentrated in the oil and gas industry. The revenue earned from each customer varies from year to year based on the services provided. Sales to customers exceeding 10 percent or more of the I. E. Miller Companies’ total revenue are summarized as follows:
         
Customer A
    13 %

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Independent Accountants’ Report
Board of Directors
Hamm Co.
Enid, Oklahoma
We have audited the accompanying consolidated balance sheet of HAMM CO., as of September 30, 2004, and the related consolidated statements of income, stockholders’ equity and cash flows for the nine months then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of HAMM CO., as of September 30, 2004, and the results of its operations and its cash flows for the nine months then ended in conformity with accounting principles generally accepted in the United States of America.
/s/ BKD LLP
Tulsa, Oklahoma
December 9, 2004

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HAMM CO.
Consolidated Balance Sheet
September 30, 2004
               
ASSETS
CURRENT ASSETS
       
 
Cash
  $ 1,907,097  
 
Accounts receivable, net of allowance of $69,917
    11,243,181  
 
Inventory
    312,635  
 
Prepaid expenses
    293,838  
       
   
Total current assets
    13,756,751  
       
PROPERTY AND EQUIPMENT, at cost
       
 
Trucks, tanks and other
    27,830,941  
 
Land and buildings
    4,574,348  
 
Equipment
    14,254,688  
 
Leasehold
    69,253  
       
      46,729,230  
 
Less accumulated depreciation and amortization
    26,674,288  
       
      20,054,942  
       
OTHER ASSETS
       
 
Equipment deposit
    1,234,867  
 
Other
    323,497  
       
      1,558,364  
       
     
Total assets
  $ 35,370,057  
       
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES
       
 
Note payable
  $ 3,458,978  
 
Line of credit
    2,625,177  
 
Accounts payable
    4,568,772  
 
Accrued expenses and other payables
    1,317,901  
       
   
Total current liabilities
    11,970,828  
       
STOCKHOLDERS’ EQUITY
       
 
Common stock, $.001 par value; authorized 10,000,000 shares; issued 1,956,300 shares and outstanding 1,956,175 shares
    1,956  
 
Additional paid-in capital
    127,385  
 
Retained earnings
    23,852,097  
 
Treasury stock, at cost, 125 shares
    (582,209 )
       
   
Total stockholders’ equity
    23,399,229  
       
     
Total liabilities and stockholders’ equity
  $ 35,370,057  
       
See notes to consolidated financial statements.

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HAMM CO.
Consolidated Statement of Income
Nine Months Ended September 30, 2004
           
REVENUE
       
 
Service revenue
  $ 42,919,515  
 
Oil and gas
    259,835  
 
Management fees
    344,086  
       
      43,523,436  
       
OPERATING EXPENSES
       
 
Salaries and benefits
    16,194,201  
 
Depreciation and amortization
    3,119,198  
 
Insurance
    3,533,095  
 
General and administrative
    3,893,141  
 
Repairs and maintenance
    1,441,134  
 
Disposal fee
    2,392,600  
 
Fuel and oil
    2,739,152  
 
Parts and supplies
    3,582,245  
 
Other
    496,218  
       
      37,390,984  
       
OPERATING INCOME
    6,132,452  
       
OTHER INCOME
    532,739  
       
INTEREST EXPENSE
    308,988  
       
NET INCOME
  $ 6,356,203  
       
BASIC EARNINGS PER SHARE
  $ 3.25  
       
DILUTED EARNINGS PER SHARE
  $ 3.21  
       
See notes to consolidated financial statements.

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HAMM CO.
Consolidated Statement of Stockholders’ Equity
Nine Months Ended September 30, 2004
                                                   
            Additional            
    Number of   Common   Paid-In   Treasury   Retained    
    Shares   Stock   Capital   Stock   Earnings   Total
                         
Balance, beginning of period
    1,956,300     $ 1,956     $ 127,385     $ (582,209 )   $ 21,805,800     $ 21,352,932  
 
Net income
                            6,356,203       6,356,203  
 
Distribution to stockholder
                            (4,309,906 )     (4,309,906 )
                                     
Balance, end of period
    1,956,300     $ 1,956     $ 127,385     $ (582,209 )   $ 23,852,097     $ 23,399,229  
                                     
See notes to consolidated financial statements.

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HAMM CO.
Consolidated Statement of Cash Flows
Nine Months Ended September 30, 2004
               
Operating Activities
       
 
Net income
  $ 6,356,203  
 
Items not requiring (providing) cash
       
   
Depreciation and amortization
    3,119,198  
   
Gain on sale of assets
    (494,368 )
   
Undistributed earnings of affiliate
    (15,052 )
 
Changes in
       
   
Accounts receivable
    138,689  
   
Inventory
    120,126  
   
Accounts payable and accrued expenses
    1,075,237  
   
Other
    125,716  
       
     
Net cash provided by operating activities
    10,425,749  
       
Investing Activities
       
 
Proceeds from sale of equipment
    1,638,575  
 
Purchase of property and equipment and deposit on equipment
    (7,430,797 )
       
     
Net cash used in investing activities
    (5,792,222 )
       
Financing Activities
       
 
Net borrowings on line-of-credit agreement
    171,241  
 
Principal payments of long-term debt and note payable
    (3,118,051 )
 
Net advances to affiliates
    (210,675 )
 
Distributions to stockholders
    (2,213,573 )
       
     
Net cash used in financing activities
    (5,371,058 )
       
Decrease in cash
    (737,531 )
Cash, beginning of period
    2,644,628  
       
Cash, end of period
  $ 1,907,097  
       
Supplemental Cash Flows Information
       
 
Interest paid
  $ 308,988  
Hamm Co. sold equipment to the principal stockholder for cash, forgiveness of a payable owed to the stockholder and an amount of a declared cash distribution to the stockholder which was applied to the purchase price. The noncash components of the transaction were as follows:
         
Cost of equipment held for sale
  $ 3,523,642  
Distribution to stockholder applied to equipment purchase price
  $ 2,096,333  
Account payable to stockholder
  $ 353,439  
See notes to consolidated financial statements.

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HAMM CO.
Notes to Consolidated Financial Statements
September 30, 2004
Note 1: Nature of Operations and Summary of Significant Accounting Policies
Nature of Operations
      Hamm Co. is an Oklahoma-based fluid-handling and well-servicing company that earns revenue predominately from providing trucking, saltwater disposal and well servicing services for oil and gas producers in Oklahoma, Texas, Montana, North Dakota and Wyoming. Hamm Co. extends unsecured credit to its customers for a limited period of time.
Principles of Consolidation
      The consolidated financial statements include the accounts of Hamm Co. and its wholly owned subsidiaries, Hamm & Phillips Service Co.; Stride Well Service, Inc.; Rigmovers, Inc.; and Guard, Inc. All significant intercompany accounts and transactions have been eliminated in consolidation.
Use of Estimates
      The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Accounts Receivable
      Accounts receivable are stated at the amount billed to customers plus any accrued and unpaid interest. Hamm Co. provides an allowance for doubtful accounts, if necessary, which is based upon a review of outstanding receivables, historical collection information and existing economic conditions. Accounts receivable are ordinarily due 30 days after the issuance of the invoice. Delinquent receivables are written off based on individual credit evaluation and specific circumstances of the customer.
Inventories
      Substantially all inventories, consisting of materials and supplies and mud, are valued at weighted average cost, which includes freight-in.
Property and Equipment
      Property and equipment are carried at cost less accumulated depreciation. Depreciation is recorded over the estimated useful life of each asset using the straight-line method. Useful lives by significant asset category were as follows at September 30, 2004:
         
    Useful Life
Asset Description   (in years)
     
Trucks, tanks and other
    4-10  
Buildings
    10-40  
Equipment
    4-14  
Leasehold improvements
    10-40  
      Hamm Co.’s property and equipment was pledged as collateral against its outstanding bank facility borrowings at September 30, 2004. See discussion at Note 3, “Note Payable.”

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
September 30, 2004
Income Taxes
      Hamm Co.’s stockholders have elected to have Hamm Co. income taxed as an “S” Corporation under provisions of the Internal Revenue Code and a similar section of the Oklahoma income tax law; therefore, taxable income or loss is reported to the individual stockholders for inclusion in their respective tax returns. No provision for federal and state income taxes is included in these statements.
Revenue Recognition
      Hamm Co. earns revenue from the sale of services and equipment rentals to customers in the oil and gas industry at agreed-upon or contractual rates. Revenues are recognized when earned during the month that the services are performed. Services are performed within a relatively short period of time, and therefore, Hamm Co. does not record revenue transactions under long-term contract arrangements, and did not participate in multiple-element revenue transactions during the nine months ended September 30, 2004.
Stock Option Plan
      During 2003, Hamm Co. implemented two stock-based employee compensation plans, which are described more fully in Note 6. Hamm Co. accounts for these plans under the recognition and measurement principles of Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees, and related Interpretations. No stock-based employee compensation cost is reflected in net income. The following table illustrates the effect on net income if Hamm Co. had applied the fair value provisions of FASB Statement No. 123, Accounting for Stock-Based Compensation, to stock-based employee compensation. Fair value has been estimated using the minimum value method.
         
Net income, as reported
  $ 6,506,203  
Less: Total stock-based employee compensation cost determined under the fair value based method
    41,974  
       
Pro forma net income
  $ 6,464,229  
       
      The stock options were redeemed subsequent to year end.
Self-Insurance
      Hamm Co. and other affiliated companies have elected to jointly self-insure costs related to employee health and accident benefit programs. Costs resulting from noninsured losses are charged to income when incurred. Hamm Co. has purchased insurance that limits its exposure for individual claims.
Fair Value of Financial Instruments
      The fair value of financial assets and liabilities approximated their carrying values at September 30, 2004.
Note 2: Line of Credit
      Hamm Co. has a line of credit agreement in the amount of $3,500,000 payable to a bank. The line of credit agreement is due in May 2005 with monthly interest payments at 4%. Accounts receivable, general intangibles and the principal stockholder’s guarantee secure the note. At September 30, 2004, $2,625,177 was drawn on the line of credit agreement. The line of credit was paid in full in October 2004.

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
September 30, 2004
Note 3: Note Payable
      The note payable is to a bank and totaled $3,458,978 at September 30, 2004. The note was to be due in May 2005 and had terms requiring that whereby 1/60th of the outstanding principal balance plus interest at 4.5% be paid monthly. The note was secured by equipment and the principal stockholder’s guarantee at September 30, 2004. The note was paid in full in October 2004.
Note 4: Related Party Transactions
      During 2001, Hamm Co. borrowed $600,000 from a rental company owned solely by one of its stockholders. The loan was payable in monthly installments and was due on demand. The note was not secured. During 2004, the note was paid in full.
      During 2004, Hamm Co. provided oil field services and other services to affiliated companies totaling approximately $8,077,000. In addition, Hamm Co. purchased various services including saltwater disposal fees and general and administrative services totaling approximately $4,433,000. At September 30, 2004, Hamm Co. had a receivable totaling $2,284,657 from this related party and a payable of $376,201 as a result of these transactions. These amounts are included in the captions Accounts Receivable and Accounts Payable, respectively, in the accompanying balance sheet.
      During 2004, Hamm Co. sold equipment to its stockholder for $3,966,447. The sales price was satisfied through the receipt of cash of $1,516,675, a distribution in kind to the stockholder of $2,096,333 and a reduction of accounts payable to the stockholder of $353,439. A gain of $442,805 was recognized as a result of the sale based on the purchase price of the equipment.
Note 5: Profit Sharing Plan
      Hamm Co. has a 401(k) profit sharing plan covering substantially all employees. Hamm Co. makes discretionary contributions to the plan based on a percentage of eligible employees’ compensation. During 2004, contributions to the plan were 5% of eligible employees’ compensation. Contributions to the plan for the nine months ended September 30, 2004, were approximately $315,000.
Note 6: Stock Option Plans
Incentive Stock Option Plan (ISOP)
      Hamm Co. has an incentive stock option plan under which it may grant options that vest in five years to its employees for up to 23,750 shares of common stock. The exercise price of each option is intended to equal the fair value of Hamm Co.’s stock on the date of grant. An option’s maximum term is ten years.
      A summary of the status of the plan at September 30, 2004, and changes during the nine months then ended is presented below:
                   
        Weighted-
        Average
    Shares   Exercise Price
         
Outstanding, beginning of period
    21,850     $ 13.20  
 
Granted
    1,900       13.20  
             
Outstanding, end of period
    23,750     $ 13.20  
             
Options exercisable, end of period
    4,750          
             

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
September 30, 2004
      The fair value of options granted is estimated on the date of the grant using the minimum value method with the following weighted-average assumptions:
         
Dividend per share
  $  
Risk-free interest rate
    3 %
Expected life of options
    10 years  
      The following table summarizes information about stock options under the plan outstanding at September 30, 2004:
                                             
        Options Outstanding    
            Options Exercisable
        Weighted-Average        
    Number   Remaining   Weighted-Average   Number   Weighted-Average
Exercise Price   Outstanding   Contractual Life   Exercise Price   Exercisable   Exercise Price
                     
$ 13.20       23,750       9 years     $ 13.20       4,750     $ 13.20  
Nonqualified Stock Option Plan (NSOP)
      Hamm Co. has a nonqualified stock option plan under which it may grant options that vest in three years to its employees for up to 23,750 shares of common stock. Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees, requires compensation cost to be recognized over the period in which an employee performs services if the exercise price is less than the fair value of Hamm Co.’s stock on the date of the grant. The exercise price of each option is less than the fair value of the company’s stock on the date of grant, however, management believes the annual compensation is not material to the operations of Hamm Co. and no cost has been recognized. An option’s maximum term is ten years.
      A summary of the status of the plan at September 30, 2004, and changes during the nine months ended is presented below:
                   
        Weighted-
        Average
    Shares   Exercise Price
         
Outstanding, beginning of period
    21,850     $ 6.60  
 
Granted
    1,900       6.60  
             
Outstanding, end of period
    23,750     $ 6.60  
             
Options exercisable, end of period
    7,917          
             
      The fair value of options granted is estimated on the date of the grant using the minimum value method with the following weighted-average assumptions:
         
Dividend per share
  $  
Risk-free interest rate
    3.0 %
Expected life of options
    10 years  
      The following table summarizes information about stock options under the plan outstanding at September 30, 2004:
                                             
        Options Outstanding    
            Options Exercisable
        Weighted-Average        
    Number   Remaining   Weighted-Average   Number   Weighted-Average
Exercise Price   Outstanding   Contractual Life   Exercise Price   Exercisable   Exercise Price
                     
$ 6.60       23,750       9 years     $ 6.60       7,917     $ 6.60  

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
September 30, 2004
Note 7: Significant Estimates and Concentrations
      Accounting principles generally accepted in the United States of America require disclosure of certain significant estimates and current vulnerabilities due to certain concentrations. Those matters include the following:
Cash
      Hamm Co.’s cash exceeded FDIC insured limits by approximately $1,226,000 at September 30, 2004.
Customers
      Hamm Co. earned approximately 20% of its revenues from one customer, an affiliated company, during 2004.
Self-Insurance
      Hamm Co. and other affiliated companies participate jointly in a self-insurance pool covering health and workers’ compensation claims made by employees up to the first $50,000 (health) and $500,000 (workers’ compensation), respectively, per claim. Any amounts paid above these are reinsured through third-party providers. Premiums charged to Hamm Co. are based on estimated costs per employee of the pool. Estimates of the liability recorded could differ materially from the ultimate loss.
Note 8: Litigation and Commitments
      Hamm Co. is a defendant in a lawsuit that asserts property damage from leakage of a wastewater disposal tank to which Hamm Co. transported wastewater. The lawsuit seeks damages of an unspecified amount against many transporters of oilfield drilling fluids, including Hamm Co. The court sustained a motion for summary judgment on behalf of the transporters. The appeal has been fully briefed by the parties and has been assigned to the Court of Appeals for decision. A decision on that appeal has not been rendered. The amount of loss, if any, which may result from the ultimate outcome of this action is not currently reasonably estimable. No liability has been recorded for the potential loss as of September 30, 2004. Events could occur in the near term that would materially change the amount of recognized liability.
      Hamm Co. had no significant future obligations under operating lease arrangements at September 30, 2004. For the nine months ended September 30, 2004, rental expense under operating leases totaled $77,238.

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
September 30, 2004
Note 9: Earnings Per Share
      Earnings per share were computed as follows:
                           
        Weighted-    
        Average   Per Share
    Income   Shares   Amount
             
Basic earnings per share:
                       
 
Net income
  $ 6,356,203       1,956,175     $ 3.25  
Effect of dilutive securities:
                       
 
Stock options
          23,750        
Diluted earnings per share:
                       
                   
 
Net income
  $ 6,356,203       1,979,925     $ 3.21  
                   
Note 10: Subsequent Event
      Subsequent to September 30, 2004, the Hamm Co. companies were restructured and 100% of the stock of the restructured entity was sold to Complete Energy Services, Inc., a majority-owned company of SCF-IV, L.P. Hamm Co.’s common stock was sold for cash and capital stock of Complete Energy Services, Inc., pursuant to the purchase agreement.

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Independent Accountants’ Report
Board of Directors
Hamm Co.
Enid, Oklahoma
We have audited the accompanying consolidated balance sheet of HAMM CO., as of December 31, 2003, and the related consolidated statements of income, stockholders’ equity and cash flows for the year then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of HAMM CO., as of December 31, 2003, and the results of its operations and its cash flows for the year ended in conformity with accounting principles generally accepted in the United States of America.
/s/ BKD LLP
Enid, Oklahoma
February 27, 2004

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HAMM CO.
Consolidated Balance Sheet
December 31, 2003
               
ASSETS
CURRENT ASSETS
       
 
Cash
  $ 2,644,628  
 
Accounts receivable, net of allowance, $47,917
    11,381,870  
 
Inventory
    432,761  
 
Prepaid expenses
    505,352  
       
   
Total current assets
    14,964,611  
       
PROPERTY AND EQUIPMENT, at cost
       
 
Trucks, tanks and other
    24,327,480  
 
Land and buildings
    3,948,231  
 
Equipment
    12,729,810  
 
Leasehold
    69,253  
       
      41,074,774  
 
Accumulated depreciation and amortization
    (23,492,800 )
       
      17,581,974  
       
OTHER ASSETS
       
 
Asset held for sale
    2,860,250  
 
Other
    141,937  
       
      3,002,187  
       
     
Total assets
  $ 35,548,772  
       
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES
       
 
Current maturities of long-term debt
  $ 5,558,801  
 
Line of credit
    2,453,936  
 
Accounts payable
    3,789,506  
 
Accounts payable-related party
    353,439  
 
Accrued expenses and other payables
    1,021,930  
       
   
Total current liabilities
    13,177,612  
       
LONG-TERM DEBT
    1,018,228  
       
STOCKHOLDERS’ EQUITY
       
 
Common stock, $.001 par value; authorized 10,000,000 shares; issued 1,956,300 shares and outstanding 1,956,175 shares
    1,956  
 
Additional paid-in capital
    127,385  
 
Retained earnings
    21,805,800  
 
Treasury stock, at cost, 125 shares
    (582,209 )
       
   
Total stockholders’ equity
    21,352,932  
       
     
Total liabilities and stockholders’ equity
  $ 35,548,772  
       
See notes to consolidated financial statements.

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HAMM CO.
Consolidated Statement of Income
Year Ended December 31, 2003
           
REVENUE
       
 
Service revenue
  $ 48,093,996  
 
Oil and gas
    495,884  
 
Management fees
    313,904  
       
      48,903,784  
       
OPERATING EXPENSES
       
 
Salaries and benefits
    19,570,318  
 
Depreciation and amortization
    3,795,280  
 
Insurance
    3,323,714  
 
General and administrative
    3,672,551  
 
Repairs and maintenance
    1,373,587  
 
Disposal fee
    2,550,948  
 
Fuel and oil
    2,607,571  
 
Parts and supplies
    4,901,500  
 
Other
    703,180  
       
      42,498,649  
       
OPERATING INCOME
    6,405,135  
       
OTHER INCOME
    51,608  
       
INTEREST EXPENSE
    348,969  
NET INCOME
  $ 6,107,774  
       
BASIC EARNINGS PER SHARE
  $ 3.12  
DILUTED EARNINGS PER SHARE
  $ 3.10  
See notes to consolidated financial statements.

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HAMM CO.
Consolidated Statement of Stockholders’ Equity
Year Ended December 31, 2003
                                                   
            Additional            
    Number of   Common   Paid-In   Treasury   Retained    
    Shares   Stock   Capital   Stock   Earnings   Total
                         
Balance, beginning of period
    10,000     $ 10,000     $ 119,341     $ (582,209 )   $ 15,698,026     $ 15,245,158  
 
Effect of change in par value
    1,946,300       (8,044 )     8,044                    
 
Net income
                            6,107,774       6,107,774  
                                     
Balance, end of period
    1,956,300     $ 1,956     $ 127,385     $ (582,209 )   $ 21,805,800     $ 21,352,932  
                                     
See notes to consolidated financial statements.

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HAMM CO.
Consolidated Statement of Cash Flows
Year Ended December 31, 2003
               
OPERATING ACTIVITIES
       
 
Net income
  $ 6,107,774  
 
Items not requiring (providing) cash
       
   
Depreciation and amortization
    3,795,280  
   
Gain on sale of assets
    (42,228 )
 
Changes in
       
   
Accounts receivable
    (4,308,913 )
   
Inventory
    14,076  
   
Accounts payable and accrued expenses
    944,524  
   
Other
    (242,585 )
       
     
Net cash provided by operating activities
    6,267,928  
       
INVESTING ACTIVITIES
       
 
Proceeds from sale of equipment
    121,305  
 
Purchase of property and equipment
    (5,192,168 )
       
     
Net cash used in investing activities
    (5,070,863 )
       
FINANCING ACTIVITIES
       
 
Net principal payments on line-of-credit agreement
    (706,866 )
 
Principal payments of long-term debt
    (2,510,376 )
 
Purchase of treasury stock
    (582,209 )
 
Proceeds from issuance of long-term debt
    4,756,900  
       
     
Net cash provided by financing activities
    957,449  
       
INCREASE IN CASH
    2,154,514  
CASH, BEGINNING OF YEAR
    490,114  
       
CASH, END OF YEAR
  $ 2,644,628  
       
SUPPLEMENTAL CASH FLOWS INFORMATION
       
 
Interest paid
  $ 348,969  
See notes to consolidated financial statements.

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HAMM CO.
Notes to Consolidated Financial Statements
December 31, 2003
Note 1: Nature of Operations and Summary of Significant Accounting Policies
Nature of Operations
      Hamm Co. is an Oklahoma-based fluid-handling and well-servicing company that earns revenue predominately from providing trucking, salt water disposal and well servicing services for oil and gas producers in Oklahoma, Texas, North Dakota and Wyoming. Hamm Co. extends unsecured credit to its customers for a limited period of time.
Principles of Consolidation
      The consolidated financial statements include the accounts of Hamm Co. and its wholly owned subsidiaries, Hamm & Phillips Service Co.; Stride Well Service, Inc.; Rigmovers, Inc.; and Guard, Inc. All significant intercompany accounts and transactions have been eliminated in consolidation.
Use of Estimates
      The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Accounts Receivable
      Accounts receivable are stated at the amount billed to customers plus any accrued and unpaid interest. Hamm Co. provides an allowance for doubtful accounts, if necessary, which is based upon a review of outstanding receivables, historical collection information and existing economic conditions. Accounts receivable are ordinarily due 30 days after the issuance of the invoice. Delinquent receivables are written off based on individual credit evaluation and specific circumstances of the customer.
Inventories
      Substantially all inventories, consisting of materials and supplies and mud, are valued at weighted average cost, which includes freight-in.
Property and Equipment
      Property and equipment are carried at cost less accumulated depreciation. Depreciation is recorded over the estimated useful life of each asset using the straight-line method. Useful lives by significant asset category were as follows at December 31, 2003.
         
    Useful Life
Asset Description   (in years)
     
Trucks, tanks and other
    4-10  
Buildings
    10-40  
Equipment
    4-14  
Leasehold improvements
    10-40  
      Hamm Co.’s property and equipment was pledged as collateral against outstanding bank facility borrowings at December 31, 2003. See discussion at Note 3, “Long-Term Debt.”

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
December 31, 2003
Income Taxes
      Hamm Co.’s stockholders have elected to have the company’s income taxed as an “S” Corporation under provisions of the Internal Revenue Code and a similar section of the Oklahoma income tax law; therefore, taxable income or loss is reported to the individual stockholders for inclusion in their respective tax returns. No provision for federal and state income taxes is included in these statements.
Revenue Recognition
      Hamm Co. earns revenue from the sale of services and equipment rentals to customers in the oil and gas industry at agreed-upon or contractual rates. Revenues are recognized when earned during the month that the services are performed. Services are performed within a relatively short period of time, and therefore, Hamm Co. does not record revenue transactions under long-term contract arrangements, and did not participate in multiple-element revenue transactions during the year ended December 31, 2003.
Stock Option Plan
      During 2003, Hamm Co. implemented two stock-based employee compensation plans, which are described more fully in Note 6. Hamm Co. accounts for these plans under the recognition and measurement principles of APB Opinion No. 25, Accounting for Stock Issued to Employees, and related Interpretations. No stock-based employee compensation cost is reflected in net income. The following table illustrates the effect on net income if Hamm Co. had applied the fair value provisions of FASB Statement No. 123, Accounting for Stock-Based Compensation, to stock-based employee compensation. Fair value has been estimated using the minimum value method.
         
Net income, as reported
  $ 6,107,774  
Less: Total stock-based employee compensation cost determined under the fair value based method
    50,100  
       
Pro forma net income
  $ 6,057,674  
       
Self-Insurance
      Hamm Co. and other affiliated companies have elected to jointly self-insure costs related to employee health and accident benefit programs. Costs resulting from noninsured losses are charged to income when incurred. Hamm Co. has purchased insurance that limits its exposure for individual claims.
Fair Value of Financial Instruments
      The fair value of financial assets and liabilities approximated their carrying values at December 31, 2003.
Note 2: Line of Credit
      Hamm Co. has a line of credit agreement in the amount of $3,500,000 payable to a bank. The line of credit agreement is due July 2004 with monthly interest payments at the Chase Manhattan prime rate less .5% with a floor of 4%. At December 31, 2003, $2,453,986 was drawn on the line of credit agreement. These borrowings bore interest at a rate of 4% and were secured by accounts receivable, general intangibles and a stockholder’s guarantee.

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
December 31, 2003
Note 3: Long-Term Debt
         
Note payable, bank(A)
  $ 103,112  
Note payable, bank(B)
    104,964  
Note payable, bank(C)
    2,000,000  
Note payable, bank(D)
    3,956,779  
Notes payable, related party(E)
    366,450  
Notes payable, finance company(F)
    45,724  
       
      6,577,029  
Less current maturities
    5,558,801  
       
    $ 1,018,228  
       
      Aggregate annual maturities of long-term debt at December 31, 2003, were:
         
2004
  $ 5,558,801  
2005
    1,018,228  
       
    $ 6,577,029  
       
 
(A)  Due June 2004; payable $18,192 monthly including interest at National prime; secured by inventory, machinery and equipment.
 
(B)  Due March 2005; payable $8,646 monthly including interest at National prime; remaining principal due at maturity; secured by inventory, machinery and equipment.
 
(C)  Due March 2004; payable $83,333 monthly plus interest at 5%, secured by equipment.
 
(D)  Due September 2004; payable monthly at 1/60th of the outstanding balance plus interest at 4.75%, secured by equipment.
 
(E)  Unsecured notes payable to a related party; payable on demand, at interest rates of 6.00% and 8.50%.
 
(F)  Various notes payable due December 2004; payable monthly; secured by automobiles.
Note 4: Related Party Transactions
      During 2001, Hamm Co. borrowed $600,000 from a rental company owned solely by one of its shareholders. These loans are payable in monthly installments and are due on demand. The notes are not secured. At December 31, 2003, Hamm Co. owed the rental company $366,450. During 2003, Hamm Co. paid $1,796 in interest expense related to the loan.
      During 2003, Hamm Co. provided oilfield services and other services to affiliated companies totaling approximately $13,720,000. In addition, Hamm Co. purchased various services including salt water disposal fees and general and administrative services totaling approximately $13,830,000. At December 31, 2003, Hamm Co. had a receivable totaling $4,144,561 from the affiliated companies, and a payable of $343,777 as a result of those transactions. These amounts are included in the captions Accounts Receivable and Accounts Payable, respectively, in the accompanying balance sheet. Hamm Co. recorded an accounts payable-related party totaling $353,439 to reimburse the owner of the Hamm Co. companies for expenses paid on behalf of Hamm Co. related to the construction of an asset. This amount was repaid in 2004.

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
December 31, 2003
Note 5: Profit Sharing Plan
      Hamm Co. has a 401(k) profit sharing plan covering substantially all employees. Hamm Co. makes discretionary contributions to the plan based on a percentage of eligible employees’ compensation. During 2003, contributions to the plan were 5% of eligible employees’ compensation. Contributions to the plan for the year ended December 31, 2003, were approximately $426,000.
Note 6: Stock Option Plans
Incentive Stock Option Plan (ISOP)
      Hamm Co. has an incentive stock option plan under which Hamm Co. may grant options that vest in five years to its employees for up to 21,850 shares of common stock. The exercise price of each option is intended to equal the fair value of Hamm Co.’s stock on the date of grant. An option’s maximum term is ten years.
      A summary of the status of the plan at December 31, 2003, and changes during the year then ended is presented below:
                   
        Weighted-
        Average
    Shares   Exercise Price
         
Outstanding, beginning of year
        $  
 
Granted
    21,850       13.20  
             
Outstanding, end of year
    21,850     $ 13.20  
             
Options exercisable, end of year
    0          
             
      The fair value of options granted is estimated on the date of the grant using the minimum value method with the following weighted-average assumptions:
         
Dividend per share
  $  
Risk-free interest rate
    3.00 %
Expected life of options
    10 years  
Weighted-average fair value of options granted during the year
  $ 74,000  
      The following table summarizes information about stock options under the plan outstanding at December 31, 2003:
                                             
        Options Outstanding    
            Options Exercisable
        Weighted-Average        
    Number   Remaining   Weighted-Average   Number   Weighted-Average
Exercise Price   Outstanding   Contractual Life   Exercise Price   Exercisable   Exercise Price
                     
$ 13.20       21,850       10 years     $ 13.20           $  
Nonqualified Stock Option Plan (NSOP)
      Hamm Co. has a nonqualified stock option plan under which it may grant options that vest in three years to its employees for up to 21,850 shares of common stock. Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees, requires compensation cost to be recognized over the period in which an employee performs services if the exercise price is less than the fair value of the Hamm Co.’s stock on the date of the grant. The exercise price of each option is less than the fair value of the Hamm Co.’s stock on the date of grant, however, management believes the annual compensation is not

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
December 31, 2003
material to the operations of Hamm Co. and no cost has been recognized. An option’s maximum term is ten years.
      A summary of the status of the plan at December 31, 2003, and changes during the year ended is presented below:
                   
        Weighted-
        Average
    Shares   Exercise Price
         
Outstanding, beginning of year
        $  
 
Granted
    21,850       6.60  
             
Outstanding, end of year
    21,850     $ 6.60  
             
Options exercisable, end of year
    0          
             
      The fair value of options granted is estimated on the date of the grant using the minimum value method with the following weighted-average assumptions:
         
Dividend per share
  $  
Risk-free interest rate
    3.00 %
Expected life of options
    10 years  
Weighted-average fair value of options granted during the year
  $ 181,000  
      The following table summarizes information about stock options under the plan outstanding at December 31, 2003:
                                             
        Options Outstanding    
            Options Exercisable
        Weighted-Average        
    Number   Remaining   Weighted-Average   Number   Weighted-Average
Exercise Price   Outstanding   Contractual Life   Exercise Price   Exercisable   Exercise Price
                     
$ 6.60       21,850       10 years     $ 6.60           $  
Note 7: Significant Estimates and Concentrations
      Accounting principles generally accepted in the United States of America require disclosure of certain significant estimates and current vulnerabilities due to certain concentrations. Those matters include the following:
Customers
      Hamm Co. earned approximately 31% of its revenues from one customer during 2003.
Self-Insurance
      Hamm Co. and other affiliated companies participate jointly in a self-insurance pool covering health and workers’ compensation claims made by employees up to the first $50,000 (health) and $500,000 (workers’ compensation), respectively, per claim. Any amounts paid above these are reinsured through third-party providers. Premiums charged to Hamm Co. are based on estimated costs per employee of the pool. Estimates of the liability recorded could differ materially from the ultimate loss.

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HAMM CO.
Notes to Consolidated Financial Statements – (Continued)
December 31, 2003
Note 8: Litigation and Commitments
      Hamm Co. is a defendant in a lawsuit that asserts property damage from leakage of a wastewater disposal tank to which Hamm Co. transported wastewater. The lawsuit seeks damages of an unspecified amount against many transporters of oilfield drilling fluids, including Hamm Co. The court sustained a motion for summary judgement on behalf of the transporters. The appeal has been fully briefed by the parties and has been assigned to the Court of Appeals for decision. A decision on that appeal has not been rendered. The amount of loss, if any, which may result from the ultimate outcome of this action is not currently reasonably estimable. No liability has been recorded for the potential loss as of December 31, 2003. Events could occur in the near term that would materially change the amount of recognized liability.
      Hamm Co. had no significant future obligations under operating lease arrangements at December 31, 2003. For the year ended December 31, 2003, rental expense under operating leases totaled $72,712.
Note 9: Combination of Commonly Controlled Interest
      On March 31, 2003, the Hamm Co. (Hamm) liquidated a wholly owned subsidiary Trinity Oil-Field Services, Inc. (Trinity) and contributed the net assets to Stride Well Services, Inc. (Stride). Because majority ownership of Trinity and Stride are substantially the same, this combination was accounted for in a manner similar to a pooling of interests, using Trinity’s historical book values.
Note 10: Common Stock
      During 2003, Hamm Co. amended and restated its certificate of incorporation. The amendment increased the number of authorized shares from 500,000 shares to 10,000,000 shares and decreased the par value from $1 per share to $.001 per share. The number of shares issued and outstanding increased from 10,000 shares to 1,956,300 shares. There was no consideration given as a result of the amendment. Common stock was decreased by $8,044 and additional paid-in capital was increased by $8.044.
Note 11: Earnings Per Share
      Earnings per share were computed as follows:
                           
        Weighted-    
        Average   Per Share
    Income   Shares   Amount
             
Basic earnings per share:
                       
 
Net income
  $ 6,107,774       1,956,175     $ 3.12  
Effect of dilutive securities:
                       
 
Stock options
          14,859        
Diluted earnings per share:
                       
                   
 
Net income
  $ 6,107,774       1,971,034     $ 3.10  
                   

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Independent Accountants’ Report
Board of Directors
Oil Tool Rentals, Inc.
Enid, Oklahoma
We have audited the accompanying balance sheets of OIL TOOL RENTALS, INC. (the Company) as of September 30, 2004, and December 31, 2003 and 2002, and the related statements of income, stockholders’ equity and cash flows for the nine months ended September 30, 2004, and the years ended December 31, 2003 and 2002. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
      We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
      In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of OIL TOOL RENTALS, INC., as of September 30, 2004, and December 31, 2003 and 2002, and the results of its operations and its cash flows for the nine months ended September 30, 2004, and the years ended December 31, 2003 and 2002, in conformity with accounting principles generally accepted in the United States of America.
/s/ BKD LLP
Tulsa, Oklahoma
December 9, 2004

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OIL TOOL RENTALS, INC.
Balance Sheets
September 30, 2004, and December 31, 2003 and 2002
                               
    2004   2003   2002
             
ASSETS
CURRENT ASSETS
                       
 
Cash and cash equivalents
  $ 354,340     $ 302,341     $ 196,609  
 
Accounts receivable
    1,219,203       834,540       548,621  
 
Other current assets
    8,183       17,013       30,722  
                   
   
Total current assets
    1,581,726       1,153,894       775,952  
                   
INVESTMENTS AND LONG-TERM RECEIVABLES
                       
 
Held-to-maturity securities
    1,887,747       1,865,770        
 
Receivable from related party
          366,450       604,505  
                   
      1,887,747       2,232,220       604,505  
                   
PROPERTY AND EQUIPMENT, at cost
                       
 
Land and buildings
    163,591       157,224       157,224  
 
Trucks, trailers and other
    620,059       627,379       639,863  
 
Rental equipment
    5,599,149       3,324,686       3,372,196  
 
Shop equipment
    151,198       150,092       160,566  
 
Furniture and fixtures
    85,704       78,304       149,260  
                   
      6,619,701       4,337,685       4,479,109  
 
Less accumulated depreciation
    3,364,286       3,133,075       3,025,635  
                   
            3,255,415       1,204,610       1,453,474  
                   
   
Total assets
  $ 6,724,888     $ 4,590,724     $ 2,833,931  
                   
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 
CURRENT LIABILITIES
                       
 
Current maturities of long-term debt
  $ 290,413     $ 589,095     $ 118,964  
 
Accounts payable
    1,423,392       28,933       64,288  
 
Accrued expenses and other
    169,368       79,823       76,773  
 
Payable to related party
    231,000              
                   
   
Total current liabilities
    2,114,173       697,851       260,025  
                   
LONG-TERM DEBT
    597,502       542,841        
                   
STOCKHOLDERS’ EQUITY
                       
 
Common stock, $1 par value, authorized 10,000 shares, issued and outstanding 500 shares
    500       500       500  
 
Additional paid-in capital
    9,500       9,500       9,500  
 
Retained earnings
    4,003,213       3,340,032       2,563,906  
                   
   
Total stockholders’ equity
    4,013,213       3,350,032       2,573,906  
                   
     
Total liabilities and stockholders’ equity
  $ 6,724,888     $ 4,590,724     $ 2,833,931  
                   
See notes to financial statements.

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OIL TOOL RENTALS, INC.
Statements of Income
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
                           
    2004   2003   2002
             
RENTAL INCOME
  $ 2,928,981     $ 3,474,707     $ 2,899,141  
                   
OPERATING EXPENSES
                       
 
Rental expense
    504,150       504,915       368,120  
 
Salaries and benefits
    908,750       1,068,029       1,000,071  
 
Depreciation
    238,338       331,564       495,679  
 
Insurance
    129,383       147,110       159,878  
 
General and administrative
    219,717       227,882       212,669  
 
Repairs and maintenance
    13,504       7,471       5,327  
 
Fuel and oil
    17,664       6,144       7,252  
 
License and permits
    1,277       8,833       4,525  
 
Parts and supplies
    134,102       121,648       116,706  
 
Gain on sale of assets
    (1,500 )     (23,500 )      
                   
      2,165,385       2,400,096       2,370,227  
                   
OPERATING INCOME
    763,596       1,074,611       528,914  
                   
OTHER INCOME
    276,036       262,128       29,887  
INTEREST EXPENSE
    32,451       57,613       25,123  
NET INCOME
  $ 1,007,181     $ 1,279,126     $ 533,678  
                   
EARNINGS PER SHARE (500 shares outstanding)
                       
BASIC AND DILUTED
  $ 2,014.36     $ 2,558.25     $ 1,067.36  
                   
See notes to financial statements.

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OIL TOOL RENTALS, INC.
Statements of Stockholders’ Equity
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
                                         
            Additional        
    Number of   Common   Paid-In   Retained    
    Shares   Stock   Capital   Earnings   Total
                     
Balance, January 1, 2002
    500     $ 500     $ 9,500     $ 2,242,663     $ 2,252,663  
Net income
                      533,678       533,678  
Distribution to stockholders
                      (212,435 )     (212,435 )
                               
Balance, December 31, 2002
    500       500       9,500       2,563,906       2,573,906  
Net income
                      1,279,126       1,279,126  
Distribution to stockholders
                      (503,000 )     (503,000 )
                               
Balance, December 31, 2003
    500       500       9,500       3,340,032       3,350,032  
Net income
                      1,007,181       1,007,181  
Distribution to stockholders
                      (344,000 )     (344,000 )
                               
Balance, September 30, 2004
    500     $ 500     $ 9,500     $ 4,003,213     $ 4,013,213  
                               
See notes to financial statements.

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OIL TOOL RENTALS, INC.
Statements of Cash Flows
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
                               
    2004   2003   2002
             
OPERATING ACTIVITIES
                       
 
Net income
  $ 1,007,181     $ 1,279,126     $ 533,678  
 
Items not requiring (providing) cash
Depreciation
    238,338       331,564       495,679  
   
Amortization of discount on held-to-maturity investment
    (21,977 )     (25,770 )      
   
Gain on sale of assets
    (1,500 )     (23,500 )      
 
Changes in
Accounts receivable
    (384,663 )     (285,919 )     (15,012 )
   
Accounts payable and accrued expenses
    298,780       (32,305 )     48,356  
   
Other current assets and liabilities
    10,723       13,709       (23,959 )
                   
     
Net cash provided by operating activities
    1,146,882       1,256,905       1,038,742  
                   
INVESTING ACTIVITIES
                       
 
Proceeds from sale of property and equipment
    1,500       23,500        
 
Purchase of property and equipment
    (1,105,812 )     (82,700 )     (1,051,299 )
 
Purchase held-to-maturity investments
          (1,840,000 )      
 
Net receipts on related party note receivable
    366,450       238,055       46,703  
                   
     
Net cash used in investing activities
    (737,862 )     (1,661,145 )     (1,004,596 )
                   
FINANCING ACTIVITIES
                       
 
Net borrowings on related party note payable
    231,000              
 
Principal payments on long-term debt
    (1,184,166 )     (737,028 )     (831,036 )
 
Proceeds from issuance of long-term debt
    940,145       1,750,000       950,000  
 
Distributions to stockholders
    (344,000 )     (503,000 )     (212,435 )
                   
     
Net cash provided by (used in) financing activities
    (357,021 )     509,972       (93,471 )
                   
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
    51,999       105,732       (59,325 )
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD
    302,341       196,609       255,934  
                   
CASH AND CASH EQUIVALENTS, END OF PERIOD
  $ 354,340     $ 302,341     $ 196,609  
                   
SUPPLEMENTAL CASH FLOWS INFORMATION
                       
 
Interest paid
  $ 33,293     $ 53,727     $ 24,555  
 
Property and equipment purchases in accounts payable
  $ 1,185,224     $     $  
See notes to financial statements.

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OIL TOOL RENTALS, INC.
Notes to Financial Statements
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
Note 1: Nature of Operations and Summary of Significant Accounting Policies
Nature of Operations
      Oil Tool Rentals, Inc. (“Oil Tools”) is an Oklahoma-based equipment rental company that earns revenue predominately from providing rental equipment and services for oil and gas producers in Oklahoma, Texas, North Dakota and Wyoming. Oil Tools extends unsecured credit to its customers for a limited period of time.
Use of Estimates
      The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Cash Equivalents
      Oil Tools considers all liquid investments with original maturities of three months or less to be cash equivalents. At September 30, 2004, and December 31, 2003 and 2002, cash equivalents consisted primarily of money market accounts with brokers.
Accounts Receivable
      Accounts receivable are stated at the amount billed to customers plus any accrued and unpaid interest. Oil Tools provides an allowance for doubtful accounts, if necessary, which is based upon a review of outstanding receivables, historical collection information and existing economic conditions. Accounts receivable are ordinarily due 30 days after the issuance of the invoice. Delinquent receivables are written off based on individual credit evaluation and specific circumstances of the customer.
Property and Equipment
      Property and equipment are carried at cost less accumulated depreciation. Depreciation is recorded over the estimated useful life of each asset using the straight-line method. Useful lives by significant asset category were as follows as of September 30, 2004:
         
Asset Description   Useful Life
     
    (in years)
Trucks, trailers and other
    4-10  
Buildings
    10-40  
Equipment
    4-14  
Furniture and fixtures
    5-7  
      Oil Tools’ property and equipment was pledged as collateral against outstanding bank facility borrowings at September 30, 2004. See discussion at Note 3, “Long-Term Debt.”
Income Taxes
      Oil Tools’ stockholder has elected to have the company’s income taxed as an “S” Corporation under provisions of the Internal Revenue Code and a similar section of the Oklahoma income tax law; therefore,

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OIL TOOL RENTALS, INC.
Notes to Financial Statements – (Continued)
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
taxable income or loss is reported to the individual stockholder for inclusion in their respective tax returns. No provision for federal and state income taxes is included in these statements.
Revenue Recognition
      Oil Tools earns revenue from the rental of equipment to customers in the oil and gas industry and for supervisory services performed at agreed-upon or contractual rates. Revenues are recognized when earned during the month that the rental is provided or the supervisory service is performed. Rental or service agreement terms are for relatively short periods of time, and therefore, Oil Tools does not record revenue transactions under long-term contract arrangements, and did not participate in multiple-element revenue transactions during the years ended December 31, 2003 and 2002, and the nine months ended September 30, 2004.
Securities
      Debt securities for which Oil Tools has the positive intent and ability to hold until maturity are classified as held to maturity and valued at historical cost, adjusted for amortization of premiums and accretion of discounts computed by the level-yield method.
      Realized gains and losses, based on the specifically identified cost of the security, are included in net income.
Self-Insurance
      Oil Tools and other affiliated companies have elected to jointly self-insure costs related to employee health and accident benefit programs. Costs resulting from noninsured losses are charged to income when incurred. Oil Tools has purchased insurance that limits its exposure for individual claims.
Fair Value of Financial Instruments
      The fair value of financial assets and liabilities, other than held-to-maturity securities which are disclosed in Note 2, approximate their carrying values at September 30, 2004 and December 31, 2003 and 2002.
Note 2: Investments
Held-to-maturity Securities
      The amortized cost and approximate fair values of held-to-maturity securities are as follows:
                             
    2004   2003   2002
             
Debt securities
                       
 
Amortized cost
  $ 1,887,747     $ 1,865,770     $  
 
Unrealized gains
    182,253       144,230        
                   
   
Fair Value
  $ 2,070,000     $ 2,010,000     $  
                   
      Maturities of held-to-maturity debt investments at September 30, 2004:
                 
    Amortized   Approximate Fair
    Cost   Value
         
After one through five years
  $ 1,887,747     $ 2,070,000  
             

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OIL TOOL RENTALS, INC.
Notes to Financial Statements – (Continued)
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
Note 3: Long-Term Debt
                         
    2004   2003   2002
             
Note payable, bank(A)
  $     $     $ 118,964  
Note payable, bank(B)
          1,131,936        
Note payable, bank(C)
    887,915              
                   
      887,915       1,131,936       118,964  
Less current maturities
    290,413       589,095       118,964  
                   
    $ 597,502     $ 542,841     $ 0  
                   
      Aggregate annual maturities of long-term debt at September 30, 2004, were:
         
2005
  $ 290,413  
2006
    315,370  
2007
    282,132  
       
    $ 887,915  
       
 
(A)  Originally due March 2005; payable $28,366 monthly including interest at 4.75%; secured by inventory, machinery and equipment. The note was also personally guaranteed by Oil Tools’ majority stockholder. The note was paid in 2003.
 
(B)  Originally due February 2006; payable $52,101 monthly including interest at 4.50%; secured by inventory, machinery and equipment. The note was also personally guaranteed by Oil Tools’ majority stockholder. The note was paid in May 2004.
 
(C)  Due July 2007; payable $29,427 monthly including interest at LIBOR; secured by inventory, machinery and equipment. The note is personally guaranteed by Oil Tools’ majority stockholder.
Note 4: Related Party Transactions
      During 2001, Oil Tools loaned $600,000 to a service company owned solely by one of its stockholders. This loan was payable in monthly installments and was due on demand. The note is not secured. At September 30, 2004, December 31, 2003 and December 31, 2002, Oil Tools was owed $0, $366,450 and $604,505, respectively, on this note.
      At September 30, 2004, Oil Tools owed $231,000 to a service company owned solely by one of its stockholders. This payable has no stated terms. Imputed interest on this note arrangement was deemed to be insignificant.
      Oil Tools provides oil field services to affiliated companies and also purchases various oil field and administrative services from affiliated companies. The following summarizes the activity for the nine months ended September 30, 2004, and the years ended December 31, 2003 and 2002:
                         
    2004   2003   2002
             
Rental income
  $ 1,072,220     $ 1,299,322     $ 990,840  
Operating expenses
    147,964       164,241       661,447  
Accounts receivable
    415,744       389,075       277,574  
Accounts payable
    2,003       4,926       14,195  

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OIL TOOL RENTALS, INC.
Notes to Financial Statements – (Continued)
Nine Months Ended September 30, 2004, and
Years Ended December 31, 2003 and 2002
      Held-to-maturity securities are corporate bonds of a company owned solely by one of its stockholders. These bonds are publicly traded on a national exchange.
Note 5: Profit Sharing Plan
      Oil Tools has a 401(k) profit sharing plan covering substantially all employees. Oil Tools makes discretionary contributions to the plan based on a percentage of eligible employees’ compensation. During 2004, 2003 and 2002 contributions to the plan were 5% of eligible employees’ compensation. Contributions to the plan for the nine months ended September 30, 2004, and years ended December 31, 2003 and 2002, were approximately $26,000, $37,000 and $30,000, respectively.
Note 6: Significant Estimates and Concentrations
      Accounting principles generally accepted in the United States of America require disclosure of certain significant estimates and current vulnerabilities due to certain concentrations. Those matters include the following:
Customers
      Oil Tools earned approximately 37%, 37% and 34% of its revenues from one related party customer during the nine months ended 2004 and the years ended 2003 and 2002, respectively.
Self-Insurance
      Oil Tools and other affiliated companies participate jointly in a self-insurance pool covering health and workers’ compensation claims made by employees up to the first $50,000 (health) and $500,000 (workers’ compensation), respectively, per claim. Any amounts paid above these are reinsured through third-party providers. Premiums charged to Oil Tools are based on estimated costs per employee of the pool. Estimates of the liability recorded could differ materially from the ultimate loss.
Cash Balances
      At September 30, 2004, Oil Tools’ cash accounts exceeded federally insured limits by approximately $340,000.
Note 7: Subsequent Event
      Subsequent to September 30, 2004, Oil Tools was restructured and 100% of the stock of the restructured entity was sold to Complete Energy Services, Inc., a majority-owned company of SCF-IV, L.P. Oil Tools’ common stock was sold for cash and for capital stock of Complete Energy Services, Inc., pursuant to the purchase agreement.

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REPORT OF INDEPENDENT CERTIFIED PUBLIC ACCOUNTANTS
Board of Directors
Big Mac Tank Trucks, Inc. and Affiliates
      We have audited the consolidated balance sheets of Big Mac Tank Trucks, Inc., Big Mac Transports, Inc. and Fugo Services, Inc. (collectively, the “Company”) as of October 31, 2005 and December 31, 2004, and the related consolidated statements of operations, shareholder’s equity, and cash flows for the period from January 1, 2005 through October 31, 2005 and for the year ended December 31, 2004. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
      We conducted our audits in accordance with auditing standards generally accepted in the United States of America as established by the Auditing Standards Board of the American Institute of Certified Public Accountants. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
      In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of October 31, 2005 and December 31, 2004, and the results of their operations and their cash flows for the period from January 1, 2005 through October 31, 2005 and for the year ended December 31, 2004, in conformity with accounting principles generally accepted in the United States of America.
  /s/ Grant Thornton LLP
Houston, Texas
January 31, 2006

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Consolidated Balance Sheets
As of October 31, 2005 and December 31, 2004
                     
    October 31,   December 31,
    2005   2004
         
ASSETS
Current assets:
               
 
Cash and cash equivalents
  $ 743,556     $ 493,511  
 
Accounts receivable – trade, net
    5,186,600       3,507,666  
 
Prepaid expenses and other current assets
    100,196       258,135  
             
   
Total current assets
    6,030,352       4,259,312  
Property, plant and equipment, net
    4,109,816       2,666,348  
             
   
Total assets
  $ 10,140,168     $ 6,925,660  
             
 
LIABILITIES AND SHAREHOLDER’S EQUITY
 
Current liabilities:
               
 
Accounts payable
  $ 274,324     $ 150,774  
 
Accrued liabilities
    452,334       145,389  
             
   
Total current liabilities
    726,658       296,163  
Shareholder’s equity:
               
 
Common stock, $1 par value; authorized 125,000 shares; issued and outstanding 4,500 shares
    4,500       4,500  
 
Additional paid-in capital
    426,046       426,046  
 
Retained earnings
    8,982,964       6,198,951  
             
   
Total shareholder’s equity
    9,413,510       6,629,497  
             
   
Total liabilities and shareholder’s equity
  $ 10,140,168     $ 6,925,660  
             
The accompanying notes are an integral part of these statements.

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Consolidated Statements of Operations
For the Ten Months Ended October 31, 2005 and the Year Ended December 31, 2004
                     
    2005   2004
         
Revenues
  $ 21,070,793     $ 19,493,625  
Cost of services
    9,280,423       8,534,590  
             
          11,790,370       10,959,035  
Selling, general and administrative expenses
               
 
Salaries and wages
    926,377       974,510  
 
Other general and administrative expenses
    664,780       708,356  
             
          1,591,157       1,682,866  
             
   
Net income
  $ 10,199,213     $ 9,276,169  
             
The accompanying notes are an integral part of these statements.

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Consolidated Statements of Shareholder’s Equity
For the Ten Months Ended October 31, 2005 and the Year Ended December 31, 2004
                                 
        Additional       Total
    Common   Paid-In   Retained   Shareholder’s
    Stock   Capital   Earnings   Equity
                 
Balance at January 1, 2004
  $ 4,500     $ 426,046     $ 4,880,782     $ 5,311,328  
Shareholder distributions
                (7,958,000 )     (7,958,000 )
Net income
                9,276,169       9,276,169  
                         
Balance at December 31, 2004
    4,500       426,046       6,198,951       6,629,497  
Shareholder distributions
                (7,415,200 )     (7,415,200 )
Net income
                10,199,213       10,199,213  
                         
Balance at October 31, 2005
  $ 4,500     $ 426,046     $ 8,982,964     $ 9,413,510  
                         
The accompanying notes are an integral part of these statements.

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Consolidated Statements of Cash Flows
For the Ten Months Ended October 31, 2005 and the Year Ended December 31, 2004
                       
    2005   2004
         
Cash flows from operating activities:
               
 
Net income
  $ 10,199,213     $ 9,276,169  
 
Depreciation
    870,473       795,578  
 
Changes in assets and liabilities:
               
   
Increase in accounts receivable
    (1,678,934 )     (555,866 )
   
(Increase) decrease in prepaids and other
    157,939       (191,172 )
   
Increase (decrease) in accounts payable
    123,550       (4,253 )
   
Increase in accrued payables
    306,945       45,576  
             
     
Net cash provided by operating activities
    9,979,186       9,366,032  
Investing activities:
               
 
Purchase of property and equipment
    (2,313,941 )     (1,207,910 )
             
     
Net cash used in investing activities
    (2,313,941 )     (1,207,910 )
Financing activities:
               
 
Distributions to shareholder
    (7,415,200 )     (7,958,000 )
             
     
Net cash used in financing activities
    (7,415,200 )     (7,958,000 )
             
Increase in cash
    250,045       200,122  
Cash and cash equivalents beginning of period
    493,511       293,389  
             
Cash and cash equivalents end of period
  $ 743,556     $ 493,511  
             
The accompanying notes are an integral part of these statements.

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Notes to Consolidated Financial Statements
Ten Months Ended October 31, 2005 and Year Ended December 31, 2004
NOTE A – NATURE OF OPERATIONS
     1. Nature of Operations
      Big Mac Tank Trucks, Inc., Big Mac Transports, Inc. and Fugo Services, Inc. (collectively, “Big Mac”), provides trucking services and saltwater disposal for oil and gas producers in Oklahoma and Arkansas.
      Big Mac’s business depends, to a large degree, on the level of spending by oil and gas companies for exploration, development and production activities. Therefore, a sustained increase or decrease in the price of natural gas or oil, which could have a material impact on exploration, development and production activities, also could materially affect our financial position, results of operations and cash flows.
NOTE B – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
     1. Basis of Consolidation
      The consolidated financial statements include the accounts of Big Mac Tank Trucks, Inc. Big Mac Transports, Inc. and Fugo Services, Inc. (see Note F). All intercompany accounts among entities in Big Mac are eliminated in consolidation.
     2.  Use of Estimates
      The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
     3.  Cash and Cash Equivalents
      Big Mac considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
     4.  Accounts Receivable
      Accounts receivable are stated at the amount billed to customers. Big Mac provides an allowance for doubtful accounts, if necessary, which is based upon a review of outstanding receivables, historical collection information and existing economic conditions. Accounts receivable are ordinarily due 30 days after the issuance of the invoice. Delinquent receivables are written off based on an individual credit evaluation and specific circumstances of the customer. The allowance for doubtful accounts was $80,695 and $0 at October 31, 2005 and December 31, 2004, respectively.
     5.  Property and Equipment
      Property, plant and equipment, which includes renewals and betterments, are stated at cost less accumulated depreciation. Repair and maintenance costs are expensed as period costs. Depreciation on our buildings, trucks and equipment is computed using the straight-line method over the estimated useful life of the asset after provision for salvage value (buildings — 39 years; trucks and equipment — 5 years). Upon retirement or other disposal of fixed assets, the cost and related accumulated depreciation are removed from the respective accounts and any gains or losses are included in our results of operations.
      Big Mac reviews its assets for impairment when events or changes in circumstances indicate that the net book value of property, plant and equipment may not be recovered over its remaining service life. Provisions for asset impairment are charged to income when the sum of estimated future cash flows, on an

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Notes to Consolidated Financial Statements — (Continued)
Ten Months Ended October 31, 2005 and Year Ended December 31, 2004
undiscounted basis, is less than the asset’s net book value. Actual impairment charges are recorded using an estimate of discounted future cash flows. There was no impairment recorded in 2005 or 2004.
     6.  Revenue Recognition
      Revenues are considered earned and directly related costs are recorded when an understanding has been agreed to between Big Mac and a financially capable customer encompassing a determinable price, and the services have been rendered by delivering the product to its final destination or completing other services, and collectibility of Big Mac’s fee is reasonably assured. Typically there are no other motor carriers involved in Big Mac’s transportation services and all deliveries are made directly to customers.
     7.  Income Taxes
      Big Mac’s shareholder has elected to have Big Mac’s income taxed as an “S” Corporation under the provisions of the Internal Revenue Code and a similar section of the Oklahoma income tax law; therefore, taxable income or loss is reported to the individual shareholder for inclusion in his respective tax returns. No provision for federal and state income taxes is included in these statements.
     8.  Advertising Costs
      Advertising costs of $7,524 and $11,846 in 2005 and 2004, respectively, were charged to operations when incurred.
NOTE C – PROPERTY, PLANT AND EQUIPMENT
      The major components of our property, plant and equipment as of October 31, 2005 and December 31, 2004 were as follows:
                   
    2005   2004
         
Automobiles, trucks and equipment
  $ 6,957,166     $ 5,705,574  
Frac tanks
    4,520,679       3,458,330  
Buildings
    148,907       148,907  
Land
    36,000       36,000  
Office equipment and other
    650,162       650,162  
             
 
Total property, plant and equipment
    12,312,914       9,998,973  
Accumulated depreciation
    (8,203,098 )     (7,332,625 )
             
 
Net property, plant and equipment
  $ 4,109,816     $ 2,666,348  
             
NOTE D – RELATED PARTY TRANSACTIONS
      An individual stockholder owns 100% of the outstanding stock in Big Mac Tank Trucks, Inc., Big Mac Transports, Inc., and Fugo Services, Inc. Big Mac Tank Trucks, Inc. leases transportation equipment from Big Mac Transports, Inc. under short term leases. Big Mac Tank Trucks, Inc. also compensates Fugo Services, Inc. to dispose of saltwater transported from wells that Big Mac Tank Trucks, Inc. services. Big Mac Tank Trucks, Inc. is the only customer of Big Mac Transports, Inc. and Fugo Services, Inc. and pays all the expenses of the other two companies. All transactions among companies and related receivables and payables have been eliminated in the consolidated financial statements.

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Notes to Consolidated Financial Statements — (Continued)
Ten Months Ended October 31, 2005 and Year Ended December 31, 2004
      The shareholder also participates in various other business activities outside of the management and ownership of the three consolidated companies. These activities are listed below:
  •  Wilburton State Bank  — The shareholder has an 82% ownership interest in this bank and is a member of the Bank’s Board. This was the only bank used by Big Mac Tank Trucks, Inc., Big Mac Transports, Inc. and Fugo Services, Inc. until October 31, 2005.
 
  •  First National Bank of McAlester  — The shareholder is a member of the Board for this bank. This bank was the primary bank that was being utilized by the three companies subsequent to October 31, 2005.
 
  •  Brower Oil & Gas — This is an exploration and production company. The shareholder has interests in wells operated by this company. Brower Oil & Gas uses the services of Big Mac Tank Trucks, Inc. at their well sites. At October 31, 2005 and December 31, 2004, Big Mac Tank Trucks, Inc. had receivables of $24,796 and $23,459, respectively, due from Brower Oil & Gas. For the periods ended October 31, 2005 and December 31, 2004, the amount of revenue related to those services was $133,325 and $188,752, respectively.
 
  •  Meade Energy Corporation — This is an exploration and production company. The shareholder has interests in wells operated by this company. Meade Energy Corporation uses the services of Big Mac Tank Trucks, Inc. at their well sites. At October 31, 2005 and December 31, 2004, Big Mac Tank Trucks, Inc. had a receivable of $50,414 and $9,527, respectively, due from Meade Energy Corporation. For the periods ended October 31, 2005 and December 31, 2004, the amount of revenue related to those services was $81,484 and $75,409, respectively.
 
  •  Chesapeake Operating Inc (Chesapeake Energy) — This is an exploration and production company. The shareholder has interests in wells operated by this company. Chesapeake Inc. uses the services of Big Mac Tank Trucks, Inc. at their well sites and is one of Big Mac’s largest customers; revenues from Chesapeake were $1,628,910 or 7.7% of Big Mac’s total sales in 2005 and $2,111,366 or 10.9% in 2004. At October 31, 2005 and December 31, 2004, Big Mac Tank Trucks, Inc. had receivables of $429,243 and $362,076, respectively, due from Chesapeake Operating Inc.
NOTE E – SIGNIFICANT ESTIMATES AND CONCENTRATIONS
      Accounting principles generally accepted in the United States of America require a disclosure of certain significant estimates and current vulnerabilities due to certain concentrations. Those matters include the following:
     1. Cash
      Big Mac’s cash in banks exceeded the FDIC insured limits by approximately $5,791,000 at October 31, 2005 and by approximately $548,000 at December 31, 2004.
     2. Concentration of Credit Risk
      Big Mac earned approximately 15% of its revenues from one unrelated customer during the period ending October 31, 2005 and approximately 20% of its revenues from the same unrelated customer during 2004.

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BIG MAC TANK TRUCKS, INC. AND AFFILIATES
Notes to Consolidated Financial Statements — (Continued)
Ten Months Ended October 31, 2005 and Year Ended December 31, 2004
NOTE F – ADOPTION OF NEW ACCOUNTING PRONOUNCEMENT — FIN 46(R) — VARIABLE INTEREST ENTITIES
      FASB Interpretation (FIN) 46(R), “Consolidation of Variable Interest Entities-An Interpretation of ARB No. 51” was applicable to Big Mac by the beginning of the first annual period beginning after December 15, 2004 which was January 1, 2005. Big Mac adopted FIN 46(R) on January 1, 2005 and has elected to reflect its application as of the beginning of 2004 for these comparative financial statements as permitted under FIN 46(R). There was no cumulative effect adjustment needed as of January 1, 2004.
      Big Mac Tank Trucks, Inc. rents truck transports from Big Mac Transports, Inc. and uses various disposal wells owned by Fugo Services, Inc. both of whom are variable interest entities (VIEs) whose sole purpose and activity is to provide services to Big Mac Tank Trucks, Inc. Big Mac Tank Trucks, Inc. consolidates these VIEs because it is the VIEs’ primary beneficiary. The consolidated financial statements include the following amounts as of October 31, 2005 and December 31, 2004 as a result of the VIEs’ consolidation:
                 
    2005 Amounts   2004 Amounts
         
    (In thousands)   (In thousands)
Assets
  $ 275     $ 95  
Liabilities and debt
           
Minority interest
           
      Big Mac Tank Trucks, Inc., Big Mac Transports, Inc. and Fugo Services, Inc. are commonly owned by one individual and therefore there is no minority interest present.
NOTE G – FAIR VALUE INSTRUMENTS
      The fair value of our cash equivalents, trade receivables and trade payables approximate their carrying values due to the short-term nature of these instruments.
NOTE H – COMMITMENTS AND CONTINGENCIES
      Big Mac is subject to various legal proceedings and claims that arise in the ordinary course of business. In the opinion of management and based on the present knowledge of the facts, management believes the amount of any potential liability with respect to these actions will not have a material adverse effect on the consolidated financial position, results of operations or liquidity of Big Mac.
NOTE I – SUBSEQUENT EVENT
      Subsequent to October 31, 2005, the companies were restructured and 100% of the membership interests in the restructured entities were sold to Complete Production Services, Inc. for cash.

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Report of Independent Certified Public Accountants
The Board of Directors and Shareholders
Hyland Enterprises, Inc.
      We have audited the balance sheets of Hyland Enterprises, Inc. (the “Company”) as of August 31, 2004 and February 29, 2004, and the related statements of earnings, shareholders’ equity and cash flows for the six months ended August 31, 2004 and the year ended February 29, 2004. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
      We conducted our audits in accordance with auditing standards generally accepted in the United States of America as established by the Auditing Standards Board of the American Institute of Certified Public Accountants. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
      In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Hyland Enterprises, Inc. as of August 31, 2004 and February 29, 2004, and the results of its operations and its cash flows for the six months and the year then ended in conformity with accounting principles generally accepted in the United States of America.
/s/ Grant Thornton LLP
Houston, Texas
March 7, 2006

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HYLAND ENTERPRISES, INC.
Balance Sheets
August 31, 2004 and February 29, 2004
                     
    August 31, 2004   February 29, 2004
         
ASSETS
CURRENT ASSETS
               
 
Cash and cash equivalents
  $ 94,901     $ 312,264  
 
Restricted certificates of deposits
    92,831       30,333  
 
Accounts receivable, net of allowance for doubtful accounts of $118,498 and $97,892
    6,900,127       7,282,059  
 
Notes receivable
    1,126,352       552,526  
 
Asset held for sale
    41,140        
 
Inventory
    1,150,282       1,033,488  
 
Prepaid expenses and other assets
    796,699       578,021  
             
   
Total current assets
    10,202,332       9,788,691  
PROPERTY, PLANT AND EQUIPMENT, net
    14,376,196       11,975,127  
             
   
TOTAL ASSETS
  $ 24,578,528     $ 21,763,818  
             
 
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
               
 
Accounts payable
  $ 2,703,830     $ 2,568,190  
 
Accrued liabilities
    2,597,594       1,944,265  
 
Transfers of receivables with recourse
    3,236,115       3,170,903  
 
Current maturities of long-term debt
    3,221,489       2,531,819  
             
   
Total current liabilities
    11,759,028       10,215,177  
DEFERRED TAX LIABILITY
    1,906,695       1,931,860  
LONG-TERM DEBT
    6,841,721       5,791,955  
             
   
Total liabilities
    20,507,444       17,938,992  
COMMITMENTS AND CONTINGENCIES
SHAREHOLDERS’ EQUITY
               
 
Common stock, no par value, 50,000 shares authorized, 12,340 shares issued and outstanding
    1,000       1,000  
 
Retained earnings
    4,070,084       3,823,826  
             
   
Total shareholders’ equity
    4,071,084       3,824,826  
             
   
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY
  $ 24,578,528     $ 21,763,818  
             
The accompanying notes are an integral part of these statements.

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HYLAND ENTERPRISES, INC.
Statements of Earnings
August 31, 2004 and February 29, 2004
                     
    Six months   Twelve months
    ended   ended
    August 31, 2004   February 29, 2004
         
REVENUES
  $ 20,179,258     $ 31,634,296  
OPERATING EXPENSES
               
 
Costs of goods and services
    9,305,121       14,926,264  
 
General and administrative expenses
    1,483,086       1,896,581  
 
Taxes and insurance
    1,141,042       1,650,904  
 
Depreciation
    1,688,280       2,181,325  
 
Salaries and employee benefits
    3,303,777       3,033,502  
 
Shop expenses
    2,561,996       4,796,404  
             
   
Total operating expenses
    19,483,302       28,484,980  
             
EARNINGS FROM OPERATIONS
    695,956       3,149,316  
OTHER INCOME
    81,231       430,654  
INTEREST EXPENSE
    398,326       590,767  
             
 
NET EARNINGS BEFORE TAXES
    378,861       2,989,203  
PROVISION FOR INCOME TAXES
    132,603       1,076,113  
             
 
NET EARNINGS
  $ 246,258     $ 1,913,090  
             
The accompanying notes are an integral part of these statements.

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HYLAND ENTERPRISES, INC.
Statement of Shareholders’ Equity
Six Months Ended August 31, 2004 and Year Ended February 29, 2004
                         
            Total
    Common   Retained   shareholders’
    Stock   earnings   equity
             
Balance at February 28, 2003
  $ 1,000     $ 1,910,736     $ 1,911,736  
Net earnings
          1,913,090       1,913,090  
                   
Balance at February 29, 2004
    1,000       3,823,826       3,824,826  
Net earnings
          246,258       246,258  
                   
Balance at August 31, 2004
  $ 1,000     $ 4,070,084     $ 4,071,084  
                   
The accompanying notes are an integral part of these statements.

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HYLAND ENTERPRISES, INC.
Statements of Cash Flows
August 31, 2004 and February 29, 2004
                         
    Six months   Twelve months
    ended   ended
    August 31 2004   February 29, 2004
         
Cash flows from operating activities:
               
 
Net earnings
  $ 246,258     $ 1,913,090  
 
Adjustments to reconcile net earnings to net cash provided by operating activities:
               
   
Gain on sale of equipment
    (54,257 )     (173,093 )
   
Depreciation
    1,688,280       2,181,325  
   
Deferred income taxes
    (25,165 )     1,044,137  
   
Changes in assets and liabilities:
               
     
Decrease (increase) in accounts receivable
    381,932       (2,605,210 )
     
Decrease (increase) in prepaid expenses and other assets
    (218,678 )     (126,203 )
     
Increase in notes receivable
    (573,826 )     (169,103 )
     
Increase in inventory
    (116,794 )     (447,079 )
     
Increase in assets held for sale
    (41,140 )      
     
Increase in accounts payable
    135,640       1,235,409  
     
Increase in accrued liabilities
    653,329       369,955  
             
       
Net cash provided by operating activities
    2,075,579       3,223,228  
Cash flows from investing activities:
               
 
Purchase of equipment
    (4,155,925 )     (3,517,668 )
 
Proceeds from sale of equipment
    120,833       357,888  
 
Proceeds from sale of investments
          172,019  
 
Purchases of certificates of deposit
    (62,498 )     (10,000 )
             
       
Net cash used in investing activities
    (4,097,590 )     (2,997,761 )
Cash flows from financing activities:
               
 
Proceeds from long-term debt
    3,074,145       1,091,580  
 
Proceeds from transfers of accounts receivable, net
    65,212       1,064,126  
 
Payments on long-term debt
    (1,334,709 )     (2,086,083 )
             
       
Net cash provided by financing activities
    1,804,648       69,623  
             
Net (increase) decrease in cash and cash equivalents
    (217,363 )     295,090  
Cash and cash equivalents at beginning of period
    312,264       17,174  
             
Cash and cash equivalents at end of period
  $ 94,901     $ 312,264  
             
Supplemental cash flow information:
               
 
Cash paid during the year for interest
  $ 398,326     $ 590,767  
 
Cash paid during the year for income taxes
    125,000       31,976  
Non-cash activities:
               
 
Purchase of equipment for notes payable
    3,074,145       4,610,438  
The accompanying notes are an integral part of these statements.

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HYLAND ENTERPRISES, INC.
Notes to Financial Statements
August 31, 2004 and February 29, 2004
NOTE A — NATURE OF OPERATIONS
      Hyland Enterprises, Inc., (“Hyland”) specializes in drilling completions, production services including production and fresh water hauling, frac tank rental, gravel hauls and construction, heavy equipment rentals and moves. Frac tanks are typically rented weekly and heavy equipment is rented monthly. Hyland is headquartered in Rawlins, Wyoming with locations in Wamsutter, Baggs and Rock Springs, Wyoming and Rifle, Colorado.
NOTE B — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
     1.  Use of Estimates and Reclassifications
      The preparation of financial statements in conformity with accounting principles generally accepted in the U.S. requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. Certain amounts from the prior year have been reclassified to conform to the current year presentation.
     2.  Cash and Cash Equivalents
      Hyland considers all highly liquid investments with an original maturity of three months or less to be cash equivalents. At August 31, 2004 and February 29, 2004, Hyland has cash accounts that exceeded the Federal Deposit Insurance Corporation insured limit by $525,819 and $857,993. Hyland has not experienced any losses in such accounts and believes it is not exposed to any significant credit risk on cash and cash equivalents. Restricted cash consists of certificates of deposit required by the State of Wyoming to ensure proper land restoration following water extraction. Certificates of deposits can not be redeemed without authorization from the State of Wyoming.
     3.  Inventory
      Inventory, which is stated at the lower of average cost or market, consists primarily of truck parts for repairs and maintenance on capitalized fixed assets, and crushed rock which is held for resale.
     4.  Accounts Receivable and Allowance for Doubtful Accounts
      Hyland’s accounts receivables are due from customers located in its service areas. Credit is extended based on evaluation of a customer’s financial condition. Accounts receivable are due within 30 days and are stated at amounts due from customers net of allowance of doubtful accounts. Hyland reviews its receivables on a regular basis and adjusts the allowance of doubtful accounts accordingly. Hyland determines its allowance by considering factors including the length of time trade accounts receivable are past due, Hyland’s previous loss history, the customer’s current ability to pay its obligation to Hyland and the condition of the general economy and the industry as a whole. The allowance for doubtful accounts was $118,498 and $97,892 at August 31, 2004 and February 29, 2004.
     5.  Notes Receivable
      Hyland’s notes receivable consist of amounts due from owner/operators that are associated with Hyland whereby Hyland has financed equipment which secures the notes for the owner/operator. An amortization schedule is prepared for each note and interest at an annual rate of 12% charged on a monthly basis in accordance with the amortization schedule. In addition, as of August 31, 2004, Hyland also had a note receivable from the president and a majority shareholder of Hyland. The total amount of

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HYLAND ENTERPRISES, INC.
Notes to Financial Statements — (Continued)
August 31, 2004 and February 29, 2004
this note receivable was $927,997 as of August 31, 2004. This amount was paid in full on September 3, 2004 when Hyland’s stock was sold (See Note K). The shareholder note receivable consisted of a series of advances from June 19, 2003 through August 9, 2004, totaling $939,113 at interest rates from 4.57% to 5.13%. These advances were not secured by any collateral. Interest income for the six months ended August 31, 2004 on all notes was $19,976 and for the year ended February 29, 2004 was $35,604.
     6.  Asset Held for Sale
      As of August 31, 2004, Hyland plans to dispose of a truck which is classified as asset held for sale. This asset was disposed of by sale in 2005.
     7.  Property, Plant and Equipment
      Capital assets are carried at cost and depreciated on a straight-line basis over the following lives:
         
    Life
     
Buildings
    39 years  
Field equipment, trucks and trailers
    5-10  years  
Office equipment
    5 years  
      Total depreciation expense for the six months ended August 31, 2004 and for the twelve months ended February 29, 2004 was $1,688,280 and $2,181,325.
     8.  Revenue Recognition
      Hyland recognizes revenues on service contracts in the period in which the service is provided. Hyland recognizes revenues on the sale of materials and supplies when products have been shipped, title and risk of loss have been transferred and collectibility is probable. Hyland recognizes revenues from the rental of machinery and equipment in the period during which these items are rented to outside parties.
     9.  Income Taxes
      Hyland recognizes deferred income tax assets and liabilities for the expected future tax consequences for events that have been included differently on the financial statements and income tax returns. The deferred tax assets and liabilities are computed based on the difference between the financial statement and income tax bases of assets and liabilities using the enacted tax rates in effect in the year in which the differences are expected to reverse. Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit Hyland does not expect to be realized.
     10.  Transfers of Receivables with Recourse
      Hyland entered into a service contract in August, 1999 with a financial factor that obligated the factor to purchase eligible accounts receivable from Hyland on a daily basis with recourse. The original term of the agreement was one year, renewed annually unless cancelled by either party within the time periods specified in the contract. Hyland accounts for the contract as a secured borrowing. Under the terms of the agreement, the factor will advance Hyland 90% of the eligible accounts receivable with the remaining 10% to be held back as a non-interest bearing reserve which will be used as security and to absorb certain expenses. The factor charges a daily service fee based on the prime rate which averaged approximately 1.2% of the receivables transferred. In addition various transactional fees are charged by the factor. Total fees for the six months ended August 31, 2004 and the year ended February 29, 2004 were $135,592 and $179,634 respectively, and are shown as interest expense in the accompanying statement of earnings. The

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HYLAND ENTERPRISES, INC.
Notes to Financial Statements — (Continued)
August 31, 2004 and February 29, 2004
advances by the factor are secured by all accounts receivable and intangible assets of Hyland. As of August 31, 2004 and February 29, 2004, secured borrowings from the factor totaled $3,236,115 and $3,170,903 and the reserve held by the factor was $366,045 and $317,090, respectively. Accounts receivable at August 31, 2004 and February 29, 2004 included $3,236,115 and $3,170,903 of factored accounts, respectively.
NOTE C — 401(k) PLAN
      Hyland provides a 401(k) plan to all eligible employees. An eligible employee is any employee who has attained age 21 and completed one year of service as defined by the plan. Participation is elective and not required. Eligible employees may begin participating in the Plan on the first day of the month following the completion of the eligibility requirements. Under the Plan, participating employees can defer an amount of their compensation not to exceed maximum dollar amounts determined by the Federal government each year. Hyland did not make discretionary matching contributions to the Plan for the periods ended August 31, 2004 and February 29, 2004.
NOTE D — PROPERTY, PLANT AND EQUIPMENT
      The major components of our property, plant and equipment as of August 31, 2004 and February 29, 2004 are as follows:
                   
    August 31, 2004   February 29, 2004
         
Land
  $ 80,049     $ 327,491  
Buildings
    730,445       585,445  
Vehicles
    4,365,827       4,220,590  
Equipment
    20,783,630       16,970,242  
             
 
Total property, plant and equipment
    25,959,951       22,103,768  
Accumulated depreciation
    11,583,755       10,128,641  
             
 
Net property, plant and equipment
  $ 14,376,196     $ 11,975,127  
             
NOTE E — RELATED PARTY TRANSACTIONS
      An individual shareholder, C. Douglas Dowlin, owns 12,203 shares which is 98.89% of the outstanding shares as of August 31, 2004. Mr. Dowlin is also the President and Treasurer of Hyland. The remaining outstanding shares in the amount of 137 shares or 1.11% of the total are owned by Joseph L. Carnes who is also the Vice President and Secretary of Hyland. Both shareholders are actively involved in the business of Hyland on a daily basis.
      C. Douglas Dowlin, dba Falcon Filters owns various facilities that are currently leased by Hyland. In addition, C. Douglas Dowlin and Lori Dowlin (wife of C. Douglas Dowlin) jointly own various facilities that are currently leased by Hyland. A third entity, Red Canyon Ventures, owns land that is also leased by Hyland. Red Canyon Ventures is a joint venture between C. Douglas Dowlin and Bill Davis, who is the manager for Hyland’s Rifle, Colorado terminal. Remote Enterprises, LLC is an entity owned by Denice

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HYLAND ENTERPRISES, INC.
Notes to Financial Statements — (Continued)
August 31, 2004 and February 29, 2004
Tripp, daughter of C. Douglas Dowlin. Following is a summary of these properties along with the total rent and other payments for the six months ended August 31, 2004:
           
        Rent
Description of facility   Lessor   payments
         
Main Office, South Shop, Washbay, Safety Office, North Shop, Drive Line Facility, Lots 1, 2, 8, 9, 15, 22 & 23 in the Wamsutter Industrial Park and the Rock Springs Terminal Yard — all leases are month to month plus monthly rental of two pickups
  C. Douglas Dowlin dba Falcon Filters, Douglas Dowlin and Lori Dowlin   $160,000
 
East storage yard in Rifle, Colorado consisting of five fenced yards
  Red Canyon Ventures   87,383
 
Rental of ten Wichita 660 BBL frac tanks — numbers 3091 through 3100
  Remote Enterprises, LLC   74,250
         
 
 
Total rents to related parties
      $321,633
         
          Other payments
         
 
 
Total advances, net of interest payments received, to related parties
  Various loans to C. Douglas Dowlin and/or Falcon Filters   $613,843
         
 
 
Total purchases of equipment from related parties
  Purchase of mobile homes and two used pick-up trucks from Falcon Filters   $124,000
         
NOTE F — INVENTORY
      The major components of inventory as of August 31, 2004 and February 29, 2004 are as follows:
                   
    August 31, 2004   February 29, 2004
         
Crushed rock
  $ 501,511     $ 406,497  
Truck parts and shop supples
    648,771       626,991  
             
 
Inventory
  $ 1,150,282     $ 1,033,488  
             
NOTE G — LONG-TERM DEBT
      Long-term debt consists of the following at August 31, 2004 and February 29, 2004:
                   
    August 31, 2004   February 29, 2004
         
Various note payables to finance companies, secured with interest of 0 to 10.5%, payable in monthly installments through various dates ranging from September 2004 to September 2009
  $ 10,063,210     $ 8,323,774  
Less current maturities
    3,221,489       2,531,819  
             
 
Total long-term debt
  $ 6,841,721     $ 5,791,955  
             

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HYLAND ENTERPRISES, INC.
Notes to Financial Statements — (Continued)
August 31, 2004 and February 29, 2004
      Substantially all of Hyland’s property and equipment secure the various notes payable. Maturities of notes payable for the five years following August 31, 2004, are as follows:
         
2005
  $ 3,221,489  
2006
    2,614,447  
2007
    2,242,039  
2008
    1,440,206  
Thereafter
    545,029  
       
    $ 10,063,210  
       
NOTE H — INCOME TAXES
      The provision for income taxes consists of:
                 
    August 31, 2004   February 29, 2004
         
Current tax provision
  $ 157,768     $ 31,976  
Deferred tax provision
    (25,165 )     1,044,137  
             
Provision for income taxes
  $ 132,603     $ 1,076,113  
             
      Deferred tax liabilities consist of the following:
                   
    August 31, 2004   February 29, 2004
         
Deferred tax liabilities
               
 
Property, plant and equipment
  $ 1,901,589     $ 1,956,600  
 
Other
    5,106       (24,740 )
             
Total deferred tax liabilities
  $ 1,906,695     $ 1,931,860  
             
NOTE I — COMMON STOCK
      Hyland has authorized 50,000 shares of no par value common stock, of which 12,340 shares are issued and outstanding on August 31, 2004 and February 29, 2004. Holders of Hyland’s common stock are entitled to one vote per share on all matters to be voted on by shareholders and are entitled to receive dividends, if any, as may be declared from time to time by Hyland’s Board of Directors. Upon any liquidation or dissolution of Hyland, the holders of the common stock are entitled to receive a pro rata share of all of the assets remaining available for distribution to shareholders after settlement of all liabilities.

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HYLAND ENTERPRISES, INC.
Notes to Financial Statements — (Continued)
August 31, 2004 and February 29, 2004
NOTE J — COMMITMENTS AND CONTINGENCIES
      Hyland and its subsidiaries occupy various facilities and lease certain equipment under various lease agreements. The minimum rental commitments under non-cancelable operating leases, with lease terms in excess of one year subsequent to August 31, 2004, are as follows:
         
2005
  $ 159,343  
2006
    79,427  
2007
    8,963  
2008
    3,803  
2009
    517  
       
    $ 252,053  
       
      Rental expense amounted to $1,250,736, including short-term equipment rentals of $1,003,283, for the period ended August 31, 2004.
      Hyland is subject to various legal proceedings and claims that arise in the ordinary course of business. As of August 31, 2004, the financial statements include an accrual in the amount of $575,000 for the settlement of a lawsuit in November 2004 with Cloverleaf Construction, Inc. dba Plum Creek Sand and Gravel and Theodore Roosevelt Jordon dba Ted Jordon. In the opinion of management, the amount of any liability with respect to any other actions is either too early to determine or will not materially affect Hyland’s financial statements or results of operations.
NOTE K — SUBSEQUENT EVENTS
      A sale of all of Hyland’s outstanding stock occurred on September 3, 2004 to Complete Energy Services, Inc.

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REPORT OF INDEPENDENT CERTIFIED PUBLIC ACCOUNTANTS
Board of Directors
Monument Well Service Company and Affiliates
      We have audited the combined balance sheets of Monument Well Service Company, R & W Rentals, Ltd. and Medco, LLC (“Monument Well Service Company and Affiliates” or the “Company”) as of April 30, 2004 and December 31, 2003, and the related combined statement of earnings, stockholder’s equity, and cash flows for the four month and twelve month periods then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
      We conducted our audits in accordance with auditing standards generally accepted in the United States of America as established by the Auditing Standards Board of the American Institute of Certified Public Accountants. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe our audits provide a reasonable basis for our opinion.
      In our opinion, the combined financial statements referred to above present fairly, in all material respects, the combined financial position of Monument Well Service Company and Affiliates at April 30, 2004 and December 31, 2003, and the combined results of their operations and their cash flows for the four month and twelve month periods then ended, in conformity with accounting principles generally accepted in the United States of America.
/s/ Grant Thornton LLP
Houston, Texas
February 24, 2006

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Combined Balance Sheets
April 30, 2004 and December 31, 2003
                       
    April 30,   December 31,
    2004   2003
         
ASSETS
CURRENT ASSETS
               
 
Cash and cash equivalents
  $ 1,791,749     $ 1,637,888  
 
Accounts receivable
    1,111,254       1,199,198  
 
Other current assets
    1,262       6,854  
             
     
Total current assets
    2,904,265       2,843,940  
PROPERTY AND EQUIPMENT
               
 
Equipment
    4,598,354       4,330,970  
 
Vehicles
    721,237       721,501  
   
Less accumulated depreciation
    (2,169,681 )     (2,026,555 )
             
     
Total property and equipment
    3,149,910       3,025,916  
INVESTMENTS
          20,526  
             
    $ 6,054,175     $ 5,890,382  
             
 
LIABILITIES AND EQUITY
CURRENT LIABILITIES
               
 
Current maturities of long-term debt
  $     $ 34,706  
 
Accounts payable
    294,565       20,916  
 
Accrued liabilities
    81,057       141,574  
 
Notes payable — stockholder
    36,442       133,427  
             
     
Total current liabilities
    412,064       330,623  
COMMITMENTS AND CONTINGENCIES
               
STOCKHOLDERS’ EQUITY
    5,642,111       5,559,759  
             
    $ 6,054,175     $ 5,890,382  
             
The accompanying notes are an integral part of these statements.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Combined Statements of Earnings
April 30, 2004 and December 31, 2003
                   
    April 30,   December 31,
    2004   2003
    (Four Months)   (Twelve Months)
         
REVENUE
  $ 3,294,758     $ 7,754,858  
 
Less discounts
    (80,101 )     (214,416 )
             
      3,214,657       7,540,442  
COSTS GOODS AND SERVICES
               
 
Wages
    772,625       1,365,898  
 
Equipment rental
    312,082       115,783  
 
Material
    186,543       680,691  
 
Repairs and maintenance
    164,827       429,134  
 
Payroll tax expense
    82,322       101,932  
 
Depreciation
    144,624       384,591  
 
Other
    280,848       565,926  
             
      1,943,871       3,643,955  
             
 
Gross profit
    1,270,786       3,896,487  
EXPENSES
               
 
Salaries and employee benefits
    184,653       1,086,774  
 
General and administrative
    114,063       347,281  
 
Rent
    19,500       77,778  
 
Taxes and insurance
    127,425       473,751  
             
 
Total expenses
    445,641       1,985,584  
OTHER (EXPENSE) INCOME
    (5,259 )     3,327  
             
NET EARNINGS
  $ 819,886     $ 1,914,230  
             
The accompanying notes are an integral part of these statements.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Combined Statements of Stockholders’ Equity
April 30, 2004
                                         
        Additional           Total
    Common   Paid-In   Members’   Retained   Stockholders’
    Stock   Capital   Capital   Earnings   Equity
                     
Balance at December 31, 2002
  $ 93,924     $ 6,914     $ 108,380     $ 3,529,620     $ 3,738,838  
Stockholder distributions
                      (95,000 )     (95,000 )
Net earning
                      1,914,230       1,914,230  
Other comprehensive income
                      1,691       1,691  
                               
Balance at December 31, 2003
    93,924       6,914       108,380       5,350,541       5,559,759  
Stockholder distributions
                      (735,566 )     (735,566 )
Net earnings
                      819,886       819,886  
Other comprehensive income
                      (1,968 )     (1,968 )
                               
Balance at April 30, 2004
  $ 93,924     $ 6,914     $ 108,380     $ 5,432,893     $ 5,642,111  
                               
The accompanying notes are an integral part of this statement.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Combined Statements of Cash Flows
Period ended April 30, 2004 and December 31, 2003
                         
    April 30, 2004   December 31, 2003
    (Four Months)   (Twelve Months)
         
Cash flows from operating activities
               
 
Net earnings
  $ 819,886     $ 1,914,230  
 
Adjustments to reconcile net earnings to net cash provided by operating activities
               
   
Depreciation
    144,624       384,591  
   
Loss on sale of property, plant and equipment
    (3,547 )      
   
Gain on sale of investment
    1,102        
   
Changes in assets and liabilities Decrease in accounts receivable
    87,944       69,630  
     
Decrease in prepaid and other assets
    5,592       16,168  
     
Increase in accounts payable and accrued liabilities
    213,132       99,765  
             
       
Net cash provided by operating activities
    1,268,733       2,484,384  
Cash flows from investing activities
               
 
Proceeds from sale of property, plant and equipment
    10,610        
 
Purchase of property, plant, and equipment
    (275,681 )     (1,424,266 )
 
Proceeds from sale of investments
    17,456        
             
       
Net cash used in investing activities
    (247,615 )     (1,424,266 )
Cash flows from financing activities
               
 
Cash distributions
    (735,566 )     (95,000 )
 
Payments on notes payable
    (131,691 )     (38,924 )
             
       
Net cash used in financing activities
    (867,257 )     (133,924 )
             
Net increase in cash and cash equivalents
    153,861       926,194  
Cash and cash equivalents at beginning of year
    1,637,888       711,694  
             
Cash and cash equivalents at end of year
  $ 1,791,749     $ 1,637,888  
             
The accompanying notes are an integral part of these statements.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Notes to Combined Financial Statements
April 30, 2004 and December 31, 2003
NOTE A — NATURE OF OPERATIONS
      Monument Well Service Company, a Colorado corporation, R & W Rentals, Ltd. and Medco, LLC (collectively “Monument”), are oil well site service providers with operations in the Rocky Mountain region of the United States. Monument provides a wide range of services to the oil and gas exploration industry, including well servicing, well site rentals, materials and supplies and other support services.
      Monument’s business depends, to a large degree, on the level of spending by oil and gas companies for exploration, development and production activities. Therefore, a sustained increase or decrease in the price of natural gas or oil, which could have a material impact on exploration, development and production activities, also could materially affect the Monument’s financial position, results of operations and cash flows.
NOTE B — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
      A summary of the significant accounting policies consistently applied in the preparation of the accompanying consolidated financial statements follows.
     1.  Basis of Combination
      The combined financial statements include Monument Well Service Company and its affiliates. These entities were 100% owned by an individual through personal ownership and affiliated persons or companies. The financial statements of these affiliates were combined with no adjustments to the balance sheet or statement of stockholder’s equity. All significant intercompany transactions and accounts have been eliminated in the combination.
     2.  Accounts Receivable and Allowance for Doubtful Accounts
      Monument’s accounts receivables are due from customers located in the service areas. Credit is extended based on evaluation of a customer’s financial condition. Accounts receivables are due within 30 days from the date of invoice. Monument reviews its accounts receivable every 30 days. When a customer balance is greater than 45 days past due, a follow-up invoice is sent. Monument has not experienced accounts receivable write-offs in the past and its current assessment is that all receivables will be collected in full. Monument had no allowance for doubtful accounts at either December 31, 2003 or April 30, 2004.
     3.  Use of Estimates
      The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Monument reviews all significant estimates affecting its financial statements on a recurring basis and records the effect of any necessary adjustments in the financial statements. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements and estimates may change in the future when improved information is available or events culminate. Certain amounts from the prior year have been reclassified to conform to the current year presentation.
     4.  Revenue Recognition
      Monument recognizes revenues for oilfield services and equipment rentals in the period in which the services or rental is provided.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Notes to Combined Financial Statements — (Continued)
April 30, 2004 and December 31, 2003
     5.  Cash and Cash Equivalents
      Monument considers all highly liquid investments with maturities of three months or less to be cash equivalents.
     6.  Property and Equipment
      Property and equipment are stated at cost and depreciated on a straight-line basis over their estimated useful lives, as follows:
         
    Life in Years
Service Rigs
    25  
Service Equipment
    7-10  
Vehicles, equipment and furniture
    3  
     7.  Income Taxes
      The stockholder has elected, under the provisions of Subchapter S of the Internal Revenue Code, to have Monument’s income treated for Federal income tax purposes substantially as if Monument were a partnership. The stockholder’s respective equitable share in the net income or losses of Monument is reportable on his individual tax return. Accordingly, the financial statements reflect no provision or liability for Federal and state income taxes.
     8.  Long-Lived Assets
      Monument reviews its long-lived assets for impairment whenever events or changes indicate that the carrying amount of an asset may not be recoverable. No impairments were recognized in the four and twelve month periods ended April 30, 2004 and December 31, 2003.
NOTE C — LONG-TERM DEBT
      Long-term debt consists of the following:
                   
    April 30,   December 31,
    2004   2003
         
Note payable to a finance company with no interest; principal payments of $828 payable monthly with the last payment due January 31, 2004; collateralized by a truck
  $     $ 9,934  
Note payable to a finance company with no interest; principal payments of $832 payable monthly with the last payment due December 16, 2004; collateralized by a truck
          10,820  
Note payable to a finance company with no interest; principal payments of $1,160 payable monthly with the last payment due December 10, 2004; collateralized by a truck
          13,952  
             
            34,706  
 
Less current maturities
          (34,706 )
             
    $     $  
             
      Monument elected to pay-off the notes due in December 2004 on January 28, 2004.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Notes to Combined Financial Statements — (Continued)
April 30, 2004 and December 31, 2003
NOTE D — FAIR VALUE INSTRUMENTS
      The fair value of Monument’s cash equivalents, trade receivables, trade payables and note payable to shareholder approximate their carrying value due to the short-term nature of these instruments.
NOTE E — EMPLOYEE BENEFIT PLANS
      Monument sponsors a 401(k) defined contribution plan that provides retirement benefits to all employees that elect to participate. Under the plan, participating employees may defer up to 15% of their base pre-tax compensation. Monument matches the first 5% of such contributions. During the four month period ended April 30, 2004 and the twelve months ended December 31, 2003, Monument contributed approximately $22,000 and $65,000, respectively, related to this plan.
NOTE F — MAJOR CUSTOMERS AND CONCENTRATION OF CREDIT RISK
      Almost all of Monument’s revenues are generated from services provided to oilfield companies throughout the Rocky Mountain region of the United States of America. While the individual job contracts may be short-term in nature, relationships with these entities may be longstanding. Customers with revenues in excess of 10% of total revenues as of the four month period ended April 30, 2004 are as follows:
                   
    April 30,   December 31,
    2004   2003
         
Monument Well Service Company
               
 
Customer A
    25 %     41 %
 
Customer B
    4 %     31 %
 
Customer C
    21 %     26 %
R & W Rentals, Ltd.
               
 
Customer A
    18 %     18 %
      Financial instruments which subject Monument to concentrations of credit risk consist almost entirely of trade accounts receivable. Management has not incurred significant bad debts in the past.
      At April 30, 2004 and December 31, 2003, Monument had deposits in domestic banks in excess of federally insured limits of approximately $1.7 million and $.2 million, respectively.
NOTE G — COMMON STOCK
      Monument has authorized 25,025 shares of no par value common stock. As of April 30, 2004 and December 31, 2003, Monument had issued 18,825 shares of common stock. The holder of the common stock has full voting rights. Dividends may be paid to the stockholder as approved by the Board of Directors.
NOTE H — RELATED PARTY TRANSACTIONS
      Monument owed its stockholder $36,442 and $133,427 at April 30, 2004 and December 31, 2003, respectively. The notes carry no interest and are due on demand.
      Monument leases office space from a stockholder. The lease is on a month-to-month basis and has been in place for over 10 years. The current lease has a rental rate of $6,500 per month.

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MONUMENT WELL SERVICE COMPANY AND AFFILIATES
Notes to Combined Financial Statements — (Continued)
April 30, 2004 and December 31, 2003
NOTE I — COMMITMENTS AND CONTINGENCIES
      In the normal course of business, Monument may become involved in litigation incidents to operations. At present, management is unaware of any matters in dispute, which would have a material effect on the financial position or results of operations of Monument.
NOTE J — SUBSEQUENT EVENT
      A sale of Monument’s ownership interest occurred on May 6, 2004 to Complete Energy Services, Inc. The Subchapter S election was terminated at that time.

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APPENDIX A
Glossary of Selected Industry Terms
      Acidizing. The pumping of acid into the wellbore to remove near-well formation damage and other damaging substances.
      Acoustic pressure surveys. Surveys that determine oil and gas reservoir pressure from surface using pressure transducers and sound waves.
      Artificial lift equipment. A system that adds energy to the fluid column in a wellbore with the objective of initiating and improving production from the well.
      Blowout. An uncontrolled flow of reservoir fluids into the wellbore, and sometimes catastrophically to the surface.
      Blowout preventer (BOP). A large valve at the top of a well that may be closed to regain control of a reservoir if the drilling crew or other wellsite personnel loses control of formation fluids.
      Bottom-hole assemblies. The lower portion of the drillstring, consisting of (from the bottom up in a vertical well) the bit, bit sub, a mud motor (in certain cases), stabilizers, drill collars, heavy-weight drillpipe, jarring devices (“jars”) and crossovers for various threadforms.
      Casing. Large-diameter pipe lowered into an openhole wellbore and cemented in place.
      Casing patch. A downhole assembly or tool system used in the remedial repair of casing damage, corrosion or leaks.
      Cementing. To prepare and pump cement into place in a wellbore.
      Choke. A device incorporating an orifice that is used to control fluid flow rate or downstream system pressure.
      Coiled tubing. A long, continuous length of pipe wound on a spool. The pipe is straightened prior to pushing into a wellbore and recoiled to spool the pipe back onto the transport and storage spool.
      Completion phase. A generic term used to describe the assembly of downhole tubulars and equipment required to enable safe and efficient production from an oil or gas well. The point at which the completion process begins may depend on the type and design of the well.
      Downhole. Pertaining to or in the wellbore (as opposed to being on the surface).
      Drillpipe. Tubular steel conduit fitted with special threaded ends called tool joints. The drillpipe connects the surface equipment with the bottomhole assembly, both to pump drilling fluid to the bit and to be able to raise, lower and rotate the bottomhole assembly and bit.
      Drill string. The combination of the drillpipe, the bottomhole assembly and any other tools used to make the drill bit turn at the bottom of the wellbore.
      Electric-line. Related to any aspect of logging that employs an electrical cable to lower tools into the borehole and to transmit data.
      Fishing. The application of tools, equipment and techniques for the removal of junk, debris or lost or stuck equipment from a wellbore.
      Flapper valves. A check valve that has a spring-loaded plate (or flapper) that may be pumped through, generally in the downhole direction, but closes if the fluid attempts to flow back through the drillstring to the surface.

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      Flare gas. A vapor or gas that is burned through a pipe or burners.
      Flowback. The process of allowing fluids to flow from the well following a treatment, either in preparation for a subsequent phase of treatment or in preparation for cleanup and returning the well to production.
      Foam. Drilling foam is a fluid that contains air or gas bubbles, that can withstand high salinity, hard water, solids, entrained oil and high temperatures.
      Frac tanks. A tank used to hold fluid during a frac job. Capacity of such tanks are from 400 to 600 bbls.
      Hydrocarbon. A naturally occurring organic compound comprising hydrogen and carbon. Hydrocarbons can be as simple as methane, but many are highly complex molecules, and can occur as gases, liquids or solids. Petroleum is a complex mixture of hydrocarbons. The most common hydrocarbons are natural gas, oil and coal.
      Jars. A mechanical device used downhole to deliver an impact load to another downhole component, especially when that component is stuck.
      Jetting. A downhole treatment in which a fluid laden with solid particles is used to remove deposits from the surface of wellbore tubulars and completion components.
      Landing nipples. A completion component fabricated as a short section of heavy wall tubular with a machined internal surface that provides a seal area and a locking profile.
      Live-well. A well that is flowing or has the ability to flow into the wellbore.
      Log. The measurement versus depth or time, or both, of one or more physical quantities in or around a well. The term comes from the word “log” used in the sense of a record or a note.
      Logging tools. The downhole hardware needed to make a log.
      Manifold. An arrangement of piping or valves designed to control, distribute and often monitor fluid flow. Manifolds are often configured for specific functions, such as a choke or kill manifold used in well-control operations and a squeeze manifold used in squeeze-cementing work.
      Milling. A downhole tool used to cut and remove material from equipment or tools located in the wellbore.
      Mud coolers. A mud cooling system is used in a variety of applications where drilling safety or efficiency is enhanced by cooling the drilling fluid.
      Nitrogen unit. A high-pressure pump or compressor unit capable of delivering high-purity nitrogen gas for use in oil or gas wells.
      Packer. A downhole device used in many completions to isolate the annulus from the production conduit, enabling controlled production, injection or treatment.
      Progressive Cavity (PC) pump. A type of sucker rod-pumping unit that uses a rotor and a stator. The rotation of the rod cavity by means of an electric motor at surface causes the fluid contained in a cavity to flow upward.
      Perforating guns. A device used to perforate oil and gas wells in preparation for production. Perforating guns contain several shaped explosive charges and are available in a range of sizes and configurations.
      Perforate. To create holes in the casing or liner to achieve efficient communication between the reservoir and the wellbore.

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      Pipe handling. Equipment used to move and connect drillpipe.
      Plug drilling. The process by which plugs are removed from the wellbore.
      Plugs. A downhole packer assembly used in a well to seal off or isolate a particular formation for testing, acidizing, cementing, etc.; also a type of plug used to seal off a well temporarily while the wellhead is removed.
      Plunger lift. An artificial-lift method principally used in gas wells to unload relatively small volumes of liquid.
      Power swivels. On a drilling rig, a swivel is a mechanical device that must simultaneously suspend the weight of the drillstring, provide for rotation of the drill string beneath it while keeping the upper portion stationary, and permit high-volume flow of high-pressure drilling mud from the fixed portion to the rotating portion without leaking. Well service rigs do not have integral swivels; therefore, if rotation capability for drilling or any other reason is required on a well service rig, then a power swivel is added to the well service rig.
      Drilling rig. The machine used to drill a wellbore.
      Shale. A fine-grained, fissile, sedimentary rock formed by consolidation of clay- and silt-sized particles into thin, relatively impermeable layers.
      Slickline. A thin non-electric cable used for selective placement and retrieval of wellbore hardware, such as plugs, gauges and valves. Valves and sleeves can also be adjusted using slickline tools.
      Sliding sleeves. Completion devices that can be operated to provide a flow path between the production conduit and the annulus.
      Snubbing. The act of putting drillpipe or tubing into the wellbore when the blowout preventers (BOPs) are closed and pressure is contained in the well.
      Stabilizers. A bottom-hole-assembly component having a body diameter about the same size as a drill collar, and having longitudinal or spiral blades that form a larger diameter, often at or near hole diameter.
      Supply stores. Retail stores that sell equipment for use in oil and gas exploration, development and production.
      Swabbing. The act of unloading liquids from the production tubing to initiate or improve flow from the reservoir.
      Tight sands. A type of unconventional tight reservoir. Tight reservoirs are those which have low permeability, often quantified as less than 0.1 millidarcies.
      Tubing string. A pipe set inside the well casing, through which the oil or gas is produced.
      Underbalanced. A well condition where the amount of pressure exerted on a formation is less than the internal fluid pressure of the formation, enabling formation fluids to enter the wellbore. The drilling rate typically increases as an underbalanced condition is approached.
      Well casing – see Casing.
      Well clean-up. A period of controlled production, generally following a stimulation treatment, during which time treatment fluids return from the reservoir formation.
      Wellbore. The physical conduit from surface into the hydrocarbon reservoir.
      Whipstock. An inclined wedge placed in a wellbore to force the drill bit to start drilling in a direction away from the wellbore axis.
      Wireline. A general term used to describe well-intervention operations conducted using single-strand or multistrand wire or cable for intervention in oil or gas wells.

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(COMPLETE PRODUCTION SERVICES LOGO)


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PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
ITEM 13. Other Expenses of Issuance and Distribution
      Set forth below are the expenses (other than underwriting discounts and commissions) expected to be incurred in connection with the issuance and distribution of the securities registered hereby. With the exception of the SEC registration fee and the NASD filing fee, the amounts set forth below are estimates:
           
SEC registration fee
  $ 40,607  
NASD filing fee
    35,000  
NYSE listing fee
       
Printing and engraving expenses
       
Legal fees and expenses
       
Accounting fees and expenses
       
Blue sky fees and expenses (including legal fees)
       
Transfer agent and registrar fees
       
Miscellaneous
       
       
 
Total
  $    
       
ITEM 14. Indemnification of Directors and Officers
      Section 145 of the Delaware General Corporation Law (“DGCL”) provides that a corporation may indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action, suit or proceeding whether civil, criminal, administrative or investigative (other than an action by or in the right of the corporation) by reason of the fact that he is or was a director, officer, employee or agent of the corporation, or is or was serving at the request of the corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement actually and reasonably incurred by him in connection with such action, suit or proceeding if he acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the corporation, and, with respect to any criminal action or proceeding, had no reasonable cause to believe his conduct was unlawful. Section 145 further provides that a corporation similarly may indemnify any such person serving in any such capacity who was or is a party or is threatened to be made a party to any threatened, pending or completed action or suit by or in the right of the corporation to procure a judgment in its favor by reason of the fact that he is or was a director, officer, employee or agent of the corporation or is or was serving at the request of the corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against expenses (including attorneys’ fees) actually and reasonably incurred in connection with the defense or settlement of such action or suit if he acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the corporation and except that no indemnification shall be made in respect of any claim, issue or matter as to which such person shall have been adjudged to be liable to the corporation unless and only to the extent that the Delaware Court of Chancery or such other court in which such action or suit was brought shall determine upon application that, despite the adjudication of liability but in view of all of the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expenses which the Delaware Court of Chancery or such other court shall deem proper. Our certificate of incorporation and bylaws provide that indemnification shall be to the fullest extent permitted by the DGCL for all our current or former directors or officers. As permitted by the DGCL, our certificate of incorporation provides that we will indemnify our directors against liability to us or our stockholders for monetary damages for breach of fiduciary duty as a director, except (1) for any breach of the director’s duty of loyalty to us or our stockholders, (2) for acts or omissions not in good faith or which involve intentional

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misconduct or knowing violation of law, (3) under Section 174 of the DGCL or (4) for any transaction from which a director derived an improper personal benefit.
      We have also entered into indemnification agreements with all of our directors and all of our executive officers (including each of our named executive officers). These indemnification agreements are intended to permit indemnification to the fullest extent now or hereafter permitted by the DGCL. It is possible that the applicable law could change the degree to which indemnification is expressly permitted.
      The indemnification agreements cover expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement incurred as a result of the fact that such person, in his or her capacity as a director or officer, is made or threatened to be made a party to any suit or proceeding. The indemnification agreements generally cover claims relating to the fact that the indemnified party is or was an officer, director, employee or agent of us or any of our affiliates, or is or was serving at our request in such a position for another entity. The indemnification agreements also obligate us to promptly advance all reasonable expenses incurred in connection with any claim. The indemnitee is, in turn, obligated to reimburse us for all amounts so advanced if it is later determined that the indemnitee is not entitled to indemnification. The indemnification provided under the indemnification agreements is not exclusive of any other indemnity rights; however, double payment to the indemnitee is prohibited.
      We are not obligated to indemnify the indemnitee with respect to claims brought by the indemnitee against:
  •  us, except for:
  •  claims regarding the indemnitee’s rights under the indemnification agreement;
 
  •  claims to enforce a right to indemnification under any statute or law; and
 
  •  counter-claims against us in a proceeding brought by us against the indemnitee; or
  •  any other person, except for claims approved by our board of directors.
      We have obtained director and officer liability insurance for the benefit of each of the above indemnitees. These policies include coverage for losses for wrongful acts and omissions and to ensure our performance under the indemnification agreements. Each of the indemnitees are named as an insured under such policies and provided with the same rights and benefits as are accorded to the most favorably insured of our directors and officers.
ITEM 15. Recent Sales of Unregistered Securities
      During the past three years, we have issued unregistered securities to a limited number of persons, as described below. None of these transactions involved any underwriters or public offerings, and we believe that each of these transactions was exempt from registration requirements pursuant to Section 3(a)(9) or Section 4(2) of the Securities Act, Regulation D promulgated thereunder or Rule 701 of the Securities Act. The recipients of these securities represented their intention to acquire the securities for investment only and not with a view to or for sale in connection with any distribution thereof, and appropriate legends were affixed to the share certificates and instruments issued in these transactions. No remuneration or commission was paid or given directly or indirectly.
      On September 20, 2002, we entered into a combination agreement with Integrated Production Services Ltd. (“IPSL”). Pursuant to the combination agreement, all of the outstanding shares of IPSL were acquired in exchange for 9,388,020 of our shares.
      On April 30, 2003, we acquired all of the shares of Ess-Ell Tool Co. Ltd. and Sentry Oil Tools LLC for a total consideration of $3.9 million in cash and 147,498 of our shares.
      On March 31, 2004, we issued an aggregate of 263,392 shares of our common stock to former stockholders of Double Jack Testing and Services, Inc. (“Double Jack”) as consideration for the purchase of all of the shares of common stock of Double Jack.

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      On December 10, 2004, we issued 208,604 shares of our common stock to former stockholders of MGM Well Services, Inc. (“MGM”), as consideration for the acquisition of all of the common stock of MGM. We also issued 28,448 shares of restricted stock to key employees who were former employees of MGM. In addition, the purchase included contingent consideration of up to 214,132 shares of our common stock over the period of March 31, 2005 to December 31, 2006 based on certain operating results of MGM.
      On February 11, 2005, we issued 2,655,336 shares of our common stock and 344,664 non-vested shares of restricted stock to former stockholders of Parchman, as consideration for the acquisition of all of the capital stock of Parchman. Of the non-vested restricted shares, 58,272 shares vested on December 31, 2005 upon termination of an employee, in accordance with the agreement terms, and were deemed issued. In addition, the acquisition included contingent consideration of up to 1,000,000 shares of our common stock over the period of February 11, 2005 to December 31, 2005 based on certain operating results of one of our divisions.
      On June 20, 2005, Joseph C. Winkler, our Chief Executive Officer and President, purchased 41,796 shares of our common stock at purchase price of $8.50 per share or an aggregate price of $355,270.
      On July 7, 2005, we issued 136,428 shares of our common stock to former stockholders of Roustabout Specialties Inc. (“RSI”), as consideration for the acquisition of all of the capital stock of RSI.
      On September 12, 2005, we completed the Combination. We issued an aggregate of 32,120,642 shares of our common stock to former stockholders of CES and 4,901,762 shares of our common stock to former stockholders of IEM. In addition, we issued 144,232 shares of restricted stock to former holders of CES restricted stock and 262,774 shares of restricted stock to former holders of IEM restricted stock. Holders of options to purchase shares of CES common stock received an aggregate of options to purchase 1,914,206 shares of our common stock and holders of options to purchase shares of IEM common stock received an aggregate of options to purchase 67,754 shares of our common stock.
      On September 29, 2005, we issued 90,364 shares of our common stock to John D. Schmitz, an officer of one of our subsidiaries, as consideration for the acquisition of the assets of Spindletop Production Services, Ltd.
      On October 3, 2005, James F. Maroney, III, our Vice President, General Counsel and Secretary, purchased 42,900 shares of our common stock at a purchase price of $11.66 per share or an aggregate price of $499,999.50
      On October 3, 2005, Kenneth L. Nibling, our Vice President, Human Resources and Administration, purchased 42,900 shares of our common stock at a purchase price $11.66 per share or an aggregate price $499,999.50.
      On October 10, 2005, we issued 16,046 shares of our common stock to some of our employees as a bonus for their services.
      On November 1, 2005, we acquired the equity interests of Big Mac. In connection with this acquisition, we issued options to purchase 90,000 shares of our common stock to the former owner of Big Mac and options to purchase 140,000 shares of our common stock to certain of Big Mac’s employees.
      On December 29, 2005, we effected a 2-for-1 common stock split. As a result, all common stock and per share data, as well as data related to other securities including stock warrants, restricted stock and stock options, have been adjusted retroactively to give effect to this stock split for all periods presented within this prospectus, except par value which remained at $0.01 per share, resulting in an insignificant reclassification between common stock and additional paid-in-capital.
      We issued options to purchase an aggregate of 504,188 shares of our common stock to certain of our current and former directors and officers under our 2001 Stock Incentive Plan and the Parchman Plan during the period beginning on January 1, 2005 and ending on November 1, 2005. During the year ended December 31, 2004, we issued options to purchase an aggregate of 166,144 shares of our common stock to certain of our current and former directors and officers under our 2001 Stock Incentive Plan. During the

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year ended December 31, 2003, we issued options to purchase an aggregate of 25,400 shares of our common stock to certain of our current and former directors and officers under our 2001 Stock Incentive Plan. During the year ended December 31, 2002, we issued options to purchase an aggregate of 118,944 shares of our common stock to certain of our current and former directors and officers under our 2001 Stock Incentive Plan.
      We also issued 97,576 shares of our restricted stock to certain of our current and former directors and officers under our 2001 Stock Incentive Plan during the period beginning on January 1, 2005 and ending on November 1, 2005. We issued 17,560 shares of our restricted stock to certain of our current and former directors and officers under our 2001 Stock Incentive Plan during the year ended December 31, 2004. During the year ended December 31, 2003, we did not issue any shares of our restricted stock to our current and former directors or officers under our 2001 Incentive Plan. During the year ended December 31, 2002, we did not issue shares of our restricted stock to our current and former directors or officers under our 2001 Stock Incentive Plan.
      We relied upon Rule 701 of the Securities Act, among others, for the exemption from registration of the issuance of these options and shares of restricted stock.
ITEM 16. Exhibits and Financial Statement Schedules
      a. Exhibits:
             
  1 .1     Form of Underwriting Agreement
  3 .1**     Amended and Restated Certificate of Incorporation
  3 .2**     Amended and Restated Bylaws
  4 .1     Specimen Stock Certificate representing common stock
  5 .1**     Form of Opinion of Vinson & Elkins L.L.P.
  10 .1**     Form of Indemnification Agreement
  10 .2**     Employment Agreement dated as of June 22, 2005 with Joseph C. Winkler
  10 .3*     Form of Amended and Restated Stockholders’ Agreement dated as of               , 2006 by and among Complete Production Services, Inc. and the stockholders listed therein
  10 .4**     Combination Agreement dated as of August 9, 2005, with Complete Energy Services, Inc., I.E. Miller Services, Inc. and Complete Energy Services, LLC and I.E. Miller Services, LLC
  10 .5**     Credit Agreement, dated as of September 12, 2005 by and among Complete Production Services, Inc., as U.S. Borrower, Integrated Production Services Ltd., as Canadian Borrower, Wells Fargo Bank, National Association, as U.S. Administrative Agent, U.S. Issuing Lender and US Swingline Lender, HSBC Bank Canada, as Canadian Administrative Agent, Canadian Issuing Lender and Canadian Swingline Lender, and the Lenders party thereto, Wells Fargo Bank, National Association as Sole Book Runner and Co-Lead Arranger, UBS Securities LLC, as Co-Lead Arranger and Syndication Agent and Amegy Bank N.A. and Comerica Bank, as Co-Documentation Agents
  10 .6**     Integrated Production Services, Inc. 2001 Stock Incentive Plan
  10 .7**     Complete Energy Services, Inc. 2003 Stock Incentive Plan
  10 .8**     First Amendment to the Complete Energy Services, Inc. 2003 Stock Incentive Plan
  10 .9**     Second Amendment to the Complete Energy Services, Inc. 2003 Stock Incentive Plan
  10 .10**     I.E. Miller Services, Inc. 2004 Stock Incentive Plan
  10 .11**     Amended and Restated Integrated Production Services and Parchman Energy Group, Inc. Stock Incentive Plan
  10 .12**     Strategic Customer Relationship Agreement, dated as of October 14, 2004, by and among Complete Energy Services, Inc., CES Mid-Continent Hamm, Inc. and Continental Resources, Inc.
  10 .13     Form of Non-Qualified Option Grant Agreement (Executive Officer)
  10 .14     Form of Non-Qualified Option Grant Agreement (Non-Employee Director)
  10 .15**     Form of Restricted Stock Grant Agreement (Employee)
  10 .16**     Form of Restricted Stock Agreement (Non-Employee Director)
  10 .17*     Compensation Package Term Sheet dated as of December 1, 2005 with J. Michael Mayer

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  10 .18*     Compensation Package Term Sheet dated as of October 3, 2005 with James F. Maroney, III
  10 .19*     Compensation Package Term Sheet dated as of October 3, 2005 with Kenneth L. Nibling
  21 .1     Subsidiaries of Complete Production Services, Inc.
  23 .1*     Consent of Grant Thornton LLP
  23 .2*     Consent of KPMG LLP
  23 .3*     Consent of Darnall, Sikes, Gardes & Frederick
  23 .4*     Consent of BKD LLP
  23 .5**     Consent of Vinson & Elkins L.L.P. (contained in Exhibit 5.1)
  24 .1**     Power of Attorney
 
  Filed herewith
**  Filed previously
      b. Financial Statement Schedules:
      None
ITEM 17. Undertakings
      The undersigned Registrant hereby undertakes:
        (a) Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to directors, officers and controlling persons of the Registrant pursuant to the provisions described in Item 14, or otherwise, the Registrant has been advised that in the opinion of the SEC such indemnification is against public policy as expressed in the Act and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the Registrant of expenses incurred or paid by a director, officer or controlling person of the Registrant in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, the Registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Act and will be governed by the final adjudication of such issue.
 
        (b) To provide to the underwriters at the closing specified in the underwriting agreement, certificates in such denominations and registered in such names as required by the underwriters to permit prompt delivery to each purchaser.
 
        (c) For purpose of determining any liability under the Securities Act of 1933, the information omitted from the form of prospectus filed as part of this Registration Statement in reliance upon Rule 430A and contained in the form of prospectus filed by the Registrant pursuant to Rule 424(b)(1) or (4) or 497(h) under the Securities Act shall be deemed to be part of this Registration Statement as of the time it was declared effective.
 
        (d) For the purpose of determining any liability under the Securities Act of 1933, each post-effective amendment that contains a form of prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

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SIGNATURES
      Pursuant to the requirements of the Securities Act of 1933, as amended, the Registrant has duly caused this Registration Statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Houston, in the State of Texas, on March 17, 2006.
  COMPLETE PRODUCTION SERVICES, INC.
  By:  /s/ Joseph C. Winkler
 
 
  Name: Joseph C. Winkler
  Title: President, Chief Executive Officer and Director
      Pursuant to the requirements of the Securities Act of 1933, as amended, this Registration Statement has been signed below by the following persons in the capacities and on the dates indicated below.
             
Signature   Position   Date
         
 
/s/ Joseph C. Winkler

Joseph C. Winkler
  President, Chief Executive Officer and Director
(Principal Executive Officer)
  March 17, 2006
 
/s/ J. Michael Mayer

J. Michael Mayer
  Senior Vice President and Chief Financial Officer (Principal Financial Officer   March 17, 2006
 
/s/ Robert L. Weisgarber

Robert L. Weisgarber
  Vice President-Accounting and Controller (Principal Accounting Officer   March 17, 2006
 
/s/ Andrew L. Waite*

Andrew L. Waite
  Chairman of the Board   March 17, 2006
 
/s/ David C. Baldwin*

David C. Baldwin
  Director   March 17, 2006
 
/s/ Robert Boswell*

Robert Boswell
  Director   March 17, 2006
 
/s/ Harold G. Hamm*

Harold G. Hamm
  Director   March 17, 2006
 
/s/ W. Matt Ralls*

W. Matt Ralls
  Director   March 17, 2006
 
/s/ R. Graham Whaling*

R. Graham Whaling
  Director   March 17, 2006

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Signature   Position   Date
         
 
/s/ James D. Woods*

James D. Woods
  Director   March 17, 2006
 
*By:   /s/ J. Michael Mayer

J. Michael Mayer
Pursuant to a Power of Attorney previously filed as Exhibit 24.1 to
this Registration Statement
       

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EXHIBIT INDEX
             
  1 .1     Form of Underwriting Agreement
  3 .1**     Amended and Restated Certificate of Incorporation
  3 .2**     Amended and Restated Bylaws
  4 .1     Specimen Stock Certificate representing common stock
  5 .1**     Form of Opinion of Vinson & Elkins LLP
  10 .1**     Form of Indemnification Agreement
  10 .2**     Employment Agreement dated as of June 22, 2005 with Joseph C. Winkler
  10 .3*     Form of Amended and Restated Stockholders’ Agreement dated as of               , 2006 by and among Complete Production Services, Inc. and the stockholders listed therein
  10 .4**     Combination Agreement dated as of August 9, 2005, with Complete Energy Services, Inc., I.E. Miller Services, Inc. and Complete Energy Services, LLC and I.E. Miller Services, LLC
  10 .5**     Credit Agreement, dated as of September 12, 2005 by and among Complete Production Services, Inc., as U.S. Borrower, Integrated Production Services Ltd., as Canadian Borrower, Wells Fargo Bank, National Association, as U.S. Administrative Agent, U.S. Issuing Lender and US Swingline Lender, HSBC Bank Canada, as Canadian Administrative Agent, Canadian Issuing Lender and Canadian Swingline Lender, and the Lenders party thereto, Wells Fargo Bank, National Association as Sole Book Runner and Co-Lead Arranger, UBS Securities LLC, as Co-Lead Arranger and Syndication Agent and Amegy Bank N.A. and Comerica Bank, as Co-Documentation Agents
  10 .6**     Integrated Production Services, Inc. 2001 Stock Incentive Plan
  10 .7**     Complete Energy Services, Inc. 2003 Stock Incentive Plan
  10 .8**     First Amendment to the Complete Energy Services, Inc. 2003 Stock Incentive Plan
  10 .9**     Second Amendment to the Complete Energy Services, Inc. 2003 Stock Incentive Plan
  10 .10**     I.E. Miller Services, Inc. 2004 Stock Incentive Plan
  10 .11**     Amended and Restated Integrated Production Services and Parchman Energy Group, Inc. Stock Incentive Plan
  10 .12**     Strategic Customer Relationship Agreement, dated as of October 14, 2004, by and among Complete Energy Services, Inc., CES Mid-Continent Hamm, Inc. and Continental Resources, Inc.
  10 .13     Form of Non-Qualified Option Grant Agreement (Executive Officer)
  10 .14     Form of Non-Qualified Option Grant Agreement (Non-Employee Director)
  10 .15**     Form of Restricted Stock Grant Agreement (Employee)
  10 .16**     Form of Restricted Stock Agreement (Non-Employee Director)
  10 .17*     Compensation Package Term Sheet dated as of December 1, 2005 with J. Michael Mayer
  10 .18*     Compensation Package Term Sheet dated as of October 3, 2005 with James F. Maroney, III
  10 .19*     Compensation Package Term Sheet dated as of October 3, 2005 with Kenneth L. Nibling
  21 .1     Subsidiaries of Complete Production Services, Inc.
  23 .1*     Consent of Grant Thornton LLP
  23 .2*     Consent of KPMG LLP
  23 .3*     Consent of Darnall, Sikes, Gardes & Frederick
  23 .4*     Consent of BKD LLP
  23 .5**     Consent of Vinson & Elkins L.L.P. (contained in Exhibit 5.1)
  24 .1**     Power of Attorney
 
 *  Filed herewith
 
**  Filed previously