Index to Financial Statements

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. ¨

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. ¨

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. ¨

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. ¨

CALCULATION OF REGISTRATION FEE

Title of Each Class

of Securities to be Registered

Proposed Maximum

Aggregate Offering

Price (1)(2)

Amount of

Registration Fee

Common Stock, par value $0.01

287,500,000

30,763

(1)	Includes common stock issuable upon the exercise of the underwriters’ option to purchase additional shares.

(2)	Estimated solely for the purpose of calculating the registration fee in accordance with Rule 457(o) under the Securities Act of 1933.

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 Commission, acting pursuant to said Section 8(a), may determine.

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 July 3, 2006

PROSPECTUS

Shares

LOGO

Common Stock

This is the initial public offering of Stallion Oilfield Services, Inc. common stock. We are offering shares of our common stock and the selling stockholders, including members of our senior management, are offering shares of our common stock in this initial public offering. No public market currently exists for our common stock. We will not receive any of the proceeds from the shares of our common stock sold by the selling stockholders.

We intend to apply for listing of our common stock on the Nasdaq National Market under the symbol “SOFS.” We currently estimate that the initial public offering price will be between $ and $ per share.

Investing in our common stock involves risk. See “ Risk Factors” beginning on page 11.


	Per Share	Total
Public offering price	$	$

Underwriting discounts and commissions	$	$

Proceeds to Stallion Oilfield Services, Inc. (before expenses)	$	$

Proceeds to the selling stockholders (before expenses)	$	$

We have granted the underwriters a 30-day option to purchase up to an aggregate of additional shares of common stock on the same terms and conditions set forth above if the underwriters sell more than shares of common stock in this offering.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed upon the accuracy or adequacy of this prospectus. Any representation to the contrary is a criminal offense.

Lehman Brothers, on behalf of the underwriters, expects to deliver the shares on or about , 2006


LEHMAN BROTHERS		CREDIT SUISSE		UBS INVESTMENT BANK

, 2006

LOGO

TABLE OF CONTENTS


		Page
Summary		1
Risk Factors		11
Forward-Looking Statements		22
Use of Proceeds		23
Dividend Policy		23
Capitalization		24
Dilution		25
Unaudited Pro Forma Consolidated Financial Data		27
Selected Consolidated Financial Data		30
Management’s Discussion and Analysis of Financial Condition and Results of Operations		33
Business		57


		Page
Management		70
Certain Relationships and Related Party Transactions		77
Principal and Selling Stockholders		80
Description of Capital Stock		81
Shares Eligible for Future Sale		84
Certain United States Federal Tax Considerations for Non-United States Holders		86
Underwriting		89
Legal Matters		94
Experts		94
Where You Can Find More Information		94
Index to Financial Statements		F-1

Dealer Prospectus Delivery Obligation

Until , 2006, 25 days after the date of this prospectus, all dealers that effect transactions in our common stock, 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 underwriters and with respect to their unsold allotments or subscriptions.

ABOUT THIS PROSPECTUS

You should rely only on the information contained in this prospectus. We and the selling stockholders have not authorized any other person to provide you with information different from that contained in this prospectus. If anyone provides you with different or inconsistent information, you should not rely on it. We and the selling stockholders are only offering to sell, and only seeking offers to buy, the common stock in jurisdictions where offers and sales are permitted.

The information contained in this prospectus is accurate only as of the date of this prospectus, regardless of the time of delivery of this prospectus or of any sale of our common stock. Our business, financial condition, results of operations and prospects may have changed since that date.

This prospectus includes market share and industry data and forecasts that we obtained from internal company surveys, market research, consultant surveys, publicly available information and industry publications and surveys. We believe the information included in this prospectus from market research, consultant surveys and industry publications and surveys is reliable, but there can be no assurance as to the accuracy and completeness of such information.

Non-GAAP Financial Measures

The body of accounting principles generally accepted in the United States of America 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 flow, 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. EBITDA is not a substitute for 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 security analysts, investors and other interested parties in the evaluation of companies in our industry, some of which present EBITDA when reporting their results.

SUMMARY

This summary highlights selected information in this prospectus, but it does not contain all of the information that you should consider before deciding to invest in our common stock. You should read this entire prospectus carefully, including the “Risk Factors” section and our historical financial statements and pro forma financial data, which are included elsewhere in this prospectus.

Unless otherwise indicated or the context otherwise requires, the information contained in this prospectus assumes that the underwriters’ option to purchase additional shares is not exercised, the information contained in this prospectus relating to us assumes the completion of the Restructuring as described under the caption “The Restructuring” below, and references in this prospectus to “Stallion,” “we,” “us” and “our” are references to Stallion Oilfield Services, Inc. together with all of its subsidiaries subsequent to the Restructuring and refer to our predecessor entities and their respective subsidiaries prior to the Restructuring.

If you are not familiar with some of the oil and natural gas industry terms used in this prospectus, please read our Glossary of Terms included as Appendix A to this prospectus.

Our Company

We provide wellsite support services and construction and logistics services to exploration and production companies and drilling contractors that conduct drilling and production activities throughout the United States. Our company slogan, Everything but the Rig ^SM, reflects our business strategy of providing a broad and comprehensive range of critical services to support wellsite operations, including workforce accommodations, surface equipment rental, solids control, site construction, rig relocation and heavy equipment hauling. We seek to differentiate ourselves by offering a broad array of wellsite services with a focus on quality and reliability. Our service offerings are designed to improve living and working conditions at the wellsite, wellsite safety and our customers’ productivity. We currently focus on oil and natural gas regions within North America that we believe have attractive long-term potential for growth, including South Texas, the Gulf Coast, ArkLaTex, North Texas, the Permian Basin, the Mid-Continent and Rocky Mountain regions.

Our services span the entire life-cycle of the wellsite—wellsite preparation, rig deployment, drilling activities, production activities and decommissioning. We are typically the first service provider on the wellsite, as we assist in the initial preparation of the wellsite and often haul the rig and related heavy equipment onto the site using our fleet of tractors, trailers, trucks and cranes. Throughout the drilling and completion phases of the well, we provide rental equipment and required support services to the wellsite. We also, in some cases, provide continuing support services during the production phase of the well, including construction of production facilities and well connections to existing pipeline infrastructure. We frequently are the last service provider to leave the wellsite as we perform production facility disassembly and site restoration, which are the last phases of the wellsite decommissioning process.

Our business is comprised of two segments:

Wellsite Support Services. Through our wellsite support services segment, we offer integral services used by oil and natural gas companies, drilling contractors and other wellsite service providers to support wellsite operations. This segment includes the following primary service lines:

•

workforce accommodation units are specifically configured to provide transportable, comfortable living quarters and functional workspaces.

•

Surface equipment rental. We provide a variety of surface rental equipment used in and critical to wellsite activities including forklifts, manlifts, power generators, compressors, loaders and water systems.

•

Communications services. We also provide integrated communications services through our StaRComm^TM (Stallion Remote Communications) satellite system that provides wireless communications via intercoms and telephone, fax and internet/data services throughout the wellsite location.

•

Solids control. We offer performance-based solids control services, closed-loop mud systems and fluid recovery services to help maximize our customers’ operating efficiency at the wellsite. We provide high-quality shakers, mud conditioners, centrifuges and peripheral backside equipment, as well as solids removal and waste handling coordination services.

Construction and Logistics Services. Through our construction and logistics services segment, we offer services that are critical to establish, maintain and decommission the wellsite and position key equipment prior to, during and after drilling operations. This segment includes the following primary service lines:

•

Site construction. We offer construction equipment and services to build and reclaim infrastructure at wellsites before, during and after drilling operations. Our services include site clearing, road construction, mat placement, production facility assembly and construction, pipeline installation, pit remediation, production decommissioning and site restoration. We provide services for wellsites in both land and inland marine environments.

•

Rig relocation and heavy equipment hauling. We offer a fleet of cranes, tractors, trailers, trucks and loaders used for the hauling and relocation of drilling rigs and related heavy equipment. We maintain a focus on providing reliable, efficient and safe transportation services.

Wellsite support services and construction and logistics services are critical to establish and operate the wellsite . These services have historically been provided by small, regional service providers and have not been the focus of larger oilfield service companies. We believe we have a distinct advantage over smaller competitors due to our scale, access to capital and our ability to provide a single supply source for many of our customers’ needs. We believe we differentiate ourselves and thus are able to achieve growth by offering our customers high- quality, professional and reliable equipment and services on a large scale.

Recent Industry Trends

Higher demand for oil and natural gas and a constrained oil and natural gas supply have resulted in higher prices and increased drilling activity. The increase in prices and drilling activity are driving several additional trends that we believe will benefit us:

•

Labor shortages and increasing safety concerns. Due to the increase in rig count and the corresponding increase in demand for labor in the oilfield, our customers continue to attempt to improve living and working conditions at the wellsite to help retain employees. Our customers also continue to enhance their safety procedures to help reduce injuries and to help ensure compliance with more stringent regulatory requirements.

•

Increasingly complex technologies. The development of unconventional oil and natural gas resources is driving the need for complex, new technologies to help increase recovery rates, lower production costs

and accelerate field development. The increasing complexity of technology used in the oil and natural gas development process requires additional technicians on location during drilling and, therefore, additional workforce accommodations.

•

Geographically dispersed drilling operations. Before the consolidation of drilling contractors that began in earnest in the 1990’s, most drilling contractors were regional operators serving an area within a radius of approximately 100 to 200 miles from their home office, and most personnel would drive to and from the wellsite on a daily basis. With the shift toward industry consolidation, crews based in one region now may be sent along with a rig to work on wellsites in geographically dispersed oil and natural gas regions significant distances away. This development has resulted in the need for full-time accommodations for multiple shifts of the rig crew.

•

Increase in drilling and developing unconventional resources. The decline of conventional North American oil and natural gas reservoirs is leading to a shift toward the drilling and development of unconventional oil and natural gas resources. We believe the increased drilling requirements of these unconventional resources will lead to continued drilling activity. Recently, there has been an increase in the construction of new drilling rigs to meet this demand.

•

Increased environmental sensitivity. Continued sensitivity to the environmental impact of drilling and production activities has resulted in increasing regulation of the oil and natural gas industry. Accordingly, wellsite operators are utilizing closed-loop solids control systems to help reduce onsite discharge of drilling fluids and cuttings in environmentally sensitive areas and when working with oil-based and synthetic drilling fluids. These systems require performance-based solids control configurations to maximize drilling fluid efficiency.

•

Outsourcing ancillary services. Some of the services we provide have been historically handled by drilling contractors themselves. In many instances, these services are only ancillary to the primary activity of drilling and completing wells and represent only a minor portion of the total well drilling cost. Many drilling contractors are increasingly electing to outsource these services to suppliers who can provide high-quality and reliable services.

Our Business Strategy

We believe we are well positioned to become a leading provider of wellsite support and construction and logistics services. Our business strategy consists of the following core elements:

Establish and maintain a leadership position in our principal operating areas. We intend to continue to build leading market positions in the areas in which we operate by offering a comprehensive and integrated package of services which allows us to provide our customers with wellsite support services required across their drilling locations. We view the incremental steps in achieving this to include:

•

Deploying our suite of services across existing operating areas. We believe we have developed expertise in specific service lines which can be effectively marketed across the majority of our operating areas. We intend to continue to roll-out our existing services across our current operating areas in an effort to deliver a comprehensive portfolio of services in each region. We believe our established customer base and strong regional relationships will continue to provide a strategic distribution network for our service deployment efforts.

•

Broadening the suite of services we provide. We work closely with our customers to define new service offerings that meet specific customer needs. We intend to continue to invest in developing or acquiring new high-quality assets and services which add to the equipment breadth and quality of our service portfolio.

Focus on service quality, business performance and safety. We have established and promote a culture of performance, accountability and safety. Our management team is responsible for assessing our service quality, performance and safety compliance and coordinates with our regional offices to help ensure that our quality and performance metrics and safety standards are met at every level of our organization. We intend to continue to invest in and promote systems and methodologies which improve the reliability, responsiveness, accountability and safety of our operations.

Continue to pursue strategic expansion opportunities. We believe that the markets in which we operate remain fragmented and that there are numerous consolidation opportunities within these markets. We intend to leverage our proven capabilities of identifying, executing on and integrating strategic acquisitions to further differentiate our service portfolio and grow our business.

Capitalize on regional experience. One component of our acquisition and growth strategy is to acquire assets located in strategic operating areas that include personnel with strong local leadership and regional experience. We believe that by having the administrative functions previously performed at the regional level centralized in and handled by our corporate office, we have enhanced our controls environment and enabled our local management to focus on our customers, our employees and the effective management and deployment of our assets.

Our Competitive Strengths

We believe our operations benefit from a number of competitive strengths, including the following:

•

Extensive breadth of service throughout the wellsite life-cycle. We provide a broad array of wellsite services throughout each phase of the drilling and production process. This breadth of service strengthens our relationships with our customers and allows us to identify and cross-sell additional services. By providing comprehensive wellsite services to our customers, we believe our customers realize more value from us than from competitors who generally offer fewer services.

•

Extensive geographic footprint with a strong regional and local presence. Our regional operations are located in some of the most active onshore oil and natural gas drilling regions of the United States, including South Texas, the Gulf Coast, ArkLaTex, North Texas, the Permian Basin, the Mid-Continent and Rocky Mountain regions. Within these regions there are approximately 1,545 active drilling rigs as of June 23, 2006. Our regional managers have developed strong field-level relationships with our customers and are largely responsible for the sales, marketing and delivery of our services.

•

Large scale of operations. We believe we are one of the largest providers of comprehensive wellsite services in our operating areas and that our workforce accommodations asset base is more than twice the size of our next largest competitor. Our scale enables us to deliver a comprehensive range of reliable and high-quality wellsite services to our customers.

•

Our management also has substantial experience in identifying, completing and integrating acquisitions and since our inception, we have acquired 16 businesses. We have also implemented a control environment consisting of a strong corporate infrastructure that includes standardized financial, accounting, safety, environmental and maintenance processes and controls.

•

Leveraged to the expected increase in rig count. The demand for our services is primarily driven by the number of contracted drilling rigs in our operating regions. We believe that favorable supply and demand fundamentals for oil and natural gas will continue to lead to increases in the number of operating drilling rigs for the foreseeable future. Also, as our package of services typically comprise less than 15% of total drilling expenditures, our business has not historically experienced the pricing volatility experienced by drilling contractors, who represent a much larger portion of total drilling expenditures.

Recent Developments

As of May 31, 2006, we have completed six acquisitions in 2006 for a total consideration of approximately $90.6 million. Of this amount, approximately $69.1 million was used to establish and expand our construction and logistics services segment and approximately $21.5 million was used to expand our wellsite services segment. We paid approximately $46.5 million as consideration for our acquisition of the membership interests of BLR Construction Companies, L.L.C. (“BLR”), which established our construction and logistics services segment. BLR is a full-service contractor that focuses on location and pipeline construction, marine services, production facility construction, crew services, heavy equipment and trucking services, remediation services, wellsite decommissioning and vegetation control. To provide these services, BLR maintains an extensive inventory of bulldozers, mats, tools and other construction-related equipment. BLR also provides inland marine site construction services through a fleet of approximately seven crew boats, three tugboats and four barges as of June 30, 2006.

On June 30, 2006, we executed a definitive agreement to purchase all of the outstanding capital stock of Abbeville Offshore Quarters, Inc., a Louisiana corporation (“Abbeville”). Abbeville provides workforce accommodations, sewage treatment units, water tanks, generators and other rental support equipment for use in the offshore Gulf Coast oil and natural gas industry. The closing of this acquisition is subject to satisfactory completion of our due diligence and closing conditions. The purchase price consists of $38.0 million in cash ($1.5 million of which is held in escrow) and 6,943,000 Class C Units representing limited partnership interests of Stallion Oilfield Holdings, Ltd. The acquisition of Abbeville would augment our workforce accommodations and surface equipment rental service lines.

Risk Factors

You should carefully consider the matters described under “Risk Factors.” These risks could materially and adversely impact our business, financial condition, operating results and cash flow, which could cause the trading price of our common stock to decline and could result in a partial or total loss of your investment.

The Restructuring

We were formed as a Delaware corporation in June 2006. In connection with this offering, we will succeed to the business and operations of Stallion Oilfield Holdings, Ltd., a Texas limited partnership (“Stallion Ltd”), which are described in this prospectus. Prior to the completion of this offering, Stallion Ltd will merge with and into Stallion Oilfield Services, Inc., with Stallion Oilfield Services, Inc. being the surviving corporate parent and

owning all of the operating subsidiaries of Stallion Ltd (the “Restructuring”). The majority owners of Stallion Ltd are C/R Stallion Investment Partnership, L.P. and C/R Energy Coinvestment II, L.P. (together, “Carlyle/Riverstone”) and an affiliate of Craig Johnson, our President, Chief Executive Officer and Chairman of the Board. In the Restructuring, assuming an initial public offering price of $ , which is the midpoint of the range set forth on the cover of this prospectus, the partners of Stallion Ltd will receive an aggregate of shares of our common stock in exchange for all of the Stallion Ltd partnership interests held by them. Immediately following completion of the Restructuring and prior to this offering, we will have shares of common stock outstanding, % of which will be owned by Carlyle/Riverstone and % of which will be owned by an affiliate of Craig Johnson.

For additional information about the Restructuring, please read “Certain Relationships and Related Party Transactions—The Restructuring.”

Our Executive Offices

Our principal executive offices are located at 410 Roberts Street, Houston, Texas 77003, and our telephone number is (713) 528-5544. Information contained on or accessible from our website, www.stallionoilfield.com, is not part of this prospectus.

The Offering

Common stock offered by us

Common stock offered by the selling stockholders

Common stock outstanding after this offering

Use of proceeds

We estimate that our net proceeds from this offering, after deducting underwriting discounts and commissions and estimated offering expenses, will be approximately $ million, assuming an initial public offering price of $ , which is the midpoint of the range set forth on the cover page of this prospectus.

We intend to use the net proceeds we receive from this offering:

•

to repay $82.5 million of term loans under our Credit Facility; and

•

for general corporate purposes, including future acquisitions.

We will not receive any of the proceeds from the sale of shares of our common stock by the selling stockholders. The selling stockholders include members of our senior management.

Nasdaq National Market symbol

“SOFS”

Risk Factors

See “Risk Factors” beginning on page 11 of this prospectus for a discussion of factors that you should carefully consider before deciding to invest in shares of our common stock.

Unless we specifically state otherwise, all information in this prospectus assumes no exercise of the underwriters’ option to purchase additional shares.

The number of shares of common stock that will be outstanding after the offering includes as of , 2006, an aggregate of shares of restricted common stock issued to officers and key employees under our 2006 Stock Incentive Plan that are subject to vesting and excludes as of , 2006, an aggregate of shares of common stock reserved and available for future issuance under our 2006 Stock Incentive Plan.

Summary Historical Financial Information

The following table sets forth our summary historical consolidated financial and operating data as of the dates and for the periods shown. Our operations are currently conducted by Stallion Oilfield Holdings, Ltd., a limited partnership, and its operating subsidiaries. Immediately prior to the closing of this offering, this limited partnership will merge with and into Stallion Oilfield Services, Inc., and we will operate under a corporate parent structure. Stallion Oilfield Services, Inc., the surviving entity of the Restructuring, will serve as the parent holding company under this new structure. The amounts for each historical annual period presented below were derived from our audited consolidated financial statements. The following information should be read in conjunction with “Capitalization,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” our consolidated financial statements and related notes and the unaudited pro forma consolidated financial data included elsewhere in this prospectus.


	Stallion Oilfield Holdings, Ltd. Historical Consolidated															Stallion Oilfield Services, Inc. Pro Forma Consolidated
	Year Ended December 31,									Three Months Ended March 31,						Year Ended December 31,		Three Months Ended March 31,
	2003			2004			2005			2005			2006			2005		2006
										(unaudited)						(unaudited)
	(in thousands except per share data)
Statement of Operations Data:
Revenue:
Wellsite support services	$	6,769		$	15,452		$	73,126		$	10,307		$	32,917		$	91,725	$	32,917
Construction and logistics services		—			—			—			—			6,045			39,630		15,728

Total revenue		6,769			15,452			73,126		$	10,307			38,962			131,355		48,645

Expenses:
Wellsite support services		3,108			8,695			42,281			5,793			14,423			49,647		14,423
Construction and logistics services		—			—			—			—			3,446			24,353		8,919
Selling, general and administrative		2,145			3,745			9,883			2,142			7,529			18,170		9,785
Depreciation and amortization		836			1,924			7,798			1,129			4,299			19,030		5,689
Loss on disposal of assets		86			92			499			3			342			254		617

Total expenses		6,175			14,456			60,461			9,067			30,039			111,454		39,433

Operating income		594			996			12,665			1,240			8,923			19,901		9,212
Interest expense, net		489			917			4,565			763			4,097			9,887		4,925
Other income (expense)		—			—			(66	)		(17	)		(10	)		51		(10	)

Income before taxes		105			79			8,034			460			4,816			10,065		4,277
Income tax (1)		—			—			598			105			911			3,825		1,625

Net income	$	105		$	79		$	7,436		$	355		$	3,905		$	6,240	$	2,652

Earnings per share:
Basic																$		$

Diluted																$		$

Weighted average shares:
Basic

Diluted

Other Financial Data:
EBITDA (2)	$	1,430		$	2,920		$	20,397		$	2,352		$	13,212		$	38,982	$	14,891
Cash flow provided by operating activities		144			1,734			7,087			1,265			10,418
Cash flow used in investing activities		(7,536	)		(7,142	)		(83,462	)		(33,222	)		(95,516	)
Cash flow provided by financing activities		7,804			5,046			77,307			33,715			112,555
Capital expenditures:
Acquisitions, net of cash acquired (3)		5,505			1,158			48,955			26,675			74,097
Property and equipment		2,046			5,961			34,187			6,483			20,310


	Stallion Oilfield Holdings, Ltd. Historical Consolidated
	Year Ended December 31,						Three Months Ended March 31,
	2003		2004		2005		2006
							(unaudited)
	(in thousands)
Balance Sheet Data
Cash and cash equivalents	$	412	$	50	$	982	$	28,439
Net property and equipment		7,131		13,899		74,583		122,597
Total assets		16,252		24,713		123,136		258,033
Total debt		11,705		18,552		67,795		171,162
Total partners’ capital		3,533		3,611		43,597		64,867

(1)

Historically, we were not subject to taxes on a consolidated basis due to our partnership structure; however, certain of our subsidiary companies are taxable corporations and are subject to income tax. Pro forma net income for the year ended December 31, 2005 and for the three months ended March 31, 2006 includes a provision for taxes on our consolidated income before tax. Pro forma income tax expense has been computed at a blended state and federal tax rate of 38% to reflect the pro forma income tax effect on net income for the periods presented assuming that the Restructuring happened on January 1, 2005.

(2)	EBITDA consists of net income before interest expense, taxes, depreciation and amortization. EBITDA is used as a supplemental financial measure by our management and by external users of our financial statements, such as investors and commercial banks, to assess:

•

the financial performance of our assets without regard to financing methods, capital structure, or historical cost basis;

•

the ability of our assets to generate cash sufficient to pay interest on our indebtedness;

•

our operating performance and return on invested capital as compared to those of other companies in the oilfield service industry, without regard to financing methods and capital structure; and

•

our compliance with certain financial covenants included in our credit facility.

EBITDA has limitations as an analytical tool and should not be considered an alternative to net income, operating income, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”). EBITDA excludes some, but not all, items that affect net income and operating income and these measures may vary among other companies. Limitations to using EBITDA as an analytical tool include:

•

EBITDA does not reflect our cash expenditures or future requirements for capital expenditures or capital commitments;

•

EBITDA does not reflect changes in, or cash requirements necessary to service interest or principal payments on, our debt;

•

although depreciation and amortization are non-cash charges, the assets being depreciated and amortized will often have to be replaced in the future, and EBITDA does not reflect any cash requirements for such replacements; and

•

other companies in our industry may calculate EBITDA differently than we do, limiting its usefulness as a comparative measure.

The following table presents a reconciliation of the non-GAAP financial measure of EBITDA to the most directly comparable GAAP financial measure on a historical basis for each of the indicated periods.


	Year Ended December 31,									Three Months Ended March 31,						Pro Forma Year Ended December 31,		Pro Forma Three Months Ended March 31,
	2003			2004			2005			2005			2006			2005		2006
	(in thousands)
Reconciliation of EBITDA to Net income:
Net income	$	105		$	79		$	7,436		$	355		$	3,905		$	6,240	$	2,652
Income taxes		—			—			598			105			911			3,825		1,625
Interest expense		489			917			4,565			763			4,097			9,887		4,925
Depreciation and amortization		836			1,924			7,798			1,129			4,299			19,030		5,689

EBITDA	$	1,430		$	2,920		$	20,397		$	2,352		$	13,212		$	38,982	$	14,891

Reconciliation of EBITDA to Cash flow provided by operations:
Net cash provided by operating activities	$	144		$	1,734		$	7,087		$	1,265		$	10,418
Bad debt expense		(24	)		(70	)		(465	)		(50	)		(220	)
Loss on disposal of property and equipment		(86	)		(92	)		(499	)		(3	)		(342	)
Interest expense		489			917			4,565			763			4,097
Amortization of debt issuance costs and debt discount included in interest expense		—			—			(495	)		(39	)		(1,716	)
Deferred income tax		—			—			73			(144	)		(65	)
Income tax		—			—			598			105			911
Change in operating assets and liabilities		907			431			9,533			455			129

EBITDA	$	1,430		$	2,920		$	20,397		$	2,352		$	13,212

(3)	Acquisitions, net of cash acquired, consists only of the cash component of acquisitions. It does not include equity and/or notes issued for acquisitions.

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. Some of the following risks relate principally to the industry in which we operate and to our business. Other risks relate principally to the securities markets and ownership of our common shares. If any of the following risks develop into actual events, our business, financial condition or results of operations could be materially adversely affected, the trading price of your shares could decline, and you may lose all or part of your investment.

Risks Related to Our Business and Our Industry

Our business depends on domestic drilling activity and spending by the oil and natural gas industry in the United States. Our business may be adversely affected by industry conditions that are beyond our control.

We depend on our customers’ willingness to make expenditures to explore for and to develop and produce oil and natural gas in the United States. Our customers’ willingness to undertake these activities depends largely upon prevailing industry conditions that are influenced by numerous factors over which management has no control, such as:

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the supply of and demand for oil and natural gas;

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long lead times associated with acquiring equipment and shortages of qualified personnel;

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the level of prices, and expectations about future prices, of oil and natural gas;

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the cost of exploring for, developing, producing and delivering oil and natural gas;

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the expected rates of declining current production;

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the discovery rates of new oil and natural gas reserves;

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available pipeline, storage and other transportation capacity;

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weather conditions, including hurricanes that can affect oil and natural gas operations over a wide area;

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domestic and worldwide economic conditions;

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political instability in oil and natural gas producing countries;

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technical advances affecting energy consumption;

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the price and availability of alternative fuels;

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the ability of oil and natural gas producers to raise equity capital and debt financing; and

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merger and divestiture activity among oil and natural gas producers.

The level of oil and natural gas exploration and production activity in the United States is volatile. Expected trends in oil and natural gas production activities may not continue and demand for our services may not reflect the level of activity then existing in the industry. Any prolonged substantial reduction in oil and natural gas prices would likely affect oil and natural gas production levels and therefore affect demand for the services we provide. A material decline in oil and natural gas prices or drilling activity levels could have a material adverse effect on our business, financial condition, results of operations and cash flow. In addition, a decrease in the development rate of oil and natural gas reserves in our market areas may also have an adverse impact on our business, even in an environment of stronger oil and natural gas prices.

A decline in or substantial volatility of oil and natural gas prices could adversely affect the demand for our services.

The demand for our services is primarily influenced by current and anticipated oil and natural gas prices and the related level of drilling activity and general production spending in the areas in which we have operations. Volatility or weakness in oil and natural gas prices (or the perception that oil and natural gas prices will decrease) affects the spending patterns of our customers and may result in the drilling of fewer new wells. This, in turn, could result in lower demand for our services. As a result, we may experience lower utilization of, and may be forced to lower our rates for, our services and equipment. A decline in oil and natural gas prices or a reduction in drilling and production activities could have a material adverse affect on the demand for our services and our results of operations.

Prices for oil and natural gas historically have been extremely volatile and are expected to continue to be 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 $74.61 per bbl on May 2, 2006. As of June 27, 2006, the WTI Cushing crude oil spot price was $71.92 per bbl. The Henry Hub natural gas spot price has ranged from $3.99 per mcf on October 31, 2003 to $19.38 per mcf on February 25, 2003. As of June 27, 2006, the Henry Hub natural gas spot price was $5.97 per mcf. Producers generally react to declining oil and natural gas prices by reducing expenditures. This has in the past and may in the future have an adverse effect on our business. We are unable to predict future oil and natural gas prices or the level of oil and natural gas industry activity. A prolonged low level of activity in the oil and natural gas industry will adversely affect the demand for our products and services and our financial condition and results of operations.

When rig counts are low, our rig relocation customers may not have a need for our services.

Many of the major United States drilling services contractors have significant capabilities to move their own drilling rigs and related oilfield equipment and to mobilize rigs. When regional rig counts are high, drilling contractors often exceed their own capabilities and contract for additional oilfield equipment hauling and rig mobilization capacity. Our rig relocation business activity is correlated to the rig count; however, the correlation varies over the rig count range. As rig count declines, some drilling contractors reach a point where all of their oilfield equipment hauling and rig mobilization needs can be met by their own fleets. If one or more of our rig relocation customers decide not to outsource their rig and equipment hauling needs, our revenue attributable to rig relocation may decline much faster than the corresponding rig count. This non-linear relationship between our rig relocation business activity and the rig count in the areas where we have rig relocation operations can significantly increase the volatility of our earnings with respect to rig relocation.

We may not be able to successfully manage future growth, to grow successfully through future acquisitions, or to effectively integrate the businesses we do acquire.

Our business strategy has included, and will continue to include, growth through the acquisition of other businesses. We may not be able to continue to identify attractive acquisition opportunities or successfully acquire identified targets on terms favorable to us. Competition for acquisition opportunities may escalate, increasing our cost of making future acquisitions or causing us to refrain from making acquisitions. 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. Our existing credit agreement requires that we meet certain financial covenants in order to borrow money to fund future acquisitions. The issuance of additional equity securities could result in significant dilution to our stockholders. In addition, we may not be successful in integrating our current or future acquisitions into our existing operations, which may result in unforeseen operational difficulties, diminished financial performance, our inability to report financial results or require a disproportionate amount of our management’s attention.

We are vulnerable to the potential difficulties associated with rapid growth and expansion.

We have grown rapidly over the last several years through organic growth and acquisitions of other companies. We believe that our future success depends on our ability to manage the rapid growth that we have experienced and the demands from increased responsibility on our management personnel. The following factors could present difficulties to us:

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lack of sufficient executive-level personnel;

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increased administrative burden;

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increased organizational challenges common to large, expansive operations; and

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long lead times associated with acquiring equipment.

Our operating results could be adversely affected if we do not successfully manage these potential difficulties. The historical financial information incorporated herein is not necessarily indicative of the results that would have been achieved had we operated on a fully integrated basis or the results that may be realized in the future.

We may require additional capital in the future, which may not be available to us.

Our business is capital intensive, requiring specialized equipment and trained personnel to provide our services. We may need to raise additional funds through public or private debt or equity financings. Adequate funds may not be available when needed or may not be available on favorable terms. If we raise additional funds by issuing equity securities, dilution to existing stockholders may result. If funding is insufficient at any time in the future, we may be unable to service our equipment, fund acquisitions, take advantage of business opportunities or respond to competitive pressures, any of which could harm our business. Our future capital requirements primarily depend on the frequency, timing, size and success of an acquisition.

We depend on significant customers.

We derive a significant amount of our revenue from exploration and production companies and drilling contractors who are active in our markets. For the year ended December 31, 2005, our top ten customers accounted for approximately 38% of our revenue. During the three months ended March 31, 2006, our top ten customers accounted for approximately 32% of our revenue. Our inability to continue to perform services for a number of our large existing customers could have a material adverse effect on our business and operations.

Our success depends on key members of our management, the loss of any of whom could disrupt our business operations.

We depend to a large extent on the services of some of our executive officers and directors. The loss of the services of our executive officers, directors, or other key personnel could disrupt and adversely affect our operations. We may not be able to retain our executive officers and may not be able to enforce the non-compete provisions in their employment agreements. Please see “Management—Employment Agreements.”

Certain of our executive officers are subject to non-competition agreements, which may restrict them and, consequently, us from providing certain oilfield services, entering into new markets or engaging in other similar businesses for a period of time.

Our Chief Executive Officer and Chief Financial Officer were principal officers of and owned equity interests in a private oilfield service company prior to its sale in 2002 to a large publicly traded oilfield service company. In connection with this sale, each of our Chief Executive Officer and Chief Financial Officer entered into a non-competition agreement with the purchaser. These agreements prevent them until July 19, 2007 from

providing certain oilfield services including fishing tool rental services, oilfield fluid transportation and logistics, completion and production services and other similar services in Texas, New Mexico, Oklahoma, Arkansas, certain parishes in Louisiana and the offshore and inland waters of the Gulf Coast. As such, we are prohibited from providing these services in these regions for as long as these executive officers are employed by us during the remaining term of their respective non-competition agreements.

Competition within the oilfield service industry may adversely affect our ability to market our services.

The oilfield service industry is competitive and fragmented and includes numerous small companies capable of competing in our markets on a local basis as well as several large companies that possess substantially greater financial and other resources than us. Our larger competitors’ greater resources could allow them to compete more effectively than us. We believe that the principal competitive factors in the market areas that we serve are quality of product and service, price, availability and technical proficiency. Our operations may be adversely affected if our current competitors or new market entrants introduce new products or services with better features, performance, prices or other characteristics than our products and services. Competitive pressures, excess capacity in our industry or other factors also may result in significant price competition that could have a material adverse effect on our results of operations and financial condition. Finally, competition among oilfield service and equipment providers is also affected by each provider’s reputation for safety and quality. Although we believe that our reputation for safety and quality service is excellent, we cannot guarantee that we will be able to maintain our competitive position.

Our industry has experienced a high rate of employee turnover. Any difficulty we experience replacing or adding personnel could adversely affect our business.

We may not be able to find enough skilled labor to meet our needs, which could limit our growth. The oilfield service business has been cyclical in the past and is heavily influenced by oil and natural gas prices. Our services require skilled workers who can perform physically demanding work. As a result of our industry volatility 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 with ours. We believe that our success is dependent upon our ability to continue to employ, train and retain skilled personnel. Although we have been able to hire workers to meet our current workforce needs, we may have problems finding enough skilled and unskilled laborers in the future if the demand increases for our services. In that event, it is possible that we will have to raise wage rates to attract workers from other fields and to retain or expand our current work force. If we are not able to increase our service rates sufficiently to compensate for wage rate increases, our operating results may be adversely affected. Our inability to employ, train or retain skilled personnel generally could have a material adverse effect on our results of operations.

Our operations are subject to hazards inherent in the oil and natural gas industry.

Through our wellsite construction services, we operate cranes, forklifts, bulldozers and other heavy equipment. In addition, in connection with providing rig logistics services, we transport drilling rigs and related equipment through the use of our heavy hauler trucks and trailers, cranes and other trucking and relocation assets. The operation of heavy equipment at the wellsite and the transportation of rigs and related assets may result in accidents, which can cause personal injury, loss of life, suspension of operations, damage to facilities and damage to or destruction of property. These and other operational risks inherent in our industry could expose us to substantial liability for personal injury, wrongful death, property damage, loss of oil and natural gas production, pollution and other environmental damages. The frequency and severity of such incidents will affect our 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 customers and substantial revenue.

We do not have insurance against all foreseeable risks, either because insurance is not available or because of the high premium costs. The occurrence of an event not fully insured against, or the failure of an insurer to meet its

insurance obligations, could result in substantial losses. In addition, we may not be able to maintain adequate insurance in the future at rates we consider reasonable, and there can be no assurance that insurance will be available to cover any or all of these risks, or, even if available, that it will be adequate or that insurance premiums or other costs will not rise significantly in the future, so as to make such insurance costs prohibitive. In addition, our insurance is subject to coverage limits and some policies exclude coverage for damages resulting from environmental contamination. See “Business—Operating Risks and Insurance.”

We are subject to federal, state and local regulation regarding issues of health, safety and protection of the environment. Under these regulations, we may become liable for penalties, damages or costs of remediation. Any changes in laws and government regulations could increase our costs of doing business.

Our operations are subject to federal, state and local laws and regulations relating to protection of natural resources and the environment, health and safety, waste management, and transportation of waste and other materials. Liability under these laws and regulations could result in cancellation of wellsite operations, fines and penalties, expenditures for remediation and liability for property damages and personal injuries. Sanctions for noncompliance with applicable environmental laws and regulations also may include assessment of administrative, civil and criminal penalties, revocation of permits and issuance of corrective action orders.

Laws protecting the environment generally have become more stringent over time and are expected to continue to do so, which could lead to material increases in costs for future environmental compliance and remediation. The modification or interpretation of existing laws or regulations, or the adoption of new laws or regulations, could curtail exploratory or developmental drilling for oil and natural gas and could limit wellsite services opportunities. Some environmental laws and regulations may impose strict liability, which means that in some situations we could be exposed to liability as a result of our conduct that was lawful at the time it occurred or conduct of, or conditions caused by, prior operators or other third parties. Clean-up costs and other damages arising as a result of environmental laws, and costs associated with changes in environmental laws and regulations could be substantial and could have a material adverse effect on our financial condition. Please read “Business—Environmental Matters” for more information on the environmental laws and government regulations that are applicable to us.

We have operations located on lands that are regulated by the Bureau of Land Management of the United States Department of Interior and these operations may be subject to long periods of interruption or suspension.

The Bureau of Land Management (the “BLM”) enforces regulations that protect certain animals, such as deer, sage chickens and raptors, that inhabit lands in the northern United States, where we have operations. We are affected by this enforcement through the following ways. The BLM may deny or delay the granting of permits to us or our customers necessary to conduct operations in these lands. In addition, the BLM may restrict access to or seek our relocation from these lands for a period of time. As a result of this enforcement, our operations on these lands have been and may be interrupted or suspended for long periods of time. For example, from mid-November until mid-May, the period during which mule deer roam these lands, certain of our operations cease and go on stand-by. In addition, during April and May of each year, sage chicken nesting occurs and as a result, we are required to relocate our operations for a period of time. If these regulations become more stringent and, as a result, our operations are interrupted or suspended for longer periods of time, we could lose revenue.

Our holding company structure makes us dependent on our subsidiaries to meet our financial obligations.

As a holding company, we have no significant assets other than the equity of our subsidiaries. In order to meet financial obligations, we rely exclusively on the cash flow from our subsidiaries. There can be no assurance that our operating subsidiaries will generate sufficient cash flow for us to meet our financial obligations.

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. As a result, our business and the trading price of our common stock could be affected as potential shareholders lose confidence in our financial reporting.

Effective internal controls are necessary for us to provide reliable financial reports and effectively prevent fraud and to operate successfully as a public company. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results would be harmed. We cannot be certain that our efforts to develop and maintain our internal controls will be successful or that we will be able 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 their implementation or other effective improvement of our internal controls could harm our operating results or cause us to fail to meet our reporting obligations. Ineffective internal controls could also cause investors to lose confidence in our reported financial information, which would likely have a negative effect on the trading price of our common stock.

Our indebtedness could restrict our operations and make us more vulnerable to adverse economic conditions.

We now have, and after this offering will continue to have, a significant amount of indebtedness. As of March 31, 2006, our total debt was $171.2 million, including $165.0 million in aggregate principal amount due under the term loan portion of our term credit facility. Following this offering and giving effect to the use of proceeds therefrom, on an as adjusted basis our total debt would have been $ million. Holding all other variables constant, if interest rates increased or decreased by 1%, interest expense for the year ended December 31, 2005 would have increased or decreased by approximately $0.7 million. We will also have the ability to incur substantially more debt. We have a total borrowing capacity of $50 million under our credit facility all of which was available as of March 31, 2006.

Our current and future indebtedness could have important consequences to you. For example, it could:

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impair our ability to make investments and obtain additional financing for working capital, capital expenditures, acquisitions or other general corporate purposes;

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limit our ability to use operating cash flow in other areas of our business because we must dedicate a substantial portion of these funds to make principal and interest payments on our indebtedness;

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limit our ability to borrow funds that may be necessary to operate or expand our business;

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prevent us from paying dividends to our stockholders, entering into transactions with affiliates or entering into sale and leaseback transactions that may be beneficial to us;

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limit our ability to purchase or acquire property or assets, merge or consolidate with other entities or sell all or substantially all of our assets;

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put us at a competitive disadvantage to competitors that have less debt;

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increase our vulnerability to interest rate increases; and

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hinder our ability to adjust to rapidly changing economic and industry conditions.

In addition, our existing term credit facility requires us to maintain certain financial ratios and to satisfy certain financial conditions, several of which become more restrictive over time and may require us to reduce our debt or take some other action in order to comply with such covenants.

These restrictions could also limit our ability to obtain future financings, make needed capital expenditures, withstand a downturn in our business or the economy in general, or otherwise conduct necessary corporate activities. We also may be prevented from taking advantage of business opportunities that arise because of the limitations imposed on us by the restrictive covenants under our credit facility. Please read “Management’s

Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—2006 Credit Facility” for a discussion of our credit facility.

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 natural gas, potentially putting downward pressure on demand for our services and causing a reduction in our revenue. Oil and natural 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.

Our operations in coastal regions of Louisiana and Texas are adversely impacted by the hurricane season, which generally occurs in the second and third calendar quarters of the year.

Hurricanes and the threat of hurricanes during this period will often result in the shut-down of oil and natural gas operations in coastal regions as well as land operations within the hurricane path. Our operations are negatively affected by hurricanes in three ways. First, we may incur significant expenses when we transport our accommodation units and surface and other equipment away from and back to the affected wellsite. Second, during a shut-down period, we are unable to access wellsites and our services are suspended resulting in loss of revenue for this period of time. Third, if we are unsuccessful in transporting our accommodation units and surface equipment away from the storm threatened area, the units and equipment may suffer significant damage resulting in additional expenses incurred to repair or replace the damaged units or equipment. For example, a number of our accommodation units and mats were damaged, displaced or lost during Hurricane Katrina. A period of approximately 60 days passed before we were able to purchase and deploy new accommodation units and mats in this area, resulting in lost revenue during such time. The occurrence of a hurricane can therefore create unpredictability in activity and utilization rates and lead to the destruction of our property, which can have a material adverse impact on our business, financial condition, results of operations and cash flow.

Increasing trucking regulations may increase our costs and negatively impact our results of operations.

We operate as a motor carrier in providing certain of our services and therefore are subject to regulation by the United States 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 specifications 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 and/or work in any specific period, onboard black box recorder device requirements or limits on vehicle weight and size.

Interstate motor carrier operations are subject to safety requirements prescribed by the United States Department of Transportation. To a large degree, intrastate motor carrier operations are subject to state safety regulations that mirror federal regulations. Such matters as the weight and dimensions of equipment are also subject to federal and state regulations.

recruitment of drivers. We cannot predict whether, or in what form, any increase in such taxes applicable to us will be enacted.

The contract period during which we provide services to our customers is relatively short, which exposes us to volatility in prices and equipment utilization levels. This volatility may have a material adverse effect on our business.

A significant portion of our revenue is derived by charging our customers for the actual period of time during which we provide services to them. The period of time for which our customers contract with us is usually relatively short, ranging from a few days to a few months. The short term of these arrangements exposes us to the risks of a rapid reduction in market prices and equipment utilization and volatility in our revenue. These reductions and volatility may have a material adverse effect on our business.

An increase in the importation of liquefied natural gas, or LNG, as a substitute for oil and natural gas drilling activities may reduce the level of these drilling activities, which may have a material adverse effect on our business.

The importation of LNG is becoming increasingly important as a supply source in order to meet domestic natural gas demand. If the importation of LNG continues to increase and replaces oil and natural gas production as a source for natural gas, then the level of North American drilling activity related to oil and natural gas may decrease. Our services support drilling for oil and natural gas. Consequently, a substantial reduction in oil or natural gas production levels could have a material adverse effect on our business, even in an environment of stronger oil and natural gas prices.

Risks Related to this Offering

Certain stockholders’ shares are restricted from immediate resale but may be sold into the market in the near future. This could cause the market price of our common stock to drop significantly.

After this offering, we will have outstanding shares of common stock. Of these shares, the shares we and the selling stockholders are selling in this offering, or shares if the underwriters exercise in full their option to purchase additional shares, will be freely tradable without restriction under the Securities Act except for any shares purchased by any of our “affiliates” as defined in Rule 144 under the Securities Act. A total of shares, or shares if the underwriters exercise in full their option to purchase additional shares, will be “restricted securities” (within the meaning of Rule 144 under the Securities Act) or subject to lock-up arrangements. In connection with this offering, we, our officers and directors and substantially all of our existing stockholders (including the selling stockholders) have entered into lock-up agreements under which we and they have agreed not to offer or sell any shares of common stock or securities convertible into or exchangeable or exercisable for shares of common stock for an initial period of 180 days from the date of this prospectus without the prior written consent of Lehman Brothers Inc., Credit Suisse Securities (USA) LLC and UBS Securities LLC. Lehman Brothers Inc., Credit Suisse Securities (USA) LLC and UBS Securities LLC may, at any time and without notice, waive any of the terms of these lock-up agreements. See “Underwriting” for a description of these lock-up agreements.

Following the lock-up period, the holders of shares of our common stock 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. The filing of a registration statement in respect of these shares, the exercise of these holders’ registration rights and the sale by these holders of a large number of shares 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.

under our stock 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 we and certain of 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.

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 March 31, 2006 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. Please read “Dilution” for a complete description of the calculation of net tangible book value.

Our certificate of incorporation, bylaws and Delaware law contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock.

Our certificate of incorporation authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our certificate of incorporation, bylaws and Delaware law could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our stockholders, including:

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limitations on the removal of directors;

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the prohibition of stockholder action by written consent; and

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limitations on the ability of our stockholders to call special meetings and establish advance notice provisions for stockholder proposals and nominations for elections to the board of directors to be acted upon at meetings of stockholders.

Delaware law prohibits us from engaging in any business combination with any “interested stockholder,” meaning generally that a stockholder who beneficially owns more than 15% of our common stock cannot acquire us for a period of three years from the date this person became an interested stockholder, unless various conditions are met, such as approval of the transaction by our board of directors. These provisions could limit the price that investors might be willing to pay in the future for shares of our common stock.

Because we have no 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 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 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. The terms of our existing credit facility restrict the payment of dividends without the prior written consent of the lenders. 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. Investors seeking cash dividends should not purchase our common stock.

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. We intend to apply for listing of our common stock on the Nasdaq National Market. 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, the selling stockholders and us will determine the initial public offering price. You may not be able to resell your shares at or above the initial public offering price.

If our stock price declines after the initial 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:

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changes in securities analysts’ recommendations and their estimates of our financial performance;

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the public’s reaction to our press releases, announcements and our filings with the Securities and Exchange Commission and those of our competitors;

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fluctuations in broader stock market prices and volumes, particularly among securities of oil and natural gas service companies;

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changes in market valuations of similar companies;

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investor perception of our industry or our prospects;

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additions or departures of key personnel;

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commencement of or involvement in litigation;

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changes in environmental and other governmental regulations;

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announcements by us or our competitors of strategic alliances, significant contracts, new technologies, acquisitions, commercial relationships, joint ventures or capital commitments;

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variations in our quarterly results of operations or cash flow or those of other oil and natural gas service companies;

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revenue and operating results failing to meet the expectations of securities analysts or investors in a particular quarter;

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changes in our pricing policies or pricing policies of our competitors;

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future issuances and sales of our common stock;

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demand for and trading volume of our common stock;

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domestic and worldwide supplies and prices of and demand for oil and natural gas; and

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changes in general conditions in the United States economy, financial markets or the oil and natural 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.

Risk Factors Relating to Our Relationship with Carlyle/Riverstone

Carlyle/Riverstone controls the outcome of stockholder voting and may exercise this voting power in a manner adverse to our other stockholders.

Prior to this offering, Carlyle/Riverstone holds approximately % of our outstanding common stock. Following this offering, Carlyle/Riverstone will hold approximately % of our outstanding common stock (or

% if the underwriters exercise in full their option to purchase additional shares). Accordingly, Carlyle/ Riverstone is in a position to effectively 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 Carlyle/Riverstone may differ from yours, and Carlyle/Riverstone may vote its common stock in a manner that may adversely affect you.

Two of our directors may have conflicts of interest because they are affiliated with Carlyle/Riverstone.

Two of our directors, John Lancaster and Pierre Lapeyre, are also current directors or officers of Carlyle/Riverstone and its owners. Carlyle/Riverstone also has the right to nominate a third representative to our board of directors. This may create conflicts of interest because these directors have responsibilities to Carlyle/Riverstone and its owners. Their duties as directors or officers of Carlyle/Riverstone and its owners may conflict with their duties as directors of our company. These conflicts may result in these directors not participating in certain decisions regarding business dealings between Carlyle/Riverstone and us and other matters.

Carlyle/Riverstone and its director nominees on our board of directors generally have no obligation to offer us business opportunities.

Affiliates of Carlyle/Riverstone have investments in other oilfield service companies that may compete with us, and Carlyle/Riverstone and its affiliates, other than our company, may invest in other such companies in the future. If an opportunity in the oilfield service industry is presented to a person who is a member of Carlyle/Riverstone or its affiliates, including any of those individuals who also serve as a Carlyle/Riverstone director nominee on our board of directors, no member of Carlyle/Riverstone or any of those individuals has any obligation to communicate or offer the opportunity to us.

The availability of shares of our common stock for future sale could depress our stock price.

Carlyle/Riverstone’s exercise of certain registration rights relating to shares of our common stock and sales of a substantial number of shares of our common stock in the public markets following this offering, or the perception that such sales might occur, could have a material adverse effect on the price of our common stock or could impair our ability to obtain capital through an offering of equity securities.

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 natural gas prices, and any related changes in expenditures by our customers;

•

a decline in oil and natural gas drilling activity in the markets in which we operate;

•

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 economical rates;

•

the effects of severe weather on our operations;

•

our ability to replace or acquire equipment;

•

political instability in oil and natural gas producing countries; and

•

environmental and other governmental regulations.

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. Please see “Risk Factors.”

USE OF PROCEEDS

We expect to receive net proceeds from this offering of approximately $ million, assuming an initial public offering price of $ per share and after deducting underwriting discounts and commissions and estimated offering expenses. We will not receive any of the net proceeds from any sale of shares of common stock by any selling stockholders. The selling stockholders include members of our senior management.

We plan to use our net proceeds from this offering as follows:

•

$82.5 million to repay a portion of term loans under our credit facility; and

•

the remainder for general corporate purposes, including potential future acquisitions.

Our credit facility consists of a $165 million term loan facility and a $50 million revolver. As of May 31, 2006, we had $165 million outstanding under our term loan and revolving credit facility and no outstanding letters of credit leaving approximately $50 million available for additional borrowing under our credit facility. Interest under our credit facility may be determined by reference to (1) the London Interbank Offered Rate (“LIBOR”) plus an applicable margin between 2.75% and 3.25% depending on the credit rating of commitments under our credit facility, or (2) the greater of (a) the base rate charged by the administrative agent and (b) the Federal Funds Rate, plus 0.5%, plus an applicable margin between 1.75% and 2.25% depending on the credit rating of commitments under our credit facility. We used the borrowings under the term loans of our credit facility primarily to fund our acquisitions and pay down previously existing debt during the last year.

Please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—2006 Credit Facility” for a description of our outstanding indebtedness and our credit facility.

A $1.00 increase (decrease) in the assumed initial public offering price of $ per share would increase (decrease) the net proceeds from this offering by approximately $ , 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.

DIVIDEND POLICY

We have not declared or paid any dividends on our common stock, and we do not currently anticipate paying any 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. We are also restricted in our ability to pay dividends under our credit facility.

CAPITALIZATION

We have provided in the table below our capitalization as of March 31, 2006: (1) on an actual basis; and (2) on a pro forma as adjusted basis to give effect to, as if each had occurred on March 31, 2006:

•

this offering;

•

the application of the estimated net proceeds from this offering as set forth under “Use of Proceeds;” and

•

the Restructuring.

The information was derived from and is qualified by reference to our unaudited historical financial statements included elsewhere in this prospectus. You should read this information in conjunction with these financial statements, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” “Use of Proceeds” and “Unaudited Pro Forma Consolidated Financial Data.”


	March 31, 2006
	Actual		Pro Forma As Adjusted
	(unaudited)
	(in thousands)
Cash and cash equivalents(1)	$	28,439	$

Total long-term debt, including current portion:
Borrowings under our credit facility(2)	$	165,000	$
Other debt and obligations under capital leases		6,162

Total		171,162

Partners’ capital/Stockholders’ equity:
Partnership Interests		64,867
Common stock, $.01 par value per share; shares authorized pro forma as adjusted; shares issued and outstanding pro forma as adjusted		—
Retained earnings		—

Total Partners’ capital/Stockholders’ equity(1)		64,867

Total capitalization(1)	$	236,029	$

(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 $ , 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 May 31, 2006, we had $165.0 million outstanding under our term loan and revolving credit facility and no outstanding letters of credit leaving approximately $50.0 million available for additional borrowing under our credit facility. As of May 31, 2006, our cash and cash equivalents totaled approximately $11.0 million.

DILUTION

Purchasers of the common stock in this offering will experience immediate and substantial dilution in the net tangible book value per share of the common stock for accounting purposes. Adjusted 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 outstanding. At March 31, 2006, assuming completion of the Restructuring, we had a net tangible book value of $1.8 million or $ per share of common stock. 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 March 31, 2006 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		$
Adjusted net tangible book value per share as of March 31, 2006 (1)	$
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		$

(1)	Assuming completion of the Restructuring as of such date.

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 the as adjusted basis set forth above as of March 31, 2006, the total number of shares of common stock owned by existing stockholders and to be owned by new investors, the total consideration paid, and the average price per share paid by our existing stockholders and to be paid 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.


	Shares Purchased(1)			Total Consideration			Average Price Per Share
	Number	%		Amount	%		Average Price Per Share
Existing stockholders(2)
New public investors

Total		100.0	%	$	100.0	%

(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)

With respect to our executive officers, directors and greater-than-10% stockholders, and assuming the exercise of all outstanding warrants and stock options, the number of shares of common stock purchased from us, the total consideration paid to us, and the average price per share paid by all of those affiliated persons, are as follows:


	Shares Purchased		Total Consideration		Average Price Per Share
	Number	%	Amount	%	Average Price Per Share
Affiliated persons

As of , 2006, there were shares of our common stock outstanding, held by stockholders. 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 or approximately % of the total number of shares of common stock outstanding after this offering.

UNAUDITED PRO FORMA CONSOLIDATED FINANCIAL DATA

The unaudited pro forma consolidated statements of operations give effect to the acquisitions of Stallion Rentals, L.P., Envirotech, Inc., Double-D Enterprises, Inc., Separation Services, Inc. (all acquired January 31, 2005), GL Trucking & Rentals, Inc. (acquired September 12, 2005), Trail Blazer Hot Shot, Inc. (acquired January 1, 2006) and BLR Construction Companies, L.L.C. (acquired March 1, 2006) as if each of those acquisitions occurred on January 1, 2005. From a balance sheet perspective, these transactions are reflected in our unaudited consolidated balance sheet as of March 31, 2006.

The Stallion historical statement of operations information for the year ended December 31, 2005 is derived from our audited consolidated financial statements. The Stallion historical statement of operations information for the year ended December 31, 2005 and the three months ended March 31, 2006 includes results of operations of acquired businesses from their respective dates of acquisition through December 31, 2005 and March 31, 2006, respectively. The historical combined statement of operations of acquired businesses for the year ended December 31, 2005 and the three months ended March 31, 2006 represents a combined statement of operations of acquired businesses from January 1, 2005 through their respective dates of acquisition and from January 1, 2006 through their respective dates of acquisition, respectively.

The unaudited pro forma consolidated statement of operations represents management’s preliminary determination of purchase accounting adjustments and are based on available information and assumptions that management considers reasonable under the circumstances. Consequently, the amounts reflected in the unaudited pro forma consolidated statement 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 statement of operations does 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 in conjunction with “Capitalization,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and our financial statements included elsewhere in this prospectus.


	Unaudited Pro Forma Consolidated Financial Data for the year ended December 31, 2005
	Stallion Historical statement of operations			Historical combined statement of operations of acquired businesses			Adjustments			Pro forma
	(in thousands except per share data)
Statement of Operations:
Revenue:
Wellsite support services	$	73,126		$	18,599		$	—		$	91,725
Construction and logistic services		—			39,630			—			39,630

Total revenue		73,126			58,229			—			131,355

Expenses:
Wellsite support services		42,281			7,366			—			49,647
Construction and logistic services		—			24,353			—			24,353
Selling, general and administrative		9,883			8,287			—			18,170
Depreciation and amortization		7,798			6,163			5,069	(1)		19,030
Loss (gain) on disposal of assets		499			(245	)		—			254

Total expenses		60,461			45,924			5,069			111,454

Operating income		12,665			12,305			(5,069	)		19,901
Interest expense, net		(4,565	)		(615	)		(4,707	)(2)		(9,887	)
Other income (expenses)		(66	)		117			—			51

Income before income tax		8,034			11,807			(9,776	)		10,065
Income tax expense		(598	)		(458	)		(2,769	)(3)		(3,825	)

Net income	$	7,436		$	11,349		$	(12,545	)	$	6,240

Earnings per share:
Basic							$			$

Diluted							$			$

Weighted average shares:
Basic

Diluted

Reconciliation of EBITDA to Net income:
Net income	$	7,436		$	11,349		$	(12,545	)	$	6,240
Income taxes		598			458			2,769			3,825
Interest expense		4,565			615			4,707			9,887
Depreciation and amortization		7,798			6,163			5,069			19,030

EBITDA	$	20,397		$	18,585		$	—		$	38,982

(1)

Depreciation and amortization of adjusted fixed assets basis and depreciable intangible assets assuming the acquisitions occurred January 1, 2005. We estimate the remaining useful lives and salvage values of all acquired assets and depreciate those assets over those useful lives using policies that have been consistently applied by us. The purchase price allocation for our acquisition of BLR has not yet been finalized. Accordingly, we estimated that $16.0 million of the purchase price would be assigned to assets having an eight-year life and $9.0 million would be assigned to intangibles subject to amortization having a six-year life.

(2)

Pro forma interest expense on notes payable to sellers of acquired businesses of $5.9 million at rates ranging from 7.0% to 8.0% plus subordinated debt of $10.0 million at 12% and advances under our Credit Agreement totaling $80.0 million at rates ranging from 6.25% to 7.95% assuming that all of the notes and advances were completed on January 1, 2005.

(3)

Historically, we were not subject to taxes on a consolidated basis due to our partnership structure; however certain of our subsidiary companies are taxable corporations and are subject to income tax. Pro forma income tax expense has been computed at the blended statutory rate of 38% to reflect the pro forma effect on net income for the period presented assuming that the Restructuring that will occur immediately prior to the closing of this offering happened on January 1, 2005.


	Unaudited Pro Forma Consolidated Financial Data for the three months ended March 31, 2006
	Stallion Historical statement of operations			Historical combined statement of operations of acquired businesses			Adjustments			Pro forma
	(unaudited)
	(in thousands except per share data)
Statement of Operations:
Revenue:
Wellsite support services	$	32,917		$	—		$	—		$	32,917
Construction and logistics services		6,045			9,683			—			15,728

Total revenue		38,962			9,683			—			48,645

Expenses:
Wellsite support services		14,423			—			—			14,423
Construction and logistics services		3,446			5,473			—			8,919
Selling, general and administrative		7,529			2,256			—			9,785
Depreciation and amortization		4,299			840			550	(1)		5,689
Loss on disposal of assets		342			275			—			617

Total expenses		30,039			8,844			550			39,433

Operating income		8,923			839			(550	)		9,212
Interest expense		(4,097	)		(213	)		(615	)(2)		(4,925	)
Other expenses		(10	)		—			—			(10	)

Income before income tax		4,816			626			(1,165	)		4,277
Income tax expense		(911	)		—			(714	)(3)		(1,625	)

Net income	$	3,905		$	626		$	(1,879	)	$	2,652

Earnings per share:
Basic							$			$

Diluted							$			$

Weighted average shares:
Basic

Diluted

Reconciliation of EBITDA to Net income:
Net income	$	3,905		$	626		$	(1,879	)	$	2,652
Income taxes		911			—			714			1,625
Interest expense		4,097			213			615			4,925
Depreciation and amortization		4,299			840			550			5,689

EBITDA	$	13,212		$	1,679		$	—		$	14,891

(1)

Depreciation and amortization of adjusted fixed assets basis and depreciable intangible assets assuming the acquisitions occurred January 1, 2006. We estimate the remaining useful lives and salvage values of all acquired assets and depreciate those assets over those useful lives using policies that have been consistently applied by us. The purchase price allocation for our acquisition of BLR has not yet been finalized. Accordingly, we estimated that $16.0 million of the purchase price would be assigned to assets having an eight-year life and $9.0 million would be assigned to intangibles subject to amortization having a six-year life.

(2)	Pro forma interest expense on notes payable to sellers of acquired businesses of $2.9 million at rates ranging from 7.0% to 7.5% and advances under our Credit Agreements totaling $44.5 million at 7.95% assuming that all of the notes and advances were completed on January 1, 2005.

(3)

SELECTED CONSOLIDATED FINANCIAL DATA

The following table sets forth our selected historical consolidated financial and operating data as of the dates and for the periods shown. Our operations are currently conducted by Stallion Oilfield Holdings, Ltd., a limited partnership, and its operating subsidiaries. Immediately prior to the closing of this offering, this limited partnership will merge with and into Stallion Oilfield Services, Inc., and we will operate under a corporate parent structure. Stallion Oilfield Services, Inc., the surviving entity of the Restructuring, will serve as the parent holding company under this new structure. The amounts for each historical annual period presented below were derived from our audited consolidated financial statements. The following information should be read in conjunction with “Capitalization,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” “Unaudited Pro Forma Consolidated Financial Data” and our consolidated financial statements and related notes included elsewhere in this prospectus.


	Year Ended December 31,									Three Months Ended March 31,
	2003			2004			2005			2005			2006
										(unaudited)
	(in thousands)
Statement of Operations Data:
Revenue:
Wellsite support services	$	6,769		$	15,452		$	73,126		$	10,307		$	32,917
Construction and logistics services		—			—			—			—			6,045

Total revenue		6,769			15,452			73,126			10,307			38,962

Expenses:
Wellsite support services		3,108			8,695			42,281			5,793			14,423
Construction and logistics services		—			—			—			—			3,446
Selling, general and administrative		2,145			3,745			9,883			2,142			7,529
Depreciation and amortization		836			1,924			7,798			1,129			4,299
Loss on disposal of assets		86			92			499			3			342

Total expenses		6,175			14,456			60,461			9,067			30,039

Operating income		594			996			12,665			1,240			8,923
Interest expense, net		489			917			4,565			763			4,097
Other expense		—			—			66			17			10

Income before income taxes		105			79			8,034			460			4,816
Income tax expense (1)		—			—			598			105			911

Net income	$	105		$	79		$	7,436		$	355		$	3,905

Other Financial Data:
EBITDA (2)	$	1,430		$	2,920		$	20,397		$	2,352		$	13,212
Cash flow provided by operating activities		144			1,734			7,087			1,265			10,418
Cash flow used in investing activities		(7,536	)		(7,142	)		(83,462	)		(33,222	)		(95,516	)
Cash flow provided by financing activities		7,804			5,046			77,307			33,715			112,555
Capital expenditures:
Acquisitions, net of cash acquired (3)		5,505			1,158			48,955			26,675			74,097
Property and equipment		2,046			5,961			34,187			6,483			20,310


	As of December 31,						As of March 31,
	2003		2004		2005		2006
							(unaudited)
	(in thousands)
Balance Sheet Data
Cash and cash equivalents	$	412	$	50	$	982	$	28,439
Net property and equipment		7,131		13,899		74,583		122,597
Total assets		16,252		24,713		123,136		258,033
Total debt		11,705		18,552		67,795		171,162
Total partners’ capital		3,533		3,611		43,597		64,867

(1)	Historically, we were not subject to taxes on a consolidated basis due to our partnership structure; however, certain of our subsidiary companies are taxable corporations and are subject to income tax.

(2)	EBITDA consists of net income before interest expense, taxes, depreciation and amortization. EBITDA is used as a supplemental financial measure by our management and by external users of our financial statements, such as investors and commercial banks, to assess:

•

the financial performance of our assets without regard to financing methods, capital structures or historical cost basis;

•

the ability of our assets to generate cash sufficient to pay interest on our indebtedness;

•

our operating performance and return on invested capital as compared to those of other companies in the oilfield service industry, without regard to financing methods and capital structure; and

•

our compliance with certain financial covenants included in our credit facility.

EBITDA has limitations as an analytical tool and should not be considered an alternative to net income, operating income, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. EBITDA excludes some, but not all, items that affect net income and operating income and these measures may vary among other companies. Limitations to using EBITDA as an analytical tool include:

•

EBITDA does not reflect our cash expenditures or future requirements for capital expenditures or capital commitments;

•

EBITDA does not reflect changes in, or cash requirements necessary to service interest or principal payments, on our debt;

•

other companies in our industry may calculate EBITDA differently than we do, limiting its usefulness as a comparative measure.

The following table presents a reconciliation of the non-GAAP financial measure of EBITDA to the most directly comparable GAAP financial measures on a historical basis and pro forma basis for each of the periods indicated.


	Year Ended December 31,									Three Months Ended March 31,
	2003			2004			2005			2005			2006
										(unaudited)
	(in thousands)
Reconciliation of EBITDA to Net income:
Net income	$	105		$	79		$	7,436		$	355		$	3,905
Income taxes		—			—			598			105			911
Interest expense		489			917			4,565			763			4,097
Depreciation and amortization		836			1,924			7,798			1,129			4,299

EBITDA		1,430		$	2,920		$	20,397		$	2,352		$	13,212

Reconciliation of EBITDA to Cash flow from operations:
Net cash provided by operating activities	$	144		$	1,734		$	7,087		$	1,265		$	10,418
Bad debt expense		(24	)		(70	)		(465	)		(50	)		(220	)
Loss on disposal of property and equipment		(86	)		(92	)		(499	)		(3	)		(342	)
Interest expense		489			917			4,565			763			4,097
Amortization of debt issuance costs and debt discount included in interest expense		—			—			(495	)		(39	)		(1,716	)
Deferred income tax		—			—			73			(144	)		(65	)
Income tax expense		—			—			598			105			911
Change in operating assets and liabilities		907			431			9,533			455			129

EBITDA	$	1,430		$	2,920		$	20,397		$	2,352		$	13,212

(3)	Acquisitions, net of cash acquired, consist only of the cash component of acquisitions. It does not include equity and/or notes issued for acquisitions.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with our historical consolidated financial statements and the related notes included within this prospectus. This discussion contains forward-looking statements based on our current expectations, assumptions, estimates and projections about our business and the oil and natural gas industry. These forward-looking statements involve risks and uncertainties that may be beyond our control. Our actual results could differ materially from the results 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 natural gas, the level of oil and natural gas drilling, economic and competitive conditions, capital expenditures, regulatory changes and other uncertainties, as well as those factors discussed 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 currently focus on oil and natural gas regions within North America that we believe have attractive long-term potential for growth, including South Texas, the Gulf Coast, ArkLaTex, North Texas, the Permian Basin, the Mid-Continent and Rocky Mountain regions. We manage our operations from 24 field service offices located throughout our operating regions.

We operate in two business segments:

•

Wellsite Support Services. Our wellsite support services segment includes: (1) workforce accommodations, with a fleet of over 1,600 transportable accommodation units designed to accommodate various personnel on wellsite locations before, during and after drilling operations, (2) surface equipment rentals used in wellsite activities, including forklifts, manlifts, power generators, compressors, loaders and water systems, (3) our StaRComm^TM (Stallion Remote Communications) satellite system, and (4) solids control, which includes closed-loop mud systems and fluid recovery services. For the year ended December 31, 2005, and the three months ended March 31, 2006, revenue relating to our wellsite support services segment was $73.1 million and $32.9 million, respectively.

•

Construction and Logistics Services. Our construction and logistics services segment includes: (1) site construction, which includes site clearing, road construction, mat placement, production facility assembly and construction, pipeline installation, pit remediation, production decommissioning, and site

restoration and (2) rig relocation and heavy equipment hauling, through which we operate a fleet of cranes, tractors, trailers, trucks and loaders used for the hauling and relocation of drilling rigs and related heavy equipment. With our recent acquisitions of BLR Construction Companies, L.L.C. (“BLR”) and Oilfield Heavy Haulers, LLC (“OHH”), we established our construction and logistics services segment. For the three months ended March 31, 2006, revenue relating to our construction and logistics services segment was $6.0 million.

Our customers include exploration and production companies and drilling contractors that conduct drilling and production activities throughout the United States. Please read “Business—Customers” for additional information about our customers. The primary factor influencing demand for our services is the level of drilling and production activity of our customers, which in turn, depends on current and anticipated future oil and natural gas prices, production depletion rates and the resultant levels of cash flow generated and allocated by our customers to their drilling and production budgets. As a result, demand for our services and products can be cyclical.

The following tables summarize average United States drilling and well service rig activity, as measured by Baker Hughes Incorporated (“BHI”), and historical commodity prices as provided by Bloomberg L.P. (“Bloomberg”):

AVERAGE RIG COUNTS


	Year Ended December 31,				Three Months Ended March 31,
	2002	2003	2004	2005	2006
BHI Rotary Rig Count:
U.S. Land	717	924	1,095	1,290	1,440
U.S. Offshore	113	108	97	93	82

Total U.S.	830	1,032	1,192	1,383	1,522

BHI Workover Rig Count:
United States	1,010	1,129	1,235	1,354	1,527

Total United States	1,840	2,161	2,427	2,737	3,049

Source: BHI

AVERAGE OIL AND NATURAL GAS PRICES


Period	Average Daily Closing Henry Hub Spot Natural Gas Prices ($/mcf)		Average Daily Closing WTI Cushing Spot Oil Price ($/bbl)
01/01/02 – 12/31/02	$	3.37	$	26.17
01/01/03 – 12/31/03		5.49		31.06
01/01/04 – 12/31/04		5.90		41.51
01/01/05 – 12/31/05		8.89		56.59
01/01/06 – 03/31/06		7.66		63.34

Source: Bloomberg

We believe that drilling rig and workover rig counts are a good indication of spending by our customers in the oil and natural gas industry for exploration and development of new and existing hydrocarbon reserves. Spending levels for these activities are a primary driver of our business, and we believe that our customers tend to invest more in these activities when oil and natural gas prices are at or trending toward higher levels.

How We Generate Our Revenue

Most of our revenue is based upon a charge for the actual period of time the service or rental is provided to our customer, usually a few days, several weeks or a few months. By contracting services on a short-term basis, we are exposed to the risks of a rapid reduction in market prices and equipment utilization and volatility in our revenue.

We generate a majority of our revenue from our wellsite support services and construction and logistics services by charging our customers a rig-up charge plus a daily rental rate based on the type of equipment used. The rig-up charge is a flat fee generally payable in connection with the initial set up of workforce accommodation units and connection of these units to water, utilities and sewer systems. The rig-up charges, demobilization charges and daily rates are determined by regional price quotes or, in some cases, a competitive bid process and depend upon the type of service to be performed, the equipment and personnel required for the particular job and the market conditions in the region in which the service is performed. We also charge customers for additional services requested while our equipment is on location including water delivery, general service calls, repairs and waste disposal. In our construction services business, we install mats at the wellsite where required by the nature of the terrain or requested to help reduce the environmental impact of wellsite activities. In these instances, we generally submit bids based on a 30, 60 or 90 day mat rental period, with an additional daily rental rate if the mats are used beyond this period. In our rig relocation and heavy equipment hauling business, we generally bid a turn key price which may vary by region, type of rig and the distance the rig is transported.

Our operating costs are comprised primarily of labor, including workers’ compensation and health insurance, repair and maintenance, fuel and insurance. A majority of our employees are paid on an hourly basis. With a reduced pool of workers in the industry, it is possible that we will have to raise wage rates to attract workers from other fields and retain or expand our current work force. We also incur costs to employ personnel to sell and supervise our services and perform maintenance on our fleet. These costs are not directly tied to our level of business activity. Compensation for our administrative personnel in local operating yards and in our corporate office is accounted for as general and administrative expenses. Repair and maintenance is performed by our crews, company maintenance personnel and outside service providers. Insurance is generally a fixed cost regardless of utilization and relates to the number of rigs, trucks and other equipment in our fleet, employee payroll and safety record. Selling, general and administrative (“SG&A”) expenses were $7.5 million for the quarter ended March 31, 2006. As a percentage of revenue, the portion of labor expenses included in SG&A expenses decreased from 15.3% in 2004 to 6.6% in 2005. Our corporate overhead makes up less than half of our SG&A expenses. A significant component of SG&A are expenses related to our field-level office personnel and other overhead, which are necessary for operations.

How We Evaluate Our Operations

Our management utilizes a variety of financial and operational measurements to analyze and monitor the performance of our services. These measurements include the following:

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operating income per operating segment (each segment is further analyzed by field office and/or region for trending and to improve overall segment profitability);

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material and labor expenses as a percentage of revenue;

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EBITDA;

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EBIT;

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revenue and EBITDA per employee;

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return on capital employed; and

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safety performance rates.

We manage our operations through two operating segments. Each segment is further analyzed across seven operating regions. Our operating regions include one or more field service offices, depending on the level of activity and the size of the region. The data generated in each of our operating regions using the foregoing measurement tools is an important part of our operational analysis. We apply these measurement tools to monitor operations separately for each of our operating regions and to analyze trends to determine our relative performance in each region. By comparing our operations on an operating region basis, we can identify and react to trends in the geographic areas in which we operate to improve productivity and margins. We seek to have strong centralized financial analysis and control to allocate our resources and local decision-making and flexibility in the delivery of services to maximize customer satisfaction.

Trends Impacting Our Business

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Labor shortages and increasing safety concerns. Due to the increase in rig count and the corresponding increase in demand for labor in the oilfield, our customers continue to attempt to improve living and working conditions at the wellsite to help retain employees. We believe our workforce accommodations solutions and custom configurations for crew quarters have improved living and working conditions at the wellsite resulting in better employee morale and reduced turnover. Our customers also continue to enhance their safety procedures to help reduce injuries and to help ensure compliance with more stringent regulatory requirements. We supply equipment designed to improve wellsite safety and productivity. For example, our extended-reach forklifts eliminate the need to manually roll drill pipe across pipe racks reducing hazards such as pinched fingers or falls. Our manlifts are used to safely place crew members under the rig floor during rig-up and rig-down of wellhead pressure control equipment. Also, our light plants provide safe lighting conditions for night time operations at the wellsite.

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Increasingly complex technologies. The development of unconventional oil and natural gas resources is driving the need for complex, new technologies to help increase recovery rates, lower production costs and accelerate field development. The increasing complexity of technology used in the oil and natural gas development process requires additional technicians on location during drilling and, therefore, additional workforce accommodations. In particular, the increasing trend of pursuing horizontal and directional wells, as indicated in the chart below, as opposed to vertical wells requires additional expertise on location and, typically, longer drilling times. In some cases, up to six to nine workforce accommodation units are used during a drilling project, an increase over traditional utilization levels. Workforce accommodations are required for the company-man (oil and natural gas operator representative), the rig toolpusher (drilling rig supervisor), the rig crew (which typically includes 12-14 persons), a directional driller, a mud engineer, a safety engineer, solids control service personnel (between one and five persons), and other company and service personnel as necessary.

LOGO

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Geographically dispersed drilling operations. Before the consolidation of drilling contractors that began in earnest in the 1990’s, most drilling contractors were regional operators serving an area within a radius of approximately 100 to 200 miles from their home office. Most personnel working at the wellsite would drive to and from the wellsite on a daily basis. With the shift toward industry consolidation, crews based in one region may now be sent along with a rig to work on wellsites in geographically dispersed oil and natural gas regions significant distances away. This development has resulted in the need for full-time accommodations for multiple shifts of the rig crew. Additionally, the increasing pursuit of unconventional resources has resulted in increasingly remote drilling locations that do not have adequate infrastructure. These remote locations require accommodation units and other equipment and services of the type provided by us.

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Increase in drilling and developing unconventional resources. The decline of conventional North American oil and natural gas reservoirs is leading to a shift toward the drilling and development of unconventional oil and natural gas resources, including tight sands, shales and coalbed methane, that require more wells to be drilled and maintained and are also characterized by high decline rates. We believe the increased drilling requirements of these unconventional resources will lead to continued drilling activity. Consequently, there has been an increase in the construction of new drilling rigs to meet this demand.

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Increased environmental sensitivity. Continued sensitivity to the environmental impact of drilling and production activities has resulted in increasing regulation of the oil and natural gas industry. Normal wellsite operations use an earthen pit to temporarily store drilling fluids and cuttings. But, when drilling in environmentally sensitive areas such as marshes or when drilling with oil-based or other synthetic drilling fluids, wellsite operations must use closed-loop solids control systems, which require zero discharge of drilling fluids and cuttings at the wellsite. In order to help reduce drill cuttings and fluids disposal costs, operators require performance-based solids control configurations that attempt to maximize drilling fluid efficiency. Additionally, in some areas of the Rocky Mountains, federal regulators have mandated a reduction of long-term environmental impacts at drilling locations. In some cases, this has required the use of mats in place of traditional scraping by earth moving equipment to preserve prairie sage brush recoverability after wellsite operations cease. We believe that continued sensitivity to the environmental impact of wellsite operations will enhance the demand for our solids control and construction services.

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Outsourcing ancillary services. Some of the services we provide have been historically handled by drilling contractors themselves. In many instances, these services are only ancillary to the primary activity of drilling and completing wells and represent only a minor portion of the total well drilling cost. Many drilling contractors are increasingly electing to outsource these services to suppliers who can provide high-quality and reliable services.

Growth Opportunities

We intend to capitalize on emerging trends in the United States oil and natural gas industry through the execution of a growth strategy focused on internal growth opportunities complemented by strategic acquisitions.

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Internal Growth Opportunities. We plan to continue to roll-out our existing services across our current operating regions in an effort to deliver a comprehensive service portfolio in each region where we operate. Additionally, we seek to continue to invest in the development of new assets and services based on customer demand to supplement the breadth and quality of our service portfolio. We also intend to continue expanding our operations into new geographic regions to provide our service offerings to existing customers in markets that we have not historically served, as well as to attract new customers in these markets. We believe our established customer base and strong regional relationships will continue to provide a distribution network for deployment of our services.

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Acquisitions. We believe that our segment of the oilfield service industry has historically experienced underinvestment. Consequently, most of our competitors are smaller operators offering a limited set of

wellsite support services. As a result of the fragmented nature of our markets, we believe that there are numerous consolidation opportunities within these markets. We intend to leverage our proven capabilities of identifying, executing on and integrating acquisitions to further differentiate our service portfolio and grow our business.

Strategic Acquisitions

From inception through May 31, 2006, we have completed 16 acquisitions as part of our acquisition and expansion program. These acquisitions greatly expanded our service offerings and our geographic reach. We intend to continue to develop or acquire new high-quality, strategic assets and services which add to the scope and quality of our service portfolio. Since our inception, we have invested an aggregate of $153.6 million in acquisitions.

We evaluate our acquisitions based on a number of factors including: market region, service line, asset quality, customers, management, service and safety quality and financial performance. We base our valuations on several factors including: revenue multiples, EBITDA multiples, asset value, earnings accretion and strategic value.

The following is a description of some of the strategic acquisitions that expanded our service offerings and geographic reach:

Expansion of Service Offering

Workforce Accommodations and Surface Equipment Rental. In April 2003, we acquired the assets of Ray’s Mobile Homes, Ltd. (“Ray’s Mobile Homes”). Ray’s Mobile Homes was engaged in the business of providing workforce accommodations, sewer and water systems, trash containers and other related equipment to wellsites in South Texas. With this acquisition, we entered the workforce accommodations and surface equipment rental business.

Solids Control. In January 2005, we acquired Separation Services, Inc. (“SSI”), a Texas company engaged in performance-based solids control services to oil and natural gas companies and drilling contractors at wellsite locations. With this acquisition, we expanded into the solids control business.

Site Construction. In March 2006, we acquired BLR. BLR provides customers with experienced personnel and high-quality equipment, specializing in location construction, pipeline construction, marine services, production facility construction, crew services, heavy equipment and trucking services, remediation services, production decommissioning and vegetation control. BLR also provides inland marine site construction services. With this acquisition, we moved into the wellsite construction business.

Logistics. In March 2006, we acquired the assets of OHH. OHH provides heavy-duty drilling rig trucking and hauling services to the oilfield. OHH’s assets included a fleet of cranes, rig-hauling trucks, trailers and loaders specifically designed for the oil and natural gas industry. With this acquisition, we entered the rig relocation and heavy equipment hauling business.

Expansion of Geographic Reach

Rocky Mountains Expansion. In January 2005, we acquired the assets of Envirotech, Inc. (“Envirotech”), a company engaged in the rental of workforce accommodations, water systems, sewer systems and other related equipment. This acquisition provided a platform for expansion into the Rocky Mountain region, which is a region currently experiencing high levels of drilling activity.

Williston Basin Expansion. In September 2005, we acquired the assets of GL Trucking & Rental, Inc. (“GL Trucking”). GL Trucking provides integrated drilling support services for the Williston Basin and

surrounding areas. Its assets included over 100 workforce accommodation units, significant heavy equipment hauling capacity, loaders and equipment setting cranes. This acquisition extended our geographic footprint in the Rocky Mountains and brought our services to the Williston Basin, which is located in parts of North and South Dakota, Montana and Canada.

North Texas Expansion. In May 2006, we acquired the assets of Bowie Dozer Service, Inc. (“Bowie”). Bowie is an oilfield construction company that provides location construction and heavy equipment services for rig sites in the Fort Worth Basin. The purchased assets included dozers, loaders, graders, backhoes, trackhoes and rollers. This acquisition provided a platform for us to expand into North Texas, an active natural gas producing area.

Items Impacting Comparability of Our Financial Results

Our historical results of operations for the periods presented may not be comparable to our results of operations in the future for the reasons discussed below.

Changes in Our Legal Structure

We were formed as a Delaware corporation in June 2006. In connection with this offering, we will succeed to the business and operations of Stallion Ltd, which are described in this prospectus. Prior to the completion of this offering, Stallion Ltd will merge with and into Stallion Oilfield Services, Inc., with Stallion Oilfield Services, Inc. being the surviving corporate parent and owning all of the operating subsidiaries of Stallion Ltd. The majority owners of Stallion Ltd are Carlyle/Riverstone and an affiliate of Craig Johnson, our President, Chief Executive Officer and Chairman of the Board. In the Restructuring, assuming an initial public offering price of $ , which is the midpoint of the range set forth on the cover of this prospectus, the partners of Stallion Ltd will receive an aggregate of shares of our common stock in exchange for all of the Stallion Ltd partnership interests held by them. Immediately following completion of the Restructuring and prior to this offering, we will have shares of common stock outstanding, % of which will be owned by Carlyle/Riverstone and % of which will be owned by an affiliate of Craig Johnson. Following this offering, we will report our results of operations and financial condition as a corporation on a consolidated basis. For more information about the restructuring, please see “Certain Relationships and Related Party Transactions—The Restructuring.”

Historically, we were not subject to federal or state income taxes on a consolidated basis due to our partnership structure; however, certain of our subsidiary companies are taxable corporations and are subject to income tax. Our consolidated pro forma financial data included in this prospectus, however, include a pro forma adjustment for income taxes calculated at a blended state and federal rate of 38% resulting in a pro forma net income adjusted for income taxes. In 2005, Stallion Ltd made a capital distribution to its partners to fund tax obligations resulting from the partners being taxed on their proportionate share of Stallion Ltd’s taxable income. As a result of the Restructuring, we will record deferred tax assets and liabilities to reflect net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial and tax reporting purposes. As of December 31, 2005 and March 31, 2006, our estimated net deferred tax liability was approximately $1.0 million and $3.1 million, respectively resulting primarily from accelerated depreciation taken by Stallion Ltd and its subsidiaries. Following this offering, we will incur income taxes under our new corporate structure and our consolidated financial statements will reflect the actual impact of income taxes.

Public Company Expenses

We believe that our selling, general and administrative expenses will increase as a result of becoming a public company following this offering. We currently anticipate that our total annual selling, general and administrative expenses following the completion of this offering will increase by approximately $3.0 to $5.0 million. This increase will be due to the cost of tax return preparations, accounting support services, filing annual and quarterly reports with the SEC, investor relations, directors’ fees, directors’ and officers’ insurance and registrar and transfer agent fees, which we expect to incur after the completion of this offering. Our consolidated

financial statements following this offering will reflect the impact of these increased expenses and will affect the comparability of our financial statements with periods prior to the completion of this offering.

Critical Accounting Policies and Estimates

Our consolidated financial statements are impacted by the accounting policies used and the estimates and assumptions made by management during their preparation. A complete summary of these policies is included in Note 1 of the notes to our historical consolidated financial statements. The following is a discussion of our critical accounting policies and estimates.

Critical Accounting Policies

We have identified below accounting policies that are of particular importance in the presentation of our financial position, results of operations and cash flow and which require the application of significant judgment by management.

Property and Equipment. Property and equipment, including renewals and betterments, are stated at cost, while maintenance and repairs are expensed as incurred. We review our assets for impairment when events or changes in circumstances indicate that the carrying amount of a long-lived asset may not be recovered over its remaining service life. Provisions for asset impairment are charged to income when the sum of the estimated future cash flow, on an undiscounted basis, is less than the assets’ carrying amount. If impairment is indicated, an impairment charge is recorded based on an estimate of future discounted cash flow.

Self-Insured Risk Accruals. One of our subsidiary companies is partially self-insured for certain losses relating to workers’ compensation and group healthcare benefits. We maintain accruals to cover the self-insured risks, which are based on third-party data and historical claims history.

Revenue Recognition. Generally, we provide our services over a relatively short period of time pursuant to short-term arrangements at pre-determined service rates or on a project bid basis. Revenue from rental agreements is recognized over the rental period, and revenue from service agreements is recognized when services have been rendered. Certain of our operations recognize revenue related to wellsite construction using the percentage-of completion method determined by the ratio of costs incurred to total estimated costs at completion. All known or anticipated losses on contracts are recognized in full when such losses become apparent.

In our wellsite support services segment we charge our customers a rig-up/rig-down charge in connection with the initial set up or takedown of workforce accommodation units and for the connection or disconnection of these units to or from water, utilities and sewer systems. Revenue related to rig-up/rig-down charges is recognized upon completion of the service. We recognize revenue when it is earned and realized. We consider revenue earned and realized when the services are performed, collection of the relevant receivables is reasonably assured, persuasive evidence of the arrangement exists and the price is fixed and determinable.

Income Taxes. We account for income taxes based upon Statement of Financial Accounting Standards No. 109, “Accounting for Income Taxes”. Under SFAS 109, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using statutory tax rates expected to apply to taxable income in years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rate is recognized in the period that includes the statutory enactment date. A valuation allowance for deferred tax assets is recognized when it is more likely than not that the benefit of deferred tax assets will not be realized.

income tax. Our income tax expense will be comprised of current and deferred tax expense. These taxes added together provide an indication of an effective rate of income tax.

Critical Accounting Estimates

The preparation of our financial statements in conformity with GAAP requires management to make certain estimates and assumptions. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the balance sheet dates and the amounts of revenue and expenses recognized during the reporting periods. We analyze our estimates based on historical experience and various other assumptions that we believe to be reasonable under the circumstances. However, actual results could differ from such estimates. The following is a discussion of our critical accounting estimates.

Impairment of Long-Lived Assets and Goodwill. Our review for potential impairment of property and equipment requires us to estimate undiscounted future cash flow. Actual impairment charges are recorded using an estimate of discounted future cash flow. The determination of future cash flow requires us to estimate rates and utilization in future periods and such estimates can change based on market conditions, technological advances in industry or changes in regulations governing the industry. In accordance with SFAS No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets,” long-lived assets, such as property and equipment, 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 in operations is measured by a comparison of the carrying amount of an asset to estimated undiscounted cash flow expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated future cash flow, 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 carrying amount or the fair value less anticipated cost to sell, and they would no longer be depreciated.

We have adopted SFAS No. 142, “Goodwill and Other Intangible Assets,” which requires us to annually test goodwill and intangible assets with indefinite useful lives recorded in business combinations for potential impairment. This requires us to estimate the fair values of our own assets and liabilities at the reporting unit level. Therefore, considerable judgment, similar to that described above in connection with our estimation of the fair value of an acquired company, is required to assess goodwill and certain other intangible assets for impairment.

No impairment losses have been recorded through December 31, 2005.

Goodwill and Other Intangible Assets. The initial recording of goodwill and other intangibles requires estimation of the fair value of assets and liabilities using fair value measurements, which include quoted market price, present value techniques (estimate of future cash flows), and other valuation techniques. Additionally, SFAS No. 142 requires goodwill and other intangible assets to be reviewed for possible impairment on an annual basis, or if circumstances indicate that an impairment may exist. Determining fair value and implied fair value is subjective and often involves the use of estimates and assumptions. These estimates and assumptions could have a significant impact on the recording of intangible assets, whether or not an impairment charge is recognized and also the magnitude of the impairment charge. Our estimates of fair value are primarily determined using present value techniques of projected cash flows. This approach uses significant assumptions such as multi-year sales projections with associated expenses. We have performed impairment analyses on our goodwill and intangible assets of indefinite life, which indicated as of December 31, 2005 an impairment charge was not appropriate.

Allowance for Doubtful Accounts. We extend credit to our customers based on an evaluation of their financial condition, and generally, we do not require collateral nor do we charge interest on our accounts receivable. We estimate our allowance for doubtful accounts based on an analysis of historical collection activity and specific identification of overdue accounts. Factors that may affect this estimate include (1) changes in the financial position of significant customers and (2) a decline in commodity prices that could affect our entire

customer base. If these factors are less favorable than those projected by management or if our historical experience is materially different from our future experience, additional allowances may be required.

Litigation and Self-Insured Risk Reserves. We estimate our reserves related to litigation and self-insured risk (with respect to BLR’s continuing operations) based on the facts and circumstances specific to the litigation and self-insured risk claims and our past experience with similar claims. The actual outcome of litigated and insured claims could differ significantly from estimated amounts. As discussed in “—Critical Accounting Policies—Self-Insured Risk Accruals” above with respect to our critical accounting policies, we maintain accruals on our balance sheet to cover self-insured retentions. These accruals are based on certain assumptions developed using third-party and historical data to project future losses. Loss estimates in the calculation of these accruals are adjusted based upon actual claim settlements and reported claims.

Depreciation and Amortization. In order to depreciate and amortize our property and equipment and our intangible assets with finite lives, we estimate the useful lives and salvage values of these items. Our estimates may be affected by such factors as changing market conditions, technological advances in industry or changes in regulations governing the industry.

Fair Value of Assets Acquired and Liabilities Assumed. We estimate the value of assets acquired and liabilities assumed in business combinations, which involves the use of various assumptions. These estimates may be affected by such factors as changing market conditions, technological advances in the oil and natural gas industry or changes in regulations governing that industry. The most significant assumptions, and the ones requiring the most judgment, involve the estimated fair value of property and equipment, and the resulting amount of goodwill, if any. To finalize purchase accounting, for significant acquisitions we utilize the services of independent valuation specialists to assist in the determination of the fair value of acquired assets. These estimates are revised during an allocation period as necessary when, and if, information becomes available to further define and quantify the value of the assets acquired and liabilities assumed. To the extent additional information to refine the original allocation becomes available during the allocation period, the allocation of the purchase price is adjusted. If information becomes available after the allocation period, those items are reflected in operating results.

Income Taxes. Our income tax expense includes local, state and federal income taxes. We account for tax ramifications using SFAS No. 109 “Accounting for Income Tax.” 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 rate is recognized in income in the period of the change. Furthermore, SFAS No. 109 requires a valuation allowance for any net deferred income tax assets which we believe are likely to not be used through future operations. If our estimates and assumptions related to our deferred tax 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 flow.

Stock-Based Compensation. In December 2004, the FASB issued SFAS No. 123R, “Share-based Payment,” which revises SFAS No. 123 and supersedes APB Opinion No. 25. SFAS No. 123R requires 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 must be re-measured at each reporting date through the settlement date, with changes in fair value recognized as compensation expense of the period. SFAS No. 123R requires that we 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. In so doing, we use an option-pricing model (Black-Scholes), which requires various assumptions as to interest rates, volatility, dividend yields and expected lives of stock-based awards. Historically, we have not issued any equity securities in exchange for employee services.

Cash Flow Estimates. Our estimates of future cash flow are based on the most recent available market and operating data for the applicable asset or reporting unit at the time we made the estimate. Our cash flow estimates are used for asset impairment analyses.

The following table describes estimates, assumptions and methods regarding critical accounting estimates 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:


Description	Estimates/Assumptions Used	Variability in Accounting	Historical Results/ Sensitivity Analysis
Revenue Recognition	We recognize revenue when it is realizable and earned as services are performed. We estimate the percentage of completion of certain wellsite construction contracts based on cost incurred. We defer unearned revenue until earned.	There is a risk that we may not record revenue in the proper period.	There were no material adjustments resulting from revenue recognition issues for the years ended December 31, 2005, 2004 and 2003 or for the three months ended March 31, 2006 and 2005.
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 flow. Our management estimates future cash flow for this purpose and for intangible assets, and discounts this cash flow 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 flow are not consistent with the actual discount rates. Our assets could be overstated if impairment losses are not identified in a timely manner.	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 revenue, 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 $1.9 million for the year ended December 31, 2005.

Allowance for Doubtful Accounts	We estimate the recoverability of receivables on an individual basis based upon historical experience and management’s judgment.	There is a risk that management may not detect uncollectible accounts in the correct accounting period.	Bad debt expense has been less than 1% of sales for each of the years ended December 31, 2005, 2004 and 2003 and the three months ended March 31, 2006 and 2005. If bad debt expense had increased by 1% of sales for the year ended December 31, 2005, net income would have declined by $0.7 million.


Description	Estimates/Assumptions Used	Variability in Accounting	Historical Results/ Sensitivity Analysis
Litigation and Self-Insured Risk Reserves	BLR self insures certain risk related to workers’ compensation and medical claims. We estimate our reserves related to litigation and self-insured risk (with respect to BLR’s continuing operations) based on facts and circumstances specific to the litigation and self-insured risk claims and our past experiences with similar claims.	There is a risk that the actual outcome of litigation and/or self insured claims could differ significantly from our estimates.	Expense related to litigation and self-insured risk has been less than 1% of revenue for each of the years ended December 31, 2005, 2004 and 2003 and for the three months ended March 31, 2006 and 2005. If this expense had increased by 1% of revenue for the year ended 31, 2005 net income would have declined by $0.7 million.
Property and Equipment	Our management estimates useful lives of depreciable equipment and salvage values. The depreciation method used is generally the straight-line method.	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 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 nor during the three months ended March 31, 2006. Depreciation expense for the year ended December 31, 2005 represented 14.8% of the average depreciable asset base for that period. An increase in depreciation relative to the depreciable base of 1%, from 14.8% to 15.8%, would have reduced net income by approximately $0.5 million.


Description	Estimates/Assumptions Used	Variability in Accounting	Historical Results/ Sensitivity Analysis

Fair Value of Assets Acquired and Liabilities Assumed	We estimate the fair value of assets acquired and liabilities assumed in acquisitions. For significant acquisitions, we utilize the services of an independent valuation specialist to assist us in the determination of the fair value of acquired assets and any resulting intangibles. Our estimates are revised, if necessary, during an allocation period, and the value of required assets is changed. If an adjustment is necessary outside of an allocation period, the adjustment is charged to operations.	There is a risk that our estimates of the fair value of acquired assets may prove to be incorrect.	There were no material adjustments to the value of acquired assets outside of the allocation period for the years ended December 31, 2005, 2004, or for the three months ended March 31, 2006.
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 not had to record a valuation allowance to reflect that our deferred tax assets would not be utilized through future operations. Deferred income tax assets totaled $0.3 million at December 31, 2005. We have not recorded a valuation allowance since we believe that the deferred tax asset is realizable. If we were required to record a valuation allowance it would affect our net income on a dollar for dollar basis.

Results of Operations

Prior to 2003, we did not have significant operations. We began our strategic acquisition and expansion program early in 2003 and operated in one business segment, wellsite support services, which at that time consisted only of our workforce accommodations and surface equipment rental business. In 2005, with our acquisition of SSI, we established our solids control service line, which is part of our wellsite support services operating segment. In March 2006, we established our second operating segment, construction and logistics services, when we acquired OHH and BLR.

The following table sets forth our results of operations for the periods indicated. Our results of operations between the periods presented vary significantly primarily due to the number of acquisitions made during the presented periods and the relative timing of the acquisitions during those periods. See the notes to our historical consolidated financial statements for more detail.


	Year ended December 31,						Variance 2003 to 2004					Variance 2004 to 2005				Three months ended March 31,				Variance March 31, 2005 to March 31, 2006
	2003		2004		2005		$			%		$		%		2005		2006		$			%
																(unaudited)
	(dollars in thousands)
Statement of Operations
Revenue:
Wellsite support services	$	6,769	$	15,452	$	73,126	$	8,683		128.3	%	$	57,674	373.2	%	$	10,307	$	32,917	$	22,610		219.4	%
Construction and logistics services																			6,045		6,045		NM

Total revenue		6,769		15,452		73,126		8,683		128.3	%		57,674	373.2	%		10,307		38,962		28,655		278.0	%

Expenses:
Wellsite support services		3,108		8,695		42,281		5,587		179.8	%		33,586	386.3	%		5,793		14,423		8,630		149.0	%
Construction and logistics services																			3,446		3,446		NM
Selling, general and administrative		2,145		3,745		9,883		1,600		74.6	%		6,138	163.9	%		2,142		7,529		5,387		251.5	%
Depreciation and amortization		836		1,924		7,798		1,088		130.1	%		5,874	305.3	%		1,129		4,299		3,170		280.8	%
Loss on disposal of assets		86		92		499		6		7.0	%		407	442.4	%		3		342		339		NM

Total expenses		6,175		14,456		60,461		8,281		134.1	%		46,005	318.2	%		9,067		30,039		20,972		231.3	%

Operating income		594		996		12,665		402		67.7	%		11,669	NM			1,240		8,923		7,683		619.6	%
Interest expense, net		489		917		4,565		428		87.5	%		3,648	397.8	%		763		4,097		3,334		437.0	%
Other expenses		—		—		66		—		NM			66	NM			17		10		(7	)	(41.2	)%

Income before income tax		105		79		8,034		(26	)	(24.8	)%		7,955	NM			460		4,816		4,356		947.0	%
Income tax expense		—		—		598		—		NM			598	NM			105		911		806		767.6	%

Net income	$	105	$	79	$	7,436	$	(26	)	(24.8	)%	$	7,357	NM		$	355	$	3,905	$	3,550		NM

NM—Denotes not meaningful

Three Months Ended March 31, 2006 Compared to Three Months Ended March 31, 2005

Revenue.

Our revenue for the three months ended March 31, 2006 increased $28.7 million or 278.0%. The increase by operating segment was as follows:

Wellsite Support Services—Segment revenue increased $22.6 million or 219.4% to $32.9 million for the three months ended March 31, 2006. The increase in segment revenue resulted principally from acquisitions

made subsequent to January 1, 2005 combined with organic growth as a result of our capital expenditures program. In addition, we have seen modest improvement in our pricing.

Construction and Logistics Services—Our acquisition of Oilfield Heavy Haulers, LLC and the BLR Construction Companies, L.L.C. in March 2006 marked the establishment of our construction and logistics services operating segment. Segment revenue increased $6.0 million for the three months ended March 31, 2006 from the similar period of 2005 due to adding the additional segment operations in 2006.

Operating Expense.

Our operating expense for the quarter ended March 31, 2006 increased $21.0 million or 231.3%.

Expenses directly related to the operation of each of our operating segments 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 our equipment. These expenses increased 208.5% or $12.1 million. The increase in these costs by operating segment was as follows:

Wellsite Support Services—Direct segment operating cost increased $8.6 million or 149.0%. Direct operating expenses as a percentage of segment revenue decreased from 56.2% for the three months ended March 31, 2005 to 43.8% for the three months ended March 31, 2006. The decrease in these costs as a percentage of revenue resulted principally from improved pricing and a more favorable mix of higher margin services.

Construction and Logistics Services—Our acquisition of Oilfield Heavy Haulers LLC and the BLR Construction Companies, L.L.C. in March 2006 marked the establishment of our construction and logistics services operating segment. Direct segment operating costs increased $3.4 million for the quarter ended March 31, 2006 from the similar period of 2005 due to adding segment operations in 2006.

Selling, General and Administrative Expense.

Selling, general and administrative expense consist primarily of salaries and other related expenses for our sales, marketing, administrative, finance, information technology and human resources functions. Selling, general and administrative expenses increased $5.4 million, or 251.5%. This increase was primarily due to the acquisitions that we made during 2005 and 2006, which provided additional headcount of 136 personnel providing support to field offices who are accounted for in selling, general and administrative expenses. Additionally, we increased our corporate headcount by 21 during the same period. Additional costs were incurred for outside consulting services for accounting, tax and information technology. As a percentage of revenue, selling, general and administrative expenses decreased from 20.8% for the three months ended March 31, 2005 to 19.3% for the three months ended March 31, 2006, as these expenses were spread over a larger revenue base.

Depreciation and Amortization Expense.

Depreciation and amortization expense increased 280.8%, or $3.2 million. 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 11.0% for both the three months ended March 31, 2005 and 2006.

Interest Expense.

Interest expense was $4.1 million for the three months ended March 31, 2006 compared to $0.8 million for the similar period ended March 31, 2005. Interest expense for the three months ended March 31, 2006 includes $1.6 million of expense related to the write off of certain debt issuance cost associated with our 2005 credit facility. We replaced that credit facility with a new credit facility during the first quarter of 2006. See “Liquidity

and Capital Resources—2006 Credit Facility.” Additionally, the increase in interest expense was attributable to an increase in the average amount of debt outstanding as a result of acquisitions completed and capital expenditures incurred in 2005 and 2006. The weighted average interest rate on our outstanding debt increased from 6.02% at March 31, 2005 to 7.55% at March 31, 2006. At December 31, 2005 our weighted average interest rate was 6.75%. The increase in our weighted average interest rate is related to borrowings under our variable interest rate facilities combined with a general increase in the prime rate of interest during that same time period.

Income Tax Expense.

Historically, we were not subject to federal or state income taxes on a consolidated basis due to our partnership structure; however, certain of our subsidiary companies are taxable corporations and are subject to income tax. Our income tax expense will be comprised of current and deferred tax expense. Together these taxes added together provide an indication of an effective rate of income tax. Our tax expense was $0.1 million and $0.9 million for the quarters ended March 31, 2005 and 2006, respectively. Following this offering, we will be subject to income taxes.

Year Ended December 31, 2005 Compared to Year Ended December 31, 2004

In 2005 and 2004 we operated only in the wellsite support services operating segment.

Revenue.

Our revenue for the year ended December 31, 2005 increased $57.7 million, or 373.2%. Our increased revenue resulted from a combination of the acquisitions that we made during 2005 and from additional capital investment in rental equipment as well as improved market conditions, including favorable pricing for our services and products.

Operating Expense.

Our operating expense for the year ended December 31, 2005 increased $46.0 million or 318.2%.

Expenses directly related to our operations 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 our equipment. These expenses increased 386.3% or $33.6 million from $8.7 million for the year ended December 31, 2004 to $42.3 million for the twelve months ended December 31, 2005.

Direct operating expense as a percentage of revenue increased from 56.3% in 2004 to 57.8% in 2005. The slight increase in direct operating expense as a percentage of revenue was primarily attributable to a temporary decrease in our margins as we integrated our recent acquisitions into our business.

Selling, General and Administrative Expense.

Selling, general and administrative expense consists primarily of salaries and other related expenses for our sales, marketing, administrative, finance, information technology and human resources functions. Selling, general and administrative expense increased $6.1 million, or 163.9%. This increase was primarily due to the acquisitions that we made during 2005, which provided additional headcount and general expenses. Additional costs were incurred in 2005 for outside consulting services for accounting, tax and information technology. As a percentage of revenue, selling, general and administrative expenses decreased from 24.2% in 2004 to 13.5% in 2005, as these expenses were spread over a larger revenue base.

Depreciation and Amortization Expense.

Depreciation and amortization expense increased 305.3%, or $5.9 million. 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 decreased from 12.5% in 2004 to 10.7% in 2005, as these expenses were spread over a larger revenue base.

Interest Expense.

Interest expense was $4.6 million for the twelve months ended December 31, 2005 compared to $0.9 million for the similar period ended December 31, 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 on our outstanding debt increased from 5.09% at December 31, 2004 to 6.75% at December 31, 2005. This increase related to borrowings under variable interest rate facilities and a general increase in the prime rate of interest during that same time period.

Income Tax Expense.

Historically, we were not subject to federal or state income taxes on a consolidated basis due to our partnership structure; however, certain of our subsidiary companies are taxable corporations and are subject to income tax. Our income tax expense will be comprised of current and deferred tax expense. Together these taxes provide an indication of an effective rate of income tax. Our tax expense was $0.6 million for the year ended December 31, 2005. We had no tax expense for the year ended December 31, 2004.

Year Ended December 31, 2004 Compared to Year Ended December 31, 2003

In 2004 and 2003, we operated only in the wellsite support services operating segment.

Revenue.

Our revenue for the year ended December 31, 2004 increased $8.7 million, or 128.3%. The increased revenue resulted principally from our capital investment in new rental equipment and improved market conditions. During 2004, we invested $6.0 million in new rental equipment and $1.2 million for the acquisition of Rebel Testers, Inc., which did not have a significant impact on our 2004 operating results.

Operating Expense.

Our operating expense for the year ended December 31, 2004 increased $8.3 million, or 134.1%.

Expenses directly related to the operation of our wellsite support services operating segment includes 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 our equipment. These expenses increased 179.8%, or $5.6 million. Direct operating expenses as a percentage of revenue increased from 45.9% for the year ended December 31, 2003 to 56.3% for the year ended December 31, 2004.

Selling, General and Administrative Expense.

Depreciation and Amortization Expense.

Depreciation and amortization expense increased 130.1% or $1.1 million. The increase in depreciation and amortization expense was principally the result of capital expenditures made to expand our inventory of rental

equipment. As a percentage of revenue, depreciation and amortization expense was 12.4% for the year ended December 31, 2003 and 12.5% for the year ended December 31, 2004.

Interest Expense.

Interest expense was $0.9 million for the twelve months ended December 31, 2004 compared to $0.5 million for the similar period ended December 31, 2003. The increase in interest expense was attributable to an increase in the average amount of debt outstanding principally as a result of our capital expenditures completed in 2003 and 2004. The weighted average interest rate on our outstanding debt decreased slightly from 5.2% at December 31, 2003 to 5.09% at December 31, 2004.

Income Tax Expense.

Historically, we were not subject to federal or state income taxes on a consolidated basis due to our partnership structure; however, certain of our subsidiary companies are taxable corporations and are subject to income tax. As such, our income tax expense will be comprised of current and deferred tax expense. Together these taxes provide an indication of an effective rate of income tax. We had no income tax expense for the years ended December 31, 2004 and 2003.

Liquidity and Capital Resources

Our primary liquidity needs are to fund capital expenditures, such as acquiring new rental equipment and funding our general working capital requirements. Additionally, we need capital to fund our acquisition program. Our primary capital resources are net cash flow from our operations and borrowings under our revolving credit facility, of which approximately $50.0 million was available at March 31, 2006. Upon completion of this offering, we anticipate that we will rely on cash generated from operations and borrowings under our revolving credit facility to satisfy our liquidity needs. We believe that funds from these sources will be sufficient to meet our working capital requirements for at least the next twelve months. Our ability to fund future capital expenditures and to make strategic 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.

Operating Activities

Our cash flow provided by operating activities for the three months ended March 31, 2006 increased $9.2 million compared to the first quarter of 2005. Our gross receipts increased during 2006 as demand for our services continued to grow, resulting in more billable days and more favorable billing rates, while we expanded our current business and entered new markets through acquisitions and capital investments. The increase in cash flow provided by operations was primarily related to our increased revenue resulting from our 2005 and 2006 capital expenditures for equipment and the acquisition of businesses.

Cash flow provided by operating activities was $7.1 million in 2005 as compared to $1.7 million in 2004 and $0.1 million in 2003. The increase in operating cash flow in 2005 over 2004 was primarily due to an increase in our gross receipts as a result of increased revenue. Our gross receipts increased during 2005 as demand for our services grew while we expanded our existing business and entered new markets through acquisitions and capital investments. The 2004 operating cash flow, as compared to 2003, also increased as a result of our improved operating results which were directly related to improved demand for our services, better billing rates and our entry into new markets.

Investing Activities

Cash flow used in investing activities was $95.5 million for the three months ended March 31, 2006 as compared to $33.2 million for the same period of 2005. During the first quarter of 2006, we made property and

equipment capital expenditures of $20.3 million compared to $6.5 million in the first quarter of 2005. Additionally in the first three months of 2006, we paid total consideration of $79.2 million for the acquisition of six businesses. In the first quarter of 2005, we made acquisitions totaling $29.5 million. Those acquisitions used cash of $74.1 million and $26.7 million for the three months ended March 31, 2006 and 2005, respectively.

Cash flow used in investing activities was $83.5 million for the twelve months ended December 31, 2005 as compared to $7.1 million in 2004 and $7.5 million in 2003. The increase in cash flow used in investing activities in 2005 over 2004 was primarily due to our acquisition of ten businesses during 2005 for a total consideration of $54.4 million and property and equipment capital expenditures we made to expand our fleet of rental and service equipment totaling $34.2 million. In 2005, we used cash of $49.0 million compared to $1.2 million in 2004 for the acquisition of businesses. In 2004, we spent $0.4 million less on investing activities than we did in 2003. We acquired one business in 2004 as compared to three businesses in 2003. Our cash used for acquisitions in 2003 was $5.5 million. The lower spending in 2004 on acquisitions was offset however as our capital expenditures for property and equipment increased $3.9 million in 2004 as compared to 2003.

Financing Activities

We also generated cash from our financing activities in the first quarter of 2006 totaling $112.6 million. Approximately $17.4 million of this amount resulted from contributions of capital made by the partners. The remaining amount was attributable to new notes payable and long-term debt of $171.0 million net of issuance costs that were offset by payments on the notes and long-term debt totaling $75.8 million.

Cash flow provided by financing activities was $77.3 million for the year ended December 31, 2005 as compared to $5.0 million in 2004 and $7.8 million in 2003. The increase in cash flow provided by financing activities in 2005 over 2004 was primarily due to capital contributions made by our partners totaling $32.4 million, increased borrowings under our credit agreement and through seller financing of a portion of certain of our 2005 acquisitions. These increases were partially offset by payments on our long-term debt totaling $21.5 million. The decline in 2004 cash flow provided by financing activities, as compared to 2003 is principally related our use of operating cash flow to fund certain of our capital expenditures of approximately $6.0 million and to payments on our long-term debt of $5.2 million.

Capital Expenditures

Capital expenditures for the purchase of property and equipment and acquisitions of companies are the main component of our investing activities. We made total capital expenditures of $85.8 million during the year ended December 31, 2005. In 2005, we significantly expanded our wellsite support services segment with capital expenditures of $34.2 million to acquire additional equipment and $42.5 million to acquire five businesses that operate in the workforce accommodations and surface equipment rental service line. Also in 2005, we made capital expenditures of $9.1 million to acquire Separation Services, Inc. which marked the formation of our solids control service line in our wellsite support services segment.

In addition to making investments in property and equipment capital expenditures, we will continue to evaluate acquisitions of complementary companies. Excluding capital expenditures for acquisitions, we expect to spend approximately $80.0 million for investment in property and equipment capital expenditures during the year ending December 31, 2006, including $8.0 million that is budgeted as maintenance capital expenditures. In the first three months of 2006, we made capital expenditures of $79.2 million to acquire five businesses. Additionally, we made capital expenditures of $20.3 million to expand our existing fleet of rental and support equipment.

2006 Credit Facility

Our credit facilities as of December 31, 2005 are described in the accompanying audited consolidated financial statements (see Note 6 to the audited consolidated financial statements).

On March 28, 2006, we amended and restated our existing secured credit facility (as amended and restated, the “Credit Agreement”) with UBS AG Stamford Branch, as Issuing Bank, Administrative Agent and Collateral Agent (“UBS AG”), and certain other financial institutions. The Credit Agreement provides for a $165 million term loan (the “Term Loan Facility”) that will mature on March 1, 2012, and up to $50 million in borrowing capacity under a revolving credit facility (the “Revolving Credit Facility”) that will mature on March 1, 2011. The Credit Agreement also provides up to $20 million for the issuance of letters of credit on our behalf. Any outstanding letters of credit reduce our borrowing capacity under the Revolving Credit Facility.

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 (“LIBOR”) plus an applicable margin between 2.75% and 3.25% depending on the credit rating of commitments under the Credit Agreement, or (2) the greater of (a) the base rate charged by UBS AG and (b) the Federal Funds Rate, plus 0.5%, plus an applicable margin between 1.75% and 2.25% depending on the credit rating of commitments under the Credit Agreement. If an event of default exists under the Credit Agreement, advances will bear interest at the then applicable rate plus 2%. Interest is payable quarterly in arrears for base rate loans and at the end of the applicable interest periods for LIBOR loans.

All of our obligations under the Credit Agreement are secured by first priority security interests on substantially all of our assets. Additionally all of our subsidiaries have guaranteed our obligations under the Credit Agreement.

The Credit Agreement contains various standard covenants that place limits on the operation of our business. Some of these covenants require us and our subsidiaries, on a consolidated basis, to maintain specific ratios or conditions as follows (with such ratios tested at the end of each fiscal quarter):

•

maintain a maximum total leverage ratio of 4.25 to 1.0 between April 1, 2006 and December 31, 2006; 4.00 to 1.0 between January 1, 2007 and December 31, 2007; 3.75 to 1.0 between January 1, 2008 and December 31, 2008; and, 3.50 to 1.0 for all periods thereafter;

•

maintain a maximum senior leverage ratio of 3.5 to 1.0 between April 1, 2006 and December 31, 2006; 3.25 to 1.0 between January 1, 2007 and December 31, 2007; 3.00 to 1.0 between January 1, 2008 and December 31, 2008; and, 2.75 to 1.0 for all periods thereafter;

•

maintain a minimum interest coverage ratio of 3.0 to 1.0 for the term of the Credit Agreement; and,

•

maintain a minimum fixed charge coverage ratio of 1.0 to 1.0 between April 1, 2006 and December 31, 2006 and 1.15 to 1.0 for all periods thereafter.

As of May 31, 2006, we were in compliance with these covenants.

Under the Credit Agreement, we are permitted to prepay certain of our borrowings. In addition, the Credit Agreement requires us to make prepayments in certain situations.

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 they may exercise other rights and remedies. While an event of default is continuing, advances will bear interest at the then applicable rate plus 2%.

As of May 31, 2006, we had $165.0 million outstanding under the Term Loan Facility and the Revolving Credit Facility and no outstanding letters of credit, leaving $50.0 million available to be drawn under the Revolving Credit Facility. Our weighted average interest rate on outstanding borrowings at May 31, 2006 was approximately 7.95%. For the years ended December 31, 2005, 2004 and 2003, our weighted average interest rate on outstanding borrowings were approximately 6.75%, 5.09%, and 5.20%, respectively.

Other Debt

We have a variety of other capital leases and notes payable outstanding that are customary in our industry. None of these debt instruments are significant individually.

Outstanding Debt and Operating Lease Commitments

We have significant contractual obligations in the future that will require capital resources. Our primary contractual cash obligations are (1) our debt, (2) our capital lease obligations, (3) our commitments under purchase orders and (4) our operating leases.

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	$	55,473	$	2,594	$	6,423	$	3,901	$	42,555
Capital lease obligations		860		412		347		101		—
Operating lease obligations		3,382		1,387		1,576		419		—
Other long-term obligations		—		—		—		—		—
Purchase obligations		—		—		—		—		—

Total contractual obligations	$	59,715	$	4,393	$	8,346	$	4,421	$	42,555

The following table summarizes our known contractual obligations as of March 31, 2006 giving effect to the completion of this offering and the application of $82.5 million of the proceeds to pay down our term loan facility (in thousands):


Contractual Obligations	Total		2006(1)		2007-2008		2009-2010		Thereafter
Long-term debt	$	88,081	$	2,163	$	5,086	$	2,251	$	78,581
Capital lease obligations		620		243		281		96		—
Operating lease obligations		3,047		1,052		1,576		419		—
Other long-term obligations		—		—		—		—		—
Purchase obligations		—		—		—		—		—

Total contractual obligations	$	91,709	$	3,458	$	6,943	$	2,766	$	78,581

(1)	Remaining nine months

Off-Balance Sheet Arrangements

We have entered into operating lease arrangements for certain of our specialized equipment and for our office and field operating locations in the normal course of business. The terms of our facility leases range from monthly to five years. The terms of the specialized equipment leases range from one to five years. Annual payments pursuant to these leases are included in the above table under “Operating lease obligations.”

Quantitative and Qualitative Disclosures about Market Risk

The demand, pricing and terms for oil and natural gas services that we provide are largely dependent upon the level of activity in the U.S. oil and natural gas industry. Industry conditions are influenced by numerous factors over which we have little or no control, including, but not limited to: the supply of and demand for oil and natural gas; the level of prices and expectations about future prices of oil and natural gas; the expected rates of declining current production; the discovery rate of new oil and natural 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 natural gas producers to raise equity capital and debt financing; and merger and divesture activity among oil and natural gas producers.

The level of activity in the oil and natural gas exploration and production industry is volatile. Expected trends in oil and natural 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 natural gas prices that would likely affect drilling activity levels could have a material adverse effect on our business, financial condition, results of operations and cash flow.

In addition, we have interest rate caps on LIBOR at 6.15% with notional amounts of approximately $82.5 million. The cost of the caps of approximately $183,000 is amortized as interest expense over the life of the contract, which approximates the interest method.

We are exposed to changes in interest rates as a result of our credit facility which has a floating rate risk as of March 31, 2006. We had a total of $165.0 million of indebtedness outstanding under our credit facility at March 31, 2006. The impact of a 1% increase in interest rates on this amount of debt would result in an annual increase in interest expense, and a corresponding decrease in net income, of approximately $1.65 million.

Recent Accounting Pronouncements

In December 2004, the FASB issued SFAS No. 153, “Exchanges of Non-monetary Assets.” SFAS No. 153 amends current guidance related to the exchange of non-monetary assets as per APB Opinion No. 29, “Accounting for Non-monetary Transactions,” to eliminate an exception that allowed exchange of similar non-monetary assets without determination of the fair value of those assets, and replaced this provision with a general exception for exchanges of non-monetary assets that do not have commercial substance. A non-monetary exchange has substance if the future cash flow of the entity are expected to change significantly as a result of the exchange. SFAS No. 153 became effective for non-monetary 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 flow.

In December 2004, the FASB issued SFAS No. 123R, “Share-based Payment,” which revises SFAS No. 123 and supersedes 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 re-measured at each reporting date through the settlement date, with changes in fair value recognized as compensation expense of the period. SFAS No. 123R requires that we 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 as of January 1, 2006, with no material impact on our financial position, results of operations or cash flow.

In March 2005, the FASB issued Interpretation No. 47, “Accounting for Conditional Asset Retirement Obligations” which requires companies to recognize a liability for the fair value of a legal obligation to perform asset-retirement activities that are conditional on a future event when the amount can be reasonably estimated. FIN 47 also clarifies when an entity would have sufficient information to reasonably estimate the fair value of an asset retirement obligation under SFAS No. 143. FIN 47 is effective for fiscal years ending after December 15, 2005, and is not expected to materially affect our financial position or results of operations.

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 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, with no material impact on our financial position, results of operations or cash flow.

BUSINESS

General

LOGO

We currently focus on oil and natural gas regions within North America that we believe have attractive long-term potential for growth, including South Texas, the Gulf Coast, ArkLaTex, North Texas, the Permian Basin, the Mid-Continent and Rocky Mountain regions. We manage our operations from field service offices located throughout our operating areas.

We conduct our operations through the following two business segments:

•

Workforce accommodations. We believe we are the leading provider of workforce accommodations in the United States with over 1,600 transportable units in our inventory. Our fleet of units is designed to accommodate various personnel on wellsite locations before, during and after drilling operations. Certain trends in the oil and natural gas exploration and production industry, including increased drilling complexity and a tight supply of labor, have resulted in wellsite personnel spending more time at the wellsite. These trends have contributed to an increase in demand for high-quality, reliable workforce accommodations. Our workforce accommodation units are specifically configured to provide transportable, comfortable living quarters and functional workspaces.

•

Communications services. We also provide integrated communications services through our StaRComm satellite system that provides wireless communications via intercoms and telephone, fax and internet/data services throughout the wellsite location.

•

Wellsite support services and construction and logistics services are critical to establish and operate the wellsite; however, these services have historically been provided primarily by small, regional service providers and have not been the focus of larger oilfield service companies. We believe we have a distinct advantage over smaller competitors due to our scale, our access to capital and our ability to provide a single supply source for many of our customers’ needs. We believe we differentiate ourselves and thus are able to achieve growth by offering our customers high-quality, professional and reliable equipment and services on a large scale.

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 natural gas, and the perceived stability and sustainability of those prices. Our services comprise a relatively small portion of the total cost of drilling the well and, accordingly, our revenue does not tend to vary significantly with changing drilling rig

rates. Our business is primarily driven by natural gas and oil drilling and production activities in North America. We believe the following three 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 its growing popularity as a cleaner burning fuel. According to the International Energy Association’s 2005 World Energy Outlook, natural gas demand in North America (United States, Canada and Mexico) is projected to grow by approximately 41% from 2002 to 2025.

•

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 to maintain existing levels of production. This is coupled with the recent development of reserve plays characterized by multiple wells having smaller average reserves per well. To supply the growing demand for natural gas, certain of the alternatives are to increase drilling and enhance recovery rates on domestic production.

LOGO

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Increased oil drilling activity and sustained higher oil prices. We believe that historical data and industry forecasts suggest an increasing demand for oil coupled with a flat or declining production curve. The average West Texas Intermediate oil price has increased 142% from an average price of $26.17 for 2002 to an average price of $63.34 for the three months ended March 31, 2006. According to BHI, the average number of drilling rigs in the United States dedicated to drilling for crude oil has increased 82% from an average of 137 for 2002 to an average of 249 from January 1, 2006 until June 23, 2006. We believe that this increasing demand for crude oil is reflected in the sharp increase in crude oil prices and utilization of oil drilling rigs. According to the U.S. Department of Energy, the average daily oil production in the United States has decreased 6.9%, from 5,822 MBbl per day in 2000 to 5,419 MBbl per day in 2004. We believe that sustained domestic drilling activity for crude oil will continue as exploration and production companies contend with constrained supply and increased demand.

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 and oil in North America in the near future. We believe these trends will continue to support high levels of drilling activity.

Our Business Strategy

We believe we are well positioned to become a leading provider of wellsite support and construction and logistics services. Our business strategy consists of the following core elements:

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Broadening the suite of services we provide. We work closely with our customers to define new service offerings that meet specific customer needs. For example, our StaRComm system was first deployed in December 2005 after a series of customer driven studies and trials. We expect to have 100 StaRComm systems deployed by the end of 2006. Also in 2006, we completed a number of acquisitions which provided us the capability in certain operating areas to provide more extensive rig relocation and heavy equipment hauling services. These acquisitions not only enhanced our revenue generating capacity but also provided us the opportunity to be the first service supplier at the wellsite and to cross-sell other services. We intend to continue to invest in developing or acquiring new high-quality assets and services which add to the equipment breadth and quality of our service portfolio.

Extend our operations into new geographic areas. We believe our expertise in wellsite support services and construction and logistics services can be readily applied in markets where we currently do not operate and provides an attractive platform for future growth. We believe our customers will continue to find value in our ability to provide services across multiple operating regions. We intend to continue to improve the ease with which our clients can use our services from one wellsite location to the next. We expect to support our customers’ entry into other active drilling regions by introducing our service offerings in those regions. In addition, we will also seek opportunities for expanding into new geographic areas where market conditions are favorable in order to attract new customers.

Focus on service quality, business performance and safety. We have established and promote a culture of performance, accountability and safety. Our management team is responsible for assessing our service quality, performance and safety compliance and coordinates with our regional offices to help ensure that our quality and performance metrics and safety standards are met at every level of our organization. We believe that our pursuit of a reliable, comprehensive and professional service solution differentiates us from smaller regional competitors. We intend to continue to invest in and promote systems and methodologies which improve the reliability, responsiveness, accountability and safety of our operations.

local management to focus on our customers, our employees and the effective management and deployment of our assets.

Our Competitive Strengths

We believe our operations benefit from a number of competitive strengths, including the following:

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Large scale of operations. We believe that we are one of the largest providers of comprehensive wellsite services in our operating areas and that our workforce accommodations asset base is more than twice the size of our next largest competitor. Our scale enables us to deliver a comprehensive range of reliable and high-quality wellsite services to our customers. Our size also provides us with increased access to capital resources and reduces our administrative burden as a percentage of sales.

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Experienced management team with proven acquisition track record and control environment. Our senior management team has extensive experience in the oil and natural gas industry, with an average of 21 years of experience. We believe that this background provides our management team with an in-depth understanding of our customers’ needs and enhances our ability to deliver customer driven solutions. Our management also has substantial experience in identifying, completing and integrating acquisitions and since our inception, we have acquired 16 businesses. We have also implemented a control environment consisting of a strong corporate infrastructure that includes standardized financial, accounting, safety, environmental and maintenance processes and controls. Our integrated systems allow us to monitor operating performance, maintain financial, accounting and asset management controls, integrate acquisitions, prepare timely financial reports and manage contractual risk. In addition, our control environment provides transparency for our management team to track regional and project level performance and reliability and frees our local personnel to focus on customer service and performance.

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Leveraged to the expected increase in rig count. The demand for our services is primarily driven by the number of contracted drilling rigs in our operating regions. We believe that favorable supply and demand fundamentals for oil and natural gas will continue to increase the number of operating drilling rigs for the foreseeable future. Also, as our package of services typically comprises less than 15% of total drilling expenditures, our business has not historically experienced the pricing volatility experienced by drilling contractors, who represent a much larger portion of total drilling expenses.

Overview of Our Segments

We manage our business through two segments: wellsite support services and construction and logistics services. Through these segments, we offer services that are essential to the successful set-up, drilling and

completion of a wellsite. Our ability to provide timely and reliable service, our extensive inventory of readily-available equipment, and our reputation for high-quality are important to drilling contractors looking to stay on schedule and attract the best crews. We also believe that larger exploration and production companies often prefer to work with service providers who offer regional and even national supply options, which many smaller vendors cannot provide. Unlike some of our competitors, we offer a comprehensive suite of wellsite support services and are well positioned to be the preferred provider of these services to our customers.

We have the ability to provide a broad array of wellsite support services through our extensive inventory of equipment and services and network of regional offices. Our diverse and integrated product offerings enhance the value of our services to our customers, while reducing our reliance on a single product line. Our core business involves offering integrated services which provides us opportunities to cross-sell our other services. For example, our construction services operations are the first service provider to begin work on a new wellsite. By delivering this service, we are strategically positioned to market our workforce accommodations and surface equipment services to the wellsite operator. Further, by staying in contact with the customer throughout the drilling phase, we are also well positioned to win business from the same customer for post drilling work, such as assembly of production facilities and pipelines, site remediation and other services. Finally, by providing rig hauling and relocation services, we transition with the client to the next wellsite location. In addition to diversifying our revenue streams, we believe we can obtain a competitive advantage by supporting our customers before, during and after their drilling activities. Maintaining an ongoing dialogue with our customers also provides us with real-time information that ultimately helps us anticipate and support our customers’ needs.

Our products and services represent only a fraction of the overall costs of a well, providing an opportunity for pricing leverage as demand for higher quality workforce accommodations, surface equipment and other services increases.

We currently provide the following types of services, including our recently acquired construction and logistics business, for our customers to support their operations before, during and after wellsite operations:

Service Line

South
Texas

Gulf
Coast

ArkLaTex

North
Texas

Permian
Basin

Mid-
Continent

Rocky
Mountains

Wellsite Support Services

Workforce Accommodations

Surface Equipment Rental

Communications Services

Solids Control

Construction and Logistics Services

Site Construction

Mat Rental

Production Equipment Assembly and Installation

Pipeline Installation

Production Facility Disassembly

Site Remediation

Rig Relocation and Heavy Equipment Hauling

Wellsite Support Services

Through our wellsite support services segment, integral services are delivered to oil and natural gas companies, drilling contractors and other wellsite service providers that are required to support wellsite

operations. This segment includes workforce accommodations, surface equipment rental, communications services and solids control services.

Workforce Accommodations

We provide basic living accommodations and rental services, primarily through equipment rental at the wellsite location. As of March 31, 2006, we owned and operated 1,662 transportable units. Each of our accommodation units is manufactured to our custom specifications for use in the oilfield environment and includes every detail to provide comfortable living quarters and functional workspaces. These accommodation services include mobile and skid-mounted units, portable bathrooms, change houses and crew quarters; water, sewer, and other specialized vehicles; and on-site water and sewer systems. We provide wellsite accommodation services in all of the regions in which we operate.

Our primary competition in most of our operating regions for workforce accommodations includes a fragmented group of smaller, independent service providers. Contracts for workforce accommodations are awarded based on the quality of accommodations and services and pricing is determined by regional supply and demand. Our revenue relating to workforce accommodations for the year ended December 31, 2005 was $48.4 million.

Surface Equipment Rental

We also offer a wide range of surface equipment for every phase of a client’s operations at the wellsite. As of March 31, 2006, we owned and operated a fleet of over 300 forklifts and loaders, including standard forklifts, extended-reach forklifts and articulating loaders. In addition, we have a number of manlifts, backhoes, generators, air compressors, light plants and trash containers as well as air, diesel and gasoline powered trash pumps, all of which can be coordinated and dispatched according to a customer’s needs.

Our primary competition in surface equipment rental includes various small service providers as well as large equipment rental companies. Contracts for our surface equipment are awarded based on the quality of equipment and service reliability and pricing is determined by regional supply and demand. Our revenue relating to surface equipment rental for the year ended December 31, 2005 was $13.7 million. Our workforce accommodations and surface equipment rental business operates in all of our operating regions.

Communications Services

We also offer our clients StaRComm, a comprehensive technology solution with intercoms, integrated telephone, fax and internet communications delivered via satellite. Communications services are critical to the productivity and reporting at the wellsite. StaRComm provides a means of delivering these communications services in remote locations where land-based communications services are not available. Our revenue relating to communications services for the year ended December 31, 2005 was $1.4 million.

Solids Control

Through our solids control business, we offer performance-based solids control and fluid management services to the wellsite, including the designing and planning of waste control systems and the installation, operation and management of solids control equipment. These services help to reduce waste, maximize fluid recovery and lower costs for our customers. To assist us in providing innovative and effective solids control solutions to our customers, we maintain an inventory of customized solids control equipment. As of March 31, 2006, we owned over 100 various pieces of solids control equipment, including centrifuges, mud conditioners, flow line shakers, drying shakers and peripheral backside equipment. This equipment is delivered and configured at the wellsite and operated by our trained technicians to maximize our customers’ fluids recovery and efficiency and to help reduce the environmental impact of fluids and solids generated during drilling and production

activities at the wellsite. Our solids control business provides packaged and ad-hoc rental services. Packaged services include closed-loop and de-watering systems.

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Closed-Loop Systems. We are a leader in providing closed-loop mud systems which provide our customers with economic and environmental advantages over traditional earthen pit disposal at the wellsite. Drilling rigs have some solids control equipment, typically shakers and mud conditioning equipment. However, this equipment often is not properly maintained and provides only basic solids control capability, which limits drilling efficiency. Closed-loop systems are used to help reduce solids disposal, fluids disposal and the environmental impact at the wellsite while enhancing drilling efficiency. Closed-loop systems are required in environmentally sensitive areas including wellsites in or around coastal waters as well as in close proximity to residential communities. Closed-loop systems include a combination of flowline shakers, drying shakers, mud conditioners (desanders and desilters), centrifuges, pumps, tanks and other equipment in a customized configuration for a specific drilling rig.

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Solids Control Coordination. We also provide coordination and management services, as needed, for all of our solids control system installations. For a particular project, we will engineer custom comprehensive solids control solutions which includes equipment rental, equipment monitoring services and waste handling coordination services in a turnkey solution package.

Our solids control business also rents individual pieces of equipment on an ad-hoc basis. As part of our solids control services, we also provide remediation services to our customers including land farm location maintenance, slurry treatment, fluid treatment, de-watering services and pit closures.

Our primary competition in solids control includes nationally focused oilfield service companies. Contracts for our solids control services are generally awarded based on a bid basis and pricing is determined by availability of equipment and ability to meet the customer’s deadlines. Our revenue relating to solids control for the year ended December 31, 2005 was $9.6 million. Our solids control business operates in Texas, Louisiana, New Mexico and Oklahoma.

Construction and Logistics Services

Through our construction and logistics services segment, we offer services that are critical to establish, maintain and decommission the wellsite and position key equipment prior to, during and after drilling operations. This segment includes site construction, rig relocation and heavy equipment hauling. We established this operating segment in March 2006 when we acquired BLR and OHH.

Site Construction

Through our site construction business, we offer equipment and services to build and reclaim infrastructure at wellsites before, during and after drilling operations. We build roads, dig pits, clear land, move earth and provide a number of construction services to oil and natural gas producers. Site construction requires the use of heavy equipment used in road construction. As of March 31, 2006, we owned and operated over 150 pieces of heavy construction equipment, including bulldozers, road graders, dump trucks and cranes, and over 30,000 mats.

We also provide oilfield construction services for inland marine environments in bays and marshes of the Gulf Coast. Our inland marine construction services utilize tug boats, barges, crew boats, marsh hoes and cranes. Construction of production facilities in the coastal areas requires driving up to 100 to 200 pilings deep into the seafloor in order to provide an adequate foundation from which to construct and assemble production equipment above sea level.

Mat Rental

In areas near coastal wetlands or areas that receive significant rainfall, mats are used to stabilize locations and roads. Mats are made of hardwood and/or composite materials and are layered on roads and the wellsite to

stabilize the location and prepare it for heavy equipment including the drilling rig. In some cases, pilings must be driven into the soil using hammer systems on cranes to provide strongback foundations to support the drilling rig. Mats are then layered across the location to provide a stable and dry area for wellsite operations. In areas with more stable foundations and soil conditions, mats are not required and crushed rock is brought in and graded to level and stabilize the wellsite pad.

Production Equipment Assembly and Installation

After the well is drilled, we also prepare the wellsite for production operations. Construction of wellsite production facilities includes the assembly and installation of tank batteries, containment barriers, condensers, heaters, compressors, flow lines and other specified production equipment.

Pipeline Installation

For natural gas wellsites, pipelines must be constructed to connect the new well to the nearest natural gas gathering system. We construct pipelines from the production site to the nearest gathering system or marketing line where the product may go to market.

Production Facility Disassembly and Site Remediation

After a well is plugged and abandoned, we provide decommissioning services including the disassembly of production equipment, removal of stabilization material or pad rock and re-seeding of native grasses to return the location to its original condition. This final process ends the life-cycle of the wellsite.

Through our acquisition of BLR in March 2006, we established our wellsite construction services business. Our primary competition in wellsite construction services includes various small service providers as well as large, integrated oilfield service companies. Contracts for our wellsite construction services are awarded based on availability of equipment and the ability to meet the customer’s deadlines and pricing is determined by regional supply and demand. Our construction business operates in Louisiana and Texas, and our services are offered for wellsites in both land and inland marine environments.

Rig Relocation and Heavy Equipment Hauling

We move drilling rigs and related equipment to and from the wellsite. We own and operate a fleet of cranes, tractors, trailers and loaders used for these relocation services. Our capabilities allow us to move some of the largest rigs in the United States. Our rig relocation and heavy equipment hauling operations are located in regions where a high concentration of the land drilling rigs in the United States are located. We maintain a focus on providing reliable, efficient and safe transportation services and believe our skilled personnel position us as one of the leading rig moving companies in the industry.

Through our acquisition of OHH in March 2006, we established our rig relocation and heavy equipment hauling business. Our primary competition in rig relocation and heavy equipment hauling includes regionally based oilfield service companies. In addition, most drilling contractors also maintain some dedicated rig hauling capacity. Contracts for our rig and heavy equipment hauling services are awarded based on availability of equipment and the ability to meet the customer’s deadlines and pricing is determined by regional supply and demand.

Properties

Our principal executive offices are located at 410 Roberts Street, Houston, Texas 77003. As of March 31, 2006, we conducted our business from 24 field offices, two of which we own and 22 of which we lease. Each field office typically includes a yard, administrative office and maintenance facility. Our 24 field offices are

located in Alvord, Bowie, Alice, Victoria, Houston, Liberty, Beaumont, Carthage, Marquez, Decatur and Midland (Texas), Minden, Duson, Rayne, Breaux Bridge, Butte La Rose and Homer (Louisiana), Elk City, Canadian and Chickasha (Oklahoma), Rifle (Colorado), Riverton (Wyoming) and Dickinson and Williston (North Dakota). We believe that our leased and owned properties are adequate for our current needs.

Sales and Marketing

Our sales and marketing activities are generally performed through our local operations in each geographic 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 corporate sales team located in our Houston headquarters that supplements our field sales efforts and focuses on large accounts and selling our complementary services.

Customers

We serve numerous major and independent oil and natural gas companies, operators and drilling contractors that are active in our core areas of operations. For the twelve months ended December 31, 2005, we provided services to several hundred customers, with our top 10 customers comprising 37.8% of our revenue. For the three months ended March 31, 2006, our top ten customers provided 32.2% of our total revenue. The majority of our business is with major and independent oil and natural gas companies. As of May 31, 2006, our top customers included Devon Energy Corp., Grey Wolf Drilling Company, Denbury Onshore, Questar Exploration, Samson Resources, EOG Resources, Hilcorp, Encana Oil & Gas, Apache Corporation and Ultra Resources. Our area managers and supervisors maintain relationships with customers whose operating decisions are generally made in the field.

Operating Risks and Insurance

Our operations are subject to hazards inherent in the oil and natural gas industry, such as accidents, blowouts, explosions, craterings, fires and oil spills that can cause:

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personal injury or loss of life;

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damage or destruction of property, equipment, the environment and marine life; and

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suspension of operations.

In addition, claims for loss of oil and natural gas production and damage to formations can occur in the well services business. If a serious accident were to occur at a location where our equipment and services were being used, it could result in our being named as a defendant in lawsuits asserting substantial claims.

Because our business involves the transportation of heavy equipment and materials, we may also experience traffic accidents which could result in spills, property damage and personal injury.

Despite our efforts to maintain high safety standards, we from time to time have suffered accidents and anticipate that we will 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 our 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 employer’s liability, pollution, cargo, umbrella, comprehensive commercial general liability, workers’ compensation and limited physical damage insurance. There can be no assurance, however, that any insurance obtained by us will be adequate to cover any losses or liabilities, or that this insurance will 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

We operate in competitive markets. To compete successfully in those markets, a company must provide high-quality, reliable services that meet the specific needs of oil and natural gas exploration companies and drilling contractors at competitive prices. In our core market areas, we compete against different companies in each of our business segments. Our competition includes many private “mom & pop” shops, as well as larger public companies including Superior Energy Services, Inc. (with respect to workforce accommodations), Newpark Resources, Inc. (with respect to site construction), National Oilwell Varco Inc. (with respect to solids control) and Complete Production Services, Inc. (with respect to rig and heavy equipment hauling).

We believe that the principal competitive factors in the market areas that we serve are quality of service, reputation for safety and technical expertise, availability and price. While we must be price competitive, we believe that our customers select our services based primarily on our professional, reliable and comprehensive provision of services in each of our service areas and the experience of our service professionals who deliver those services.

Safety Program

In the wellsite support services industry, an important competitive factor in establishing and maintaining long-term customer relationships is having an experienced and skilled work force. In recent years, many of our larger customers have placed an emphasis not only on pricing, but also on safety records and quality management systems of contractors. We believe that these factors will gain further importance in the future. We have directed substantial resources toward employee safety and quality management training programs as well as our employee review process. Many of our competitors, particularly small contractors, have not undertaken similar training programs for their employees or managers.

Environmental Matters

Extensive federal, state and local laws regulating the discharge of materials into the environment or otherwise relating to health and safety or the protection of the environment affect our business. Numerous governmental departments issue regulations to implement and enforce these laws, which are often difficult and costly to comply with. Failure to comply with these laws and regulations often carries substantial administrative, civil and even criminal penalties. Some laws and regulations relating to protection of the environment may, in some circumstances, impose strict liability for environmental contamination, rendering a person liable for environmental damages and cleanup costs without regard to negligence or fault on the part of that person. Compliance with these regulatory requirements increases our cost of doing business and consequently affects our profitability. We believe that we are in substantial compliance with current applicable environmental laws and regulations and that continued compliance with existing requirements will not have a material adverse impact on our operations. However, environmental laws and regulations have been subject to frequent changes over the years, and the imposition of more stringent requirements could have a materially adverse effect upon our capital expenditures, earnings or our competitive position.

We generate non-hazardous and hazardous solid wastes that are subject to the requirements of the federal Solid Waste Disposal Act, as amended by the Resource Conservation and Recovery Act of 1976, referred to as “RCRA” in this prospectus, and comparable state statutes. Our operations generate minimal quantities of

hazardous wastes because RCRA currently excludes drilling fluids, produced waters and other wastes associated with the exploration, development or production of oil and natural gas from regulation as hazardous waste. Disposal of wastes from oil and natural gas exploration, development and production that are non-hazardous wastes is usually regulated under state law. Other wastes handled at exploration and production sites or used in the course of providing well services may not fall within this exclusion from RCRA and may be regulated as hazardous waste. In addition, stricter standards for waste handling and disposal may be imposed on the oil and natural gas industry in the future. For instance, from time to time legislation has been proposed in Congress that would revoke or alter the current exclusion of exploration, development and production wastes from the RCRA definition of “hazardous wastes,” potentially subjecting these wastes to more stringent handling, disposal and cleanup requirements. If this legislation were enacted it could have a significant adverse impact on our operating costs, as well as the oil and natural gas industry and well servicing industry in general.

The Comprehensive Environmental Response, Compensation and Liability Act, referred to as “CERCLA” in this prospectus, and comparable state laws impose liability, without regard to fault on some classes of persons that are considered to be responsible for the release of a hazardous substance into the environment. These persons include the current or former owner or operator of the disposal site or sites where the release occurred and companies that disposed or arranged for the disposal of hazardous substances. Under CERCLA, these persons may be subject to joint and several liability for the costs of investigating and cleaning up hazardous substances that have been released into the environment, for damages to natural resources and for the costs of some health studies. In addition, companies that incur liability frequently confront additional claims because it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment from a polluted site.

Our operations are also subject to the federal Clean Water Act and analogous state laws. Under the Clean Water Act, the Environmental Protection Agency has adopted regulations concerning discharges of storm water runoff. This program requires covered facilities to obtain individual permits, participate in a group permit or seek coverage under an Environmental Protection Agency general permit. Some of our properties may require permits for discharges of storm water runoff and as part of our overall evaluation of our current operations. We are applying for storm water discharge permit coverage and updating storm water discharge management practices at some of our facilities. We believe that, where necessary, we will be able to obtain, or be included under, these permits and make minor modifications to existing facilities and operations that would not have a material effect on us.

The federal Clean Water Act and the federal Oil Pollution Act of 1990, which contains numerous requirements relating to the prevention of and response to oil spills into waters of the United States, require some owners or operators of facilities that store or otherwise handle oil to prepare and implement spill prevention, control, countermeasure and response plans relating to the possible discharge of oil into surface waters. We believe we are in substantial compliance with these regulations.

We maintain insurance against some risks associated with underground contamination that may occur as a result of wellsite service activities. However, this insurance is limited to activities at the wellsite and there can be no assurance that this insurance will continue to be available or that this insurance will be available at premium levels that justify its purchase. The occurrence of a significant event not fully insured or indemnified against could have a materially adverse effect on our financial condition and operations.

Government Regulation

We operate under the jurisdiction of a number of regulatory bodies that regulate worker safety standards, the hauling of hazardous materials, the transportation of explosives, the protection of the environment and driving standards of operation. Regulations concerning equipment certifications create an ongoing need for regular maintenance which is incorporated into our daily operating procedures.

Among the services that we provide, we operate as a motor carrier and therefore we are subject to regulation by the U.S. Department of Transportation (the “DOT”) 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 related 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 the possible changes include increasingly stringent environmental regulations; changes in hours of service regulations which govern the amount of time a driver may drive or work in any specific time period, onboard black box recorder devices or limits on vehicle weight and size.

Interstate motor carrier operations are also subject to safety requirements prescribed by the DOT. To a large extent, interstate 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. DOT regulations also mandate regular 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.

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 citizens. 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 March 31, 2006, we employed approximately 800 people, 50 of which were administrative employees located in our Houston headquarters, and 750 of which were field workers and others employed in regional operations. Approximately 71% of our employees are employed on an hourly basis. Our future success will depend in part on our ability to attract, retain and motivate qualified personnel. We are not a party to any collective bargaining agreements, and we consider our relations with our employees to be satisfactory.

Legal Proceedings

From time to time, we are a party to litigation or other legal proceedings that we consider to be a part of the ordinary course of our business. We are not currently involved in any legal proceedings that could reasonably be expected to have a material adverse affect on our financial condition or results of operations.

MANAGEMENT

Directors and Executive Officers

Our directors and executive officers and their ages and positions, as of May 31, 2006, are as follows:


Name	Age	Position
Craig M. Johnson	43	President, Chief Executive Officer and Chairman of the Board
David S. Schorlemer	39	Vice President, Chief Financial Officer and Director
Hill Dishman	44	Vice President and Chief Operating Officer
N. John Lancaster, Jr.	38	Director
Pierre F. Lapeyre, Jr.	43	Director

Set forth below is a description of the backgrounds of our directors and executive officers.

Craig M. Johnson. Mr. Johnson has over 20 years of experience in the oilfield service industry. Mr. Johnson has served as our Chief Executive Officer, President and Chairman of our board of directors since our formation in June 2006. Prior to the formation of Stallion Oilfield Services, Inc., he established Stallion Oilfield Holdings, Ltd., our predecessor, and served as the Chief Executive Officer, President and Chairman of its general partner, Stallion Oilfield Holdings GP, LLC, since December 2002. From September 2002 until December 2002, Mr. Johnson surveyed various investment and employment opportunities. Prior to September 2002, Mr. Johnson managed the rental and fishing tools division at Key Energy Services, Inc, a publicly traded well servicing and workover company. Mr. Johnson joined Key in July 2002 in connection with Key’s purchase of Q Services, Inc., a private production services company. From 1997 through July 2002, Mr. Johnson served as President and Chief Operating Officer of Q Services, Inc. Mr. Johnson earned his Bachelor of Arts degree from the University of Mississippi. Mr. Johnson served on the board of Remote Knowledge, Inc. between September 2004 and August 2005.

David S. Schorlemer. Mr. Schorlemer serves as our Chief Financial Officer, Vice President and director. Prior to the formation of Stallion Oilfield Services, Inc., he served in the same positions with Stallion Oilfield Holdings GP, LLC, the general partner of our predecessor, since September 2004. From July 2002 until September 2004, Mr. Schorlemer served as the Vice President of Marketing and Strategic Planning at Key Energy Services, Inc. From 1997 until July 2002, Mr. Schorlemer served as the Chief Financial Officer of Q Services, Inc. Prior to that, Mr. Schorlemer was with Andersen Consulting (now Accenture) where he worked on a variety of projects for numerous oil and natural gas companies, including Shell Oil Company, Conoco, PEMEX and Tenneco. Mr. Schorlemer earned his BBA at the University of Texas at Austin and his MBA at Texas A&M University.

Hill Dishman. Mr. Dishman serves as our Chief Operating Officer and Vice President. Prior to the formation of Stallion Oilfield Services, Inc., he served in the same positions with Stallion Oilfield Holdings GP, LLC, the general partner of our predecessor, since December 2002. From 1997 until December 2002, Mr. Dishman served as Vice President of Texas Operations for SOLOCO Texas, LP, an operating unit of Newpark Resources, Inc., an NYSE-listed oilfield service company. Mr. Dishman earned his Bachelor of Arts degree from Lamar University.

N. John Lancaster, Jr. Mr. Lancaster has served as one of our directors since our formation in June 2006. Prior to the formation of Stallion, he served as a director of Stallion Oilfield Holdings GP, LLC, the general partner of our predecessor, since January 2005. Mr. Lancaster is a Managing Director of Riverstone Holdings, LLC (“Riverstone”), an affiliate of Carlyle/Riverstone. Prior to joining Riverstone in 2000, Mr. Lancaster was a Director with The Beacon Group, LLC, a privately held firm specializing in principal investing and strategic advisory services in the energy and other industries. Prior to Beacon, Mr. Lancaster was a Vice President with Credit Suisse First Boston’s Natural Resources Group. Mr. Lancaster received his BBA from the University of Texas at Austin and his MBA from Harvard Business School. Mr. Lancaster serves on the boards of directors (or equivalent governing bodies) of Frontier Drilling ASA, Magellan Midstream Partners, L.P., International

Logging, Inc., Petroplus International B.V. and 4Gas International. Mr. Lancaster was nominated pursuant to the Nominating Agreement.

Pierre F. Lapeyre, Jr. Mr. Lapeyre has served as one of our directors since our formation in June 2006. Prior to the formation of Stallion, he served as a director of Stallion Oilfield Holdings GP, LLC, the general partner of our predecessor, since January 2005. Mr. Lapeyre is a founder and Senior Managing Director of Riverstone. Prior to founding Riverstone in 2000, Mr. Lapeyre was a Managing Director of Goldman, Sachs & Co. in its Global Energy & Power Group. While at Goldman, Sachs, Mr. Lapeyre’s responsibilities included client coverage and leading the execution of a wide variety of M&A, IPO, strategic advisory and capital markets financings for clients across all sectors of the industry, and he was involved extensively in the origination and execution of energy private equity investments on behalf of the firm. Mr. Lapeyre received his BS in finance/economics from the University of Kentucky and his MBA from the University of North Carolina at Chapel Hill. Mr. Lapeyre serves on the boards of directors (or equivalent governing bodies) of SemGroup, L.P., Legend Natural Gas, LP, CDM Resource Management, Ltd., Topaz Power Group, LLC, Cobalt International Energy, L.P., Phoenix Exploration Company LP, Frontier Drilling ASA, 4Gas International, Niska GS Holdings I, L.P. and Niska GS Holdings II, L.P. Mr. Lapeyre was nominated pursuant to the Nominating Agreement.

Board of Directors

Our board of directors currently consists of four members. In compliance with the requirements of the Sarbanes-Oxley Act of 2002, the rules of the Nasdaq Stock Market and SEC rules and regulations, a majority of the directors on our corporate governance and nominating and compensation committees will be independent within 90 days of quotation on the Nasdaq National Market and, within one year, these committees will be fully independent and a majority of our board will be independent. A majority of the directors on our audit committee will be independent within 90 days of the effectiveness of the registration statement and, within one year, the committee will be fully independent.

Committees

Audit Committee

We will have an audit committee comprised of three independent directors, as defined under and required by the federal securities laws and the rules of the Nasdaq Stock Market. One member of the audit committee will be designated as the audit committee financial expert, as defined by Item 401(h) of Regulation S-K of the Securities Exchange Act of 1934, as amended. The audit committee will be responsible for reviewing our external financial reporting, engaging our independent auditors and reviewing procedures for internal auditing and the adequacy of our internal accounting controls.

Our board of directors will adopt a written charter for the audit committee which will be available on our website.

Corporate Governance and Nominating Committee

We will establish a corporate governance and nominating committee consisting of independent directors after the closing of this offering. The principal duties of the corporate governance and nominating 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 will adopt a written charter for the corporate governance and nominating committee which will be available on our website.

We are a party to the Nominating Agreement. Please read “Certain Relationships and Related Party Transactions—Nominating Agreement” for additional information about the Nominating Agreement.

Compensation Committee

Following the completion of this offering, we will establish a compensation committee comprised of independent directors. The compensation committee will administer our stock plans and incentive compensation plans, including our 2006 Stock Incentive Plan, and in this capacity will make all option grants or awards to our non-independent directors and employees under such plans. In addition, the compensation committee will be responsible for making recommendations to the board of directors with respect to the compensation of our chief executive officer and our other executive officers and for establishing compensation and employee benefit policies.

Our board of directors will adopt a written charter for the compensation committee which will be available on our website.

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.

Compensation of Executive Officers

The following table summarizes all compensation earned by our Chief Executive Officer and our other most highly compensated executive officers with total annual salary and bonuses exceeding $100,000 for services rendered in all capacities to us during the year ended December 31, 2005.

Summary Compensation Table


		Annual Compensation(1)(2)
	Year	Salary		Bonus		Other Annual Compensation(3)		All Other Compensation(4)
Craig M. Johnson(5)	2005	$	243,750	$	125,000			$	3,630
President, Chief Executive Officer and Chairman	2004	$	225,000	$	—			$	—
	2003	$	99,387	$	—			$	—

David S. Schorlemer(5)(6)	2005	$	220,673	$	112,500			$	2,670
Vice President and Chief Financial Officer	2004	$	67,500	$	—			$	—
	2003	$	—	$	—			$	—

Hill Dishman(5)(7)	2005	$	176,539	$	90,000	$	1,200	$	1,280
Vice President and Chief Operating Officer	2004	$	22,500	$	—	$	2,400	$	—
	2003	$	—	$	—			$	—

(1)	Under the terms of their employment agreements, Messrs. Johnson, Schorlemer and Dishman are entitled to the compensation described under “—Employment Agreements” below.

(2)	No stock awards have been made to employees as of May 31, 2006.

(3)	Represents vehicle allowances.

(4)	Represents premium payments for term life insurance.

(5)	In connection with Messrs. Johnson’s and Schorlemer’s employment agreements, each of Mr. Johnson and Mr. Schorlemer indirectly received 600,000 Class E Units representing limited partnership interests of our

predecessor. In addition, Mr. Johnson indirectly received 7,653,061 Class F Units representing limited partnership interests of our predecessor. In connection with Mr. Dishman’s employment agreement, Mr. Dishman indirectly received 300,000 Class E Units representing limited partnership interests of our predecessor. The Class E Units were granted directly to Stallion Value, L.P, in which Messrs. Johnson, Schorlemer and Dishman and certain of our other employees own interests. Upon the closing of the Restructuring, the Class E Units and the Class F Units will be converted into shares of our common stock. Upon this conversion, Messrs. Johnson, Schorlemer and Hill will receive , and shares of our common stock, respectively. In connection with the closing of this offering, these shares will no longer be subject to the forfeiture restrictions that previously encumbered the Class E Units and the Class F Units.

(6)	Mr. Schorlemer became our Chief Financial Officer on September 13, 2004.

(7)	Mr. Dishman became our Chief Operating Officer on November 15, 2004.

Compensation of Directors

Directors who are our employees do not receive a retainer or fees for service on the board or any committees. We pay non-employee members of the board for their service as directors. Directors who are not employees currently receive a fee of $ for each board meeting attended in person, and a fee of $ for attendance at a meeting held telephonically. In addition, each non-employee director has received, upon election to the board, a stock option to purchase shares of our common stock at the market price on the date of grant that vests ratably over three years. Directors are reimbursed for reasonable out-of-pocket expenses incurred in attending meetings of the board or committees and for other reasonable expenses related to the performance of their duties as directors.

2006 Stock Incentive Plan

We currently anticipate that, prior to the consummation of this offering, the Company’s board of directors and stockholders will adopt the 2006 Stock Incentive Plan (the “Plan”). The principal purpose of the Plan will be to promote our success, enhance our value, and attract, retain and motivate selected employees, consultants and directors through the granting of stock-based compensation awards. The Plan will provide for a variety of such incentive awards, including nonstatutory stock options, incentive stock options (within the meaning of Section 422 of the Internal Revenue Code, or the “Code”), stock appreciation rights, restricted stock awards, restricted stock unit awards, performance-based awards, and other stock-based awards. We currently anticipate that shares of the Company’s common stock will be reserved for issuance under the Plan.

Administration

Prior to the consummation of this offering, the Plan will be administered by the committee appointed by the Company’s board of directors. Upon and following the consummation of this offering, the Plan will be administered by a compensation committee of the board of directors. The board of directors, or the compensation committee if so empowered, has the authority to interpret the Plan and to adopt such rules for the administration, interpretation and application of the Plan according to its terms. However, the board of directors may not delegate, to the compensation committee or otherwise, the power to grant awards to independent directors.

Grant of Awards

Certain employees, consultants and directors will be eligible to be granted awards under the Plan. The Company’s board of directors, or the compensation committee if so empowered, will determine:

•

which employees, consultants and directors are to be granted awards;

•

the type of award that is granted (only employees can be granted incentive stock options under Code Section 422);

•

the number of shares subject to the awards; and

•

terms and conditions of each award, as consistent with the Plan.

Under the Plan, performance-based awards are intended to comply with the requirements of Code Section 162(m), in order to allow those awards, when payable, to be fully tax deductible by the Company.

Expiration of Stock Options

The term of an option will be set by the Company’s board of directors, or the compensation committee if so empowered, subject to the following conditions: (1) no option term will be longer than ten years from the date of grant; and (2) the option term for an incentive stock option granted to an employee owning more than 10% of the total combined voting power of all classes of the Company’s capital stock will not exceed five years from the date of grant. Upon termination of an outstanding option holder’s services, the holder may exercise his or her options within the time period specified in the option grant, to the extent that the options were vested as of the termination date.

Adjustments of Awards

If the Company shall effect any stock dividend, stock split, subdivision, consolidation, recapitalization, or other capital readjustment, without receiving compensation therefor, then the number of outstanding shares under the Plan and the option price or fair market value of awards shall be proportionately adjusted.

The board of directors, or the compensation committee if so empowered, shall take such action as it deems appropriate in order that the value of each outstanding award shall not be adversely affected by any of these events.

Amendment or Termination

The board of directors may generally amend or terminate the Plan at any time; however, the board must generally obtain approval of the shareholders: (i) to increase the number of shares of common stock that may be issued under the Plan; (ii) to amend the group of employees eligible for awards under the Plan; (iii) to extend the term of the Plan; (iv) to increase the per person limits on awards intended to qualify for the performance-based exception; or (v) to the extent otherwise required by applicable law, rule or regulation.

Employment Agreements

We have entered into a separate employment agreement with each of Messrs. Johnson, Schorlemer and Dishman (together the “Employees,” and each an “Employee”), the initial term of which terminates on January 31, 2008 (together, the “Employment Agreements,” and each an “Employment Agreement”). Unless either party to an Employment Agreement gives notice of its intention not to renew prior to November 2, 2007, the term of such agreement will be automatically extended for successive one-year periods until notice is given by either party prior to November 2 of any subsequent year that the term of employment will expire on January 31 of the following year. Messrs. Johnson’s, Schorlemer’s and Dishman’s annual base salaries are $250,000, $225,000 and $180,000, respectively, subject to increase at the discretion of our board of directors, and they will be eligible to receive an annual bonus, if any, as determined by our board of directors, taking into account our profitability and each Employee’s performance during that calendar year. Each Employee is also entitled to participate in all employee benefit plans and programs that we may provide from time to time.

In connection with Messrs. Johnson’s and Schorlemer’s employment agreements, each of Mr. Johnson and Mr. Schorlemer indirectly received 600,000 Class E Units representing limited partnership interests of our predecessor. In addition, Mr. Johnson indirectly received 7,653,061 Class F Units representing limited partnership interests of our predecessor.

In connection with Mr. Dishman’s employment agreement, Mr. Dishman indirectly received 300,000 Class E Units representing limited partnership interests of our predecessor.

The Class E Units were granted directly to Stallion Value, L.P, in which Messrs. Johnson, Schorlemer and Dishman and certain of our other employees own interests.

Upon the closing of the Restructuring, the Class E Units and the Class F Units will be converted into shares of our common stock. Upon this conversion, Messrs. Johnson, Schorlemer and Hill will receive , and shares of our common stock, respectively. In connection with the closing of this offering, these shares will no longer be subject to the forfeiture restrictions that previously encumbered the Class E Units and the Class F Units.

Under the Employment Agreements, if an Employee’s employment is terminated (and not during any 12 month period following any Change of Control (as such term is defined in the Employee’s Employment Agreement)) (1) by the Employee for Good Reason (as defined in the Employee’s Employment Agreement), (2) by us for any reason other than for Cause (as such term is defined in the Employee’s Employment Agreement) or (3) because we do not extend the Employee’s term (and with respect to a non-extension of the Employee’s term, the Employee complies with the provisions relating to non-competition, non-disclosure of proprietary information, and inventions), the Employee will be entitled to receive the following benefits:

(A) an amount equal to the Employee’s annual base salary accrued through the date of termination and not previously paid plus any reimbursable expenses paid by and owed to the Employee plus any accrued vacation pay owed to the Employee,

(B) an amount equal to the Employee’s annual base salary that the Employee would have received if he had continued his employment under his Employment Agreement for a period equal to the greater of 24 months following the date of termination and the remainder of the Employee’s term under his Employment Agreement,

(C) an amount equal to any earned portion of the Employee’s annual bonus for the completed year preceding the date of termination that remains unpaid, and

(D) upon termination, any accrued vested benefits will be paid, and any compensation awards not vested or exercisable as of the date of termination will be forfeited.

Under the Employment Agreements, if during the one-year period commencing on the effective date of any Change of Control, an Employee’s employment is terminated by the Employee for Good Reason or by us for any reason other than for Cause, the Employee will be entitled to receive the following benefits:

(A) an amount equal to three times his annual base salary,

(B) an amount equal to any earned portion of the Employee’s annual bonus for the completed year preceding the date of termination that remains unpaid,

(C) continued coverage for the Employee and his dependents under our health benefit plans until the earlier date of the Employee’s coverage under another employee benefit plan or 18 months after the date of termination, and

(D) upon termination, any accrued vested benefits will be paid, and any compensation awards not vested or exercisable as of the date of termination will be forfeited.

Under the terms of the Employment Agreements, subject to certain exceptions, during their employment and for 24 months following the termination of their employment, the Employees may not compete in the markets in which we and our affiliates engage in business or planned to engage in business as of the date of termination of each Employee’s respective employment.

Indemnification Agreements

We have entered into indemnification agreements with all of our directors and some of our officers under which we indemnify such persons against 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. These persons are indemnified to the fullest extent now or hereafter permitted by the General Corporation Law of the State of Delaware. The indemnification agreements also provide for the advancement of expenses to these directors and officers in connection with any suit or proceeding.

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 this offering by the selling stockholders, other than underwriting discounts, commissions and transfer taxes with respect to shares of our common stock sold by the selling stockholders. We have agreed to indemnify the selling stockholders against liabilities under the Securities Act, or contribute to payments that the selling stockholders may be required to make in that respect.

Registration Rights Agreement

Stallion and Carlyle/Riverstone are parties to a registration rights agreement (the “Registration Rights Agreement”).

Demand Registration Rights

Under the Registration Rights Agreement, at any time after 180 days following this offering, Carlyle/Riverstone has the right, subject to certain limitations, to demand on six occasions 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 $20.0 million. After such time as we become eligible to use Form S-3 (or comparable form) for the registration under the Securities Act of any securities, Carlyle/Riverstone may request that securities be registered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act, provided that any such registration will be treated as two demand registrations.

Piggyback Registration Rights

If we propose to file a registration statement under the Securities Act relating to an offering of our common stock, upon the written request of Carlyle/Riverstone, we will 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 Registration Rights 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, up to a total of six registrations, including all registration, qualification and filing fees, printing expenses, reasonable fees of one counsel to Carlyle/Riverstone, 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.

Nominating Agreement

We are party to a nominating agreement (the “Nominating Agreement”) with C/R Stallion Investment Partnership, L.P. (“Investment Partnership”). Pursuant to the Nominating Agreement, as long as Investment Partnership beneficially owns at least 30%, 20% or 10% of our issued and outstanding shares of common stock, we have agreed to take all corporate action within our power required to cause the board of directors at all times to include at least three, two or one member(s), respectively, designated by Investment Partnership. In addition, as long as Investment Partnership beneficially owns at least a majority of the aggregate amount of shares of common stock it held immediately following the Restructuring, we have agreed to take all corporate action within our power required to cause the board of directors at all times to include at least one member designated

by Investment Partnership. In the event that such designees are not elected to our board of directors, Investment Partnership will have the right to appoint observers to our board of directors.

The Restructuring

Transactions with Our Significant Stockholder

The partnership agreement governing our predecessor required our predecessor to pay Carlyle/Riverstone an annual fee of $250,000 for the provision of support services. Our obligation to pay this fee terminates upon the closing of our initial public offering.

Transactions with Officers and Directors

Two of our directors, Mr. John Lancaster and Mr. Pierre Lapeyre, are affiliated with Riverstone, an affiliate of Carlyle/Riverstone.

Mr. Craig Johnson, our President, Chief Executive Officer and Chairman of the Board, was party to a promissory note with us pursuant to which we borrowed $7.3 million from Mr. Johnson. We repaid Mr. Johnson in full on January 31, 2005.

We lease an industrial facility in Alice, Texas from Q2 Rentals, L.L.C. for approximately $90,000 per year. Pursuant to an informal arrangement, we lease a houseboat and certain other recreational boats in coastal Louisiana on a month-to-month basis from Q2 Rentals in exchange for paying the operating expenses of the facilities which are approximately $140,000 per year. Q2 Rentals is operated by Mr. David M. Johnson, Mr. Craig Johnson’s father, and owned equally by Mr. Craig Johnson, Mr. Clayton D. Johnson, Mr. Craig Johnson’s brother, and Mr. David M. Johnson.

In addition, we lease a King-Air airplane from Permian Mud Service, Inc. and have entered into an operating agreement to operate the aircraft with ChampAir, L.L.C. We share in the operating expenses and pay direct expenses of approximately $600,000 annually. ChampAir is owned and operated by Permian Mud Service, Inc., of which Mr. David Johnson and our Chief Executive Officer, President and Chairman of the Board are minority shareholders. Our executive officers reimburse us for operating expenses associated with the personal use of the aircraft. The term of our lease for this plane will expire on December 31, 2006, but will continue on a month-to-month basis thereafter.

We utilize a Pilatus single-engine airplane from Rivers Aviation, L.L.C. in connection with the performance of Mr. Fred Lausen, Jr.’s duties as division manager of our solids control business. We share in the operating expenses and pay Rivers Aviation approximately $20,000 per month for the use of this aircraft. Rivers Aviation is owned by Mr. Lausen. We have an arrangement to use this plane on a month-to-month basis which is cancellable by either party with 30 days notice.

It is customary for us to lease real property from the former owners of businesses that we acquire. It is typical for many of these former owners to be employed by us. Thus, we and certain of our employees may be parties to leases relating to real property.

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.

PRINCIPAL AND SELLING STOCKHOLDERS

The following table sets forth information with respect to the beneficial ownership of our common stock as of March 31, 2006, assuming the Restructuring had taken place prior to such date, by:

•

each person who is known by us to own beneficially 5% or more of our outstanding common stock;

•

our named executive officers;

•

our directors; and

•

all of our executive officers and directors as a group.

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 410 Roberts Street, Houston, Texas 77003.


	Shares Beneficially Owned Prior to this Offering		Number of Shares Offered	Shares Beneficially Owned After this Offering
Name of Beneficial Owner	Number	%	Number of Shares Offered	Number	%

C/R Stallion Investment Partnership, L.P.(1)		%			%

C/R Energy Coinvestment II, L.P.(1)

Cardigan Holdings, Inc.(2)

Craig M. Johnson

Stallion Value, LP

David S. Schorlemer

Hill Dishman

John Lancaster(1)(3)

Pierre Lapeyre(1)(4)

Directors and Executive Officers as a Group (4 persons)(2)(3)(4)

*	Less than 1%.

(1)	The address of this stockholder is c/o The Carlyle Group, 1001 Pennsylvania Avenue, N.W., Suite 200, Washington, D.C. 20004.

(2)	Craig M. Johnson is the natural person who has voting and investment control over the securities owned by Cardigan Holdings, Inc. Mr. Johnson serves as Chief Executive Officer and the sole stockholder of Cardigan Holdings, Inc.

(3)

Mr. Lancaster serves as a Managing Director of Riverstone, an affiliate of Carlyle/Riverstone. As such, Mr. Lancaster may be deemed to have voting and dispositive power over the shares beneficially owned by Carlyle/Riverstone. Mr. Lancaster disclaims beneficial ownership of the shares owned by Carlyle/Riverstone.

(4)

Mr. Lapeyre serves as a Senior Managing Director of Riverstone, an affiliate of Carlyle/Riverstone. As such, Mr. Lapeyre may be deemed to have voting and dispositive power over the shares beneficially owned by Carlyle/Riverstone. Mr. Lapeyre disclaims beneficial ownership of the shares owned by Carlyle/Riverstone.

DESCRIPTION OF CAPITAL STOCK

Upon the completion of this offering, our authorized capital stock will consist of:

•

shares of common stock, $0.01 par value; and

•

shares of preferred stock, $0.01 par value, none of which are currently designated.

Upon the completion of this offering, shares of common stock and no shares of preferred stock will be outstanding.

The following summarizes the material provisions of our capital stock and important provisions of our certificate of incorporation and bylaws. This summary is qualified by our certificate of incorporation and bylaws, copies of which have been filed as exhibits to the registration statement of which this prospectus is a part and by the provisions of applicable law.

Common Stock

Holders of common stock are entitled to one vote per share on all matters to be voted upon by the stockholders. Because holders of common stock do not have cumulative voting rights, the holders of a majority of the shares of common stock can elect all of the members of the board of directors standing for election. The holders of common stock are entitled to receive dividends as may be declared by the board of directors. Upon our liquidation, dissolution or winding up, and subject to any prior rights of outstanding preferred stock, the holders of our common stock will be entitled to share pro rata in the distribution of all of our assets available for distribution to our stockholders after satisfaction of all of our liabilities and the payment of the liquidation preference of any preferred stock that may be outstanding. There are no redemption or sinking fund provisions applicable to the common stock. All outstanding shares of common stock are fully paid and non-assessable. The holders of our common stock will have no preemptive or other subscription rights to purchase our common stock.

Preferred Stock

Subject to the provisions of the certificate of incorporation and limitations prescribed by law, the board of directors will have the authority to issue up to shares of preferred stock in one or more series and to fix the rights, preferences, privileges and restrictions of the preferred stock, including dividend rights, dividend rates, conversion rates, voting rights, terms of redemption, redemption prices, liquidation preferences and the number of shares constituting any series or the designation of the series, which may be superior to those of the common stock, without further vote or action by the stockholders. We have no present plans to issue any shares of preferred stock.

One of the effects of undesignated preferred stock may be to enable the board of directors to render more difficult or to discourage an attempt to obtain control of us by means of a tender offer, proxy contest, merger or otherwise, and, as a result, protect the continuity of our management. The issuance of shares of the preferred stock under the board of directors’ authority described above may adversely affect the rights of the holders of common stock. For example, preferred stock issued by us may rank prior to the common stock as to dividend rights, liquidation preference or both, may have full or limited voting rights and may be convertible into shares of common stock. Accordingly, the issuance of shares of preferred stock may discourage bids for the common stock or may otherwise adversely affect the market price of the common stock.

Provisions of Our Certificate of Incorporation and Bylaws

Written Consent of Stockholders

Our certificate of incorporation and bylaws provide that any action required or permitted to be taken by our stockholders must be taken at a duly called meeting of stockholders and not by written consent.

Amendment of the Bylaws

Under Delaware law, the power to adopt, amend or repeal bylaws is conferred upon the stockholders. A corporation may, however, in its certificate of incorporation also confer upon the board of directors the power to adopt, amend or repeal its bylaws. Our charter and bylaws grant our board the power to adopt, amend and repeal our bylaws on the affirmative vote of a majority of the directors then in office. Our stockholders may adopt, amend or repeal our bylaws but only at any regular or special meeting of stockholders by the holders of not less than of the voting power of all outstanding voting stock.

Special Meetings of Stockholders

Our bylaws preclude the ability of our stockholders to call special meetings of stockholders.

Other Limitations on Stockholder Actions

Advance notice is required for stockholders to nominate directors or to submit proposals for consideration at meetings of stockholders. In addition, the ability of our stockholders to remove directors without cause is precluded.

Limitation of Liability of Officers and Directors

Our certificate of incorporation provides that no director shall be personally liable to us or our stockholders for monetary damages for breach of fiduciary duty as a director, except for liability as follows:

•

for any breach of the director’s duty of loyalty to us or our stockholders;

•

for acts or omissions not in good faith or which involve intentional misconduct or a knowing violation of laws;

•

for unlawful payment of a dividend or unlawful stock purchase or stock redemption; and

•

for any transaction from which the director derived an improper personal benefit.

The effect of these provisions is to eliminate our rights and our stockholders’ rights, through stockholders’ derivative suits on our behalf, to recover monetary damages against a director for a breach of fiduciary duty as a director, including breaches resulting from grossly negligent behavior, except in the situations described above.

Business Combination Under Delaware Law

We are subject to the provisions of Section 203 of the Delaware General Corporation Law. In general, Section 203 prohibits a publicly held Delaware corporation from engaging in a “business combination” with an “interested stockholder” for a period of three years after the date of the transaction in which the person became an interested stockholder, unless the business combination is approved in a prescribed manner.

Section 203 defines a “business combination” as a merger, asset sale or other transaction resulting in a financial benefit to the interested stockholders. Section 203 defines an “interested stockholder” as a person who, together with affiliates and associates, owns, or, in some cases, within three years prior, did own, 15% or more of the corporation’s voting stock. Under Section 203, a business combination between us and an interested stockholder is prohibited unless:

•

our board of directors approved either the business combination or the transaction that resulted in the stockholders becoming an interested stockholder prior to the date the person attained the status;

•

upon consummation of the transaction that resulted in the stockholder becoming an interested stockholder, the interested stockholder owned at least 85% of our voting stock outstanding at the time

the transaction commenced, excluding, for purposes of determining the number of shares outstanding, shares owned by persons who are directors and also officers and issued under employee stock plans, under which employee participants do not have the right to determine confidentially whether shares held under the plan will be tendered in a tender or exchange offer; or

•

the business combination is approved by our board of directors on or subsequent to the date the person became an interested stockholder and authorized at an annual or special meeting of the stockholders by the affirmative vote of the holders of at least 66²/3% of the outstanding voting stock that is not owned by the interested stockholder.

This provision has an anti-takeover effect with respect to 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. With approval of our stockholders, we could amend our certificate of incorporation in the future to elect not to be governed by the anti-takeover law. This election would be effective 12 months after the adoption of the amendment and would not apply to any business combination between us and any person who became an interested stockholder on or before the adoption of the amendment.

Transfer Agent and Registrar

The transfer agent and registrar for the common stock is .

Quotation of Common Stock

We intend to apply to include our shares of common stock for quotation on the Nasdaq National Market under the symbol “SOFS.”

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, or shares if the underwriters exercise in full their option to purchase additional shares. Of these shares, the shares sold in this offering, or shares if the underwriters exercise in full their option to purchase additional shares, will be freely tradable without restriction under the Securities Act, except for any shares purchased by one of our “affiliates” as defined in Rule 144 under the Securities Act. A total of shares 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 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.

Our officers and directors and substantially all of our stockholders have entered into lock-up agreements described in “Underwriting.” Approximately shares, representing approximately %, of our common stock will not be subject to any lock-up arrangements. These shares may be freely tradable upon the consummation of this offering.

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 option 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 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, 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 of the common stock on the Nasdaq National Market during the four calendar weeks immediately proceeding the date on which the notice of the sale on Form 144 is filed with the Securities Exchange Commission.

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.

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 provisions of Rule 144.

CERTAIN UNITED STATES FEDERAL TAX CONSIDERATIONS

FOR NON-UNITED STATES HOLDERS

The following is a general discussion of the principal United States federal income and estate tax consequences of the ownership and disposition of our common stock by a non-U.S. holder. As used in this discussion, the term “non-U.S. holder” means a beneficial owner of our common stock that is not, for U.S. federal income tax purposes:

•

an individual who is a citizen or resident of the United States;

•

a corporation or partnership (including any entity treated as a corporation or partnership for U.S. federal income tax purposes) created or organized in or under the laws of the United States, or of any political subdivision of the United States;

•

an estate whose income is subject to U.S. federal income taxation regardless of its source; or

•

a trust, in general, if a U.S. court is able to exercise primary supervision over the administration of the trust and one or more U.S. persons have authority to control all substantial decisions of the trust, or if it has a valid election in effect under applicable U.S. Treasury Regulations to be treated as a U.S. person.

An individual may be treated as a resident of the United States in any calendar year for U.S. federal income tax purposes, instead of a nonresident, by, among other ways, being present in the United States for at least 31 days in that calendar year and for an aggregate of at least 183 days during a three-year period ending in the current calendar year. For purposes of this calculation, you would count all of the days present in the current year, one-third of the days present in the immediately preceding year and one-sixth of the days present in the second preceding year. Residents are taxed for U.S. federal income tax purposes as if they were U.S. citizens. This discussion does not consider:

•

U.S. state or local or non-U.S. tax consequences;

•

all aspects of U.S. federal income and estate taxes or specific facts and circumstances that may be relevant to a particular non-U.S. holder’s tax position, including the fact that in the case of a non-U.S. holder that is an entity treated as a partnership for U.S. federal income tax purposes, the U.S. tax consequences of holding and disposing of our common stock may be affected by certain determinations made at the partner level;

•

the tax consequences for the stockholders, partners or beneficiaries of a non-U.S. holder;

•

special tax rules that may apply to particular non-U.S. holders, such as financial institutions, insurance companies, tax-exempt organizations, U.S. expatriates, broker-dealers, and traders in securities; or

•

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.

The following discussion is based on provisions of the U.S. Internal Revenue Code of 1986, as amended, existing and proposed Treasury regulations and administrative and judicial interpretations, all as of the date of this prospectus, and all of which are subject to change, retroactively or prospectively. The following summary assumes that a non-U.S. holder holds our common stock as a capital asset. Each non-U.S. holder should consult a tax advisor regarding the U.S. Federal, state, local and non-U.S. income and other tax consequences of acquiring, holding and disposing of shares of our common stock.

Distributions on Common Stock

In the event that we make cash distributions on our common stock, these distributions 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. Dividends paid to non-U.S. holders

of our common stock that are not effectively connected with the non-U.S. holder’s conduct of a U.S. trade or business will be subject to U.S. withholding tax at a 30% rate, or if a tax treaty applies, a lower rate specified by the treaty. Non-U.S. holders should consult their tax advisors regarding their entitlement to benefits under a relevant income tax treaty.

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, are attributable to a permanent establishment in the United States, are taxed on a net income basis at the regular graduated rates and in the manner applicable to U.S. persons. In that case, we will not have to withhold U.S. federal withholding tax if the non-U.S. holder complies with applicable certification and disclosure requirements. In addition, a “branch profits tax” may be imposed at a 30% rate, or a lower rate under an applicable income tax treaty, on dividends received by a foreign corporation that are effectively connected with the conduct of a trade or business in the United States.

A non-U.S. holder who claims the benefit of an applicable income tax treaty generally will be required to satisfy applicable certification and other requirements. However,

•

in the case of common stock held by a foreign partnership, the certification requirement will generally be applied to the partners of the partnership and the partnership will be required to provide certain information;

•

in the case of common stock held by a foreign trust, the certification requirement will generally be applied to the trust or the beneficial owners of the trust depending on whether the trust is a “foreign complex trust,” “foreign simple trust” or “foreign grantor trust” as defined in the U.S. Treasury regulations; and

•

look-through rules will apply for tiered partnerships, foreign simple trusts and foreign grantor trusts.

A non-U.S. holder that is a foreign partnership or a foreign trust is urged to consult its own tax advisor regarding its status under these U.S. Treasury regulations and the certification requirements applicable to it.

A non-U.S. holder that is eligible for a reduced rate of U.S. federal withholding tax under an income tax treaty may obtain a refund or credit of any excess amounts withheld by filing an appropriate claim for a refund with the U.S. Internal Revenue Service.

Gain on Disposition of Common Stock

A non-U.S. holder generally will not be subject to U.S. federal income tax on gain recognized on a disposition of our common stock unless:

•

the gain is effectively connected with the non-U.S. holder’s conduct of a trade or business in the United States and, if an income tax treaty applies, is attributable to a permanent establishment maintained by the non-U.S. holder in the United States; in these cases, the gain will be taxed on a net income basis at the regular graduated rates and in the manner applicable to U.S. persons and, if the non-U.S. holder is a foreign corporation, the “branch profits tax” described above may also apply;

•

the non-U.S. holder is an individual who is present in the United States for 183 days or more in the taxable year of the disposition and meets other requirements; or

•

we are or have been a “United States real property holding corporation” for U.S. federal income tax purposes at any time during the shorter of the five-year period ending on the date of disposition or the period that the non-U.S. holder held our common stock.

Generally, a corporation is a “United States real property holding corporation” if the fair market value of its “United States real property interests” equals or exceeds 50% of the sum of the fair market value of its worldwide real property interests plus its other assets used or held for use in a trade or business. The tax relating

to stock in a “United States real property holding corporation” generally will not apply to a non-U.S. holder whose holdings, direct and indirect, at all times during the applicable period, constituted 5% or less of our common stock, provided that our common stock was regularly traded on an established securities market. We believe that we are not currently, and we do not anticipate becoming in the future, a “United States real property holding corporation” for U.S. federal income tax purposes.

U.S. Federal Estate Tax

Common stock owned or treated as owned by an individual who is not a citizen or resident of the United States (as defined for U.S. federal estate tax purposes) at the time of death will be included in the individual’s gross estate for U.S. federal estate tax purposes, unless an applicable estate tax or other treaty provides otherwise and, therefore, may be subject to U.S. federal estate tax.

Information Reporting and Backup Withholding Tax

Dividends paid to you may be subject to information reporting and U.S. backup withholding. If you are a non-U.S. holder you will be exempt from this backup withholding tax if you properly 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 otherwise establish an exemption.

The gross proceeds from the disposition of our common stock may be subject to information reporting and backup withholding. 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, then the U.S. backup withholding and information reporting requirements generally will not apply to that payment. However, U.S. 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;

•

derives 50% or more of its gross income in specific periods from the conduct of a trade or business in the United States;

•

is a “controlled foreign corporation” for U.S. tax purposes; or

•

is a foreign partnership, if at any time during its tax year:

one or more of its partners are U.S. persons who in the aggregate hold more than 50% of the income or capital interest 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. person 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 and information reporting unless you properly provide a Form W-8BEN certifying that you are a non-U.S. person or you otherwise establish an exemption.

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.

UNDERWRITING

Lehman Brothers Inc., Credit Suisse Securities (USA) LLC and UBS Securities LLC are acting as joint book-running managers and representatives of the underwriters of this offering. Under the terms of an underwriting agreement, which will be filed as an exhibit to the registration statement, each of the underwriters named below has severally agreed to purchase from us and the selling shareholders the respective number of common stock shown opposite its name below:


Underwriters		Number of Shares
Lehman Brothers Inc.
Credit Suisse Securities (USA) LLC
UBS Securities LLC

Total

The underwriting agreement provides that the underwriters’ obligation to purchase shares of common stock depends on the satisfaction of the conditions contained in the underwriting agreement including:

•

the obligation to purchase all of the shares of common stock offered hereby (other than those shares of common stock covered by their option to purchase additional shares as described below), if any of the shares are purchased;

•

the representations and warranties made by us and the selling stockholders to the underwriters are true;

•

there is no material adverse change in our business or the financial markets; and

•

we deliver customary closing documents to the underwriters.

Commissions and Expenses

The following table summarizes the underwriting discounts and commissions we and the selling stockholders will pay to the underwriters. These amounts are shown assuming both no exercise and full exercise of the underwriters’ option to purchase additional shares. The underwriting fee is the difference between the initial price to the public and the amount the underwriters pay to us and the selling stockholders for the shares.

Per Share

Total

No Exercise

Full Exercise

No Exercise

Full Exercise

Paid by us

Paid by selling stockholders

The representatives of the underwriters have advised us that the underwriters propose to offer the shares of common stock directly to the public initially at the public offering price on the cover of this prospectus and to selected dealers, which may include the underwriters, at such offering price less a selling concession not in excess of $ per share. After the initial offering, the representatives may change the offering price and other selling terms.

The expenses of the offering that are payable by us and the selling stockholders are estimated to be $ (excluding underwriting discounts and commissions). We have agreed to pay expenses incurred by the selling stockholders in connection with the offering, other than the underwriting discounts and commission.

Option to Purchase Additional Shares

We have granted the underwriters an option exercisable for 30 days after the date of this prospectus, to purchase, from time to time, in whole or in part, up to an aggregate of shares at the public offering

price less underwriting discounts and commissions. This option may be exercised if the underwriters sell more than shares in connection with this offering. To the extent that this option is exercised, each underwriter will be obligated, subject to certain conditions, to purchase its pro rata portion of these additional shares based on the underwriter’s underwriting commitment in the offering as indicated in the table at the beginning of this underwriting section.

Lock-Up Agreements

We, all of our directors and executive officers and the selling stockholders have agreed that, subject to certain exceptions, without the prior written consent of each of Lehman Brothers Inc., Credit Suisse Securities (USA) LLC and UBS Securities LLC, we and they will not directly or indirectly, (1) offer for sale, sell, pledge, or otherwise dispose of (or enter into any transaction or device that is designed to, or could be expected to, result in the disposition by any person at any time in the future of) any shares of common stock (including, without limitation, shares of common stock that may be deemed to be beneficially owned by us or them in accordance with the rules and regulations of the Securities and Exchange Commission and shares of common stock that may be issued upon exercise of any options or warrants) or securities convertible into or exercisable or exchangeable for common stock, (2) enter into any swap or other derivatives transaction that transfers to another, in whole or in part, any of the economic consequences of ownership of the common stock, (3) make any demand for or exercise any right or file or cause to be filed a registration statement, including any amendments thereto, with respect to the registration of any shares of common stock or securities convertible, exercisable or exchangeable into common stock or any of our other securities, or (4) publicly disclose the intention to do any of the foregoing for a period of 180 days after the date of this prospectus.

The 180-day restricted period described in the preceding paragraph will be extended if:

•

during the last 17 days of the 180-day restricted period we issue an earnings release or material news or announce a material event relating to us; or

•

prior to the expiration of the 180-day restricted period, we announce that we will release earnings results during the 16-day period beginning on the last day of the 180-day period,

in which case the restrictions described in the preceding paragraph will continue to apply until the expiration of the 18-day period beginning on the issuance of the earnings release or the announcement of the material news or material event.

Lehman Brothers Inc., Credit Suisse Securities (USA) LLC and UBS Securities LLC in their sole discretion, may release the common stock and other securities subject to the lock-up agreements described above in whole or in part at any time with or without notice. When determining whether or not to release common stock and other securities from lock-up agreements, Lehman Brothers Inc., Credit Suisse Securities (USA) LLC and UBS Securities LLC will consider, among other factors, the holder’s reasons for requesting the release, the number of shares of common stock and other securities for which the release is being requested and market conditions at the time.

Offering Price Determination

Prior to this offering, there has been no public market for our common stock. The initial public offering price will be negotiated between the representatives and us. In determining the initial public offering price of our common stock, the representatives will consider:

•

the history and prospects for the industry in which we compete;

•

our financial information;

•

the ability of our management and our business potential and earning prospects;

•

the prevailing securities markets at the time of this offering; and

•

the recent market prices of, and the demand for, publicly traded shares of generally comparable companies.

Indemnification

We and the selling stockholders have agreed to indemnify the underwriters against certain liabilities, including liabilities under the Securities Act, and to contribute to payments that the underwriters may be required to make for these liabilities.

Directed Share Program

At our request, the underwriters have reserved for sale at the initial public offering price up to % 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 offered hereby.

Stabilization, Short Positions and Penalty Bids

The representatives may engage in stabilizing transactions, short sales and purchases to cover positions created by short sales, and penalty bids or purchases for the purpose of pegging, fixing or maintaining the price of the common stock, in accordance with Regulation M under the Securities Exchange Act of 1934:

•

Stabilizing transactions permit bids to purchase the underlying security so long as the stabilizing bids do not exceed a specified maximum.

•

A short position involves a sale by the underwriters of shares in excess of the number of shares the underwriters are obligated to purchase in the offering, which creates the syndicate short position. This short position may be either a covered short position or a naked short position. In a covered short position, the number of shares involved in the sales made by the underwriters in excess of the number of shares they are obligated to purchase is not greater than the number of shares that they may purchase by exercising their option to purchase additional shares. In a naked short position, the number of shares involved is greater than the number of shares in their option to purchase additional shares. The underwriters may close out any short position by either exercising their option to purchase additional shares and/or purchasing shares in the open market. 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 their option to purchase additional shares. 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.

•

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.

•

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 the common stock may be higher than the price that might otherwise exist in the open market. These transactions may be effected on the Nasdaq National Market or otherwise and, if commenced, may be discontinued at any time.

Neither we nor any of the underwriters make any representation or prediction as to the direction or magnitude of any effect that the transactions described above may have on the price of the common stock. In addition, neither we nor any of the underwriters make representations that the representatives will engage in these stabilizing transactions or that any transaction, once commenced, will not be discontinued without notice.

Electronic Distribution

A prospectus in electronic format may be made available on the Internet sites or through other online services maintained by one or more of the underwriters and/or selling group members participating in this offering, or by their affiliates. In those cases, prospective investors may view offering terms online and, depending upon the particular underwriter or selling group member, prospective investors may be allowed to place orders online. The underwriters may agree with us to allocate a specific number of shares for sale to online brokerage account holders. Any such allocation for online distributions will be made by the representatives on the same basis as other allocations.

Other than the prospectus in electronic format, the information on any underwriter’s or selling group member’s web site and any information contained in any other web site maintained by an underwriter or selling group member is not part of the prospectus or the registration statement of which this prospectus forms a part, has not been approved and/or endorsed by us or any underwriter or selling group member in its capacity as underwriter or selling group member and should not be relied upon by investors.

Listing

We intend to apply to list our shares of common stock for quotation on the Nasdaq National Market under the symbol “SOFS.”

Discretionary Sales

The underwriters have informed us that they do not intend to confirm sales to discretionary accounts that exceed 5% of the total number of shares offered by them.

Stamp Taxes

If you purchase shares of common stock offered in this prospectus, you may be required to pay stamp taxes and other charges under the laws and practices of the country of purchase, in addition to the offering price listed on the cover page of this prospectus.

Other Relationships

The underwriters may in the future perform investment banking and advisory services for us from time to time for which they may in the future receive customary fees and expenses. UBS Securities LLC was the lead arranger for our Credit Agreement and is an affiliate of certain lenders party thereto.

Foreign Selling Restrictions

United Kingdom

This document is only being distributed to and is only directed at (i) persons who are outside the United Kingdom or (ii) to investment professionals falling within Article 19(5) of the Financial Services and Markets

Act 2000 (Financial Promotion) Order 2005 (the “Order”) or (iii) high net worth entities, and other persons to whom it may lawfully be communicated, falling within Article 49(2)(a) to (e) of the Order (all such persons together being referred to as “relevant persons”). The shares of common stock are only available to, and any invitation, offer or agreement to subscribe, purchase or otherwise acquire such common stock will be engaged in only with, relevant persons. Any person who is not a relevant person should not act or rely on this document or any of its contents.

Each of the underwriters has represented and agreed that:

(a) it has only communicated or caused to be communicated and will only communicate or cause to be communicated an invitation or inducement to engage in investment activity (within the meaning of Section 21 of the Financial Services and Markets Act 2000 or FSMA) received by it in connection with the issue or sale of the shares in circumstances in which Section 21(1) of the FSMA does not apply to us, and

(b) it has complied with, and will comply with all applicable provisions of the FSMA with respect to anything done by it in relation to the shares in, from or otherwise involving the United Kingdom.

European Economic Area

To the extent that the offer of the common stock is made in any Member State of the European Economic Area that has implemented the Prospectus Directive before the date of publication of a prospectus in relation to the common stock which has been approved by the competent authority in the Member State in accordance with the Prospectus Directive (or, where appropriate, published in accordance with the Prospectus Directive and notified to the competent authority in the Member State in accordance with the Prospectus Directive), the offer (including any offer pursuant to this document) is only addressed to qualified investors in that Member State within the meaning of the Prospectus Directive or has been or will be made otherwise in circumstances that do not require us to publish a prospectus pursuant to the Prospectus Directive.

In relation to each Member State of the European Economic Area which has implemented the Prospectus Directive (each, a “Relevant Member State”), each underwriter has represented and agreed that with effect from and including the date on which the Prospectus Directive is implemented in that Relevant Member State (the “Relevant Implementation Date”) it has not made and will not make an offer of shares to the public in that Relevant Member State prior to the publication of a prospectus in relation to the shares which has been approved by the competent authority in that Relevant Member State or, where appropriate, approved in another Relevant Member State and notified to the competent authority in that Relevant Member State, all in accordance with the Prospectus Directive, except that it may, with effect from and including the Relevant Implementation Date, make an offer of shares to the public in that Relevant Member State at any time:

(a) to legal entities which are authorized or regulated to operate in the financial markets or, if not so authorized or regulated, whose corporate purpose is solely to invest in securities,

(b) to any legal entity which has two or more of (1) an average of at least 250 employees during the last financial year; (2) a total balance sheet of more than €43,000,000 and (3) an annual net turnover of more than €50,000,000, as shown in its last annual or consolidated accounts, or

(c) in any other circumstances which do not require the publication by us of a prospectus pursuant to Article 3 of the Prospectus Directive.

For the purposes of this provision, the expression an “offer of shares to the public” in relation to any shares in any Relevant Member State means the communication in any form and by any means of sufficient information on the terms of the offer and the shares to be offered so as to enable an investor to decide to purchase or subscribe the shares, as the same may be varied in that Member State by any measure implementing the Prospectus Directive in that Member State and the expression “Prospectus Directive” means Directive 2003/71/ EC and includes any relevant implementing measure in each Relevant Member State.

LEGAL MATTERS

The validity of the shares of common stock offered by this prospectus and certain other legal matters in connection with this offering will be passed upon for us by Vinson & Elkins L.L.P., Houston, Texas. Certain legal matters in connection with this offering will be passed on for certain of the selling stockholders by Latham & Watkins LLP, Washington, D.C. 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 audited financial statements included in this prospectus, except as they relate to BLR Construction Companies, L.L.C. and affiliate and BLR Construction Co., Inc. and affiliates, have been audited by UHY Mann Frankfort Stein & Lipp CPAs, LLP, independent registered public accountants as indicated in their reports with respect thereto, and, insofar as they relate to BLR Construction Companies, L.L.C. and affiliate and BLR Construction Co., Inc. and affiliates, by Wright, Moore, DeHart, Dupuis & Hutchinson, LLC, independent public accountants as indicated in their reports with respect thereto, whose reports thereon appear herein. Such financial statements have been so included in reliance on the reports of such independent accountants given on the authority of such firms as experts in auditing and accounting.

WHERE YOU CAN FIND MORE INFORMATION

We have filed with the SEC a registration statement on Form S-1 regarding the common stock. 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 100 F Street, N.E., Washington, D.C. 20549, at prescribed rates or from the SEC’s website on the Internet at http://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 Nasdaq National Market, Reports Section, 1735 K Street, N.W., Washington, D.C. 2006.

You should rely only on the information contained in this prospectus. We have not, and the underwriters have not, authorized any other person to provide you with different information. If anyone provides you with different or inconsistent information, you should not rely on it. 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 http://www.stallionoilfield.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: 410 Roberts Street, Houston, Texas 77003, Attention: Chief Financial Officer, (713) 528-5544.

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 by Form 10-Q, for the first three fiscal quarters of each fiscal year.

INDEX TO FINANCIAL STATEMENTS


		Page
Audited Consolidated Financial Statements
Report of Independent Registered Public Accounting Firm		F-4
Consolidated Balance Sheets as of December 31, 2005 and 2004		F-5
Consolidated Statements of Operations for the Years Ended December 31, 2005, 2004, and 2003		F-6
Consolidated Statements of Changes in Partners’ Capital for the Years Ended December 31, 2005, 2004 and 2003		F-7
Consolidated Statements of Cash Flows for the Years Ended December 31, 2005, 2004 and 2003		F-8
Notes to Consolidated Financial Statements for the Years Ended December 31, 2005, 2004 and 2003		F-9

Unaudited Consolidated Financial Statements
Consolidated Balance Sheets as of March 31, 2006 and December 31, 2005		F-27
Consolidated Statements of Operations for the Three Months Ended March 31, 2006 and 2005		F-28
Consolidated Statements of Partners’ Capital for the Three Months Ended March 31, 2006		F-29
Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2006 and 2005		F-30
Notes to Consolidated Financial Statements for the Three Months Ended March 31, 2006 and 2005		F-31

Audited Combined Financial Statements—BLR Construction Companies, L.L.C. and affiliate (Acquired Entity)
Report of Independent Auditors		F-46
Combined Balance Sheet as of December 31, 2005		F-47
Combined Statement of Income for the Year ended December 31, 2005		F-48
Combined Statement of Changes in Members’ Equity for the Year ended December 31, 2005		F-49
Combined Statement of Cash Flows for the Year ended December 31, 2005		F-50
Notes to Combined Financial Statements for the Year ended December 31, 2005		F-51
Independent Auditors’ Report on Supplementary Information		F-57
Combined Schedule of General and Administrative Expenses		F-58

Audited Combined Financial Statements—BLR Construction Co., Inc. and affiliates (Acquired Entity)
Report of Independent Auditors		F-60
Combined Balance Sheet as of December 31, 2004		F-61
Combined Statement of Income for the Year ended December 31, 2004		F-62
Combined Statement of Retained Earnings for the Year ended December 31, 2004		F-63
Combined Statement of Cash Flows for the Year ended December 31, 2004		F-64
Notes to Combined Financial Statements for the Year ended December 31, 2004		F-65
Independent Auditors’ Report on Supplementary Information		F-72
Combined Schedule of General and Administrative Expenses		F-73

Audited Combined Financial Statements—BLR Construction Co., Inc. and affiliates (Acquired Entity)
Report of Independent Auditors		F-75
Combined Balance Sheet as of December 31, 2003		F-76
Combined Statement of Income for the Year ended December 31, 2003		F-77
Combined Statement of Retained Earnings for the Year ended December 31, 2003		F-78
Combined Statement of Cash Flows for the Year ended December 31, 2003		F-79
Notes to Combined Financial Statements for the Year ended December 31, 2003		F-80
Independent Auditors’ Report on Supplementary Information		F-87
Combined Schedule of General and Administrative Expenses		F-88

F-1


		Page

Audited Financial Statements—Trail Blazer Hot Shot, Inc. (Acquired Entity)
Report of Independent Auditors		F-89
Balance Sheets as of December 31, 2005 and 2004		F-90
Statements of Operations for the Years ended December 31, 2005 and 2004		F-91
Statement of Changes in Stockholder’s Equity for the Years ended December 31, 2005 and 2004		F-92
Statements of Cash flows for the Years ended December 31, 2005 and 2004		F-93
Notes to Financial Statements for the Years ended December 31, 2005 and 2004		F-94
Schedule of Operating Expenses for the Years ended December 31, 2005 and 2004		F-97

Audited Financial Statements—GL Trucking & Rental, Inc. (Acquired Entity)
Report of Independent Auditors		F-98
Balance Sheets as of September 12, 2005 and December 31, 2004		F-99
Statements of Operations for the Period January 1, 2005 through September 12, 2005 and the Year ended December 31, 2004		F-100
Statements of Changes in Stockholders’ Equity for the period January 1, 2005 through September 12, 2005 and the Year ended December 31, 2004		F-101
Statements of Cash flows for the Period January 1, 2005 through September 12, 2005 and the Year ended December 31, 2004		F-102
Notes to Financial Statements for the Period January 1, 2005 through September 12, 2005 and the Year ended December 31, 2004		F-103
Schedule of Operating Expenses for the Period January 1, 2005 through September 12, 2005 and the Year ended December 31, 2004		F-107

Audited Financial Statements—Separation Services, Inc. (Acquired Entity)
Report of Independent Auditors		F-108
Balance Sheet as of December 31, 2004		F-109
Statement of Operations for the Year ended December 31, 2004		F-110
Statement of Changes in Stockholder’s Equity for the Year ended December 31, 2004		F-111
Statement of Cash flows for the Year ended December 31, 2004		F-112
Notes to Financial Statements for the Year ended December 31, 2004		F-113
Schedule of Operating Expenses for the Year ended December 31, 2004		F-117

Audited Combined Financial Statements—Stallion Rentals, LP dba Trinity Valley Rentals (Acquired Entity)
Report of Independent Auditors		F-118
Balance Sheet as of December 31, 2004		F-119
Combined Statement of Operations for the Year ended December 31, 2004		F-120
Combined Statement of Changes in Partners’ Deficit for the Year ended December 31, 2004		F-121
Combined Statement of Cash flows for the Year ended December 31, 2004		F-122
Notes to Combined Financial Statements for the Year ended December 31, 2004		F-123
Schedule of Combined Operating Expenses for the Year ended December 31, 2004		F-128

Audited Financial Statements—Envirotech, Inc. (Acquired Entity)
Report of Independent Auditors		F-129
Balance Sheet as of December 31, 2004		F-130
Statement of Operations for the Year ended December 31, 2004		F-131
Statement of Changes in Stockholders’ Equity for the Year ended December 31, 2004		F-132
Statement of Cash flows for the Year ended December 31, 2004		F-133
Notes to Financial Statements for the Year ended December 31, 2004		F-134
Schedule of Operating Expenses for the Year ended December 31, 2004		F-139

F-2


		Page

Audited Financial Statements—Double D Enterprises, Inc. (Acquired Entity)
Report of Independent Auditors		F-140
Balance Sheet as of December 31, 2004		F-141
Statement of Operations for the Year ended December 31, 2004		F-142
Statement of Changes in Stockholder’s Equity for the Year ended December 31, 2004		F-143
Statement of Cash flows for the Year ended December 31, 2004		F-144
Notes to Financial Statements for the Year ended December 31, 2004		F-145
Schedule of Operating Expenses for the Year ended December 31, 2004		F-149

F-3

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Partners of Stallion Oilfield Services, Ltd. and subsidiaries:

We have audited the accompanying consolidated balance sheets of Stallion Oilfield Services Ltd. and subsidiaries as of December 31, 2005 and 2004, and the related consolidated statements of operations, changes in partners’ capital and cash flows for each of the three years ended December 31, 2005. These consolidated financial statements are the responsibility of the Partnerships’ management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

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 audits 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 consolidated 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 consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of Stallion Oilfield Services Ltd. and subsidiaries as of December 31, 2005 and 2004, and the consolidated results of their operations and their cash flows for each of the three years ended December 31, 2005, in conformity with accounting principles generally accepted in the United States of America.

/S/ UHY MANN FRANKFORT STEIN & LIPP CPAS, LLP

UHY Mann Frankfort Stein & Lipp CPAs LLP

Houston, Texas

June 23, 2006

F-4

STALLION OILFIELD SERVICES LTD. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS


	December 31,
	2005		2004
	(in thousands)
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	982	$	50
Accounts receivable, net		22,348		3,882
Prepaid expenses		430		129
Deferred tax assets		259		—

TOTAL CURRENT ASSETS		24,019		4,061
PROPERTY AND EQUIPMENT, net		74,583		13,899
GOODWILL		18,625		6,444
INTANGIBLE AND OTHER ASSETS, net		5,909		309

TOTAL ASSETS	$	123,136	$	24,713

LIABILITIES AND PARTNERS’ CAPITAL
CURRENT LIABILITIES
Accounts payable—trade	$	4,244	$	1,435
Accounts payable—related party		—		135
Distribution payable		786		—
Accrued expenses		5,425		980
Current portion of long-term debt		11,201		1,604
Current portion of notes payable—related party		500		100
Current portion of convertible notes payable—related parties		232		—
Current portion of capital leases		393		352

TOTAL CURRENT LIABILITIES		22,781		4,606
LONG-TERM DEBT, net of current portion		44,272		8,042
OBLIGATIONS UNDER CAPITAL LEASES, net of current portion		368		681
CONVERTIBLE NOTES PAYABLE—RELATED PARTIES, net of current portion		1,187		—
NOTES PAYABLE—RELATED PARTY, net of current portion		—		7,773
NOTE PAYABLE TO PARTNER, net		9,642		—
DEFERRED INCOME TAX LIABILITIES		1,289		—

TOTAL LIABILITIES		79,539		21,102
COMMITMENTS AND CONTINGENCIES		—		—
PARTNERS’ CAPITAL		43,597		3,611

TOTAL LIABILITIES AND PARTNERS’ CAPITAL	$	123,136	$	24,713

See notes to consolidated financial statements.

F-5

STALLION OILFIELD SERVICES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS


	Year Ended December 31,
	2005			2004			2003
	(in thousands)
SERVICE REVENUE	$	73,126		$	15,452		$	6,769

OPERATING EXPENSES:
Cost of services		42,281			8,695			3,108
Selling, general and administrative expenses		9,883			3,745			2,145
Depreciation and amortization		7,798			1,924			836
Loss on disposal of property and equipment		499			92			86

TOTAL OPERATING EXPENSES		60,461			14,456			6,175

INCOME FROM OPERATIONS		12,665			996			594
OTHER EXPENSE
Interest expense		(4,565	)		(917	)		(489	)
Other expense		(66	)		—			—

TOTAL OTHER EXPENSE		(4,631	)		(917	)		(489	)

INCOME BEFORE INCOME TAXES		8,034			79			105
PROVISION FOR INCOME TAXES		598			—			—

NET INCOME	$	7,436		$	79		$	105

See notes to consolidated financial statements.

F-6

Description

Estimates/Assumptions Used

Variability in Accounting

Historical Results/
Sensitivity Analysis

Stock Options

We have adopted the provisions of SFAS No. 123R which requires that we measure the cost of employee services received in exchange for an award of equity instruments based on the fair value of those instruments on their grant date. The fair value of these instruments must be re-evaluated at each reporting date through the settlement date with changes in fair value recognized as compensation expense of the period.

GAAP permits the use of various models to determine the fair value of stock options and the variables used for the model are subjective. The use of different assumptions or a different model may have a material impact on our results of operations and related disclosures.

Historically, we have not issued any equity securities in exchange for employee services. In connection with future such awards we anticipate estimating compensation expense that would be required to be recognized under SFAS No. 123R, using a Black-Scholes model including assumptions for expected term , a 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.

S TALLION OILFIELD SERVICES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS’ CAPITAL

YEARS ENDED DECEMBER 31, 2005, 2004 AND 2003


	General Partner		Limited Partner			Total
	(in thousands)
Balances as of December 31, 2002	$	—	$	—		$	—
Contributions		34		3,393			3,427
Net income		—		105			105

Balances as of December 31, 2003		34		3,498			3,532
Net income		—		79			79

Balances as of December 31, 2004		34		3,577			3,611
Contributions, net of issuance costs		—		32,406			32,406
Distributions		—		(786	)		(786	)
Conversion of notes payable into limited partner interest		—		500			500
Limited partner interest issued in connection with note payable		—		430			430
Net income		1		7,435			7,436

Balances as of December 31, 2005	$	35	$	43,562		$	43,597

See notes to consolidated financial statements.

F-7

Stallion Oilfield Services, Inc. S-1