As filed with the Securities and Exchange Commission on July 21, 2006

Registration No. 333-            

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form F-1

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

NACG Holdings Inc.

(Exact name of registrant as specified in its charter)

Canada

(State or Other Jurisdiction of
Incorporation or Organization) 1629
(Primary Standard Industrial
Classification Code Number) Not Applicable
(I.R.S. Employer
Identification Number)

Zone 3, Acheson Industrial Area
2-53016 Highway 60
Acheson, Alberta T7X 5A7
(780) 960-7171
(Address, including zip code, and telephone
number, including area code, of registrant’s
principal executive offices) Vincent J. Gallant
Zone 3, Acheson Industrial Area
2-53016 Highway 60
Acheson, Alberta T7X 5A7
(780) 960-7171
(Name, address, including zip code, and telephone
number, including area code, of agent for service)

Copies to:

Gary W. Orloff, Esq.
Bracewell & Giuliani LLP
711 Louisiana Street, Suite 2300
Houston, Texas 77002-2770
Phone: (713) 221-1306
Fax: (713) 221-2166 Kris F. Heinzelman, Esq.
Cravath, Swaine & Moore LLP
825 Eighth Avenue
New York, New York 10019-7475
Phone: (212) 474-1336
Fax: (212) 474-3700

     Approximate date of commencement of proposed sale of the securities to the public: As soon as practicable after the effective date of this Registration Statement.

     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, check the following box.    o

     If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.    o

     If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration number of the earlier effective registration statement for the same offering.    o

     If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration number of the earlier effective registration statement for the same offering.    o

CALCULATION OF REGISTRATION FEE

	Proposed Maximum
	Aggregate	Amount of
Title of Each Class of Securities to be Registered	Offering Price(1)(2)	Registration Fee
Common shares, no par value	$250,000,000	$26,750

(1)	Estimated solely for purposes of calculating the registration fee pursuant to Rule 457 under the Securities Act.
(2)	Includes shares that may be sold pursuant to the underwriters’ over-allotment option.

      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 this Registration Statement shall become effective on such date as the Securities and Exchange 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 21, 2006

                             Shares

North American Energy Partners Inc.

Common Shares

        Prior to the offering, there has been no public market for our common shares. The initial public offering price of our common shares is expected to be between US$                    and US$                     per share. We will apply to list our common shares on the New York Stock Exchange under the symbol “                    ”. We also will apply to list our common shares on the Toronto Stock Exchange under the symbol “                    ”.

      We are selling                      common shares, and the selling shareholders are selling                      common shares. The underwriters have an option to purchase a maximum of                      additional common shares from the selling shareholders to cover over-allotments. We will not receive any of the proceeds from the sale of common shares by the selling shareholders.

      Investing in our common shares involves risks. See “Risk Factors” beginning on page 15.

			Underwriting		Proceeds to North		Proceeds to the
	Price to		Discounts and		American Energy		Selling
	Public		Commissions		Partners Inc.		Shareholders
Per Share		US$		US$		US$		US$
Total		US$		US$		US$		US$

      Delivery of the common shares will be made on or about                     , 2006.

      Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.

Credit Suisse UBS Investment Bank Jefferies & Company

The date of this prospectus is                     , 2006.

[Maps of Canadian oil sands]

[Pictures of our equipment]

TABLE OF CONTENTS

	Page
Prospectus Summary		1
Risk Factors		15
Cautionary Note Regarding Forward-Looking Statements		29
Use of Proceeds		31
Dividend Policy		31
Capitalization		32
Dilution		33
The Reorganization		34
Selected Historical Financial Data		36
Unaudited Pro Forma Financial Information		42
Management’s Discussion and Analysis of Financial Condition and Results of Operations		47
Business		68
Our Equity Sponsors		85
Management		86
Related Party Transactions		95
Principal and Selling Shareholders		99
Description of Certain Indebtedness		102
Description of Share Capital		105
Shares Eligible For Future Sale		109
Income Tax Considerations		111
Underwriting		115
Legal Matters		119
Experts		119
Where You Can Find More Information		119
Enforceability of Civil Liabilities Against Foreign Persons		120
Index to Financial Statements		F-1
Articles of Incorporation of NACG Holdings Inc., as amended
By-law No.1 of NACG Holdings Inc.
Registration Rights Agreement
First Amended and Restated Credit Agreement
Subsidiaries of NACG Holdings Inc.
Consent of KPMG LLP
Powers of Attorney

      You should rely only on the information contained in this document or to which we have referred you. We have not and the underwriters have not authorized anyone to provide you with information that is different. If anyone provides you with different or inconsistent information, you should not rely on it. This document may only be used where it is legal to sell these securities. The information in this document may only be accurate on the date of this document.

Dealer Prospectus Delivery Obligation

      Until                     , 2006 (25 days after the commencement of this offering), all dealers that effect transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to the dealer’s obligation to deliver a prospectus when acting as an underwriter and with respect to unsold allotments or subscriptions.

i

INDUSTRY DATA AND FORECASTS

      This prospectus includes industry data and forecasts that we have obtained from publicly available information, various industry publications, other published industry sources and our internal data and estimates.

      For example, in this prospectus, information regarding actual and anticipated production, reserves and current and scheduled projects in the Canadian oil sands was obtained from the Alberta Energy and Utilities Board, or EUB, and from the Energy Market Assessment – June 2006, Canada’s Oil Sands: Opportunities and Challenges to 2015 – An Update, referred to as the “2006 Energy Market Assessment,” published by the Canadian National Energy Board, or NEB. Information regarding historical capital expenditures in the oil sands was obtained from the Canadian Association of Petroleum Producers, or CAPP.

      Industry publications and other published industry sources generally indicate that the information contained therein was obtained from sources believed to be reliable, but do not guarantee the accuracy and completeness of such information. Although we believe that these publications and reports are reliable, we have not independently verified the data.

      Our internal data, estimates and forecasts are based upon information obtained from our customers, trade and business organizations and other contacts in the markets in which we operate and our management’s understanding of industry conditions. Although we believe that such information is reliable, we have not had such information verified by any independent sources.

      References to barrels of oil related to the oil sands in this document are quoted directly from source documents and refer to both barrels of bitumen and barrels of bitumen that have been upgraded into synthetic crude oil, which is considered synthetic because its original hydrocarbon mark has been altered in the upgrading process. We understand that there is generally some shrinkage of bitumen volumes through the upgrading process. The shrinkage is approximately 11% according to the NEB. We have not made any estimates or calculations with regard to these volumes and have quoted these volumes as they appeared in the related source documents.

NON-GAAP FINANCIAL MEASURES

      The body of generally accepted accounting principles applicable to us is commonly referred to as “GAAP.” A non-GAAP financial measure is generally defined by the Securities and Exchange Commission, or SEC, and by the Canadian securities regulatory authorities as one that purports to measure historical or future financial performance, financial position or cash flows, but excludes or includes amounts that would not be so adjusted in the most comparable GAAP measures. In this prospectus, we disclose EBITDA and Consolidated EBITDA, both non-GAAP financial measures. Our revolving credit facility requires us to maintain a minimum Consolidated EBITDA. EBITDA is calculated as net income (or loss) before interest expense, taxes, depreciation and amortization. Consolidated EBITDA is defined as EBITDA, excluding the effects of foreign exchange gain or loss, realized and unrealized gain or loss on derivative financial instruments and non-cash stock-based compensation expense. EBITDA and Consolidated EBITDA are not substitutes for the GAAP measures of net income (or loss) or cash flows. We believe that EBITDA is a meaningful measure of the performance of our business because it excludes items, such as depreciation and amortization, interest and taxes, that are not directly related to the operating performance of our business. Non-compliance with the minimum Consolidated EBITDA financial covenant could result in our being required to immediately repay all amounts outstanding under our revolving credit facility. We are required to maintain a minimum Consolidated EBITDA through December 31, 2006 of $65.5 million, with this minimum amount increasing periodically until maturity. Our methods of calculating EBITDA and Consolidated EBITDA may vary from others in our industry.

ii

EXCHANGE RATE DATA

      The following table sets forth, for the periods indicated, the high, low and average noon buying rates, in each case for the purchase of one Canadian dollar, expressed in U.S. dollars, based on the inverse of the noon buying rate in the city of New York for cable transfers in Canadian dollars as certified for customs purposes by the Federal Reserve Bank of New York. As of July 17, 2006, the noon buying rate was C$1.00 = US$0.8832.

	2006
	January		February		March		April		May		June
High for period		0.8744		0.8788		0.8834		0.8926		0.9100		0.9098
Low for period		0.8528		0.8638		0.8531		0.8534		0.8903		0.8896

	Year Ended March 31,
	2002		2003		2004		2005		2006
Average for period(1)		0.6381		0.6474		0.7412		0.7852		0.8409

(1)  Determined by averaging the exchange rates on the last day of each month during the respective period.

GLOSSARY OF TERMS

      The following are definitions of certain terms commonly used in our industry and this prospectus.

      “Bitumen” means the molasses-like substance that comprises the oil in the oil sands.

      “Established reserves” means those reserves recoverable under current technology and present and anticipated economic conditions specifically proved by drilling, testing or production, plus the portion of contiguous recoverable reserves that are interpreted to exist from geological, geophysical or similar information with reasonable certainty.

      “Muskeg” means a swamp or bog formed by an accumulation of sphagnum moss, leaves and decayed matter resembling peat.

      “Oil sands” means the grains of sand covered by a thin layer of water and coated by heavy oil, or bitumen

      “Overburden” means the layer of rocky, clay-like material that covers the oil sands.

      “Ultimately recoverable oil reserves” means an estimate of the initial established reserves that will have been developed in an area by the time all exploratory and development activity has ceased, having regard for the geological prospects of that area and anticipated technology and economic conditions. Ultimate recoverable oil reserves include cumulative production, remaining established reserves and future additions through extensions and revisions to existing pools and the discovery of new pools. Ultimate potential can be expressed by the following simple equation: Ultimate potential = initial established reserves + additions to existing pools + future discoveries.

      “Upgrading” means the conversion of heavy bitumen into a lighter crude oil by increasing the hydrogen to carbon ratio, either through the removal of carbon (coking) or the addition of hydrogen (hydroprocessing).

iii

PROSPECTUS SUMMARY

      This summary highlights key information contained elsewhere in this prospectus. It does not contain all of the information that you should consider in making your investment decision. For a more complete understanding of us and this offering, you should read and consider the entire prospectus, including the information set forth under “Risk Factors.” We state our financial statements in Canadian dollars. In this prospectus, references to “Canadian dollars,” “dollars,” “C$” or “$” are to the currency of Canada, and references to “U.S. dollars” or “US$” are to the currency of the United States. Unless the context otherwise requires, the information in this prospectus gives effect to the proposed amalgamation of NACG Holdings Inc., NACG Preferred Corp. and North American Energy Partners Inc., which amalgamated company will continue under the name North American Energy Partners Inc. See “The Reorganization.” The common shares of the amalgamated North American Energy Partners Inc. are the common shares being offered hereby.

Our Company

      We are a leading resource services provider to major oil and natural gas and other natural resource companies, with a primary focus in the Canadian oil sands. We provide a wide range of mining and site preparation, piling and pipeline installation services to our customers across the entire lifecycle of their projects. We are the largest provider of contract mining services in the oil sands area, and we believe we are the largest piling foundations installer in western Canada. In addition, we believe that we operate the largest fleet of equipment of any contract resource services provider in the oil sands. Our total fleet includes over 525 pieces of diversified heavy construction equipment supported by over 540 ancillary vehicles. While our expertise covers heavy earth moving, piling and pipeline installation in any location, we have a specific capability operating in the harsh climate and difficult terrain of the oil sands and northern Canada. By understanding the terrain, having skilled personnel and a diverse, well-maintained and well-positioned fleet, we are able to meet the demands of a growing customer base.

      Our core market is the Canadian oil sands, where we generated 71% of our fiscal 2006 revenue. The oil sands are located in three regions of northern Alberta: Athabasca, Cold Lake and Peace River. Oil sands operators produce and process bitumen, which is the extremely heavy oil trapped in the sands. According to the Alberta Energy and Utilities Board, or EUB, Canada’s oil sands are estimated to hold 315 billion barrels of ultimately recoverable oil reserves, with established reserves of almost 174 billion barrels as of the end of 2004, second only to Saudi Arabia. According to the Canadian National Energy Board, or NEB, oil sands production of bitumen is expected to increase from 1.1 million barrels per day, or “bpd,” in 2005 to approximately 3.0 million bpd by 2015 and account for 75% of total Canadian oil output, compared to approximately 50% of output today. In order to achieve this increase in production, the NEB estimates that over $95 billion of capital expenditures by companies operating in the oil sands will be required through 2015.

      Our significant knowledge, experience, equipment capacity and scale of operations in the oil sands differentiates us from our competition. Our principal customers are the major operators in the oil sands, including all three of the producers that currently mine bitumen, being Syncrude Canada Ltd., Suncor Energy Inc. and Albian Sands Energy Inc. (a joint venture among Shell Canada Limited, Chevron Canada Limited and Western Oil Sands Inc.). Canadian Natural Resources Limited, or CNRL, another significant customer, is developing a bitumen-mining project in the oil sands. We provide services to every company in the oil sands that uses surface mining techniques for its production. These mining surface techniques account for over 70% of total oil sands production. We also provide site construction services for in-situ producers, which use horizontally drilled wells to inject steam into deposits and pump bitumen to the surface.

1

      We have long-term relationships with most of our customers. For example, we have been providing services to Syncrude and Suncor since they pioneered oil sands development over 30 years ago. We believe our customers’ leases have an average remaining productive life of over 35 years. In addition, 34% of our revenues in fiscal 2006 were derived from recurring, long-term contracts, which assists in providing stability in our operations.

      We provide services to our customers through three primary segments:

•  Mining and Site Preparation. Surface mining for oil sands and other natural resources, including overburden removal, hauling sand and gravel and supplying labor and equipment to support customers’ mining operations; construction of infrastructure associated with mining operations and reclamation activities; clearing, stripping, excavating and grading for mining operations and industrial site construction mega-projects; and underground utility installation for plant, refinery and commercial building construction;

•  Piling. Installing all types of driven and drilled piles, caissons and earth retention and stabilization systems for industrial projects primarily focused in the oil sands and related petrochemical or refinery complexes, as well as commercial buildings and infrastructure projects; and

•  Pipeline Installation. Installing transmission and distribution pipe made of various materials for oil, natural gas and water.

      As a result of our extensive experience and expertise in the oil sands, we are often engaged at an early stage to help our customers plan and estimate costs to develop oil sands projects which may entail the expenditure of several billions of dollars over the three to four year life of project construction. We provide our customers with information about working in the oil sands, including details about the differential in the cost of undertaking various projects in the summer or the winter, constructability, equipment availability and requirements and availability of labor. Our early stage or “first-in” involvement in projects gives us the opportunity to demonstrate our capability and insight into our customers’ plans and schedules, thereby allowing us to achieve greater accuracy in forecasting our future equipment and labor needs. With large trucks costing $3 million to $4 million each, shovels costing up to $20 million each, the global shortage of large truck tires and the lead times for delivery of this equipment extending many months into the future, the insight we gain about future projects facilitates our long-term planning.

      During the year ended March 31, 2006, we generated record revenues of $492.2 million and gross profits of $80.3 million. Since the beginning of our fiscal 2002, we have grown revenues and gross profits at a compound annual growth rate of 19% and 25%, respectively.

      The following charts provide our revenues by segment and by end market for the year ended March 31, 2006:

2

Our Competitive Strengths

      We believe our competitive strengths include:

      Leading market position. We are the largest provider of contract mining services in the oil sands area, and we believe we are the largest piling foundations installer in western Canada. We have operated in western Canada for over 50 years and have participated in every significant oil sands mining project since operators first began working in the oil sands over 30 years ago. We believe the combination of our significant size, extensive experience and broad service offerings has allowed us to develop our leading market position and reputation as the service provider of choice in the oil sands.

      Large, well-maintained equipment fleet strategically located in the Canadian oil sands. As of March 31, 2006, we had a heavy equipment fleet of over 350 units and over 270 ancillary vehicles located in the oil sands. Many of these units are among the largest pieces of equipment in the world and are designed for use in the largest earthmoving and mining applications globally. Our large, diverse fleet gives us flexibility in scheduling jobs and allows us to be responsive to our customers’ needs. A well-maintained fleet is critical in the harsh climatic and environmental conditions we encounter. We operate four significant maintenance and repair centers, which are capable of accommodating the largest pieces of equipment in our fleet, on the sites of the major oil sands projects. These factors help us to be more efficient, thereby reducing costs to our customers to further improve our competitive edge, while concurrently increasing our equipment utilization and thereby improving our profitability.

      Broad service offering across a project’s lifecycle. We provide our customers with resource services to meet their needs across the entire lifecycle of a project. These services include overburden removal, engineering assistance, construction of infrastructure, site grading, piling and pipe installation, day-to-day site maintenance, equipment supply, site upgrading services and land rehabilitation. Given the capital intensive and long-term nature of oil sands projects, our broad service offerings provide us with a competitive advantage and position us to transition from one stage of the project to the next, as we typically have knowledge of a project during its initial planning and budgeting phase. We use this knowledge to help secure contracts during the initial construction of the project as well as plan for recurring and follow-on work. As a result, we have a reputation as a “first-in, last-out” service provider in the oil sands.

      Long-term customer relationships. We have worked successfully for many years and believe we have well-established relationships with major oil sands and conventional oil and gas producers. These relationships are based on our success in meeting our customers’ requirements, including strong safety and performance records, a well-maintained, highly capable fleet with specific equipment dedicated to individual customers and a staff of well-trained, experienced supervisors, operators and mechanics. Historically, our largest customers by revenue have included Syncrude, Suncor, Albian and EnCana Corporation, or EnCana. We have worked with oil sands mining operators Syncrude, Suncor and Albian since they began operations in the oil sands, which in the case of Syncrude and Suncor, was over 30 years ago. We also have worked with EnCana for over 20 years, providing pipe installation services throughout western Canada and, more recently, services to support its new in-situ mining operations in the oil sands.

      Experienced management team. Our management team has well-established relationships with major oil sands producers and other resource industry leaders in our core markets. We believe that our management team’s experience in the resource services and mining industries enhances our ability to accomplish our strategic objectives and effectively manage our transition from a private company to a public company. The entire management team is focused on further developing our culture of performance and accountability and continuing our tradition of offering high quality service to our customers. In addition, our management and operations teams have the necessary local-level knowledge of our markets to identify acquisition opportunities.

3

Our Strategy

      We intend to pursue the following strategies:

      Capitalize on growth opportunities in the Canadian oil sands. We intend to leverage our market leadership position and successful track record with our customers in the oil sands to benefit from the expected rapid growth in this end market. The NEB estimates that between 2006 and 2015 $8.5 billion to $10.9 billion of annual capital expenditures, for a total of over $95 billion, will be required to achieve expected increases in production. We believe that these planned expenditures will not only allow us to increase our business from current projects but also create opportunities to provide our services to new projects. To capitalize on these opportunities, we plan to continue to add to our equipment fleet. This new equipment will be delivered in regular intervals and, together with our existing fleet, will enable us to compete for new business opportunities in the oil sands as they arise.

      Leverage our complementary services. We intend to build on our “first-in” position to cross-sell other services that we provide. Our complementary service segments allow us to compete for many different forms of business. Given our technical capabilities, performance history and on-site presence, we are well positioned to compete for new business in our service segments. Unplanned work requirements frequently arise with little notice, which we are well-positioned to execute, given our on-site location and complementary service offerings. Furthermore, we intend to pursue selective acquisition growth opportunities that expand our complementary service offerings.

      Increase our recurring revenue base. We provide services both during construction and while the project is in operation. Once the capital expenditures for a project are complete, the operation of that project results in ongoing operating expenditures. Work required as an integral part of an operating project provides us with the opportunity to perform recurring services for our customers. Over the past several years we have increased our recurring revenues from mining services, including overburden removal, reclamation, road construction and maintenance and surface mining, from 20% of revenues in fiscal 2004 to 34% in fiscal 2006. Oil sands operators’ needs for these types of services will increase as they expand their operations and as new oil sands operations come on line.

      Leverage long-term relationships with existing customers. Several of our oil sands customers have announced intentions to increase their production capacity by expanding the infrastructure at their sites. We intend to continue to build on our relationships with these and other existing oil sands customers to win a substantial share of the mining and site preparation, piling and pipeline services outsourced in connection with these projects.

      Increase our presence outside of the Canadian oil sands. Canada has significant reserves of various natural resources, including diamonds, coal and gold. We intend to utilize the expertise we have gained in the oil sands to provide similar services to other natural resource mining companies.

      Enhance operating efficiencies to improve revenue and margins. We have initiated an operational improvement plan focused on implementing systems and process improvements, performance measurement techniques, enhanced communication and improved organizational effectiveness. This plan is designed to enhance our profitability, competitiveness and ability to effectively respond to opportunities in the markets we serve by improving the availability of our equipment through enhanced maintenance, providing the opportunity for increased utilization, revenues and profitability.

4

Our Markets

      Our business is primarily driven by the demand for our services from the development, expansion and operation of oil sands projects. Decisions by oil sands operators to make capital investments are driven by a number of factors, with one of the most important being the expected long-term price of oil.

Canadian Oil Sands

      Oil sands are grains of sand covered by a thin layer of water and coated by heavy oil or bitumen. Bitumen, because of its structure, does not flow, and therefore requires non-conventional extraction techniques to separate it from the sand and other foreign matter. There are currently two main methods of extraction: open pit mining, where bitumen deposits are sufficiently close to the surface to make it economically viable to recover the bitumen by treating mined sand in a surface plant; and in-situ, where bitumen deposits are buried too deep for open pit mining to be cost effective, and operators instead inject steam into the deposit so that the bitumen can be separated from the sand and pumped to the surface. We currently provide most of our services to companies operating open pit mines to recover bitumen reserves. These customers utilize our services for surface mining, site preparation, piling, pipe installation, site maintenance, equipment and labor supply and land reclamation.

      According to the EUB, the Canadian oil sands contained almost 174 billion barrels of established oil reserves as of the end of 2005. This is second only to Saudi Arabia’s 264 billion barrels and approximately six times the recoverable reserves in the United States. Beginning in the mid-1990’s, increasing global energy demand and improvements in mining and in-situ technology resulted in a significant increase in Canadian oil sands investments. This increased level of investment was also driven by a revised royalty regime adopted by the Government of Alberta in 1997, which was designed to accelerate investment in the oil sands.

      Outlook. According to the Canadian Association of Petroleum Producers, or CAPP, approximately $36 billion was invested in the oil sands from 1996 through 2004. Oil sands production has grown four-fold since 1990 and exceeded one million barrels per day in 2005. The NEB expects oil sands production to reach approximately 3.0 million barrels per day and account for over 75% of total Canadian oil production by 2015. By comparison, the Ghawar field in Saudi Arabia currently produces 4.5 million barrels per day, representing 6% of the world’s total production and almost 50% of Saudi Arabia’s production.

      According to the NEB’s 2006 Energy Market Assessment, between 2006 and 2015 approximately $95 billion is projected to be spent sustaining and expanding existing oil sands projects as well as developing new projects. According to the NEB, as of June 2006, there were 21 mining and upgrader projects in various stages, ranging from announcement to construction, with start-up dates through 2010. If all of these projects proceed as scheduled, the planned investment in new projects for 2006 through 2010 will exceed $38 billion and an additional $17 billion will be invested in project additions or existing projects over the same period. Beyond 2010, several new multibillion dollar projects and a number of smaller multimillion dollar projects are being considered by various oil sands operators.

      Pipeline Infrastructure and Construction. To transport the increased production expected from the oil sands and to provide natural gas as an energy source to the oil sands region, significant investment will be required to expand pipeline capacity. To date, there have been significant greenfield and expansion projects announced. We are in various stages of discussions to provide services for some of these projects. We believe that our service offerings and pipeline construction experience position us well to compete for the sizeable pipeline opportunities required for the expected growth in oil sands production.

5

Conventional Oil and Gas

      We provide services to conventional oil and gas producers, in addition to our work in the oil sands. The Canadian Energy Pipeline Association estimates that over $20 billion of pipeline investment in Canada will be required for the development of new long haul pipelines, feeder systems and other related pipeline construction. Conventional oil and gas producers require pipeline installation services in order to connect producing wells to nearby pipeline systems. According to CAPP, Canada is one of the world’s largest producers of oil and gas, producing approximately 2.5 million barrels of oil per day and approximately 17.1 billion cubic feet of natural gas per day. Canadian natural gas production is expected to increase with the development of arctic gas reserves. A producer group has been formed by Imperial Oil Limited, ConocoPhillips Canada Limited, Shell Canada and the Aboriginal Pipeline Group for the purpose of bidding for work on construction of a pipeline proposed to extend 1,220 kilometers (758 miles) from the MacKenzie River delta in the Beaufort Sea to existing natural gas pipelines in northern Alberta. Under the group’s proposal, Imperial Oil will lead the construction and operate the pipeline. We are actively working with Imperial Oil and have provided it with constructability and planning reviews. We hope to repeat our history of providing initial engineering assistance on projects and then subsequently being awarded contracts on these projects.

Minerals Mining

      According to the government agency Natural Resources Canada, Canada is also one of the largest mining nations in the world, producing approximately 70 different minerals and metals. In 2004, the mining and minerals processing industries contributed $41.8 billion to the Canadian economy, an amount equal to approximately 4.0% of GDP. The value of minerals produced (excluding petroleum and natural gas) reached $26.4 billion in 2005. According to the EUB, Canada ranks tenth in the world in total proven coal reserves. Alberta contains 70% of Canada’s coal reserves and, by volume, produces approximately half of the coal mined in Canada annually.

      The diamond mining industry in Canada is relatively new, having extracted diamonds for only eight years. According to Natural Resources Canada, the industry has grown from 2.6 million carats of production in 2000 to an estimated 12.3 million carats of production in 2005, representing a compounded annual growth rate of approximately 36%, and establishing Canada as the third largest diamond producing country in the world by value after Botswana and Russia. We believe Canadian diamond mining will continue to grow as existing mines increase production and new mine projects are developed. Outside the oil sands, we have identified the growing Canadian diamond mining industry as a primary target for new business opportunities.

      We intend to build on our core services and strong regional presence to capitalize on the opportunities in the minerals mining industries of Canada. According to Natural Resources Canada’s 2004 estimate, the capital and repair expenditures needed to support the minerals mining industry would be over $5.6 billion in 2005.

Commercial and Public Construction

      According to the government agency Statistics Canada, the Canadian commercial and public construction market was approximately $22 billion in 2005. According to the Alberta government, the commercial and public construction market in Alberta is expected to grow 3% annually through 2009. As a result of the significant activity in the energy sector, western Canada has experienced and is expected to continue to experience strong economic and population growth. The Alberta government has responded to the potential strain that this growth will have on public facilities and infrastructure by allocating approximately $6.5 billion to improvement and expansion projects from 2004 to 2007. This need for infrastructure to support growth, along with historic under investment in infrastructure, provides for a strong infrastructure spending outlook.

6

      The success of the energy industry in western Canada is also leading to increased commercial development in many urban centers in British Columbia and Alberta. According to the Alberta government, as of June 2006, the inventory of commercial, retail and residential projects in Alberta was valued at approximately $5.1 billion. These large expenditures will be further supplemented by the 2010 Olympic Winter Games, which will be held in the Vancouver area. The Organizing Committee of the Olympic Games estimates that the 2010 Olympic Winter Games will require an additional $3.0 billion in infrastructure and construction spending. The significant resources and capital intensive nature of the core infrastructure and construction services required to meet these demands, along with our strong local presence and significant regional experience, position us to implement our business model to capitalize on the large and growing infrastructure and construction demands of western Canada.

The Reorganization

      Concurrently with the consummation of this offering, NACG Holdings Inc., NACG Preferred Corp. and North American Energy Partners Inc. will amalgamate into one entity, North American Energy Partners Inc. This amalgamation, together with certain other reorganization transactions, are referred to collectively as the “Reorganization.” The voting common shares of North American Energy Partners Inc. after giving effect to the Reorganization are the shares being offered hereby. The consummation of the Reorganization is contingent upon receiving approval from the various shareholders of each of the amalgamating companies. This offering is contingent upon completion of the Reorganization. See “The Reorganization.”

Corporate Information

      We were incorporated under the Canada Business Corporations Act in October 2003 in connection with the acquisition on November 26, 2003 (the “Acquisition”) of certain businesses from Norama Ltd., our predecessor company. Our head office is located at Zone 3, Acheson Industrial Area, 2-53016 Highway 60, Acheson, Alberta, T7X 5A7, Canada, our registered office is located at 2700, 10155-102 Street, Edmonton, Alberta, T5J 4G8, Canada, and our telephone number is (780) 960-7171.

7

The Offering

Common shares offered by us	shares
Common shares offered by the selling shareholders	shares (                     shares if the underwriters’ over-allotment option is fully exercised)
Underwriters’ over-allotment option	shares
Common shares to be outstanding after this offering	shares
Common shares to be owned by the selling shareholders after this offering	shares (                     shares if the underwriters’ over-allotment option is fully exercised)
Use of proceeds	We estimate that our proceeds from this offering, after deducting underwriting discounts and commissions and estimated offering expenses payable by us, will be approximately US$           million, or C$                     million, assuming the shares are offered at US$                    , or C$                    , per share, respectively, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus. We will use the net proceeds of this offering to purchase equipment currently under operating leases, tender for all or a portion of our outstanding 9% senior secured notes and for other general corporate purposes, including potential acquisitions. See “Use of Proceeds.”
	We will not receive any proceeds from the sale of shares by the selling shareholders.
Proposed New York Stock Exchange symbol	“          ”
Proposed Toronto Stock Exchange symbol	“          ”

      Unless otherwise indicated, all information in this prospectus assumes the underwriters do not exercise their over-allotment option and references to the number of common shares to be outstanding after the completion of this offering do not include:

• 103,542 shares issuable upon exercise of outstanding stock options under our 2004 share option plan as of June 30, 2006; and

• 1,458 additional shares reserved for issuance under our 2004 share option plan.

Risk Factors

      Investing in our common shares involves substantial risk. Please read “Risk Factors” beginning on page 15 for a discussion of certain factors you should consider in evaluating an investment in our common shares.

8

Summary Consolidated Historical and Pro Forma Financial Data

      We were initially formed in October 2003 in connection with the Acquisition on November 26, 2003. As a result, the summary consolidated historical financial data presented below for the period from April 1, 2003 to November 25, 2003 is derived from the historical audited consolidated financial statements of Norama Ltd., our predecessor, included elsewhere in this prospectus. The summary consolidated historical financial data presented below for the period from November 26, 2003 to March 31, 2004 and as of and for the fiscal years ended March 31, 2005 and 2006 is derived from our audited consolidated financial statements included elsewhere in this prospectus. As a result of the Acquisition, the consolidated financial data for the period before November 26, 2003 is not necessarily comparable to the consolidated financial data for periods after November 25, 2003.

      The summary consolidated pro forma financial data presented below as of and for the fiscal year ended March 31, 2006 gives effect to the Reorganization and this offering and the use of proceeds therefrom and is derived from our unaudited pro forma financial statements. See “Unaudited Pro Forma Financial Information.” The summary consolidated pro forma financial data is presented for informational purposes only and does not purport to represent what our results of operations actually would have been had the transactions reflected occurred on the dates indicated or to project our results of operations for any future period.

      The information presented below should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” “Unaudited Pro Forma Financial Information” and our audited consolidated financial statements and related notes included elsewhere in this prospectus. All of the financial information presented below has been prepared in accordance with Canadian GAAP, which differs in certain significant respects from U.S. GAAP. For a discussion of the principal differences between Canadian GAAP and U.S. GAAP as they pertain to us, see note 23 to our consolidated financial statements included elsewhere in this prospectus.

		Historical												Pro Forma
		Predecessor
		April 1, 2003			November 26,
		to			2003 to			Year Ended March 31,
		November 25,			March 31,
		2003			2004			2005			2006			2006
		(Dollars in thousands, except per share amounts)
Statement of Operations Data:
Revenue(a)		$	250,652		$	127,611		$	357,323		$	492,237		$
	Project costs		156,976			83,256			240,919			308,949
	Equipment costs		43,484			13,686			52,831			64,832
	Equipment operating lease expense		10,502			1,430			6,645			16,405
	Depreciation		6,566			6,674			20,762			21,725
Gross profit			33,124			22,565			36,166			80,326
	General and administrative		7,783			6,065			22,873			30,903
	(Gain) loss on sale of capital assets		(49	)		131			494			(733	)
	Amortization of intangible assets		—			12,928			3,368			730
Operating income			25,390			3,441			9,431			49,426
	Management fee(b)		41,070			—			—			—
	Interest expense(c)		2,457			10,079			31,141			68,776
	Foreign exchange gain		(7	)		(661	)		(19,815	)		(13,953	)
	Other (income) expense		(367	)		(230	)		(421	)		1,118
	Realized and unrealized loss on derivative financial instruments		—			12,205			43,113			14,689
Loss before income taxes			(17,763	)		(17,952	)		(44,587	)		(21,204	)
	Income taxes (benefit)		(6,622	)		(5,670	)		(2,264	)		737
Net loss(d)		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)	$

9

		Historical												Pro Forma
		Predecessor
		April 1, 2003			November 26,
		to			2003 to			Year Ended March 31,
		November 25,			March 31,
		2003			2004			2005			2006			2006
		(Dollars in thousands, except per share amounts)
Net income (loss) per share:
	Basic and diluted				$	(13.28	)	$	(45.66	)	$	(23.62	)	$
Weighted average shares:
	Basic and diluted					925,000			926,986			928,740
Balance Sheet Data (end of period):
Cash					$	36,595		$	17,924		$	42,804		$
Property, plant and equipment, net						167,905			177,089			185,566
Total assets						489,974			540,155			587,011
Total debt(e)						313,798			310,402			314,959
Seller preferred shares(f)						35,000			35,000			35,000
Series A preferred shares(f)						—			—			375
Series B preferred shares(f)						—			—			42,193
Total shareholders’ equity(g)						80,355			38,829			18,111
Other Financial Data:
EBITDA(h)		$	(8,740	)	$	11,729		$	10,684		$	70,027		$
Consolidated EBITDA(h)			(8,747	)		23,410			34,479			71,686
Cash provided by (used in) operating activities			2,509			15,477			(4,833	)		33,864
Cash used in investing activities			(4,625	)		(364,514	)		(25,055	)		(22,168	)
Cash provided by financing activities			6,967			385,632			11,217			13,184
Capital expenditures, net of capital leases			5,234			2,501			25,679			29,015

(a)

Effective April 1, 2005, we changed our accounting policy regarding the recognition of revenue on claims. This change in accounting policy has been applied retroactively. Prior to this change, revenue from claims was included in total estimated contract revenue when awarded or received. After this change, claims are included in total estimated contract revenue, only to the extent that contract costs related to the claim have been incurred and when it is probable that the claim will result in a bona fide addition to contract value and can be reliably estimated. Those two conditions are satisfied when (1) the contract or other evidence provides a legal basis for the claim or a legal opinion is obtained providing a reasonable basis to support the claim, (2) additional costs incurred were caused by unforeseen circumstances and are not the result of deficiencies in our performance, (3) costs associated with the claim are identifiable and reasonable in view of work performed and (4) evidence supporting the claim is objective and verifiable. No profit is recognized on claims until final settlement occurs. This can lead to a situation where costs are recognized in one period and revenue is recognized when customer agreement is obtained or claim resolution occurs, which can be in subsequent periods. Historical claim recoveries should not be considered indicative of future claim recoveries. The change in policy resulted in an increase in claims revenue and unbilled revenue of approximately $12.9 million for the year ended March 31, 2006, but did not result in any adjustments to prior periods. Substantially all of the amounts recognized as claims revenue have been collected subsequent to March 31, 2006.

(b)

Management fees paid to the corporate shareholder of our predecessor company, Norama Ltd., represented fees for services rendered and were determined with reference to taxable income. Subsequent to the Acquisition on November 26, 2003, these fees are no longer paid.

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(c) Interest expense consists of the following (in thousands):

	Historical								Pro Forma
	Predecessor
	April 1, 2003		November 26,
	to		2003 to		Year Ended March 31,
	November 25,		March 31,
	2003		2004		2005		2006		2006
Interest on senior notes	$	—	$	8,096	$	23,189	$	28,838
Interest on senior secured credit facility		599		1,089		3,274		564
Change in redemption value of Series B preferred shares		—		—		—		34,668
Amortization of deferred financing costs		—		814		2,554		3,338
Other		1,858		80		2,124		1,368
	$	2,457	$	10,079	$	31,141	$	68,776

(d) Our consolidated financial statements have been prepared in accordance with Canadian GAAP, which differs in certain material respects from U.S. GAAP. If U.S. GAAP were employed, our net loss would be adjusted as follows (in thousands):

		Historical												Pro Forma
		Predecessor
					November 26,
		April 1, 2003 to			2003 to			Year Ended March 31,
		November 25,			March 31,
		2003			2004			2005			2006			2006
Net loss (as reported)		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)
Capitalized interest(1)			—			—			—			847
Amortization using effective interest method(2)			—			—			—			590
Realized and unrealized loss on derivative financial instruments(3)			—			—			—			(484	)
Loss before income taxes			(11,141	)		(12,282	)		(42,323	)		(20,988	)
Income taxes:
	Deferred income taxes		—			—			—			—
Net loss – U.S. GAAP		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(20,988	)
Net loss per share – basic and diluted – U.S. GAAP					$	(13.28	)	$	(45.66	)	$	(22.60	)

(1) U.S. GAAP requires capitalization of interest costs as part of the historical cost of acquiring certain qualifying assets that require a period of time to prepare for their intended use. This is not required under Canadian GAAP.

(2) Under Canadian GAAP, we defer and amortize debt issuance costs on a straight-line basis over the stated term of the related debt. Under U.S. GAAP, we are required to amortize financing costs over the stated term of the related debt using the effective interest method resulting in a consistent interest rate over the term of the debt.

(3) U.S. GAAP requires that every derivative instrument (including certain derivative instruments embedded in other contracts and debt instruments) be recorded in the balance sheet as either an asset or liability measured at its fair value. The issuances of our 8³/4 % senior notes and 9% senior secured notes both included certain contingent embedded derivatives which provided for the acceleration of redemption by the holder at a premium in certain instances. These embedded derivatives met the criteria for bifurcation from the debt contract and separate measurement at fair value. Under U.S. GAAP, the embedded derivatives have been measured at fair value and classified as part of the carrying amount of the senior notes on the consolidated balance sheet, with changes in the fair value being recorded in net income as realized and unrealized (gain) loss on derivative financial instruments for the period. Under Canadian GAAP, separate accounting of embedded derivatives from the host contract is not permitted.

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(e) Total debt as of March 31, 2006 consists of the following (in thousands):

Revolving credit facility	$	—
Obligations under capital leases		10,952
9% senior secured notes due 2010		70,587
83/4 % senior notes due 2011		233,420
	$	314,959

	Our 83/4% senior notes are reflected above at the current exchange rate at each balance sheet date. We have entered into cross-currency and interest rate swaps, which represent an economic hedge of the 83/4 % senior notes. At maturity, we will be required to pay $263.0 million in order to retire these senior notes as a result of the swaps. This amount is the fixed exchange rate of C$1.315 = US$1.00 established as of November 26, 2003, the inception of the swap contracts.
(f)	The Series A preferred shares of NACG Preferred Corp. are referred to as the Seller preferred shares. The Series A preferred shares of North American Energy Partners Inc. are referred to as the Series A preferred shares. The Series B preferred shares of North American Energy Partners Inc. are referred to as the Series B preferred shares.
(g)	The cumulative effect of material differences between Canadian and U.S. GAAP on shareholders’ equity is as follows (in thousands):

	March 31,		March 31,		March 31,
	2004		2005		2006
Shareholders’ equity (as reported) – Canadian GAAP	$	80,355	$	38,829	$	18,111
Capitalized interest(1)		—		—		847
Amortization using effective interest method(2)		—		—		590
Realized and unrealized loss on derivative financial instruments(3)		—		—		(484	)
Excess of fair value of amended Series B preferred shares over carrying value of original Series B preferred shares(4)		—		—		(3,707	)
Shareholders’ equity – U.S. GAAP	$	80,355	$	38,829	$	15,357

(1) U.S. GAAP requires capitalization of interest costs as part of the historical cost of acquiring certain qualifying assets that require a period of time to prepare for their intended use. This is not required under Canadian GAAP.

(2) Under Canadian GAAP, we defer and amortize debt issuance costs on a straight-line basis over the stated term of the related debt. Under U.S. GAAP, we are required to amortize financing costs over the stated term of the related debt using the effective interest method resulting in a consistent interest rate over the term of the debt.

(3) U.S. GAAP requires that every derivative instrument (including certain derivative instruments embedded in other contracts and debt instruments) be recorded in the balance sheet as either an asset or liability measured at its fair value. The issuances of our 8³/4 % senior notes and 9% senior secured notes both included certain contingent embedded derivatives which provided for the acceleration of redemption by the holder at a premium in certain instances. These embedded derivatives met the criteria for bifurcation from the debt contract and separate measurement at fair value. Under U.S. GAAP, the embedded derivatives have been measured at fair value and classified as part of the carrying amount of the senior notes on the consolidated balance sheet, with changes in the fair value being recorded in net income as realized and unrealized (gain) loss on derivative financial instruments for the period. Under Canadian GAAP, separate accounting of embedded derivatives from the host contract is not permitted.

(4) Prior to the modification of the terms of the Series B preferred shares, there were no differences between Canadian GAAP and U.S. GAAP related to the Series B preferred shares. As a result of the modification of terms of the Series B preferred shares on March 30, 2006, under Canadian GAAP, we continue to classify the Series B preferred shares as a liability and accrete the carrying amount to the December 31, 2011 redemption value of $69.6 million using the effective interest method. Under U.S. GAAP, the Company recognized the fair value of the Series B preferred shares as minority interest as such amount was recognized as temporary equity in the accounts of North American Energy Partners Inc., the issuer of the shares, in accordance with EITF Topic D-98 and recognized a charge of $3.7 million to retained earnings for the difference between the fair value and the carrying amount of the Series B preferred shares on the modification date. Under U.S. GAAP, we accrete the initial fair value of the Series B preferred shares of $45.9 million to the December 31, 2011 redemption value of $69.6 million using the effective interest method, which is consistent with the treatment of the

12

Series B preferred shares as temporary equity in the financial statements of North American Energy Partners Inc. The accretion charge is recognized as a charge to minority interest as opposed to retained earnings in the accounts of North American Energy Partners Inc. under U.S. GAAP and interest expense in our financial statements under Canadian GAAP.

(h)

EBITDA is calculated as net income (loss) before interest expense, income taxes, depreciation and amortization. Consolidated EBITDA is defined as EBITDA, excluding the effects of foreign exchange gain or loss, realized and unrealized gain or loss on derivative financial instruments and non-cash stock-based compensation expense. We believe that EBITDA is a meaningful measure of the performance of our business because it excludes items, such as depreciation and amortization, interest and taxes, that are not directly related to the operating performance of our business. Management reviews EBITDA to determine whether capital assets are being allocated efficiently. In addition, our revolving credit facility requires us to maintain a minimum Consolidated EBITDA. Non-compliance with this financial covenant could result in our being required to immediately repay all amounts outstanding under our revolving credit facility. We are required to maintain a minimum Consolidated EBITDA through December 31, 2006 of $65.5 million, with this minimum amount increasing periodically until maturity. However, EBITDA and Consolidated EBITDA are not measures of performance under Canadian GAAP or U.S. GAAP and our computations of EBITDA and Consolidated EBITDA may vary from others in our industry. EBITDA and Consolidated EBITDA should not be considered as alternatives to operating income or net income as measures of operating performance or cash flows as measures of liquidity. EBITDA and Consolidated EBITDA have important limitations as analytical tools, and you should not consider them in isolation, or as substitutes for analysis of our results as reported under Canadian GAAP or U.S. GAAP. For example, EBITDA and Consolidated EBITDA:

•  do not reflect our cash expenditures or requirements for capital expenditures or capital commitments;

•  do not reflect changes in, or cash requirements for, our working capital needs;

•  do not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt;

•  exclude tax payments that represent a reduction in cash available to us; and

•  do not reflect any cash requirements for assets being depreciated and amortized that may have to be replaced in the future.

In addition, Consolidated EBITDA excludes foreign exchange gains and losses and unrealized and realized gains and losses on derivative financial instruments, which, in the case of unrealized losses, may ultimately result in a liability that will need to be paid and, in the case of realized losses, represents an actual use of cash during the period.

13

A reconciliation of net loss to EBITDA as set forth in our consolidated statements of operations is as follows:

		Historical												Pro Forma
		Predecessor
		April 1, 2003			November 26,
		to			2003 to			Year Ended March 31,
		November 25,			March 31,
		2003			2004			2005			2006			2006
		(Dollars in thousands)
Net loss		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)	$
Adjustments:
	Depreciation		6,566			6,674			20,762			21,725
	Amortization		—			12,928			3,368			730
	Interest expense		2,457			10,079			31,141			68,776
	Income taxes (benefit)		(6,622	)		(5,670	)		(2,264	)		737
EBITDA		$	(8,740	)	$	11,729		$	10,684		$	70,027		$

      A reconciliation of EBITDA to Consolidated EBITDA is as follows:

		Historical												Pro Forma
		Predecessor
		April 1, 2003			November 26,
		to			2003 to			Year Ended March 31,
		November 25,			March 31,
		2003			2004			2005			2006			2006
		(Dollars in thousands)
EBITDA		$	(8,740	)	$	11,729		$	10,684		$	70,027		$
Adjustments:
	Foreign exchange gain		(7	)		(661	)		(19,815	)		(13,953	)
	Realized and unrealized loss on derivative financial instruments		—			12,205			43,113			14,689
	Non-cash stock-based compensation expense		—			137			497			923
Consolidated EBITDA		$	(8,747	)	$	23,410		$	34,479		$	71,686		$

14

RISK FACTORS

      An investment in our common shares entails a high degree of risk. You should carefully consider the following risk factors and other information presented in this prospectus before deciding to purchase our common shares. If the events underlying these risks actually occur, our business, financial condition and results of operations could be materially adversely affected and you may lose all or part of your investment. The risks described below are not the only ones facing us. Additional risks not presently known to us or that we currently deem immaterial may also impair our business operations.

Risks Related to Our Business

Anticipated major projects in the oil sands may not materialize.

      Notwithstanding the NEB’s estimates regarding new investment and growth in the Canadian oil sands, planned and anticipated projects in the oil sands and other related projects may not materialize. The underlying assumptions on which the projects are based are subject to significant uncertainties, and actual investments in the oil sands could be significantly less than estimated. Projected investments and new projects may be postponed or cancelled for any number of reasons, including among others:

•  changes in the perception of the economic viability of these projects;

•  shortage of pipeline capacity to transport production to major markets;

•  lack of sufficient governmental infrastructure to support growth;

•  shortage of skilled workers in this remote region of Canada; and

•  cost overruns on announced projects.

Changes in our customers’ perception of oil prices over the long-term could cause our customers to defer, reduce or stop their investment in oil sands projects, which would in turn reduce our revenue from those customers.

      Due to the amount of capital investment required to build an oil sands project, or construct a significant expansion to an existing project, investment decisions by oil sands operators are based upon long-term views of the economic viability of the project. Economic viability is dependent upon the anticipated revenues the project will produce, the anticipated amount of capital investment required and the anticipated cost of operating the project. One of the most important considerations is the price of oil. The long-term outlook for the price of oil is influenced by many factors, including the condition of developed and developing economies and the resulting demand for oil and gas, the level of supply of oil and gas, the actions of the Organization of Petroleum Exporting Countries, governmental regulation, political conditions in oil producing nations, including those in the Middle East, war or the threat of war in oil producing regions and the availability of fuel from alternate sources. If our customers believe the long-term outlook for the price of oil is not favorable or believe oil sands projects are not viable for any other reason, they may delay, reduce or cancel plans to construct new oil sands projects or expansions to existing projects. Delays, reductions or cancellations of major oil sands projects could have a material adverse impact on our financial condition and results of operations.

Insufficient pipeline and refining capacity could cause our customers to delay, reduce or cancel plans to construct new oil sands projects or expansions to existing projects, which would, in turn, reduce our revenue from those customers.

      For our customers to operate successfully in the oil sands, they must be able to transport the bitumen produced to upgrading facilities and transport the upgraded oil to refineries. Some oil sands projects have upgraders at the mine site and others transport bitumen to upgraders located elsewhere. While current pipeline and upgrading capacity is sufficient to upgrade current bitumen production and transport such production to refineries, future increases in production from new oil sands projects and expansions to

15

existing projects will require increased upgrading and pipeline capacity. If these increases do not materialize, whether due to inadequate economics for the sponsors of such projects, shortages of labor or materials or any other reason, our customers may be unable to efficiently deliver increased production to market and may therefore delay, reduce or cancel planned capital investment. Such delays, reductions or cancellations of major oil sands projects would adversely affect our prospects and could have a material adverse impact on our financial condition and results of operations.

Lack of sufficient governmental infrastructure to support the growth in the oil sands region could cause our customers to delay, reduce or cancel their future expansions, which would, in turn, reduce our revenue from those customers.

      The development in the oil sands region has put a great strain on the existing government infrastructure, necessitating substantial improvements to accommodate the growth in the region. The local government having responsibility for a majority of the oil sands region has been exceptionally impacted by this growth and is not currently in a position to provide the necessary additional infrastructure. In an effort to delay further development until infrastructure funding issues are resolved, the local governmental authority has sought to intervene in a hearing in July 2006 to consider an application by a major oil sands company to the EUB for approval to expand its operations and may take similar action with respect to any future applications. If the necessary infrastructure is not put in place, future growth of our customers’ operations could be delayed, reduced or canceled which could in turn adversely affect our prospects and could have a material adverse impact on our financial condition and results of operations.

Shortages of qualified personnel or significant labor disputes could adversely affect our business.

      Alberta, and in particular the oil sands area, has had and continues to have a shortage of skilled labor and other qualified personnel. New mining projects in the area will only make it more difficult for us and our customers to find and hire all the employees required to work on these projects. We are continuously seeking ways to hire the people we need, including more project managers, trades people and other employees with the required skills. We have expanded our efforts to find qualified candidates outside of Canada who might relocate to our area. In addition, we have undertaken more extensive training of existing employees and we are enhancing our use of technology and developing programs to provide better working conditions. We believe the labor shortage, which affects us and all of our major customers, will continue to be a challenge for everyone in the mining and oil and gas industries in western Canada for the foreseeable future. If we are not able to recruit and retain enough employees with the appropriate skills, we may be unable to maintain our customer service levels, and we may not be able to satisfy any increased demand for our services. This, in turn, could have a material adverse effect on our business, financial condition and results of operations. If our customers are not able to recruit and retain enough employees with the appropriate skills, they may be unable to develop projects in the oil sands area.

      Substantially all of our hourly employees are subject to collective bargaining agreements to which we are a party or are otherwise subject. Any work stoppage resulting from a strike or lockout could have a material adverse effect on our business, financial condition and results of operations. In addition, our customers employ workers under collective bargaining agreements. Any work stoppage or labor disruption experienced by our key customers could significantly reduce the amount of our services that they need.

Cost overruns by our customers on their projects may cause our customers to terminate future projects or expansions which could adversely affect the amount of work we receive from those customers.

      Oil sands development projects require substantial capital expenditures. In the past, several of our customers’ projects have experienced significant cost overruns, impacting their returns. As new projects are contemplated or built, if cost overruns continue to challenge our customers, they could reassess future projects and expansions which could adversely affect the amount of work we receive from our customers.

16

Our ability to grow our operations in the future may be hampered by our inability to obtain long lead time equipment, particularly tires, which are currently in limited supply.

      Our ability to grow our business is in part dependent upon obtaining equipment on a timely basis. Due to the long production lead times of our suppliers of large mining equipment, we must forecast our demand for equipment many months or even years in advance. If we fail to forecast accurately, we could suffer equipment shortages or surpluses, which could have a material adverse impact on our financial condition and results of operations.

      Global demand for tires of the size and specifications we require is exceeding the available supply. For example, we currently have four trucks that we cannot utilize because we cannot get tires of the appropriate size and specifications. We expect the supply/demand imbalance for certain tires to continue for several years. Our inability to procure tires to meet the demands for our existing fleet as well as to secure tires to meet new demand for our services could have an adverse effect on our ability to grow our business.

Our customer base is concentrated, and the loss of or a significant reduction in business from a major customer could adversely impact our financial condition.

      We receive most of our revenues from providing services to a small number of major oil sands mining companies. Revenue from our five largest customers represented approximately 68% and 69% of our total revenue for the fiscal years ended March 31, 2005 and 2006, respectively, and those customers are expected to continue to account for a significant percentage of our revenues in the future. For the year ended March 31, 2006, CNRL, Syncrude and Grande Cache Coal Corp. were our three largest customers, accounting for 32%, 16% and 10%, respectively, of our total revenue. For the last five fiscal years, the majority of our revenues in our pipeline business resulted from work performed for EnCana. If we lose or experience a significant reduction of business from one or more of our significant customers, we may not be able to replace the lost work with work from other customers. Our long-term contracts typically allow our customers to unilaterally reduce or eliminate the work which we are to perform under the contract. Our contracts generally allow the customer to terminate the contract without cause. The loss of or significant reduction in business with one or more of our major customers, whether as a result of completion of a contract, early termination or failure or inability to pay amounts owed to us, could have a material adverse effect on our business and results of operations.

Because most of our customers are Canadian energy companies, a downturn in the Canadian energy industry could result in a decrease in the demand for our services.

      Most of our customers are Canadian energy companies. A downturn in the Canadian energy industry could cause our customers to slow down or curtail their current production and future expansions which would, in turn, reduce our revenue from those customers. Such a delay or curtailment could have a material adverse impact on our financial condition and results of operations.

Lump sum and unit-price contracts expose us to losses when our estimates of project costs are too low or when we fail to perform within our cost estimates.

      Approximately 51% and 58% of our revenue for the fiscal years ended March 31, 2005 and 2006, respectively, was derived from lump sum and unit-price contracts. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Critical Accounting Policies and Estimates – Revenue Recognition.” Lump sum and unit-price contracts require us to guarantee the price of the services we provide and thereby expose us to losses if our estimates of project costs are lower than the actual project costs we incur. Our profitability under these contracts is dependent upon our ability to accurately predict the costs associated with our services. The costs we actually incur may be affected by a

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variety of factors beyond our control. Factors that may contribute to actual costs exceeding estimated costs and which therefore affect profitability include, without limitation:

•  site conditions differing from those assumed in the original bid;

•  scope modifications during the execution of the project;

•  the availability and cost of skilled workers in the geographic location of the project;

•  the availability and proximity of materials;

•  unfavorable weather conditions hindering productivity;

•  inability or failure of our customers to perform their contractual commitments;

•  equipment availability and productivity and timing differences resulting from project construction not starting on time; and

•  the general coordination of work inherent in all large projects we undertake.

      When we are unable to accurately estimate the costs of lump sum and unit-price contracts, or when we incur unrecoverable cost overruns, the related projects result in lower margins than anticipated or may incur losses, which could adversely impact our results of operations, financial condition and cash flow. For example, on a recent major site preparation and underground installation contract, a combination of unfavorable weather conditions hindering productivity, higher than expected costs due to labor shortages, schedule acceleration and higher than expected costs resulting from underestimation of the project’s complexity at the time the contract bid was prepared led to significant cost overruns. This had a significant impact on our operations. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Segmented Results of Operations – Fiscal Year Ended March 31, 2006 Compared to Fiscal Year Ended March 31, 2005 – Mining and Site Preparation.”

Until we establish and maintain effective internal controls over financial reporting, we cannot assure you that we will have appropriate procedures in place to eliminate future financial reporting inaccuracies and avoid delays in financial reporting.

      North American Energy Partners Inc., our subsidiary prior to the Reorganization, has financial reporting obligations arising from the indentures governing the 8³/4% senior notes and 9% senior secured notes. NACG Holdings Inc. is a holding company for North American Energy Partners Inc. and the two companies will amalgamate as part of the Reorganization. We have had continuing problems providing accurate and timely financial information and reports and have restated North American Energy Partners’ financial statements three times since the beginning of our 2005 fiscal year. In April of 2005, we had to restate North American Energy Partners’ financial statements for the first and second quarters of fiscal 2005 to properly account for costs incurred in those quarters. During fiscal 2006, we had to restate North American Energy Partners’ financial statements for each period after November 26, 2003 to eliminate the impact of hedge accounting with respect to the derivative financial instruments. We also had to restate North American Energy Partners’ financial statements for the first quarter of fiscal 2006 to correct the accounting for various aspects of the refinancing transactions which occurred in May 2005. Each of these restatements resulted in our inability to file North American Energy Partners’ financial statements within the deadlines imposed by covenants in the indentures governing our 8³/4 % senior notes and 9% senior secured notes. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Restatements.”

      In connection with the audit of our fiscal 2006 financial statements, our auditors identified a number of significant weaknesses (as defined under Canadian auditing standards) in our financial reporting processes and internal controls. We are currently addressing these deficiencies through the implementation of the requirements of Section 404 of the Sarbanes-Oxley Act of 2002 and Multilateral Instrument 52-109 in Canada and with a focused effort on the high risk areas. For example, we started a procurement project in the spring of 2005 to implement the purchase order functionality in our financial systems and to train

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our staff in the effective use of purchase orders to track our commitments and to record our expenses in a timely manner. We also added to our finance staff, and in particular we now have in-house GAAP expertise. There are a number of initiatives that still need to be completed, and there can be no assurance that we will be able to generate accurate financial reports in a timely manner. Failure to do so would cause us to breach the reporting requirements of U.S. and Canadian securities regulations as well as the covenants applicable to our indebtedness. This could, in turn, have a material adverse effect on our business and financial condition. Until we establish and maintain effective internal controls and procedures for financial reporting, we may not have appropriate measures in place to eliminate financial statement inaccuracies and avoid delays in financial reporting.

If, as of the end of our 2008 fiscal year, we are unable to assert that our internal control over financial reporting is effective, or if our auditors are unable to confirm our assessment, investors could lose confidence in our reported financial information, and the trading price of our common shares and our business could be adversely affected.

      We are in the process of documenting, and plan to test during the current and next fiscal year, our internal control procedures in order to satisfy the requirements of Section 404 of the Sarbanes-Oxley Act. Commencing with our fiscal year ending March 31, 2008, the Sarbanes-Oxley Act requires an annual assessment by management of the effectiveness of our internal control over financial reporting and an attestation report by our independent auditors addressing this assessment. We cannot be certain at this time that we will be able to comply with all of our reporting obligations and successfully complete the procedures, certification and attestation requirements of Section 404 of the Sarbanes-Oxley Act in a timely manner. During the course of our testing we may identify deficiencies that we may not be able to remedy in time to meet the deadline imposed by the Sarbanes-Oxley Act for compliance with the requirements of Section 404. Effective internal control over financial reporting is important to help produce reliable financial reports and to prevent financial fraud. If we are unable to assert that our internal control over financial reporting is effective as of the end of our 2008 fiscal year, or if our independent auditors are unable to attest that our management’s report is fairly stated or are unable to express an opinion on management’s evaluation or on the effectiveness of our internal controls, we could be subject to heightened regulatory scrutiny, investors could lose confidence in our reported financial information and the trading price of our common shares and our ability to maintain confidence in our business could be adversely affected.

Our substantial debt could adversely affect us, make us more vulnerable to adverse economic or industry conditions and prevent us from fulfilling our debt obligations.

      We have a substantial amount of debt outstanding and significant debt service requirements. As of March 31, 2006, we had outstanding approximately $315.0 million of debt, including approximately $81.5 million of secured indebtedness and capital leases. We also have cross-currency and interest rate swaps with a balance sheet liability of $63.6 million as of March 31, 2006 and which are secured equally and ratably with our revolving credit facility. We also had $18.0 million of outstanding, undrawn letters of credit, which reduce the amount of available borrowings under our revolving credit facility. Our substantial indebtedness could have serious consequences, such as:

•  limiting our ability to obtain additional financing to fund our working capital, capital expenditures, debt service requirements, potential growth or other purposes;

•  limiting our ability to use operating cash flow in other areas of our business;

•  limiting our ability to post surety bonds required by some of our customers;

•  placing us at a competitive disadvantage compared to competitors with less debt;

•  increasing our vulnerability to, and reducing our flexibility in planning for, adverse changes in economic, industry and competitive conditions; and

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•  increasing our vulnerability to increases in interest rates because borrowings under our revolving credit facility and payments under some of our equipment leases are subject to variable interest rates.

      The potential consequences of our substantial indebtedness make us more vulnerable to defaults and place us at a competitive disadvantage. Further, if we do not have sufficient earnings to service our debt, we would need to refinance all or part of our existing debt, sell assets, borrow more money or sell securities, none of which we can guarantee we will be able to achieve on commercially reasonable terms, if at all.

The terms of our debt agreements may restrict our current and future operations, particularly our ability to respond to changes in our business or take certain actions.

      Our revolving credit facility and the indentures governing our notes limit, among other things, our ability and the ability of our subsidiaries to:

•  incur or guarantee additional debt, issue certain equity securities or enter into sale and leaseback transactions;

•  pay dividends or distributions on our shares or repurchase our shares, redeem subordinated debt or make other restricted payments;

•  incur dividend or other payment restrictions affecting certain of our subsidiaries;

•  issue equity securities of subsidiaries;

•  make certain investments or acquisitions;

•  create liens on our assets;

•  enter into transactions with affiliates;

•  consolidate, merge or transfer all or substantially all of our assets; and

•  transfer or sell assets, including shares of our subsidiaries.

      Our revolving credit facility and some of our equipment lease programs also require us, and our future credit facilities may require us, to maintain specified financial ratios and satisfy specified financial tests, some of which become more restrictive over time. Our ability to meet these financial ratios and tests can be affected by events beyond our control, and we may be unable to meet those tests.

      As a result of these covenants, our ability to respond to changes in business and economic conditions and to obtain additional financing, if needed, may be significantly restricted, and we may be prevented from engaging in transactions that might otherwise be considered beneficial to us. The breach of any of these covenants could result in a default under our revolving credit facility or any future credit facilities or under the indentures governing our notes. Upon the occurrence of an event of default under our revolving credit facility or future credit facilities, the lenders could elect to stop lending to us or declare all amounts outstanding under such credit facilities to be immediately due and payable. Similarly, upon the occurrence of an event of default under the indentures governing our notes, the outstanding principal and accrued interest on the notes may become immediately due and payable. If amounts outstanding under such credit facilities and indentures were to be accelerated, or if we were not able to borrow under our revolving credit facility, we could become insolvent or be forced into insolvency proceedings and you could lose your investment in us.

      Between March 31, 2004 and May 19, 2005, it was necessary to obtain a series of waivers and amend our then-existing credit agreement to avoid or to cure our default of various covenants contained in that credit agreement. We ultimately replaced that credit agreement with a new credit agreement on May 19, 2005, which we replaced with our current amended and restated credit agreement on July 19, 2006.

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      Our inability to file North American Energy Partners’ financial statements for the periods ended December 31, 2004, March 31, 2005 and September 30, 2005 with the SEC within the deadlines imposed by covenants in the indentures governing our 8³/4 % senior notes and our 9% senior secured notes caused us to be out of compliance with such covenants. In each case, we filed these financial statements before the lack of compliance became an event of default under the indentures.

We may not be able to generate sufficient cash flow to meet our debt service and other obligations due to events beyond our control.

      For the year ended March 31, 2005, we had negative operating cash flow of $4.8 million. Our ability to generate sufficient operating cash flow to make scheduled payments on our indebtedness and meet other capital requirements will depend on our future operating and financial performance. Our future performance will be impacted by a range of economic, competitive and business factors that we cannot control, such as general economic and financial conditions in our industry or the economy generally.

      A significant reduction in operating cash flows resulting from changes in economic conditions, increased competition, reduced work or other events could increase the need for additional or alternative sources of liquidity and could have a material adverse effect on our business, financial condition, results of operations, prospects and our ability to service our debt and other obligations. If we are unable to service our indebtedness, we will be forced to adopt an alternative strategy that may include actions such as selling assets, restructuring or refinancing our indebtedness, seeking additional equity capital or reducing capital expenditures. We may not be able to effect any of these alternative strategies on satisfactory terms, if at all, or they may not yield sufficient funds to make required payments on our indebtedness.

Currency rate fluctuations could adversely affect our ability to borrow under our revolving credit facility and to repay our 8³/4% senior notes and 9% senior secured notes and may affect the cost of goods we purchase.

      Our ability to borrow under our revolving credit facility is limited, in part, by the mark-to-market liabilities under our interest rate and cross-currency swap agreements. If the Canadian dollar increases in value against the U.S. dollar, as it has in the recent past, the mark-to-market liabilities under the swap agreements will increase, which may adversely affect our liquidity or even cause a default under our revolving credit facility if the mark-to-market liabilities were to increase to the extent that the amount of outstanding borrowings and letters of credit would exceed the reduced availability under our revolving credit facility.

      We have entered into cross-currency and interest rate swaps that represent economic hedges of our 8³/4% senior notes, which are denominated in U.S. dollars. The current exchange rate between the Canadian and U.S. dollars as compared to the rate implicit in the swap agreement has resulted in a large liability on the balance sheet under the caption “derivative financial instruments.” If the Canadian dollar increases in value or remains at its current value against the U.S. dollar, then if we repay the 8³/4 % senior notes prior to their maturity in 2011, we will have to pay this liability.

      Substantially all of our revenues and costs are incurred in Canadian dollars. However, the obligation represented by our 9% senior secured notes is denominated in U.S. dollars. If the Canadian dollar loses value against the U.S. dollar while other factors remain constant, our ability to pay interest and principal on these notes may be diminished.

      Exchange rate fluctuations may also cause the price of goods to increase or decrease for us. For example, a decrease in the value of the Canadian dollar compared to the U.S. dollar would proportionately increase the cost of equipment which is sold to us or priced in U.S. dollars. Between January 1, 2006 and June 30, 2006, the Canadian dollar/U.S. dollar exchange rate varied from a high of 0.9100 Canadian dollars per U.S. dollar to a low of 0.8528 Canadian dollars per U.S. dollar.

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If we are unable to obtain surety bonds or letters of credit required by some of our customers, our business could be impaired.

      We are at times required to post a bid or performance bond issued by a financial institution, known as a surety, to secure our performance commitments. The surety industry experiences periods of unsettled and volatile markets, usually in the aftermath of substantial loss exposures or corporate bankruptcies with significant surety exposure. Historically, these types of events have caused reinsurers and sureties to reevaluate their committed levels of underwriting and required returns. If for any reason, whether because of our financial condition, our level of secured debt or general conditions in the surety bond market, our bonding capacity becomes insufficient to satisfy our future bonding requirements, our business and results of operations could be adversely affected.

      Some of our customers require letters of credit to secure our performance commitments. Our revolving credit facility provides for the issuance of letters of credit up to $55.0 million, and at June 30, 2006, we had $18.0 million of issued letters of credit outstanding. One of our major contracts allows the customer to request up to $50.0 million in letters of credit. While this level has not been requested to date, we would either have to lower other letters of credit or cash collateralize other obligations to provide this amount of letters of credit. If we were unable to provide letters of credit in the amount requested by this customer, we could lose business from such customer and our business and cash flow would be adversely affected. In addition, the company that provides our surety bonds currently requires $10.0 million of security in the form of either letters of credit, cash collateralization or a combination thereof. If our capacity to issue letters of credit under our revolving credit facility and our cash on hand are insufficient to satisfy our customers and surety, our business and results of operations could be adversely affected.

A change in strategy by our customers to reduce outsourcing could adversely affect our results.

      Outsourced mining and site preparation services constitute a large portion of the work we perform for our customers. For example, our mining and site preparation project revenues constituted approximately 74% of our revenues in each of the fiscal years ended March 31, 2005 and March 31, 2006. The election by one or more of our customers to perform some or all of these services themselves, rather than outsourcing the work to us, could have a material adverse impact on our business and results of operations.

Our operations are subject to weather-related factors that may cause delays in our completion of projects.

      Because our operations are located in western Canada and northern Ontario, we are often subject to extreme weather conditions. While our operations are not significantly affected by normal seasonal weather patterns, extreme weather, including heavy rain and snow, can cause us to delay the completion of a project, which could adversely impact our results of operations.

We are dependent on our ability to lease equipment, and a tightening of this form of credit could adversely affect our ability to bid for new work and/or supply some of our existing contracts.

      A portion of our equipment fleet is currently leased from third parties. Further, we anticipate leasing substantial amounts of equipment to perform the work on contracts for which we have been engaged in the upcoming year, particularly the overburden removal contract with CNRL. Other projects on which we are engaged in the future may require us to lease additional equipment. If equipment lessors are unable or unwilling to provide us with the equipment we need to perform our work, our results of operations will be materially adversely affected.

Competitors may outbid us on major projects that are awarded based on bid proposals.

      Approximately 80% of the major projects that we pursue are awarded to us based on bid proposals, and projects are typically awarded based in large part on price. We often compete for these projects against companies that have substantially greater financial and other resources than we do and therefore can better bear the risk of underpricing projects. We also compete against smaller competitors that may

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have lower overhead cost structures and, therefore, may be able to provide their services at lower rates than we can. In addition, we expect the growth in the oil sands region will attract new and sometimes larger competitors to enter the region and compete against us for projects. Our business may be adversely impacted to the extent that we are unable to successfully bid against these companies.

A significant amount of our revenue is generated by providing non-recurring services.

      More than 60% of our revenue for the year ended March 31, 2006 was derived from projects which we consider to be non-recurring. This revenue primarily relates to site preparation and piling services provided for the construction of extraction, upgrading and other oil sands mining infrastructure projects. Future revenues from these types of services will depend upon customers expanding existing mines and developing new projects.

Penalty clauses in our customer contracts could expose us to losses if total project costs exceed original estimates or if projects are not completed by specified completion date milestones.

      A portion of our revenue is derived from contracts which have performance incentives and penalties depending on the total cost of a project as compared to the original estimate. We could incur significant penalties based on cost overruns. In addition, the total project cost as defined in the contract may include not only our work, but also work performed by other contractors. As a result, we could incur penalties due to work performed by others over which we have no control. We may also incur penalties if projects are not completed by specified completion date milestones. These penalties, if incurred, could have a significant impact on our profitability under these contracts.

Demand for our services may be adversely impacted by regulations affecting the energy industry.

      Our principal customers are energy companies involved in the development of the oil sands and in natural gas production. The operations of these companies, including their mining operations in the oil sands, are subject to or impacted by a wide array of regulations in the jurisdictions where they operate, including those directly impacting mining activities and those indirectly affecting their businesses, such as applicable environmental laws. As a result of changes in regulations and laws relating to the energy production industry, including the operation of mines, our customers’ operations could be disrupted or curtailed by governmental authorities. The high cost of compliance with applicable regulations may cause customers to discontinue or limit their operations, and may discourage companies from continuing development activities. As a result, demand for our services could be substantially affected by regulations adversely impacting the energy industry.

Environmental laws and regulations may expose us to liability arising out of our operations or the operations of our customers.

      Our operations are subject to numerous environmental protection laws and regulations that are complex and stringent. We regularly perform work in and around sensitive environmental areas such as rivers, lakes and forests. Significant fines and penalties may be imposed on us or our customers for non-compliance with environmental laws and regulations, and our contracts generally require us to indemnify our customers for environmental claims suffered by them as a result of our actions. In addition, some environmental laws impose strict, joint and several liability for investigative and remediation costs in relation to releases of harmful substances. These laws may impose liability without regard to negligence or fault. We also may be subject to claims alleging personal injury or property damage if we cause the release of, or any exposure to, harmful substances.

      We own or lease, and operate, several properties that have been used for a number of years for the storage and maintenance of equipment and other industrial uses. Fuel may have been spilled, or hydrocarbons or other wastes may have been released on these properties. Any release of substances by us or by third parties who previously operated on these properties may be subject to laws which impose joint

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and several liability for clean-up, without regard to fault, on specific classes of persons who are considered to be responsible for the release of harmful substances into the environment.

Failure by our customers to obtain required permits and licenses may affect the demand for our services.

      The development of the oil sands requires our customers to obtain regulatory or other permits and licenses from various governmental licensing bodies. Our customers may not be able to obtain all necessary permits and licenses that may be required for the development of the oil sands on their properties. In such a case, our customers’ projects will not proceed, thereby adversely impacting demand for our services.

Our projects expose us to potential professional liability, product liability, warranty or other claims.

      We install deep foundations, often in congested and densely populated areas, and provide construction management services for significant projects. Notwithstanding the fact that we generally will not accept liability for consequential damages in our contracts, any catastrophic occurrence in excess of insurance limits at projects where our structures are installed or services are performed could result in significant professional liability, product liability, warranty or other claims against us. Such liabilities could potentially exceed our current insurance coverage and the fees we derive from those services. A partially or completely uninsured claim, if successful and of a significant magnitude, could result in substantial losses.

We may not be able to achieve the expected benefits from any future acquisitions, which would adversely affect our financial condition and results of operations.

      We intend to pursue selective acquisitions as a method of expanding our business. However, we may not be able to identify or successfully bid on businesses that we might find attractive. If we do find attractive acquisition opportunities, we might not be able to acquire these businesses at a reasonable price. If we do acquire other businesses, we might not be able to successfully integrate these businesses into our then-existing business. We might not be able to maintain the levels of operating efficiency that acquired companies will have achieved or might achieve separately. Successful integration of acquired operations will depend upon our ability to manage those operations and to eliminate redundant and excess costs. Because of difficulties in combining operations, we may not be able to achieve the cost savings and other size-related benefits that we hoped to achieve after these acquisitions. Any of these factors could harm our financial condition and results of operations.

Aboriginal peoples may make claims against our customers or their projects regarding the lands on which their projects are located.

      Aboriginal peoples have claimed aboriginal title and rights to a substantial portion of western Canada. Any claims that may be asserted against our customers, if successful, could have an adverse effect on our customers which may, in turn, negatively impact our business.

Unanticipated short term shutdowns of our customers’ operating facilities may result in temporary cessation or cancellation of projects in which we are participating.

      The majority of our work is generated from the development, expansion and ongoing maintenance of oil sands mining, extraction and upgrading facilities. Unplanned shutdowns of these facilities due to events outside our control or the control of our customers, such as fires, mechanical breakdowns and technology failures, could lead to the temporary shutdown or complete cessation of projects in which we are working. When these events have happened in the past, our business has been adversely affected. Our ability to maintain revenues and margins may be affected to the extent these events cause reductions in the utilization of equipment.

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Many of our senior officers have either recently joined the company or have just been promoted and have only worked together as a management team for a short period of time.

      We recently made several significant changes to our senior management team. In May 2005, we hired a new Chief Executive Officer and promoted our Vice President, Operations to Chief Operating Officer. In January 2005 we hired a new Treasurer, who is now our Vice President, Finance. In June 2006, we hired a new Vice President, Human Resources, Health, Safety and Environment. We are currently searching for a Chief Financial Officer. As a result of these and other recent changes in senior management, many of our officers have only worked together as a management team for a short period of time and do not have a long history with us. Because our senior management team is responsible for the management of our business and operations, failure to successfully integrate our senior management team could have an adverse impact on our business, financial condition and results of operations.

We will incur significantly higher costs as a result of being a public company.

      As a public company, we will incur significantly higher legal, accounting and other expenses than we did as a private company. In addition, the Sarbanes-Oxley Act of 2002, as well as similar or related rules adopted by the SEC, Canadian securities regulatory authorities and the U.S. and Canadian stock exchanges on which we may list our common shares, have imposed substantial requirements on public companies, including requiring changes in corporate governance practices and requirements relating to internal control over financial reporting under Section 404 of the Sarbanes-Oxley Act. We expect these rules and regulations to increase our legal and financial compliance costs and to make some activities more time-consuming and costly.

Risks Related to Our Common Shares and This Offering

If you purchase common shares in this offering, you will experience immediate dilution in the net tangible book value per share and could experience further dilution as a result of any additional share issuances, such as under our share option plan.

      The initial public offering price of our common shares is substantially higher than the net tangible book value per share of the common shares that will be issued. Accordingly, if you purchase common shares in this offering, at an assumed initial public offering price of US$                    , or C$                    , per share (the midpoint of the range set forth on the cover of this prospectus), you will incur immediate dilution of approximately US$                    , or C$                    , respectively, in the pro forma net tangible book value per common share. This means that investors who purchase shares will pay a price per share that exceeds the book value of our net tangible assets after subtracting our liabilities. See “Dilution.”

      Moreover, each person purchasing common shares in this offering will experience further dilution to the extent that additional common shares are issued, such as upon exercise of options granted under our 2004 share option plan.

There has been no active trading market for our common shares, and an active trading market for the common shares may not develop.

      Prior to this offering, there has not been a public market for our common shares. We cannot predict the extent to which investor interest in our company will lead to the development of an active trading market on a United States or Canadian stock exchange or otherwise or how liquid that market might become. If an active market does not develop, it will affect your ability to sell our common shares that you buy and the market price of the shares.

      The offering price for the common shares being sold in this offering will be determined by negotiations between the underwriters and us and does not purport to be indicative of prices that will prevail in the market for our common shares following this offering.

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If our share price fluctuates after this offering, you could lose a significant part of your investment.

      There has been significant volatility in the market price and trading volume of equity securities, which is unrelated to the financial performance of the companies issuing the securities. The market price of our common shares is likely to be similarly volatile, and you may not be able to resell your shares at or above the offering price due to fluctuations in the market price of our common shares, including changes in price caused by factors unrelated to our operating performance or prospects.

      Specific factors that may have a significant effect on the market price for our common shares include:

•  changes in projections as to the level of capital spending in the oil sands region;

•  changes in stock market analyst recommendations or earnings estimates regarding our common shares, other comparable companies or the construction or oil and gas industries generally;

•  actual or anticipated fluctuations in our operating results or future prospects;

•  reaction to our public announcements;

•  strategic actions taken by us or our competitors, such as acquisitions or restructurings;

•  new laws or regulations or new interpretations of existing laws or regulations applicable to our business and operations;

•  changes in accounting standards, policies, guidance, interpretations or principles;

•  adverse conditions in the financial markets or general economic conditions, including those resulting from war, incidents of terrorism and responses to such events;

•  sales of common shares by us, members of our management team or our existing shareholders; and

•  the extent of analysts’ interest in following our company.

Future sales, or the perception of future sales, of a substantial amount of our common shares may depress the price of our common shares.

      Future sales, or the perception of the availability for sale, of substantial amounts of our common shares could adversely affect the prevailing market price of our common shares and could impair our ability to raise capital through future sales of equity securities at a time and price that we deem appropriate.

      We, our executive officers and directors and the selling shareholders have agreed, subject to certain exceptions, that neither we nor they will offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, or file with the SEC or the securities regulatory authorities in Canada, a registration statement or prospectus under applicable securities legislation, relating to any of our common shares or securities convertible into or exchangeable or exercisable for any of our common shares, or publicly disclose the intention to make any offer, sale, pledge, disposition or filing without the prior consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC for 180 days after the date of this prospectus, subject under certain circumstances to extension. See “Underwriting.” Following the expiration of this lock-up period, all of the common shares owned by our existing investors that will not be sold in this offering will be eligible for future sale pursuant to Rule 144 (in the case of sales in the United States), subject to the applicable volume, manner of sale, holding period and other limitations of that rule and pursuant to National Instrument 45-102-Resale of Securities (in the case of sales in Canada), subject to fulfilling the procedural requirements of that instrument. In addition, our existing equity investors have registration rights with respect to their common shares that they will retain following this offering. See “Shares Eligible for Future Sale” for a discussion of the common shares that may be sold into the public market in the future.

      We may issue our common shares or convertible securities from time to time as consideration for future acquisitions and investments. In the event any such acquisition or investment is significant, the

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number of common shares or convertible securities that we may issue could be significant. We may also grant registration rights covering those shares or convertible securities in connection with any such acquisitions and investments. Any additional capital raised through the sale of our common shares or securities convertible into our common shares will dilute your percentage ownership in us.

Fluctuations in the value of the Canadian and U.S. dollars can affect the value of our common shares and future dividends, if any.

      Our operations and our principal executive offices are in Canada. Accordingly, we report our results in Canadian dollars. If you are a U.S. shareholder, the value of your investment in us will fluctuate as the U.S. dollar rises and falls against the Canadian dollar. Also, if we pay dividends in the future, we will pay those dividends in Canadian dollars. Accordingly, if the U.S. dollar rises in value relative to the Canadian dollar, the U.S. dollar value of the dividend payments received by a U.S. common shareholder would be less than they would have been if exchange rates were stable.

We currently do not intend to pay cash dividends on our common shares, and our ability to pay dividends is limited by our preferred shares, our debt agreements, our subsidiaries’ ability to distribute funds to us and Canadian law.

      We have never paid cash dividends on our common shares. It is our present intention to retain all future earnings for use in our business, and we do not expect to pay cash dividends on the common shares in the foreseeable future. Any future determination to pay cash dividends will be at the discretion of our board of directors and will depend on our results of operations, financial condition, current and anticipated cash needs, contractual restrictions, restrictions imposed by applicable law and other factors that our board of directors considers relevant. Our ability to declare dividends is restricted by the terms of the Series A preferred shares originally issued by NACG Preferred Corp. and assumed by us as part of the amalgamation described under “The Reorganization,” referred to as the “Seller preferred shares,” our revolving credit facility and the indentures that govern our notes. See “Description of Share Capital – Seller Preferred Shares” and “Description of Certain Indebtedness.”

      Substantially all of the assets shown on our consolidated balance sheet are held by our subsidiaries. Accordingly, our earnings and cash flow and our ability to pay dividends are largely dependent upon the earnings and cash flows of our subsidiaries and the distribution or other payment of such earnings to us in the form of dividends.

      Our ability to pay dividends is also subject to the satisfaction of a statutory solvency test under Canadian law, which requires that there be no reasonable grounds for believing that (1) we are, or would after the payment be, unable to pay our liabilities as they become due or (2) the realizable value of our assets would, after payment of the dividend, be less than the aggregate of our liabilities and stated capital of all classes.

Our principal shareholders are in a position to affect our ongoing operations, corporate transactions and other matters, and their interests may conflict with or differ from your interests as a shareholder.

      Upon the consummation of the Reorganization and this offering, investment entities controlled by The Sterling Group, L.P., Genstar Capital, L.P., Perry Corp. and SF Holding Corp. (formerly Stephens Group, Inc.), whom we collectively refer to as the sponsors, will collectively own approximately           % of our common shares (approximately           % of our common shares if the underwriters’ over-allotment option is exercised in full). As a result, the sponsors and their affiliates effectively will be able to control the outcome of most matters submitted to a vote of our shareholders, including the election of members of our board of directors. We also are party to a voting agreement with the sponsors, pursuant to which the sponsors have agreed to vote the shares held by them for the director nominees designated by the sponsors. See “Related Party Transactions – Voting and Corporate Governance Agreement.”

      For so long as the sponsors own a significant percentage of our outstanding common shares, even if less than a majority, the sponsors will be able to control or exercise a controlling influence over our

27

business and affairs, including the incurrence of indebtedness by us, the issuance of any additional common shares or other equity securities, the repurchase of common shares and the payment of dividends, if any, and will have the power to determine or significantly influence the outcome of matters submitted to a vote of our shareholders, including election of directors, mergers, consolidations, sales or dispositions of assets, other business combinations and amendments to our articles of incorporation. The interests of the sponsors and their affiliates may not coincide with the interests of our other shareholders. In particular, the sponsors and their affiliates are in the business of making investments in companies and they may, from time to time, acquire and hold interests in businesses that compete directly or indirectly with us. The sponsors and their affiliates may also pursue, for their own account, acquisition opportunities that may be complementary to our business, and as a result, those acquisition opportunities may not be available to us. So long as the sponsors and their affiliates continue to own a significant portion of the outstanding common shares, they will continue to be able to significantly influence or effectively control our decisions.

We are a holding company and rely on our subsidiaries for our operating funds, and our subsidiaries have no obligation to supply us with any funds.

      We are a holding company with no operations of our own. We conduct our operations through subsidiaries and are dependent upon our subsidiaries for the funds we need to operate. Each of our subsidiaries is a distinct legal entity and has no obligation to transfer funds to us. The ability of our subsidiaries to transfer funds to us could be restricted by the terms of our financings. The payment of dividends to us by our subsidiaries is subject to legal restrictions as well as various business considerations and contractual provisions, which may restrict the payment of dividends and distributions and the transfer of assets to us.

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

      This prospectus contains forward-looking statements within the meaning of the United States federal securities laws and securities legislation in the provinces and territories of Canada. Statements that are not historical facts, including statements about activities, events or developments that we or a third party expect, believe or anticipate will occur in the future, are forward-looking statements. Forward-looking statements include statements preceded by, followed by or that include the words “may,” “could,” “would,” “should,” “believe,” “expect,” “anticipate,” “plan,” “estimate,” “target,” “project,” “intend,” “continue,” “further” or similar expressions. These statements include, among others, statements regarding our expected business outlook, anticipated financial and operating results, our business strategy and means to implement the strategy, our objectives, the amount and timing of capital expenditures, the likelihood of our success in expanding our business, financing plans, budgets, working capital needs and sources of liquidity.

      Forward-looking statements are only predictions and are not guarantees of performance. These statements are based on beliefs and assumptions, which in turn are based on currently available information. Important assumptions relating to the forward-looking statements include, among others, assumptions regarding demand for our services, the expansion of our business, the timing and cost of planned capital expenditures, competitive conditions and general economic conditions. These assumptions could prove inaccurate. Forward-looking statements also involve risks and uncertainties, which could cause actual results to differ materially from those contained in any forward-looking statement. Many of these risks and uncertainties are beyond our ability to control or predict and the occurrence of any such risk or uncertainty could be material. These factors include, but are not limited to, the following:

•  the timing and success of business development efforts;

•  changes in oil and gas prices;

•  our ability to hire and retain a skilled labor force;

•  our ability to bid successfully on new projects and accurately forecast costs associated with unit-price or lump sum contracts;

•  our ability to establish and maintain effective internal controls;

•  our substantial debt, which could make us more vulnerable to adverse economic conditions and affect our ability to comply with the terms of the agreements governing our indebtedness;

•  restrictive covenants in our debt agreements, which may restrict the manner in which we operate our business;

•  foreign currency exchange rate fluctuations, capital markets conditions and inflation rates;

•  weather conditions;

•  our ability to obtain surety bonds as required by some of our customers;

•  decreases in outsourcing work by our customers or shut-downs or cutbacks at major businesses that use our services;

•  our ability to purchase or lease equipment;

•  changes in laws or regulations, third party relations and approvals, and decisions of courts, regulators and governmental bodies that may adversely affect our business or the business of the customers we serve;

29

•  our ability to successfully identify and acquire new businesses and assets and integrate them into our existing operations; and

•  those other factors discussed in the section entitled “Risk Factors.”

      The foregoing list should not be construed to be exhaustive. We believe the forward-looking statements in this prospectus are reasonable; however, there is no assurance that the actions, events or results of the forward-looking statements will occur or, if any of them do, what impact they will have on our results of operations or financial condition. In view of these uncertainties, you should not place undue reliance on any forward-looking statements, which are based on our current expectations. Further, forward-looking statements speak only as of the date they are made, and, other than as required by applicable law, we undertake no obligation to update publicly any of them in light of new information or future events.

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USE OF PROCEEDS

      We estimate that our proceeds from this offering, after deducting underwriting discounts and commissions and estimated offering expenses payable by us, will be approximately US$           million, or C$           million, assuming the shares are offered at US$                    , or C$                    , per share, respectively, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus. A $1.00 increase or decrease in the assumed initial public offering price per share would increase or decrease the net proceeds to us by approximately $           million. We will not receive any proceeds from the sale of shares by the selling shareholders.

      We intend to use the net proceeds of this offering as follows:

•  approximately $           million to purchase equipment currently under operating leases, including prepayment penalties,

•  approximately $           million to tender for all or a portion of our outstanding principal of and accrued interest on our 9% senior secured notes due 2010, which notes were used for refinancing bank indebtedness, related fees and expenses and for general corporate purposes, and

•  with the balance available for general corporate purposes, including potential acquisitions. While we currently have no agreements for the acquisition of any material business or assets, we regularly evaluate potential acquisitions and may effect them quickly and at any time.

      As noted above, we intend to use a portion of the proceeds from this offering to tender for our 9% senior secured notes due 2010. Assuming that we are successful in acquiring all of the notes, we would incur a pre-tax charge in the fiscal period that the tender offer is consummated of approximately $           million, representing the tender offer premium and the write-off of debt issuance costs associated with these notes. In addition, upon consummation of this offering, we have agreed to pay the sponsors approximately $           million to terminate our advisory services agreement, which will also represent a charge in a like amount. See “Related Party Transactions — Advisory Services Agreement.”

DIVIDEND POLICY

      We have not declared or paid any dividends on our common shares since our inception on October 17, 2003, and we do not anticipate declaring or paying any dividends on our common shares for the foreseeable future. We currently intend to retain any future earnings to finance future growth. Any future determination to pay dividends will be at the discretion of our board of directors and will depend on our financial condition, results of operations, capital requirements and other factors the board of directors considers relevant. In addition, our ability to declare and pay dividends is restricted by our governing statute, as well as the terms of the Seller preferred shares, our revolving credit facility and the indentures that govern our notes. See “Description of Share Capital – Seller Preferred Shares” and “Description of Certain Indebtedness.”

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CAPITALIZATION

      The following table sets forth our cash and consolidated capitalization as of March 31, 2006:

•  on an actual basis;

•  as adjusted on a pro forma basis to give effect to the Reorganization; and

•  as further adjusted on a pro forma basis to give effect to this offering and the use of proceeds therefrom, assuming the shares are offered at US$                    , or C$                    , per share, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus.

      The following table should be read in conjunction with, and is qualified in its entirety by reference to, the information under the sections entitled “Use of Proceeds,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Description of Share Capital” and our consolidated financial statements and the notes thereto included elsewhere in this prospectus.

				March 31, 2006
										Pro Forma
										for the
							Pro Forma			Reorganization
							for the			and the
				Actual			Reorganization			Offering(a)
				(In thousands)
Cash and cash equivalents				$	42,804		$			$
Total debt (including current portion):
	Revolving credit facility(b)			$	—		$	—		$	—
	Obligations under capital leases				10,952			10,952
	9% senior secured notes due 2010				70,587			70,587
	83/4 % senior notes due 2011				233,420			233,420
		Total debt, including current portion			314,959			314,959
Redeemable preferred shares:
	Seller preferred shares				35,000			35,000
	Series A preferred shares				375
	Series B preferred shares				42,193
		Total redeemable preferred shares			77,568
Shareholders’ equity(c):
	Common shares				93,100
	Contributed surplus				1,557			1,557
	Deficit				(76,546	)		(76,546	)
		Total shareholders’ equity			18,111
			Total capitalization	$	410,638		$			$

(a)	A $1.00 increase or decrease in the assumed initial public offering price per share would increase or decrease each of cash, share capital, total shareholders’ equity and total capitalization by $           million, assuming the number of shares offered by us, as set forth on the cover page of this prospectus, remains the same and after deducting the estimated underwriting discounts and estimated offering expenses payable by us.
(b)	On July 19, 2006, we amended and restated our revolving credit facility to provide for borrowings and letters of credit in an aggregate amount of $55.0 million. As of July 19, 2006, we had approximately $37.0 million of available borrowings under the revolving credit facility after taking into account $18.0 million of outstanding and undrawn letters of credit. See “Description of Certain Indebtedness – Revolving Credit Facility.”
(c)	This table does not reflect 103,542 common shares issuable upon exercise of outstanding stock options under our existing stock option plan as of June 30, 2006.

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DILUTION

      If you invest in our common shares, your interest will be diluted to the extent of the difference between the public offering price per common share and the as adjusted net tangible book value per common share after this offering. Dilution results from the fact that the per share offering price of the common shares is in excess of the net tangible book value per share attributable to our existing shareholders for the presently outstanding common shares.

      Our net tangible book value as of March 31, 2006 was approximately $           million, or $                     per common share. Net tangible book value per share is determined by dividing our tangible shareholders’ equity, which is total tangible assets less total liabilities, by the aggregate number of common shares outstanding. Tangible assets represent total assets excluding goodwill and other intangible assets.

      After giving effect to the Reorganization, our sale of                      common shares in this offering at an assumed offering price of US$                    , or C$                    , per share (which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus) and the application of the proceeds from this offering as described under “Use of Proceeds,” as adjusted net tangible book value (deficiency) as of March 31, 2006 would have been $           million, or $                     per share. This represents an immediate increase in as adjusted net tangible book value of $                     per share to our existing shareholders and an immediate dilution of $                     per share to new investors purchasing common shares in this offering.

      The following table illustrates this dilution on a per share basis:

Assumed initial public offering price per share			$
	Net tangible book value (deficiency) per share as of March 31, 2006	$
	Increase in pro forma net tangible book value per share attributable to the offering
Pro forma net tangible book value per share after the offering
Dilution in net tangible book value per share to new investors			$

      A $1.00 increase or decrease in the assumed initial public offering price per share would increase or decrease our net tangible book value after the offering by $                    and increase or decrease the dilution to new investors by $                    , assuming the number of shares offered by us, as set forth on the cover page of this prospectus, remains the same and after deducting the estimated underwriting discounts and estimated offering expenses payable by us.

      The following table summarizes, on the same pro forma as adjusted basis as of March 31, 2006, the total number of common shares purchased from us or the selling shareholders, the total consideration paid and the average price per share paid by the existing shareholders and by new investors purchasing shares in this offering:

	Shares Purchased			Total Consideration
							Average Price
	Number	Percent		Amount	Percent		Per Share
Existing shareholders			%	$		%	$
New investors
Total			100.0%	$		100.0%

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THE REORGANIZATION

      The following chart depicts our organizational structure prior to the consummation of the transactions described below and this offering.

      Concurrently with the consummation of this offering, each of NACG Holdings Inc., NACG Preferred Corp. and North American Energy Partners Inc. propose to amalgamate into one entity, North American Energy Partners Inc. As a result, the amalgamated North American Energy Partners Inc. will own all of the assets of and assume all of the liabilities and obligations of the three amalgamated entities. The share capital of North American Energy Partners Inc. after the amalgamation will consist of common shares, non-voting common shares and the Seller preferred shares. The Seller preferred shares are mandatorily redeemable and have been classified as debt on our balance sheet. Prior to the amalgamation, our common shares will undergo a      -for-     split.

      Prior to the amalgamation, the Series A preferred shares issued by the pre-amalgamated North American Energy Partners Inc. will be purchased by us for its redemption value of $1.0 million of cash. Each holder of Series B preferred shares issued by the pre-amalgamated North American Energy Partners Inc. will receive five common shares in the amalgamated North American Energy Partners Inc. for each Series B preferred share held. Subsequent to the amalgamation, existing common and non-voting common shareholders of NACG Holdings Inc. will hold common and non-voting common shares of the amalgamated North American Energy Partners Inc. Immediately prior to the amalgamation, the holder of the Seller preferred shares will receive preferred shares in NACG Holdings Inc. with substantially the same terms. Any outstanding options under our 2004 share option plan will become options to purchase common shares of the amalgamated North American Energy Partners Inc., and the number and exercise price of such options will be adjusted accordingly.

      The above transactions are referred to collectively as the “Reorganization.” The voting common shares of North American Energy Partners Inc. after giving effect to the Reorganization are the shares being offered hereby.

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      The consummation of the Reorganization is contingent upon receiving required approval from the various shareholders of each of the amalgamating companies. The following depicts our organizational structure after the Reorganization and this offering:

      This offering is contingent upon completion of the Reorganization.

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SELECTED HISTORICAL FINANCIAL DATA

      We were initially formed in October 2003 in connection with the Acquisition on November 26, 2003. As a result, the selected historical consolidated financial data presented below as of and for each of the fiscal years ended March 31, 2002 and 2003 and for the period from April 1, 2003 to November 25, 2003 is derived from the audited consolidated financial statements of Norama Ltd., our predecessor, included elsewhere in this prospectus. The selected historical consolidated financial data presented below for the period from November 26, 2003 to March 31, 2004 and as of and for each of the fiscal years ended March 31, 2005 and 2006 is derived from our audited consolidated financial statements included elsewhere in this prospectus. As a result of the Acquisition, the consolidated financial data for the periods before November 26, 2003 is not necessarily comparable to the consolidated financial data for periods after November 25, 2003.

      The information presented below should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our audited consolidated financial statements and related notes included elsewhere in this prospectus. All of the financial information presented below has been prepared in accordance with Canadian GAAP, which differs in certain significant respects from U.S. GAAP. For a discussion of the principal differences between Canadian GAAP and U.S. GAAP as they pertain to us, see note 23 to our consolidated financial statements included elsewhere in this prospectus.

		Predecessor
								April 1, 2003			November 26,
		Year Ended March 31,						to			2003 to			Year Ended March 31,
								November 25,			March 31,
		2002			2003			2003			2004			2005			2006
		(Dollars in thousands, except per share amounts)
Statement of operations data:
Revenue(a)		$	249,351		$	344,186		$	250,652		$	127,611		$	357,323		$	492,237
	Project costs		127,996			219,979			156,976			83,256			240,919			308,949
	Equipment costs		56,693			55,871			43,484			13,686			52,831			64,832
	Equipment operating lease expense		20,596			16,357			10,502			1,430			6,645			16,405
	Depreciation		11,299			10,974			6,566			6,674			20,762			21,725
Gross profit			32,767			41,005			33,124			22,565			36,166			80,326
	General and administrative		12,794			12,233			7,783			6,065			22,873			30,903
	Gain on sale of capital assets		(218	)		(2,265	)		(49	)		131			494			(733	)
	Amortization of intangible assets		—			—			—			12,928			3,368			730
Operating income			20,191			31,037			25,390			3,441			9,431			49,426
	Management fee(b)		14,400			8,000			41,070			—			—			—
	Interest expense(c)		3,510			4,162			2,457			10,079			31,141			68,776
	Foreign exchange gain		(17	)		(234	)		(7	)		(661	)		(19,815	)		(13,953	)
	Other (income) expense		—			—			(367	)		(230	)		(421	)		1,118
	Realized and unrealized loss on derivative financial instruments		—			—			—			12,205			43,113			14,689
Income (loss) before income taxes			2,298			19,109			(17,763	)		(17,952	)		(44,587	)		(21,204	)
	Income taxes (benefit)		689			6,620			(6,622	)		(5,670	)		(2,264	)		737
Net income (loss)(d)		$	1,609		$	12,489		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)
Net income (loss) per share data:
Net income (loss) per share:
	Basic and diluted										$	(13.28	)	$	(45.66	)	$	(23.62	)
Weighted average shares:
	Basic and diluted											925,000			926,986			928,740

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	Predecessor
							April 1, 2003			November 26,
	Year Ended March 31,						to			2003 to			Year Ended March 31,
							November 25,			March 31,
	2002			2003			2003			2004			2005			2006
	(Dollars in thousands, except per share amounts)
Balance sheet data (end of period):
Cash	$	436		$	651					$	36,595		$	17,924		$	42,804
Property, plant and equipment, net		56,759			76,234						167,905			177,089			185,566
Total assets		120,431			158,584						489,974			540,155			587,011
Total debt(e)		50,139			63,401						313,798			310,402			314,959
Seller preferred shares		—			—						35,000			35,000			35,000
Series A preferred shares		—			—						—			—			375
Series B preferred shares		—			—						—			—			42,193
Total shareholders’ equity(f)		17,379			29,818						80,355			38,829			18,111
Other financial data:
EBITDA(g)	$	17,107		$	34,245		$	(8,740	)	$	11,729		$	10,684		$	70,027
Consolidated EBITDA(g)		17,090			34,011			(8,747	)		23,410			34,479			71,686
Cash provided by (used in) operating activities		4,175			16,283			2,509			15,477			(4,833	)		33,864
Cash used in investing activities		(6,464	)		(18,745	)		(4,625	)		(364,514	)		(25,055	)		(22,168	)
Cash provided by (used in) financing activities		(8,522	)		2,677			6,967			385,632			11,217			13,184
Capital expenditures, net of capital leases		8,668			22,932			5,234			2,501			25,679			29,015

(a)

Effective April 1, 2005, we changed our accounting policy regarding the recognition of revenue on claims. This change in accounting policy has been applied retroactively. Prior to this change, revenue from claims was included in total estimated contract revenue when awarded or received. After this change, claims are included in total estimated contract revenue, only to the extent that contract costs related to the claim have been incurred and when it is probable that the claim will result in a bona fide addition to contract value and can be reliably estimated. Those two conditions are satisfied when (1) the contract or other evidence provides a legal basis for the claim or a legal opinion is obtained providing a reasonable basis to support the claim, (2) additional costs incurred were caused by unforeseen circumstances and are not the result of deficiencies in our performance, (3) costs associated with the claim are identifiable and reasonable in view of work performed and (4) evidence supporting the claim is objective and verifiable. No profit is recognized on claims until final settlement occurs. This can lead to a situation where costs are recognized in one period and revenue is recognized when customer agreement is obtained or claim resolution occurs, which can be in subsequent periods. Historical claim recoveries should not be considered indicative of future claim recoveries. The change in policy resulted in an increase in claims revenue and unbilled revenue of approximately $12.9 million for the year ended March 31, 2006, but did not result in any adjustments to prior periods. Substantially all of the amounts recognized as claims revenue have been collected subsequent to March 31, 2006.

(b)

Management fees paid to the corporate shareholder of our predecessor company, Norama Ltd., represented fees for services rendered and were determined with reference to taxable income. Subsequent to the Acquisition on November 26, 2003, these fees are no longer paid.

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(c) Interest expense consists of the following (in thousands):

	Predecessor
	April 1, 2003
	to		November 26,		Year Ended
	November 25,		2003 to		March 31,
			March 31,
	2003		2004		2005		2006
Interest on senior notes	$	—	$	8,096	$	23,189	$	28,838
Interest on senior secured credit facility		599		1,089		3,274		564
Change in redemption value of Series B preferred shares		—		—		—		34,668
Amortization of deferred financing costs		—		814		2,554		3,338
Other		1,858		80		2,124		1,368
	$	2,457	$	10,079	$	31,141	$	68,776

(d) Our consolidated financial statements have been prepared in accordance with Canadian GAAP, which differs in certain material respects from U.S. GAAP. If U.S. GAAP were employed, our net income (loss) would be adjusted as follows (in thousands):

		Predecessor
		Year Ended							November 26,
		March 31,				April 1, 2003 to			2003 to			Year Ended March 31,
						November 25,			March 31,
		2002		2003		2003			2004			2005			2006
Net income (loss) (as reported)		$	1,609	$	12,489	$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)
Capitalized interest(1)			—		—		—			—			—			847
Amortization using effective interest method(2)			—		—		—			—			—			590
Realized and unrealized loss on derivative financial instruments(3)			—		—		—			—			—			(484	)
Income (loss) before income taxes			1,609		12,489		(11,141	)		(12,282	)		(42,323	)		(20,988	)
Income taxes:
	Deferred income taxes		—		—		—			—			—			—
Net income (loss) – U.S. GAAP		$	1,609	$	12,489	$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(20,988	)
Net loss per share – basic and diluted – U.S. GAAP									$	(13.28	)	$	(45.66	)	$	(22.60	)

(1) U.S. GAAP requires capitalization of interest costs as part of the historical cost of acquiring certain qualifying assets that require a period of time to prepare for their intended use. This is not required under Canadian GAAP.

(2) Under Canadian GAAP, we defer and amortize debt issuance costs on a straight-line basis over the stated term of the related debt. Under U.S. GAAP, we are required to amortize financing costs over the stated term of the related debt using the effective interest method resulting in a consistent interest rate over the term of the debt.

(3) U.S. GAAP requires that every derivative instrument (including certain derivative instruments embedded in other contracts and debt instruments) be recorded in the balance sheet as either an asset or liability measured at its fair value. The issuances of our 8³/4 % senior notes and 9% senior secured notes both included certain contingent embedded derivatives which provided for the acceleration of redemption by the holder at a premium in certain instances. These embedded derivatives met the criteria for bifurcation from the debt contract and separate measurement at fair value. Under U.S. GAAP, the embedded derivatives have been measured at fair value and classified as part of the carrying amount of the senior notes on the consolidated balance sheet, with changes in the fair value being recorded in net income as realized and unrealized (gain) loss on derivative financial instruments for the period. Under Canadian GAAP, separate accounting of embedded derivatives from the host contract is not permitted.

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(e) Total debt as of March 31, 2006 consists of the following (in thousands):

Revolving credit facility	$	—
Obligations under capital leases		10,952
9% senior secured notes due 2010		70,587
83/4 % senior notes due 2011		233,420
	$	314,959

Our 83/4% senior notes are reflected above at the current exchange rate at each balance sheet date. We have entered into cross-currency and interest rate swaps, which represent an economic hedge of the 83/4 % senior notes. At maturity, we will be required to pay $263.0 million in order to retire these senior notes as a result of the swaps. This amount is the fixed exchange rate of C$1.315 = US$1.00 established as of November 26, 2003, the inception of the swap contracts.

(f)

The cumulative effect of material differences between Canadian and U.S. GAAP on shareholders’ equity is as follows (in thousands):

	March 31,		March 31,		March 31,
	2004		2005		2006
Shareholders’ equity (as reported) – Canadian GAAP	$	80,355	$	38,829	$	18,111
Capitalized interest(1)		—		—		847
Amortization using effective interest method(2)		—		—		590
Realized and unrealized loss on derivative financial instruments(3)		—		—		(484	)
Excess of fair value of amended Series B preferred shares over carrying value of original Series B preferred shares(4)		—		—		(3,707	)
Shareholders’ equity – U.S. GAAP	$	80,355	$	38,829	$	15,357

(1) U.S. GAAP requires capitalization of interest costs as part of the historical cost of acquiring certain qualifying assets that require a period of time to prepare for their intended use. This is not required under Canadian GAAP.

(2) Under Canadian GAAP, we defer and amortize debt issuance costs on a straight-line basis over the stated term of the related debt. Under U.S. GAAP, we are required to amortize financing costs over the stated term of the related debt using the effective interest method resulting in a consistent interest rate over the term of the debt.

(3) U.S. GAAP requires that every derivative instrument (including certain derivative instruments embedded in other contracts and debt instruments) be recorded in the balance sheet as either an asset or liability measured at its fair value. The issuances of our 8³/4 % senior notes and 9% senior secured notes both included certain contingent embedded derivatives which provided for the acceleration of redemption by the holder at a premium in certain instances. These embedded derivatives met the criteria for bifurcation from the debt contract and separate measurement at fair value. Under U.S. GAAP, the embedded derivatives have been measured at fair value and classified as part of the carrying amount of the senior notes on the consolidated balance sheet, with changes in the fair value being recorded in net income as realized and unrealized (gain) loss on derivative financial instruments for the period. Under Canadian GAAP, separate accounting of embedded derivatives from the host contract is not permitted.

(4) Prior to the modification of the terms of the Series B preferred shares, there were no differences between Canadian GAAP and U.S. GAAP related to the Series B preferred shares. As a result of the modification of terms of the Series B preferred shares on March 30, 2006, under Canadian GAAP, we continue to classify the Series B preferred shares as a liability and accrete the carrying amount to the December 31, 2011 redemption value of $69.6 million using the effective interest method. Under U.S. GAAP, the Company recognized the fair value of the Series B preferred shares as minority interest as such amount was recognized as temporary equity in the accounts of North American Energy Partners Inc., the issuer of the shares, in accordance with EITF Topic D-98 and recognized a charge of $3.7 million to retained earnings for the difference between the fair value and the carrying amount of the Series B preferred shares on the modification date. Under U.S. GAAP, we accrete the initial fair value of the Series B preferred shares of $45.9 million to the December 31, 2011 redemption value of $69.6 million using the effective interest method, which is consistent with the treatment of the Series B preferred shares as temporary equity in the financial statements of North American Energy Partners Inc. The accretion charge is recognized as a charge to minority interest as opposed to retained earnings in the accounts of North American Energy Partners Inc. under U.S. GAAP and interest expense in our financial statements under Canadian GAAP.

39

(g) EBITDA is calculated as net income (loss) before interest expense, income taxes, depreciation and amortization. Consolidated EBITDA is defined as EBITDA, excluding the effects of foreign exchange gain or loss, realized and unrealized gain or loss on derivative financial instruments and non-cash stock-based compensation expense. We believe that EBITDA is a meaningful measure of the performance of our business because it excludes items, such as depreciation and amortization, interest and taxes, that are not directly related to the operating performance of our business. Management reviews EBITDA to determine whether capital assets are being allocated efficiently. In addition, our revolving credit facility requires us to maintain a minimum Consolidated EBITDA. Non-compliance with this financial covenant could result in our being required to immediately repay all amounts outstanding under our revolving credit facility. We are required to maintain a minimum Consolidated EBITDA through December 31, 2006 of $65.5 million, with this minimum amount increasing periodically until maturity. However, EBITDA and Consolidated EBITDA are not measures of performance under Canadian GAAP or U.S. GAAP and our computations of EBITDA and Consolidated EBITDA may vary from others in our industry. EBITDA and Consolidated EBITDA should not be considered as alternatives to operating income or net income as measures of operating performance or cash flows as measures of liquidity. EBITDA and Consolidated EBITDA have important limitations as analytical tools, and you should not consider them in isolation, or as substitutes for analysis of our results as reported under Canadian GAAP or U.S. GAAP. For example, EBITDA and Consolidated EBITDA:

•  do not reflect our cash expenditures or requirements for capital expenditures or capital commitments;

•  do not reflect changes in, or cash requirements for, our working capital needs;

•  do not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt;

•  exclude tax payments that represent a reduction in cash available to us; and

•  do not reflect any cash requirements for assets being depreciated and amortized that may have to be replaced in the future.

In addition, Consolidated EBITDA excludes foreign exchange gains and losses and unrealized and realized gains and losses on derivative financial instruments, which, in the case of unrealized losses, may ultimately result in a liability that will need to be paid and, in the case of realized losses, represents an actual use of cash during the period.

A reconciliation of net income (loss) to EBITDA as set forth in our consolidated statements of operations is as follows:

		Predecessor
		Year Ended				April 1, 2003			November 26,
		March 31,				to			2003 to			Year Ended March 31,
						November 25,			March 31,
		2002		2003		2003			2004			2005			2006
		(Dollars in thousands)
Net income (loss)		$	1,609	$	12,489	$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)
Adjustments:
	Depreciation		11,299		10,974		6,566			6,674			20,762			21,725
	Amortization		—		—		—			12,928			3,368			730
	Interest expense		3,510		4,162		2,457			10,079			31,141			68,776
	Income taxes		689		6,620		(6,622	)		(5,670	)		(2,264	)		737
EBITDA		$	17,107	$	34,245	$	(8,740	)	$	11,729		$	10,684		$	70,027

40

      A reconciliation of EBITDA to Consolidated EBITDA is as follows:

		Predecessor
								April 1, 2003			November 26,
		Year Ended						to			2003 to
		March 31,
														Year Ended March 31,
								November 25,			March 31,
		2002			2003			2003			2004			2005			2006
		(Dollars in thousands)
EBITDA		$	17,107		$	34,245		$	(8,740	)	$	11,729		$	10,684		$	70,027
Adjustments:
	Foreign exchange gain		(17	)		(234	)		(7	)		(661	)		(19,815	)		(13,953	)
	Realized and unrealized loss on derivative financial instruments		—			—			—			12,205			43,113			14,689
	Non-cash stock-based compensation expense		—			—			—			137			497			923
Consolidated EBITDA		$	17,090		$	34,011		$	(8,747	)	$	23,410		$	34,479		$	71,686

41

UNAUDITED PRO FORMA FINANCIAL INFORMATION

      The following unaudited pro forma financial information is derived from our historical consolidated financial statements included elsewhere in this prospectus. The unaudited pro forma financial information should be read in conjunction with our consolidated financial statements and related notes included elsewhere in this prospectus, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the other financial information included elsewhere in this prospectus.

      The unaudited pro forma statement of operations for the fiscal year ended March 31, 2006 and balance sheet as of March 31, 2006 have been prepared to give pro forma effect to (a) the Reorganization and (b) the sale of common shares in this offering and application of the net proceeds from this offering, in the case of the statement of operations, as if they had occurred on April 1, 2005 and, in the case of the balance sheet, as if they had occurred on March 31, 2006.

      The unaudited pro forma consolidated financial statements reflect pro forma adjustments that are described in the accompanying notes and are based on available information and assumptions we believe are reasonable, but are subject to change. We have made, in our opinion, all adjustments that are necessary to present fairly the pro forma financial information. The unaudited pro forma financial information is presented for informational purposes only and does not purport to represent what our actual results of operations or financial position would have been had the Reorganization and this offering been consummated on the dates indicated and does not purport to be indicative of our financial position as of any future date or our results of operations for any future period.

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Unaudited Pro Forma Balance Sheet

March 31, 2006

Pro Forma

for the

Adjustments

Pro Forma

Adjustments

Reorganization

for the

for the

for this

and this

Historical

Reorganization

Reorganization

Offering

Offering

(In thousands)

ASSETS

Current assets:

Cash and cash equivalents

$

42,804

(a)

(c)

Accounts receivable & unbilled revenue

110,729

Prepaid expenses & other current assets

1,853

Future income taxes

5,583

160,969

Future income taxes

23,367

Plant and equipment

185,566

(d)

Goodwill

198,549

Intangible assets, net

772

Deferred financing costs, net

17,788

(e)

Total assets

$

587,011

LIABILITIES AND SHAREHOLDERS’ EQUITY

Current liabilities:

Accounts payable & accrued liabilities

$

78,688

Billings in excess of costs on uncompleted contracts

5,124

Current portion of capital lease obligations

3,046

Future income taxes

5,583

92,441

Capital lease obligations

7,906

Senior notes

304,007

(e)

Total long-term debt

311,913

Future income taxes

23,367

Derivative financial instruments

63,611

Seller preferred shares

35,000

Series A preferred shares

375

(a)

Series B preferred shares

42,193

(b)

Total liabilities

568,900

Shareholders’ equity:

Common shares

93,100

(b)

(f)

Contributed surplus

1,557

(a)

Deficit

(76,546

)

(e)

Total shareholders’ equity

18,111

Total liabilities and shareholders’ equity

$

587,011

43

Notes to Unaudited Pro Forma Balance Sheet

(a)	Reflects the purchase of the Series A preferred shares for $1.0 million in connection with the Reorganization. The excess of the redemption amount over the carrying value will be recorded as an expense in the statement of operations and charged to deficit.
(b)	Reflects the conversion of the Series B preferred shares into common shares in connection with the Reorganization.
(c)	Reflects the net cash proceeds from this offering that will be available for general corporate purposes.
(d)	Reflects the purchase of certain equipment under operating leases with a portion of the proceeds from this offering, excluding prepayment penalties.
(e)	Reflects the repurchase of all of our outstanding 9% senior secured notes with a portion of the proceeds from this offering, including the tender offer premium and write-off of deferred financing costs related to the 9% senior secured notes.
(f)	Reflects the issuance of the common shares in this offering at an assumed offering price of US$                    , or C$                    , per share (which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus).

A $1.00 increase or decrease in the assumed initial public offering price per share would increase or decrease each of cash and shareholder’s equity by $           million, assuming the number of shares offered by us, as set forth on the cover page of this prospectus, remains the same and after deducting the estimated underwriting discounts and estimated offering expenses payable by us.

44

Unaudited Pro Forma Statement of Operations

Fiscal Year Ended March 31, 2006

												Pro Forma
												for the
					Adjustments			Pro Forma	Adjustments			Reorganization
					for the			for the	for this			and this
		Historical			Reorganization			Reorganization	Offering(a)			Offering
		(In thousands)
Revenue		$	492,237
	Project costs		308,949
	Equipment costs		64,832
	Equipment operating lease expense		16,405							(c	)
	Depreciation		21,725							(d	)
Gross profit			80,326
	General and administrative		30,903
	Gain on disposal of property and equipment		(733	)
	Amortization of intangible assets		730
Operating income			49,426
	Interest expense		68,776			(b	)			(e	)
	Foreign exchange gain		(13,953	)						(f	)
	Realized and unrealized loss on derivative financial instruments		14,689
	Financing costs		2,095							(g	)
	Loss on repurchase of 9% senior secured notes									(h	)
	Other income		(977	)
Loss before income taxes			(21,204	)
	Income taxes		737
Net loss		$	(21,941	)

45

Notes to Unaudited Pro Forma Statement of Operations

(a)	The Unaudited Pro Forma Statement of Operations does not give effect to the application of our proceeds from this offering that will be available for general corporate purposes.
(b)	Reflects the decrease in interest expense resulting from the conversion of the Series B preferred shares to common shares and the purchase of Series A preferred shares in connection with the Reorganization.
(c)	Reflects the reduction in equipment operating lease expense, net of prepayment penalties, resulting from the purchase of equipment under certain operating leases with a portion of the proceeds from this offering.
(d)	Reflects the increase in depreciation expense resulting from the purchase of equipment under certain operating leases with a portion of the proceeds from this offering.
(e)	Reflects the decrease in interest expense, net of tender offer premium and deferred financing costs, resulting from the repurchase of all of our outstanding 9% senior secured notes, assuming the repurchase occurred on May 19, 2005, the date the notes were issued.
(f)	Reflects the adjustment to foreign exchange gain resulting from the repurchase of all of our outstanding 9% senior secured notes.
(g)	Reflects the write-off of deferred financing costs related to the repurchase of all of our outstanding 9% senior secured notes.
(h)	Reflects the tender offer premium required to repurchase all of our outstanding 9% senior secured notes.

46

MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

      The following discussion should be read in conjunction with the financial statements and the notes thereto included elsewhere in this prospectus. The following discussion contains forward-looking statements, which reflect the expectations, beliefs, plans and objectives of management about future financial performance and assumptions underlying our judgments concerning the matters discussed below. See “Cautionary Note Regarding Forward-Looking Statements.” These statements, accordingly, involve estimates, assumptions, judgments and uncertainties. In particular, this pertains to management’s comments on financial resources, capital spending and the outlook for our business. Our actual results could differ from those discussed in the forward-looking statements. Factors that could cause or contribute to any differences include, but are not limited to, those discussed below and elsewhere in this prospectus, particularly in “Risk Factors.”

Overview

      We provide services primarily to major oil and natural gas, petrochemical and other natural resource companies operating in western Canada. These services are offered through three operating segments: Mining and Site Preparation, Piling and Pipeline.

      The Mining and Site Preparation operating segment, accounting for 74.5% of our fiscal 2006 revenues, is involved in a variety of activities, including: surface mining for oil sands and other natural resources, including overburden removal, hauling sand and gravel and supplying labor and equipment to support customers’ mining operations; construction of infrastructure associated with mining operations and reclamation activities; clearing, stripping, excavating and grading for mining operations and industrial site construction mega-projects; and underground utility installation for plant, refinery and commercial building construction.

      The Piling operating segment, accounting for 18.6% of our fiscal 2006 revenues, installs all types of driven and drilled piles, caissons and earth retention and stabilization systems for industrial projects primarily focused in the oil sands and related petrochemical or refinery complexes, as well as commercial buildings and infrastructure projects.

      The Pipeline operating segment, accounting for 6.9% of our fiscal 2006 revenues, installs transmission and distribution pipe made of various materials for oil, natural gas and water.

The Reorganization, the Acquisition and Financial Statement Presentation

      Concurrently with the consummation of this offering, NACG Holdings Inc., NACG Preferred Corp. and North American Energy Partners Inc. propose to amalgamate into one entity, North American Energy Partners Inc. As a result, the amalgamated North American Energy Partners Inc. will own all of the assets and assume all of the liabilities and obligations of the three amalgamated entities. See “The Reorganization.” Accordingly, our results of operations and financial condition after the amalgamation may not be comparable to our historical results discussed below.

      We were initially formed in October 2003 in connection with the Acquisition on November 26, 2003. Included in the comparative information presented for the fiscal year ended March 31, 2004 are the results of Norama Ltd., our predecessor company, up to November 25, 2003, plus our results subsequent to November 25, 2003. The information for the periods that occurred after November 25, 2003 may not be directly comparable to the information provided for the pre-acquisition period as a result of the purchase of equipment under operating leases and the effect of the revaluation of assets and liabilities to their estimated fair values in accordance with the application of purchase accounting pursuant to Canadian and U.S. GAAP.

47

Restatements

      The consolidated financial statements of North American Energy Partners Inc., our subsidiary which has financial reporting obligations arising from the 8³/4 % senior notes and 9% senior secured notes, restated its financial statements for the fiscal year ended March 31, 2004 and the quarters ended June 30, 2004, September 30, 2004, December 31, 2004 and June 30, 2005, as described more fully below. The consolidated financial statements of NACG Holdings Inc. presented in this prospectus have not been restated. NACG Holdings Inc. is a holding company for North American Energy Partners Inc., and the two companies will amalgamate as part of the Reorganization.

Misstatements due to internal control deficiencies

      During the third quarter of fiscal 2005, our management discovered a number of accounts payable invoices recorded in the third fiscal quarter which related to costs actually incurred in the first and second quarters of fiscal 2005. Management proceeded to review the matter and discovered a number of additional accounting errors, leading management to conduct a review of our accounts and balances. The review identified a number of deficiencies in our processes and internal controls that contributed to several misstated amounts in North American Energy Partners’ unaudited interim consolidated financial statements for the two quarters ended June 30, 2004 and September 30, 2004. We restated these quarters in April of 2005, after which we made a late filing of North American Energy Partners’ December 31, 2004 financial statements.

      Management’s review identified project, equipment and general and administrative expenses related to the previously reported three months ended June 30, 2004 and six months ended September 30, 2004 that had not been recorded in the appropriate periods. The understated expenses resulted primarily from our failure to accrue in a timely manner the related costs of unprocessed accounts payable invoices. In addition, in performing its review, management also identified certain equipment costs related to the replacement of heavy construction equipment component parts which were expensed and should have been capitalized in accordance with our capital assets policy. As a result, in the restatement we recorded adjustments to capitalize certain equipment costs previously expensed. Finally, we reduced the management bonus provision accordingly in light of the reduction in earnings resulting from the restatement adjustments.

      In addition to the increase in costs resulting from our review, several errors related to revenues were also discovered. Some of the unrecorded costs described above that should have been recorded in the three months and six months ended September 30, 2004 related to projects under cost plus and time-and-material type contracts. Revenues under these types of contracts are recognized as costs are incurred. Consequently, the understatement of costs for the three months and six months ended September 30, 2004 resulted in an understatement of related revenues. Additionally, we determined that we had understated our proportionate share of revenues related to our interest in a joint venture. These increases in revenues were offset by an overstatement of revenues primarily from one customer due to incorrect billing rates as well as duplicate and non-billable transactions in our financial systems.

Derivative financial instruments

      In preparing North American Energy Partners’ financial statements for the fiscal year ended March 31, 2005, we reviewed the accounting treatment of our derivative financial instruments and concluded that there were technical deficiencies in the hedge documentation of the cross-currency swap and interest rate swap contracts used to manage our foreign exchange risk exposure related to our U.S. dollar denominated 8³/4 % senior notes since the inception of the derivative financial contracts on November 26, 2003, which deficiencies could not be corrected retroactively. Therefore, we determined that it was necessary to restate all reported periods after November 26, 2003 to eliminate the impact of hedge accounting. This restatement also resulted in the late filing of North American Energy Partners’ financial statements for the fiscal year ended March 31, 2005. The restatement was accomplished by recognizing the foreign exchange gain or loss relating to the senior notes for each period and recording the derivative

48

financial instruments at fair value and the realized and unrealized gains and losses in the derivative instruments for each period through the consolidated statements of operations, along with the associated future income tax effects.

      The resulting accounting does not impact our risk management activities and has no impact on the timing or amount of cash flows related to our 8³/4 % senior notes or interest rate and cross-currency swap agreements. It does not affect our ability to make required payments on our outstanding debt obligations. Finally, our economic risk management strategies have not required amendment.

Valuation of Series A and Series B preferred shares

      After issuing North American Energy Partners’ financial statements for the quarter ended June 30, 2005, we reviewed the accounting treatment of the Series A and Series B preferred shares issued as part of the refinancing transactions which occurred on May 19, 2005. We previously recorded the Series A preferred shares at the redemption amount of $1.0 million. However, we determined that since both the amount to be paid and the settlement date related to the Series A preferred shares are fixed, the Series A preferred shares should be measured at the present value of the amount to be paid at settlement, accruing interest expense using the interest rate implicit at inception. These preferred shares were issued to one of the counterparties to our swap agreements. Accordingly, we reduced the initial value of the preferred shares from $1.0 million to $0.3 million, decreasing financing costs for the current period by $0.7 million. In addition, we accrued interest expense and recorded the increase in the associated liability in the three months ended June 30, 2005.

      The Series B preferred shares were initially recorded at $7.5 million, the amount of cash consideration received upon their issuance. Since both the amount to be paid and the settlement date vary based on specified conditions, we determined that the Series B preferred shares should be measured initially at fair value and subsequently re-measured at the amount of cash that would be paid based upon the redemption conditions specified in the contract as if settlement occurred at the current reporting date. Any change in the redemption amount from the previous reporting date, in excess of the initial measurement amount, is recorded as interest expense. We restated the carrying value of the Series B preferred shares to the amount that would be paid if the shares were redeemed at the reporting date, which resulted in an increase in the value of the preferred shares of $41.4 million as of June 30, 2005 with an equal and corresponding increase in interest expense.

Financing costs

      After issuing North American Energy Partners’ financial statements for the quarter ended June 30, 2005, we reviewed the accounting treatment of the financing costs incurred in connection with the issuance of our 9% senior secured notes and the establishment of our revolving credit facility on May 19, 2005. $5.3 million of these costs were inappropriately expensed. We concluded that these costs should have been deferred and amortized over the term of the related financing, which is up to five years.

      The restatements of North American Energy Partners’ financial statements for the quarter ended June 30, 2005 to correct the accounting for the Series A and Series B preferred shares and the financing costs resulted in our untimely filing of North American Energy Partners’ financial statements for the quarter ended September 30, 2005.

Critical Accounting Policies and Estimates

      Certain accounting policies require management to make significant estimates and assumptions about future events that affect the amounts reported in our financial statements and the accompanying notes. Therefore, the determination of estimates requires the exercise of management’s judgment. Actual results could differ from those estimates, and any differences may be material to our financial statements.

49

Revenue recognition

      Our contracts with customers fall under the following contract types: cost-plus, time-and-materials, unit-price and lump sum. While the contracts are generally less than one year in duration, we do have several long-term contracts.

•  Cost-plus. A cost-plus contract is where all work is completed based on actual costs incurred to complete the work. These costs include all labor, equipment, materials and any subcontractor’s costs. In addition to these direct costs, all site and corporate overhead costs are charged to the project. An agreed upon fee in the form of a fixed percentage is then applied to all costs charged to the project. This type of contract is utilized where the project involves a large amount of risk or the scope of the project cannot be readily determined. Revenue recognition is based on actual incurred costs to date plus an applicable fee that represents profit.

•  Time-and-materials. A time-and-materials contract involves using the components of a cost-plus job to calculate rates for the supply of labor and equipment. In this regard, all components of the rates are fixed and we are compensated for each hour of labor and equipment supplied. The risk associated with this type of contract is the estimation of the rates and incurring expenses in excess of a specific component of the agreed upon rate. Therefore, any cost overrun must come out of the fixed margin included in the rates. Revenue is recognized as the labor, equipment, materials, subcontract costs and other services are supplied to the customer.

•  Unit-price. A unit-price contract is utilized in the execution of projects with large repetitive quantities of work and is commonly utilized for site preparation, mining and pipeline work. We are compensated for each unit of work we perform (for example, cubic meters of earth moved, lineal meters of pipe installed or completed piles). Within the unit price contract, there is an allowance for labor, equipment, materials and any subcontractor’s costs. Once these costs are calculated, we add any site and corporate overhead costs along with an allowance for the margin we want to achieve. The risk associated with this type of contract is in the calculation of the unit costs with respect to completing the required work. Revenue on unit-price contracts is recognized using the percentage-of-completion method, measured by the ratio of costs incurred to date to estimated total cost.

•  Lump sum. A lump sum contract is utilized when a detailed scope of work is known for a specific project. Thus, the associated costs can be readily calculated and a firm price provided to the customer for the execution of the work. The risk lies in the fact that there is no escalation of the price if the work takes longer or more resources are required than were estimated in the established price. The price is fixed regardless of the amount of work required to complete the project. Revenue on lump sum contracts is recognized using the percentage-of-completion method, measured by the ratio of costs incurred to date to estimated total cost.

      The mix of contract types varies year-by-year. For the fiscal year ended March 31, 2006, our contracts consisted of 15% cost-plus, 25% time-and-materials, 45% unit-price and 15% lump sum.

      Profit for each type of contract is included in revenue when its realization is reasonably assured. Estimated contract losses are recognized in full when determined. Change orders are included in total estimated contract revenue when it is probable that the change order will result in a bona fide addition to contract value and can be reliably estimated. Revenue in excess of costs from unpriced change orders, extra work and variations in the scope of work is recognized after both the costs are incurred or services are provided and realization is assured beyond a reasonable doubt. Claims are included in total estimated contract revenue, only to the extent that contract costs related to the claim have been incurred, when it is probable that the claim will result in a bona fide addition to contract value and the amount of revenue can be reliably estimated. Costs incurred for bidding and obtaining contracts are expensed as incurred.

      The accuracy of our revenue and profit recognition in a given period is dependent, in part, on the accuracy of our estimates of the cost to complete each unit-price and lump sum project. Our cost estimates use a detailed “bottom up” approach. We believe our experience allows us to produce materially

50

reliable estimates. However, our projects can be highly complex, and in almost every case, the profit margin estimates for a project will either increase or decrease to some extent from the amount that was originally estimated at the time of the related bid. Because we have many projects of varying levels of complexity and size in process at any given time, these changes in estimates can offset each other without materially impacting our profitability. However, large changes in cost estimates, particularly in the bigger, more complex projects, can have a significant effect on profitability.

      Factors that can contribute to changes in estimates of contract cost and profitability include, without limitation:

•  site conditions that differ from those assumed in the original bid, to the extent that contract remedies are unavailable;

•  identification and evaluation of scope modifications during the execution of the project;

•  the availability and cost of skilled workers in the geographic location of the project;

•  the availability and proximity of materials;

•  unfavorable weather conditions hindering productivity;

•  equipment productivity and timing differences resulting from project construction not starting on time; and

•  general coordination of work inherent in all large projects we undertake.

The foregoing factors, as well as the stage of completion of contracts in process and the mix of contracts at different margins, may cause fluctuations in gross profit between periods, and these fluctuations may be significant.

Property, plant and equipment

      The most significant estimate in accounting for property, plant and equipment is the expected useful life of the asset and the expected residual value. Most of our property, plant and equipment has a long life which can exceed 20 years with proper repair work and preventative maintenance. Useful life is measured in operated hours, excluding idle hours, and a depreciation rate is calculated for each type of unit. Depreciation expense is determined each day based on actual operated hours.

      Another key estimate is the expected cash flows from the use of an asset and the expected disposal proceeds in applying Canadian Institute of Chartered Accountants Handbook Section 3063 “Impairment or Disposal of Long-Lived Assets” and the revised Section 3475 “Disposal of Long-Lived Assets and Discontinued Operations.” These standards require the recognition of an impairment loss for a long-lived asset to be held and used when changes in circumstances cause its carrying value to exceed the total undiscounted cash flows expected from its use. An impairment loss, if any, is determined as the excess of the carrying value of the asset over its fair value. Equally important is the expected fair value of assets that are available-for-sale.

Goodwill

      As described under “Consolidated Financial Position – Impairment of Goodwill”, we perform our annual goodwill impairment test in the third quarter of each year, and more frequently if events or changes in circumstances indicate that an impairment loss may have been incurred. Impairment is tested at the reporting unit level by comparing the reporting unit’s carrying amount to its fair value. The process of determining fair values is subjective and requires us to exercise judgment in making assumptions about future results, including revenue and cash flow projections at the reporting unit level, and discount rates.

Derivative financial instruments

      We use derivative financial instruments to manage economic risks from fluctuations in exchange rates and interest rates. These instruments include cross-currency swap agreements and interest rate swap agreements. These instruments are only used for risk management purposes. We do not hold or issue

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derivative financial instruments for trading or speculative purposes. Derivative financial instruments are subject to standard credit terms and conditions, financial controls, management and risk monitoring procedures.

      Our derivative financial instruments are recorded on the balance sheet at fair value, which is determined based on values quoted by the counterparties to the agreements.

Description of Components of Statement of Operations

Revenue

      Revenue includes all amounts earned from the performance of our projects, including amounts arising from change orders and claims. For a description of our revenue recognition policy, refer to note 2(c) to our consolidated financial statements included elsewhere in this prospectus.

Project costs

      Included in project costs are all direct expenses incurred in the execution of our projects, including direct labor, short-term equipment rentals, materials and payments to subcontractors.

Equipment costs

      Included in equipment costs are parts, shop labor and overhead related to the maintenance of our equipment fleet. Equipment insurance premiums and demobilization costs are also included in equipment costs.

Equipment operating lease expense

      Lease payments on plant and equipment, other than payments on capital leases, are recorded as equipment operating lease expense.

Depreciation

      Depreciation includes amortization of our plant and equipment. For a description of our depreciation policy, please see note 2(g) to our consolidated financial statements included elsewhere in this prospectus.

General and administrative

      General and administrative expenses include administrative and other expenses that are not directly attributable to the execution of our contracts. These would include, but are not limited to, management and administrative salaries and wages, non-equipment related insurance, professional fees, office and computer expenses and travel. Stock based compensation is also recorded as general and administrative expense, as are advisory fees paid to the sponsors.

Amortization of intangible assets

      Amortization of intangible assets includes the amortization of our intangible assets, being customer contracts, trade names, non-competition agreements and employee arrangements arising from the Acquisition.

Interest expense

      Interest expense includes the interest on our 9% senior secured notes, 8³/4 % senior notes, revolving credit facility and capital lease obligations. Interest expense also includes amortization of deferred financing costs, the change in redemption value of the Series B preferred shares and the accretion of the Series A preferred shares to their redemption value.

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      Prior to our amendment of the terms of the Series B preferred shares on March 30, 2006, the definition of the redemption price of the Series B preferred shares included a calculation tied to the fair value of the common shares of North American Energy Partners Inc. Any increase or decrease in the fair value of North American Energy Partners’ common shares resulted in a corresponding increase or decrease in the redemption value and, as a consequence, fluctuations in interest expense. The amendment eliminated this calculation from the definition of redemption price. As a result, the Series B preferred shares will now be accreted from $42.2 million to their December 31, 2011 redemption value of $69.6 million, with corresponding periodic charges to interest expense.

Foreign exchange gain

      Foreign exchange gain includes realized and unrealized foreign currency gains or losses on our 9% senior secured notes and 8³/4% senior notes, as well as miscellaneous currency gains or losses realized on the settlement of payables or receivables in the normal course of operations. The foreign currency risk relating to both the principal and interest payments on the 8³/4% senior notes has been managed with a cross currency swap and interest rate swaps which went into effect concurrent with the issuance of the same notes. The swaps on the 8³/4 % senior notes do not qualify for hedge accounting under CICA Accounting Guideline 13 and are remeasured at fair value each reporting period and the changes in fair value are recorded under the caption “Realized and unrealized (gain) loss on derivative financial instruments” in our consolidated financial statements. For more information regarding our derivative financial instruments, refer to note 18(c) to our consolidated financial statements included elsewhere in this prospectus.

Financing costs

      Costs incurred in the course of financing or refinancing debt obligations, and which cannot be deferred for accounting purposes, are included in financing costs. Deferred financing costs associated with debt that has been retired are also written off and recorded as financing costs.

Realized and unrealized loss on derivative financial instruments

      Derivative financial instruments are carried on the balance sheet at fair value, and periodic unrealized changes in fair value are recorded as realized and unrealized loss on derivative financial instruments. For more information regarding our derivative financial instruments, refer to note 18(c) to our consolidated financial statements included elsewhere in this prospectus.

Management fees

      Management fees were fees charged for management services provided to the predecessor company by Norama Inc., its former parent company. Subsequent to the Acquisition on November 26, 2003, these fees are no longer paid.

Income taxes (benefit)

      Income and capital taxes, as well as the impact of changes in our future income tax assets and liabilities are included in income taxes (benefit).

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Results of Operations

			Year Ended March 31,
			2004(a)					2005					2006
			(Dollars in thousands)
Revenue			$	378,263		100.0	%	$	357,323		100.0	%	$	492,237		100.0	%
Project costs				240,232		63.5			240,919		67.4			308,949		62.8
Equipment costs				57,170		15.1			52,831		14.8			64,832		13.2
Equipment operating lease expense				11,932		3.2			6,645		1.9			16,405		3.3
Depreciation				13,240		3.5			20,762		5.8			21,725		4.4
Gross profit				55,689		14.7			36,166		10.1			80,326		16.3
General and administrative				13,848		3.7			22,873		6.4			30,903		6.3
Loss (gain) on sale of capital assets				82		0.0			494		0.1			(733	)	(0.1	)
Amortization of intangible assets				12,928		3.4			3,368		1.0			730		0.1
Operating income				28,831		7.6			9,431		2.6			49,426		10.0
Interest expense				12,536		3.3			31,141		8.7			68,776		14.0
Foreign exchange gain				(668	)	(0.2	)		(19,815	)	(5.5	)		(13,953	)	(2.8	)
Other income				(597	)	(0.2	)		(421	)	(0.1	)		(977	)	(0.2	)
Financing costs				—		—			—		—			2,095		0.4
Realized and unrealized loss on derivative financial instruments				12,205		3.2			43,113		12.1			14,689		3.0
Management fees				41,070		10.9			—		—			—		—
Income (loss) before income taxes				(35,715	)	(9.4	)		(44,587	)	(12.5	)		(21,204	)	(4.4	)
Income taxes (benefit)				(12,292	)	(3.2	)		(2,264	)	(0.6	)		737		0.1
Net income (loss)			$	(23,423	)	(6.2	)%	$	(42,323	)	(11.8	)%	$	(21,941	)	(4.5	)%
Segmented Results of Operations
Revenue by operating segment:
	Mining and site preparation		$	235,772		62.3	%	$	264,835		74.1	%	$	366,721		74.5	%
	Piling			48,982		13.0			61,006		17.1			91,434		18.6
	Pipeline			93,509		24.7			31,482		8.8			34,082		6.9
		Total	$	378,263		100.0	%	$	357,323		100.0	%	$	492,237		100.0	%
Profit by operating segment:
	Mining and site preparation		$	25,899		47.4	%	$	11,617		38.9	%	$	50,730		61.7	%
	Piling			10,831		19.8			13,319		44.6			22,586		27.4
	Pipeline			17,946		32.8			4,902		16.5			8,996		10.9
		Total	$	54,676		100.0	%	$	29,838		100.0	%	$	82,312		100.0	%
Equipment hours by operating segment:
	Mining and site preparation			511,546		73.6	%		673,613		88.2	%		811,891		93.0	%
	Piling			57,569		8.3			56,460		7.4			37,300		4.3
	Pipeline			126,033		18.1			33,847		4.4			24,197		2.8
		Total		695,148		100.0	%		763,920		100.0	%		873,388		100.0	%

(a) Consists of the results of Norama Ltd., our predecessor company, from April 1, 2003 to November 25, 2003, prior to the Acquisition, combined with our results from November 26, 2003 to March 31, 2004, after the Acquisition. The pre- and post-Acquisition periods are presented on a combined basis to allow for a meaningful comparison to other full fiscal years. Any references to the fiscal year ended March 31, 2004 below shall refer to the combined periods.

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Fiscal Year Ended March 31, 2006 Compared to Fiscal Year Ended March 31, 2005

      Revenue. Revenue increased by $134.9 million, or 37.8%, from $357.3 million for the fiscal year ended March 31, 2005 to $492.2 million for the fiscal year ended March 31, 2006.

•  Mining and Site Preparation. Mining and Site Preparation revenue increased by $101.9 million, or 38.5%, from $264.8 million for the fiscal year ended March 31, 2005 to $366.7 million for the fiscal year ended March 31, 2006, primarily due to activity in fiscal 2006 related to the large site preparation and underground utility installation and overburden removal project for CNRL and a substantial mining services project for Grande Cache Coal Corporation. Revenue generated by these projects in fiscal 2006 more than offset the decline in revenue resulting from the substantial completion of the Syncrude Upgrader Expansion, or UE-1, and OPTI/ Nexen Long Lake projects.

•  Piling. Piling revenue increased by $30.4 million, or 49.9%, from $61.0 million for the fiscal year ended March 31, 2005 to $91.4 million for the fiscal year ended March 31, 2006, primarily due to a higher volume of projects in the Fort McMurray, Vancouver and Regina regions because of strong economic and construction activity, as well as the addition of several large piling projects, including projects for Suncor Energy and Flint Infrastructure Services Ltd.

•  Pipeline. Pipeline revenue increased by $2.6 million, or 8.3%, from $31.5 million for the fiscal year ended March 31, 2005 to $34.1 million for the fiscal year ended March 31, 2006 due to an increase in work performed for EnCana and CNRL in fiscal 2006.

      Gross profit. Gross profit increased by $44.2 million, or 122.1%, from $36.2 million for the fiscal year ended March 31, 2005 to $80.3 million for the fiscal year ended March 31, 2006, primarily due to increased project activity and performance combined with efficient use of equipment and the loss recognition on a large steam-assisted gravity drainage site project in fiscal 2005. As a percentage of revenue, gross profit increased to 16.3% for the fiscal year ended March 31, 2006 from 10.1% for the fiscal year ended March 31, 2005, primarily due to improved performance on site preparation projects, increased activity levels and more efficient use of equipment.

      Project costs. Project costs increased by $68.0 million, or 28.2%, from $240.9 million for the fiscal year ended March 31, 2005 to $308.9 million for the fiscal year ended March 31, 2006, primarily due to higher activity levels. As a percentage of revenue, project costs were 62.8% in the fiscal year ended March 31, 2006 as compared to 67.4% in the prior fiscal year. The decline was primarily due to better performance on site preparation projects over the prior fiscal year and a changing project work mix from more labor-intensive projects in the prior fiscal year to more equipment-intensive projects in fiscal 2006.

      Equipment costs. Equipment costs increased by $12.0 million, or 22.7%, from $52.8 million for the fiscal year ended March 31, 2005 to $64.8 million for the fiscal year ended March 31, 2006, primarily due to increased activity levels and higher repair and maintenance costs. Our heavy equipment fleet size increased by five units over the prior year fleet size of 457. As a percentage of revenue, equipment costs were 13.2% as compared to 14.8% in the prior fiscal year, primary due to increased activity levels allowing higher efficiency usage of equipment.

      Equipment operating lease expense. Equipment operating lease expense increased by $9.8 million, or 146.9%, from $6.6 million for the fiscal year ended March 31, 2005 to $16.4 million for the fiscal year ended March 31, 2006, primarily due to the addition of new leased equipment to support new projects, including the 10-year CNRL overburden project.

      Depreciation. Depreciation expense increased by $1.0 million, or 4.6%, from $20.8 million for the fiscal year ended March 31, 2005 to $21.7 million for the fiscal year ended March 31, 2006. The increase was primarily due to the increase in equipment hours related to higher activity levels, as our heavy equipment fleet is depreciated based on operated hours, which increase was partially offset by the use of more leased equipment. As a percentage of revenue, depreciation decreased to 4.4% from 5.8% primarily due to our use of more leased equipment relative to owned equipment.

      Operating income. Operating income increased by $40.0 million, or 424.1%, from $9.4 million for the fiscal year ended March 31, 2005 to $49.4 million for the fiscal year ended March 31, 2006. The

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increase was primarily due to the $44.2 million increase in gross profit, the $0.7 million gain from the disposal of property, plant and equipment and the $2.6 million reduction in amortization of intangible assets, partially offset by the $8.0 million increase in general and administrative expenses.

      General and administrative expenses. General and administrative expenses increased by $8.0 million, or 35.1%, from $22.9 million for the fiscal year ended March 31, 2005 to $30.9 million for the fiscal year ended March 31, 2006. The increase was primarily due to increased professional fees incurred in the first and second quarters of fiscal 2006 as a result of the May 2005 financing transactions and increased salaries as a result of bonus accruals from improved financial performance and our hiring of new executive officers and staff to manage increased activity and corporate requirements. As a percentage of revenue, general and administrative expenses were 6.2% for the fiscal year ended March 31, 2006, as compared to 6.4% for the fiscal year ended March 31, 2005.

      Amortization of intangible assets. Amortization of intangible assets decreased by 78.3%, from $3.4 million for the fiscal year ended March 31, 2005 to $0.7 million for the fiscal year ended March 31, 2006. The amortization of intangible assets in both fiscal 2006 and fiscal 2005 was related to the customer contracts in progress, trade names, a non-competition agreement and employee arrangements that were acquired in the Acquisition on November 26, 2003. Substantially all of the cost of the intangible assets had been amortized as of March 31, 2006 as the majority of the cost relates to customer contracts in progress that were amortized at a rapid rate due to their short-term nature.

      Interest expense. Interest expense increased by $37.6 million, or 120.9%, from $31.1 million for the fiscal year ended March 31, 2005 to $68.8 million for the fiscal year ended March 31, 2006. Interest expense increased by $5.6 million due to the issuance of US$60.5 million of 9% senior secured notes in May 2005 and by $34.7 million due to the issuance and valuation of the redemption value of our Series B preferred shares in May 2005, partially offset by a $3.3 million decrease in interest expense due to full repayment of the borrowings under our senior secured credit facility in May 2005.

      Foreign exchange gain. We recognized a foreign exchange gain of $14.0 million for the fiscal year ended March 31, 2006 as compared to a gain of $19.8 million for the prior fiscal year. Substantially all of the gain in fiscal 2006 related to the exchange difference between the Canadian and U.S. dollar on translation of the US$60.5 million of 9% senior secured notes issued in May 2005 and the US$200.0 million of 8³/4% senior notes, while the gain in the prior fiscal year related only to the US$200.0 million of 8³/4 % senior notes.

      Financing costs. Financing costs were $2.1 million for the fiscal year ended March 31, 2006, and there were no financing costs for the fiscal year ended March 31, 2005. Financing costs included $0.3 million representing the issuance of the Series A preferred shares in May 2005, plus a write off of $1.8 million for deferred financing costs related to the previous senior secured credit facility that was repaid in May 2005.

      Realized and unrealized loss on derivative financial instruments. The realized and unrealized loss on the cross-currency and interest rate swap agreements was $14.7 million for the fiscal year ended March 31, 2006. These losses relate primarily to the mark-to-market changes in the fair value of the derivatives, which relate to the 8³/4 % senior notes. The realized and unrealized loss on the derivative financial instruments was $43.1 million for the fiscal year ended March 31, 2005.

      Income taxes. Income tax expense was $0.7 million for the fiscal year ended March 31, 2006, as compared to a net benefit of $2.3 million for the fiscal year ended March 31, 2005. At March 31, 2006, we had accumulated non-capital losses for income tax purposes of approximately $66.4 million, the majority of which expire in 2012 and 2013. We have recorded a full valuation allowance to reduce the net future income tax asset to zero, reflecting the uncertainty of realizing the benefit of the losses before they expire. The income tax expense reflects only the Large Corporations Tax, which is a form of minimum tax that is paid currently.

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Fiscal Year Ended March 31, 2005 Compared to Fiscal Year Ended March 31, 2004

      Revenue. Revenue decreased by $21.0 million, or 5.6%, from $378.3 million for the fiscal year ended March 31, 2004 to $357.3 million for the fiscal year ended March 31, 2005.

•  Mining and Site Preparation. Mining and Site Preparation revenue increased by $29.0 million, or 12.3%, from $235.8 million for the fiscal year ended March 31, 2004 to $264.8 million for the fiscal year ended March 31, 2005. Contributing to this increase was revenue from new projects such as the underground utility installation contract for CNRL and the mining services contract for Grande Cache Coal Corporation, as well as the OPTI/ Nexen Long Lake project. Offsetting these increases were decreases in revenue from the Syncrude UE-1 project as this contract neared completion, the Syncrude Aurora II project as this contract was completed in the fiscal 2004, and the Albian site as they lowered their demand for contract services in fiscal 2005.

•  Piling. Piling revenue increased by $12.0 million, or 24.5% from $49.0 million for the fiscal year ended March 31, 2004 to $61.0 million for the fiscal year ended March 31, 2005, primarily due to a higher volume of contracts in the Vancouver, Regina and Fort McMurray regions due to strong economic activity, as well as the addition of large piling contracts for Flint Infrastructure Services Ltd. and Suncor Energy. This additional work more than offset the loss of revenue generated by the Syncrude UE-1 piling contract in fiscal 2004.

•  Pipeline. Pipeline revenue decreased by $62.0 million, or 66.3%, from $93.5 million for the fiscal year ended March 31, 2004 to $31.5 million for the fiscal year ended March 31, 2005, primarily due to a decrease in work performed for our major pipeline customer in fiscal 2005. The decrease in volume was primarily due to our customer repositioning its efforts in the region and drilling a much lower number of gas wells.

      Gross profit. Gross profit decreased by $19.5 million, or 35.1%, from $55.7 million for the fiscal year ended March 31, 2004 to $36.2 million for the fiscal year ended March 31, 2005, primarily due to loss recognition on a large steam-assisted gravity drainage site project and a significant decrease in revenue from our Pipeline segment. As a percentage of revenue, gross profit decreased to 10.1% for the fiscal year ended March 31, 2005 from 14.7% for the fiscal year ended March 31, 2004, primarily due to the loss recognition described above.

      Project costs. Project costs increased by $0.6 million, or 0.3%, from $240.2 million for the fiscal year ended March 31, 2004 to $240.9 million for the fiscal year ended March 31, 2005. As a percentage of revenue, project costs were 67.4% of revenue in the fiscal year ended March 31, 2005 as compared to 63.5% in the prior fiscal year. In the fiscal year ended March 31, 2005, abnormally high costs as a percentage of revenue were incurred on a large steam-assisted gravity drainage site project.

      Equipment costs. Equipment costs decreased by $4.3 million, or 7.6%, from $57.2 million for the fiscal year ended March 31, 2004 to $52.8 million for the fiscal year ended March 31, 2005. As a percentage of revenue, equipment costs were 14.8% as compared to 15.1% in the prior fiscal year. Equipment maintenance costs were lower in fiscal 2005 because newer equipment added during the year required fewer repairs and we experienced a decrease in equipment hours in fiscal 2005.

      Equipment operating lease expense. Equipment operating lease expense decreased by $5.3 million, or 44.3%, from $11.9 million for the fiscal year ended March 31, 2004 to $6.6 million for the fiscal year ended March 31, 2005, primarily due to the purchase of equipment under operating leases in connection with the Acquisition on November 26, 2003.

      Depreciation. Depreciation expense increased by $7.5 million, or 56.8%, from $13.2 million for the fiscal year ended March 31, 2004 to $20.8 million for the fiscal year ended March 31, 2005. As a percentage of revenue, depreciation increased to 5.8% from 3.5%. The increase was primarily due to the addition of new equipment resulting from the buy-out of the leased and rented equipment in November 2003 and increased depreciable asset values resulting from the revaluation of assets to their estimated fair values in accordance with the application of purchase accounting in connection with the Acquisition on November 26, 2003. The year-over-year increase in equipment hours also contributed to the increased depreciation expense for the fiscal year ended March 31, 2005.

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      Operating income. Operating income decreased by $19.4 million, or 67.3%, from $28.8 million for the fiscal year ended March 31, 2004 to $9.4 million for the fiscal year ended March 31, 2005. The decrease was primarily due to the $19.5 million decrease in gross profit and the $9.0 million increase in general and administrative expenses, partially offset by the $9.6 million decrease in amortization expense.

      General and administrative expenses. General and administrative expenses increased by $9.0 million, or 65.2%, from $13.8 million for the fiscal year ended March 31, 2004 to $22.9 million for the fiscal year ended March 31, 2005. As a percentage of revenue, general and administrative expenses increased from 3.7% to 6.4%. The increase was primarily attributable to higher staff levels, increased salaries, higher legal and consulting costs and increased accounting and audit fees related to North American Energy Partners’ restatement of two quarters of financial statements in the fiscal year ended March 31, 2005.

      Amortization of intangible assets. Amortization of intangible assets decreased by $9.6 million, or 73.9%, from $12.9 million for the fiscal year ended March 31, 2004 to $3.4 million for the fiscal year ended March 31, 2005. The amortization of intangible assets in both fiscal 2005 and fiscal 2004 was related to the customer contracts in progress and related relationships, trade names, a non-competition agreement and employee arrangements that were acquired in the Acquisition on November 26, 2003. A majority of the cost of the intangible assets had been amortized as of March 31, 2005, as most of the costs related to customer contracts acquired in the Acquisition in November 2003 that were amortized at a rapid rate due to their short-term nature.

      Interest expense. Interest expense increased by $18.6 million, or 148.4%, from $12.5 million for the fiscal year ended March 31, 2004 to $31.1 million for the fiscal year ended March 31, 2005, primarily due to the addition of our 8³/4 % senior notes issued in November 2003, to finance a portion of the Acquisition and borrowings under our senior secured credit facility.

      Foreign exchange gain. We recognized a foreign exchange gain of $19.8 million for the fiscal year ended March 31, 2005 as compared to a gain of $0.7 million for the prior fiscal year. The foreign exchange gains in both the current and prior periods related primarily to the change in the balance owed on the 8³/4 % senior notes due to the appreciation in the value of the Canadian dollar relative to the U.S. dollar.

      Realized and unrealized loss on derivative financial instruments. For the fiscal year ended March 31, 2005, the realized and unrealized losses on our cross-currency and interest rate swap agreements related to our 8³/4 % senior notes were $2.7 million and $40.4 million, respectively, as compared to $0.9 million and $11.3 million, respectively, for the fiscal year ended March 31, 2004. The losses in both fiscal 2005 and fiscal 2004 related primarily to the changes in the fair value of the derivatives in the period due to the appreciation in the value of the Canadian dollar relative to the U.S. dollar.

      Management fees. We did not incur any management fee expense for the fiscal year ended March 31, 2005. For the fiscal year ended March 31, 2004, we incurred management fee expense of $41.1 million.

      Income taxes. We had a net benefit from income taxes of $2.3 million for the fiscal year ended March 31, 2005, as compared to a net benefit of $12.3 million for the fiscal year ended March 31, 2004. At March 31, 2005, we had accumulated non-capital losses for income tax purposes of approximately $90.8 million, the majority of which expire in 2012 and 2013. We recorded a full valuation allowance to reduce the net future income tax asset to zero, reflecting the uncertainty of realizing the benefit of the losses before they expire.

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Comparative Quarterly Results

      A number of factors contribute to variations in our results between periods, such as weather, customer capital spending on large oil sands and natural gas related projects, our ability to manage our project related business so as to avoid or minimize periods of relative inactivity and the strength of the western Canadian economy.

	Fiscal Year 2005												Fiscal Year 2006
	Q1			Q2			Q3			Q4			Q1			Q2		Q3		Q4
	(In millions of dollars, except equipment hours)
Revenue	$	70.9		$	82.7		$	81.0		$	122.7		$	104.4		$	124.0	$	121.5	$	142.3
Gross profit		8.1			9.8			(5.7	)		24.0			12.9			21.9		13.8		31.7
Net income (loss)		(5.1	)		(4.7	)		(32.4	)		(0.1	)		(49.2	)		11.5		2.1		13.7
Equipment hours		137,434			193,205			191,555			241,727			185,751			234,649		221,355		231,633

Seasonality

      We generally experience a decline in revenues during our first quarter of each fiscal year due to seasonality, as weather conditions make operations in our operating regions difficult during this period. The level of activity in our mining and site preparation and pipeline installation segments declines when frost leaves the ground and many secondary roads are temporarily rendered incapable of supporting the weight of heavy equipment. The duration of this period is referred to as “spring breakup” and has a direct impact on our activity levels. Our fourth quarter revenues are typically our highest as ground conditions are best and customers often begin spending their new capital expenditure budgets. As a result, full-year results are not likely to be a direct multiple of any particular quarter or combination of quarters.

Consolidated Financial Position

      At March 31, 2006, we had net working capital of $68.5 million compared to a net working capital position of $41.7 million at March 31, 2005. The increase was primarily due to increased cash and cash equivalents of $24.9 million, work in progress generating higher accounts receivable by $11.6 million, partially offset by an increase of $9.5 million in accounts payable, accrued liabilities, billings in excess of costs on uncompleted projects and current portion of capital lease obligations.

      Plant and equipment net of depreciation increased by $8.5 million at March 31, 2006 from March 31, 2005 primarily due to the construction of a shop to support the maintenance requirements of our 10-year overburden removal project for CNRL and the expansion of our head office. A portion of the increase also resulted from equipment purchases to replace retired equipment.

      Capital lease obligations, including the current portion, increased by $3.7 million at March 31, 2006 from the balance at March 31, 2005 due to the addition of new leased vehicles and a viper drill to support new projects.

Impairment of Goodwill

      In accordance with Canadian Institute of Chartered Accountants’ Handbook Section 3062, “Goodwill and Other Intangible Assets”, we review our goodwill for impairment annually or whenever events or changes in circumstances suggest that the carrying amount may not be recoverable. We are required to test our goodwill for impairment at the reporting unit level and we have determined that we have three reporting units. The test for goodwill impairment is a two-step process:

•  Step 1 – We compare the carrying amount of each reporting unit to its fair value. If the carrying amount of a reporting unit exceeds its fair value, we have to perform the second step of the process. If not, no further work is required.

•  Step 2 – We compare the implied fair value of each reporting unit’s goodwill to its carrying amount. If the carrying amount of a reporting unit’s goodwill exceeds its fair value, an impairment loss will be recognized in an amount equal to that excess.

      We completed this test during the quarter ended December 31, 2005 and were not required to record an impairment loss on goodwill. We conduct our annual assessment of goodwill in December of each year.

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Liquidity and Capital Resources

Operating activities

      Operating activities for the fiscal year ended March 31, 2006 resulted in a net increase in cash of $33.9 million. Increased earnings and accrued liabilities were partially offset by an increase in accounts receivable. The net usage of cash in operating activities for the fiscal year ended March 31, 2005 was $4.8 million primarily due to an increase in unbilled revenue due to billing delays and poor performance from a major site grading project. Operating activities for the fiscal year ended March 31, 2004 resulted in a net increase in cash of $18.0 million, primarily as a result of a decrease in accounts receivable.

Investing activities

      During the fiscal year ended March 31, 2006, we invested $7.4 million in sustaining capital expenditures and $21.6 million in growth capital expenditures, for total capital expenditures of $29.0 million. In the fiscal year ended March 31, 2005, we invested $7.5 million in sustaining capital expenditures and $18.2 million in growth capital expenditures, for total capital expenditures of $25.7 million. In the fiscal year ended March 31, 2004, we invested $4.5 million in sustaining capital expenditures and $3.2 million in growth capital expenditures, for total capital expenditures of $7.7 million. These capital expenditure amounts exclude any equipment additions financed under capital leases.

      Sustaining capital expenditures are those that are required to keep our existing fleet of equipment at its optimum average age through maintenance or replacement. Growth capital expenditures relate to equipment additions required to perform increased sizes or numbers of projects.

Financing activities

      Financing activities during the fiscal year ended March 31, 2006 resulted in a cash inflow of $13.2 million. A portion of the proceeds from the issuance of the US$60.5 million of 9% senior secured notes and $7.5 million of Series B preferred shares was used to repay the amount outstanding under our senior secured credit facility and to pay the fees and expenses related to the refinancing. Payments of $2.2 million were also made on our capital lease obligations. Financing activities during the fiscal year ended March 31, 2005 related primarily to borrowings under our revolving credit facility, term credit facility scheduled repayments and repayment of capital lease obligations.

Liquidity Requirements

      Our primary uses of cash are to purchase property, plant and equipment, fulfill debt repayment and interest payment obligations and finance working capital requirements.

      We have outstanding US$200 million of 8³/4% senior notes due 2011. The foreign currency risk relating to both the principal and interest payments on the 8³/4% senior notes has been managed with a cross-currency swap and interest rate swaps which went into effect concurrent with the issuance. Interest of $12.8 million is payable semi-annually in June and December of each year until the notes mature on December 1, 2011. The swap agreements are economic hedges of the changes in the Canadian dollar-U.S. dollar exchange rate, but they do not meet the criteria to qualify for hedge accounting. There are no principal payments required on the 8³/4 % senior notes until maturity.

      Our US$60.5 million of 9% senior secured notes were issued on May 19, 2005 pursuant to a private placement. On July 26, 2005, we registered substantially identical notes with the United States Securities and Exchange Commission and exchanged them for the notes issued in the private placement. The foreign currency risk relating to both the principal and interest payments on the 9% senior secured notes has not been hedged. Interest of US$2.7 million is payable semi-annually in June and December of each year until the notes mature on June 1, 2010. There are no principal payments required on the 9% senior secured notes until maturity.

      Further, one of our major contracts allows the customer to request up to $50 million in letters of credit. While this level has not been requested to date, we would either have to lower other letters of credit or cash collateralize other obligations to provide this amount of letters of credit.

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      We maintain a significant equipment and vehicle fleet comprised of units with various remaining useful lives. Once units reach the end of their useful lives, it becomes cost prohibitive to continue to maintain them and, therefore, they must be replaced. As a result, we are continually acquiring new equipment to replace retired units and to expand the fleet to meet growth as new projects are awarded to us. It is important to adequately maintain the large revenue-producing fleet in order to avoid equipment downtime which can impact our revenue stream and inhibit our ability to satisfactorily perform on our projects. In order to conserve cash, we have financed our recent requirements for large pieces of heavy construction equipment through operating leases. In addition, we continue to lease a portion of our motor vehicle fleet and assumed several heavy equipment operating leases from Norama Ltd. in connection with the Acquisition on November 26, 2003.

      Our cash requirements during the fiscal year ended March 31, 2006 increased due to continued growth and additional operating and capital expenditures associated with new projects. Our cash requirements for fiscal 2007 include funding operating lease obligations, debt and interest repayment obligations and working capital as activity levels are expected to continue to increase. In addition, we will require capital to finance further vehicle and equipment acquisitions for upcoming new projects.

      We expect our sustaining capital expenditures to range from $10 million to $15 million per year over the next two years. We expect our total capital expenditures to range from $50 million to $60 million in fiscal 2007.

Sources of Liquidity

      Our principal sources of cash are funds from operations and borrowings under our revolving credit facility. On July 19, 2006, we amended and restated our revolving credit facility to provide for borrowings and the issuance of letters of credit of up to $55.0 million, subject to borrowing base limitations. As of July 19, 2006, we had approximately $37.0 million of available borrowings under the revolving credit facility after taking into account $18.0 million of outstanding and undrawn letters of credit to support bonding requirements and performance guarantees associated with customer contracts and operating leases. The facility bears interest at the Canadian prime rate plus 2% or Canadian bankers’ acceptance rate plus 3%. The indebtedness under the revolving credit facility, including the liability under the swaps used to manage the foreign currency risk on the 8³/4 % senior notes, is secured by substantially all of our assets and those of our subsidiaries, including accounts receivable, inventory and plant and equipment, and a pledge of the shares of the pre-amalgamated North American Energy Partners Inc. and that of its subsidiaries.

      Our revolving credit facility contains covenants that restrict our activities, including restrictions on creating liens, engaging in mergers, consolidations and sales of assets, incurring additional indebtedness, giving guaranties, engaging in different businesses, making loans and investments, making certain capital expenditures and making certain dividend, debt and other restricted payments. Under the revolving credit facility, we also are required to satisfy certain financial covenants, including a minimum interest coverage ratio, a maximum leverage ratio and a minimum consolidated EBITDA requirement. Consolidated EBITDA is defined in the credit facility as the sum, without duplication, of (1) consolidated net income, (2) consolidated interest expense, (3) provisions for taxes based on income, (4) total depreciation expense, (5) total amortization expense, (6) costs and expenses incurred by us in entering into the credit facility, (7) accrual of stock-based compensation expense to the extent not paid in cash, and (8) other non-cash items (other than any such non-cash item to the extent it represents an accrual of or reserve for cash expenditures in any future period), but only, in the case of clauses (2)-(8), to the extent deducted in the calculation of consolidated net income, less other non-cash items added in the calculation of consolidated net income (other than any such non-cash item to the extent it will result in the receipt of cash payments in any future period), all of the foregoing as determined on a consolidated basis for us in conformity with GAAP. The required minimum Consolidated EBITDA through December 31, 2006 is $65.5 million, and this minimum amount increases periodically until the credit facility matures. We believe Consolidated EBITDA as defined in the credit facility is an important measure of our liquidity.

      The Series B preferred shares were initially issued by the pre-amalgamated North American Energy Partners Inc. for net cash proceeds of $7.5 million on May 19, 2005 to our existing common shareholders,

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including the sponsors. For additional information on the Series B preferred shares, see note 13(b) to our consolidated financial statements included elsewhere in this prospectus.

      Between March 31, 2004 and May 19, 2005, it was necessary to obtain a series of waivers and amend our then-existing credit agreement to avoid or to cure our default of various covenants contained in that credit agreement. We ultimately replaced that credit agreement with a new credit agreement on May 19, 2005, which we replaced with our current amended and restated credit agreement on July 19, 2006.

      Our inability to file North American Energy Partners Inc.’s financial statements for the periods ended December 31, 2004, March 31, 2005 and September 30, 2005 with the SEC within the deadlines imposed by covenants in the indentures governing our 8³/4 % senior notes and our 9% senior secured notes caused us to be out of compliance with such covenants. In each case, we filed our financial statements before the lack of compliance became an event of default under the indentures.

Contractual Obligations and Other Commitments

      Our principal contractual obligations relate to our long-term debt (8³/4 % senior notes and 9% senior secured notes), preferred shares and capital and operating leases. The following table summarizes our future contractual obligations, excluding interest payments unless otherwise noted, as of March 31, 2006.

	Payments Due by Fiscal Year
											2011 and
	Total		2007		2008		2009		2010		After
	(In millions)
Long-term debt	$	304.0	$	—	$	—	$	—	$	—	$	304.0
Seller preferred shares		35.0		—		—		—		—		35.0
Series A preferred shares(a)		1.0		—		—		—		—		1.0
Series B preferred shares(a)		69.6		—		—		—		—		69.6
Capital leases (including interest)		12.7		3.8		3.6		3.0		2.1		0.2
Operating leases		57.6		21.2		16.5		9.6		8.1		2.2
Total contractual cash obligations	$	479.9	$	25.0	$	20.1	$	12.6	$	10.2	$	412.0

(a)  Reflected at fully accreted redemption value.

Off-Balance Sheet Arrangements

      As of March 31, 2006, we had $18.0 million of outstanding, undrawn letters of credit issued under our revolving credit facility.

Stock-Based Compensation

      Some of our directors, officers, employees and service providers have been granted options to purchase our common shares under a stock-based compensation plan. See “Management.”

Recently Adopted Canadian Accounting Pronouncements

Hedge relationships

      Effective November 26, 2003, the Company prospectively adopted the provisions of CICA Accounting Guideline 13, “Hedging Relationships” (“AcG-13”), which specifies the circumstances in which hedge accounting is appropriate, including the identification, documentation, designation, and effectiveness of hedges, and the discontinuance of hedge accounting. The Company determined that all of its then existing derivative financial instruments did not qualify for hedge accounting on the adoption date of AcG-13.

Generally accepted accounting principles

      Effective November 26, 2003, the Company adopted CICA Handbook Section 1100, “Generally Accepted Accounting Principles,” which establishes standards for financial reporting in accordance with Canadian GAAP, and describes what constitutes Canadian GAAP and its sources. This section also provides guidance on sources to consult when selecting accounting policies and determining appropriate

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disclosures when the primary sources of Canadian GAAP do not provide guidance. The adoption of this standard did not have a material impact on the consolidated financial statements.

Revenue recognition

      Effective January 1, 2004, the Company prospectively adopted CICA Emerging Issues Committee Abstract No. 141, “Revenue Recognition,” and CICA Emerging Issues Committee Abstract No. 142, “Revenue Arrangements with Multiple Deliverables,” which incorporate the principles and guidance for revenue recognition provided under United States generally accepted accounting principles (“U.S. GAAP”). No changes to the recognition, measurement or classification of revenue were made as a result of the adoption of these standards.

Consolidation of variable interest entities

      Effective January 1, 2005, we prospectively adopted CICA Accounting Guideline 15, “Consolidation of Variable Interest Entities” (“AcG-15”). Variable interest entities (“VIEs”) are entities that have insufficient equity at risk to finance their operations without additional subordinated financial support and/or entities whose equity investors lack one or more of the specified essential characteristics of a controlling financial interest. AcG-15 provides specific guidance for determining when an entity is a variable interest entity (“VIE”) and who, if anyone, should consolidate the VIE. We have determined the joint venture in which we have an investment (see note 15(c) to our consolidated financial statements included elsewhere in this prospectus) qualifies as a VIE and began consolidating this VIE effective January 1, 2005.

Arrangements containing a lease

      Effective January 1, 2005, we adopted EIC-150, “Determining Whether an Arrangement Contains a Lease” (“EIC-150”). EIC-150 addresses a situation where an entity enters into an arrangement, comprising a transaction that does not take the legal form of a lease but conveys a right to use a tangible asset in return for a payment or series of payments. The implementation of this standard did not have a material impact on our consolidated financial statements.

Vendor rebates

      In April 2005, we adopted amended EIC-144, “Accounting by a Customer (Including a Reseller) for Certain Consideration Received from a Vendor” (“EIC-144”). EIC-144 requires companies to recognize the benefit of non-discretionary rebates for achieving specified cumulative purchasing levels as a reduction of the cost of purchases over the relevant period, provided the rebate is probable and reasonably estimable. Otherwise, the rebates would be recognized as purchasing milestones are achieved. The implementation of this new standard did not have a material impact on our consolidated financial statements.

Accounting for convertible debt instruments

      In October 2005, the CICA issued EIC-158 “Accounting for Convertible Debt Instruments” (“EIC-158”) which provides guidance on whether an issuer of certain types of convertible debt instruments should classify the instruments as liabilities or equity and, if a liability, when it should be classified as a current liability. EIC-158 was applicable for convertible debt instruments issued after October 17, 2005. The adoption of this standard did not have an impact on our consolidated financial statements.

Non-monetary transactions

      Effective January 1, 2006, we adopted CICA Handbook Section 3831, “Non-monetary Transactions”. The new standard requires that an asset exchanged or transferred in a non-monetary transaction must be measured at its fair value except when: the transaction lacks commercial substance; the transaction is an exchange of production or property held for sale in the ordinary course of business for production or property to be sold in the same line of business to facilitate sales to customers other than the parties to the exchange; neither the fair value of the assets or services received nor the fair value of the assets or services given up is reliably measurable; or the transaction is a non-monetary, non-reciprocal transfer to owners that represents a spin-off or other form of restructuring or liquidation. In these cases, the transaction must

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be measured at carrying value. The adoption of this standard did not have a material impact on our consolidated financial statements.

Implicit variable interests under AcG-15

      Effective January 1, 2006, we adopted EIC-157, “Implicit Variable Interests Under AcG-15” (“EIC-157”). EIC-157 requires a company to assess whether it has an implicit variable interest in a VIE or potential VIE when specific conditions exist. An implicit variable interest acts the same as an explicit variable interest except it involves the absorbing and/or receiving of variability indirectly from the entity (rather than directly). The identification of an implicit variable interest is a matter of judgment that depends on the relevant facts and circumstances. The adoption of this standard did not have a material impact on our consolidated financial statements.

Conditional asset retirement obligations

      In November 2005, the CICA issued EIC-159, “Conditional Asset Retirement Obligations” (“EIC-159”) to clarify the accounting treatment for a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Under EIC-159, an entity is required to recognize a liability for the fair value of a conditional asset retirement obligation if the obligation can be reasonably estimated. The guidance is effective April 1, 2006, although early adoption is permitted, and is to be applied retroactively, with restatement of prior periods. We adopted this standard in fiscal 2006, and the adoption did not have a material impact on our consolidated financial statements.

Recent Canadian Accounting Pronouncements Not Yet Adopted

Financial instruments

      In January 2005, the CICA issued Handbook Section 3855, “Financial Instruments – Recognition and Measurement”, Handbook Section 1530, “Comprehensive Income”, and Handbook Section 3865, “Hedges”. The new standards are effective for interim and annual financial statements for fiscal years beginning on or after October 1, 2006, specifically April 1, 2007 for us. Earlier adoption is permitted. The new standards will require presentation of a separate statement of comprehensive income under specific circumstances. Foreign exchange gains and losses on the translation of the financial statements of self-sustaining subsidiaries previously recorded in a separate section of shareholder’s equity will be presented in comprehensive income. Derivative financial instruments will be recorded in the balance sheet at fair value and the changes in fair value of derivatives designated as cash flow hedges will be reported in comprehensive income. We are currently assessing the impact of the new standards.

Accounting Policy Changes

Revenue recognition

      Effective April 1, 2005, we amended our accounting policy regarding the recognition of revenue on claims to be fully compliant with AICPA Statement of Position 81-1 by reflecting the amount of claims revenue on unit price contracts and to provide better matching of revenues and expenses. Once contract performance is underway, we often experience changes in conditions, client requirements, specifications, designs, materials and work schedule. Generally, a “change order” will be negotiated with our customer to modify the original contract to approve both the scope and price of the change. Occasionally, however, disagreements arise regarding changes, their nature, measurement, timing and other characteristics that impact costs and revenue under the contract. When a change becomes a point of dispute between our customer and us, we then consider it as a claim.

      Costs related to change orders and claims are recognized when they are incurred. Change orders are included in total estimated contract revenue when it is probable that the change order will result in a bona fide addition to contract value and can be reliably estimated. Prior to April 1, 2005, revenue from claims was included in total estimated contract revenue when awarded or received. After April 1, 2005, claims are included in total estimated contract revenue, only to the extent that contract costs related to the claim have been incurred, when it is probable that the claim will result in a bona fide addition to contract value

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and can be reliably estimated. Those two conditions are satisfied when (1) the contract or other evidence provides a legal basis for the claim or a legal opinion is obtained providing a reasonable basis to support the claim, (2) additional costs incurred were caused by unforeseen circumstances and are not the result of deficiencies in our performance, (3) costs associated with the claim are identifiable and reasonable in view of work performed and (4) evidence supporting the claim is objective and verifiable. This can lead to a situation where costs are recognized in one period and revenue, when the above conditions warrant recognition of the claim, occurs in subsequent periods. Historical claim recoveries should not be considered indicative of future claim recoveries. For additional information, refer to note 2(c) to our consolidated financial statements included elsewhere in this prospectus.

U.S. Generally Accepted Accounting Principles

      Our consolidated financial statements have been prepared in accordance with Canadian GAAP, which differs in certain material respects from U.S. GAAP. The nature and effect of these differences are set out in note 23 to our consolidated financial statements included in this prospectus.

United States accounting pronouncements recently adopted

      In December 2003, the U.S. Financial Accounting Standards Board (the “FASB”) issued FASB Interpretation No. 46 (revised December 2003), “Consolidation of Variable Interest Entities” (“FIN 46R”), which addresses how a business enterprise should evaluate whether it has a controlling financial interest in an entity through means other than voting rights and accordingly should consolidate the entity. FIN 46R replaces FASB Interpretation No. 46, “Consolidation of Variable Interest Entities,” which was issued in January 2003. We are required to apply FIN 46R to variable interests in VIEs created after December 31, 2003. With respect to entities that do not qualify to be assessed for consolidation based on voting interests, FIN 46R generally requires a company that has a variable interest(s) that will absorb a majority of the VIE’s expected losses if they occur, receive a majority of the entity’s expected residual returns if they occur, or both, to consolidate that VIE. For variable interests in VIEs created before January 1, 2004, the Interpretation was applied beginning on January 1, 2005. For any VIEs that must be consolidated under FIN 46R that were created before January 1, 2004, the assets, liabilities and noncontrolling interests of the VIE initially would be measured at their carrying amounts with any difference between the net amount added to the balance sheet and any previously recognized interest being recognized as the cumulative effect of an accounting change. If determining the carrying amounts is not practicable, fair value at the date FIN 46R first applies may be used to measure the assets, liabilities and noncontrolling interest of the VIE. We have has determined the joint venture in which we have an investment (see note 15(c) to our consolidated financial statements included elsewhere in this prospectus) qualifies as a VIE.

      Statement of Financial Accounting Standards No. 150, “Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity,” was issued in May 2003. This Statement establishes standards for the classification and measurement of certain financial instruments with characteristics of both liabilities and equity. The Statement also includes required disclosures for financial instruments within its scope. We adopted the Statement as of January 1, 2004, except for certain mandatorily redeemable financial instruments. For certain mandatorily redeemable financial instruments, we adopted the Statement on January 1, 2005. The adoption of the standard required us to reclassify the carrying value of the Seller preferred shares from minority interest to redeemable preferred shares. After the adoption of the standard, the Company issued other mandatorily redeemable preferred shares that were within the scope of the standard, which have been disclosed in note 13(a) to our consolidated financial statements included elsewhere in this prospectus.

      In November 2004, the FASB issued Statement of Financial Accounting Standards No. 151, “Inventory Costs.” This standard requires the allocation of fixed production overhead costs be based on the normal capacity of the production facilities and unallocated overhead costs recognized as an expense in the period incurred. In addition, other items such as abnormal freight, handling costs and wasted materials require treatment as current period charges rather than being considered an inventory cost. This standard

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was effective for fiscal 2006 for us. The adoption of this standard did not have a material impact on our financial statements.

      In March 2005, the FASB issued FASB Interpretation No. 47, “Accounting for Conditional Asset Retirement Obligations, an interpretation of FASB Statement No. 143” (“FIN 47”), which requires an entity to recognize a liability for the fair value of a conditional asset retirement obligation when incurred if the liability’s fair value can be reasonably estimated. FIN 47 is effective for fiscal years ending after December 15, 2005. The adoption of this standard did not have a material impact on our financial statements.

      Statement of Financial Accounting Standards No. 153, “Exchanges of Non-monetary Assets – an Amendment of APB Opinion 29” (“SFAS 153”), was issued in December 2004. Accounting Principles Board (“APB”) Opinion 29 is based on the principle that exchanges of non-monetary assets should be measured based on the fair value of assets exchanged. SFAS 153 amends APB Opinion 29 to eliminate the exception for non-monetary exchanges of similar productive assets and replaces it with a general exception for exchanges of non-monetary assets that do not have commercial substance. The standard is effective for us for non-monetary asset exchanges occurring in fiscal periods beginning after June 15, 2005, beginning July 1, 2005 for us. The adoption of this standard did not have a material impact on our financial statements.

      In March 2005, FASB Staff Position FIN 46R-5, “Implicit Variable Interests under FASB Interpretation No. 46(R), Consolidation of Variable Interest Entities”, to address whether a company has an implicit variable interest in a VIE or potential VIE when specific conditions exist. The guidance describes an implicit variable interest as an implied financial interest in an entity that changes with changes in the fair value of the entity’s net assets exclusive of variable interests. An implicit variable interest acts the same as an explicit variable interest except that it involves the absorbing and/or receiving of variability indirectly from the entity (rather than directly). This guidance was adopted in 2006 and did not have a material impact on our consolidated financial statements.

Recent United States accounting pronouncements not yet adopted

      Statement of Financial Accounting Standards No. 123R, “Share-Based Payment” (“SFAS 123R”) requires companies to recognize in the income statement, the grant-date fair value of stock options and other equity-based compensation issued to employees. The fair value of liability-classified awards is remeasured subsequently at each reporting date through the settlement date, while the fair value of equity-classified awards is not subsequently remeasured. The revised standard is effective for non-public companies beginning with the first annual reporting period that begins after December 15, 2005, which in our case is the period beginning April 1, 2006. We have used the fair value method under Statement 123 since its inception. We will be required to adopt SFAS 123R prospectively since we use the minimum value method for purposes of complying with Statement 123. We are currently evaluating the other impacts of the revised standard.

      In May 2005, the FASB issued Statement of Financial Accounting Standards No. 154, “Accounting Changes and Error Corrections” (“SFAS 154”) which replaces Accounting Principles Board Opinions No. 20 “Accounting Changes” and Statement of Financial Accounting Standards No. 3, “Reporting Accounting Changes in Interim Financial Statements – An Amendment of APB Opinion No. 28.” SFAS 154 provides guidance on the accounting for and reporting of accounting changes and error corrections. It establishes retrospective application, or the latest practicable date, as the required method for reporting a change in accounting principle and the reporting of a correction of an error. SFAS 154 is effective for accounting changes and corrections of errors made in fiscal years beginning after December 15, 2005 and is required to be adopted by us in our fiscal year beginning on April 1, 2006. We are currently evaluating the effect that the adoption of SFAS 154 will have on our consolidated results of operations and financial position but do not expect it to have a material impact.

      Statement of Financial Accounting Standards No. 155, “Accounting for Certain Hybrid Financial Instruments – an amendment of FASB Statements No. 133 and 140” (“SFAS 155”) was issued February 2006. This Statement is effective for all financial instruments acquired, issued, or subject to a

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remeasurement (new basis) event occurring after the beginning of an entity’s first fiscal year that begins after September 15, 2006. The fair value election provided for in paragraph 4(c) of this Statement may also be applied upon adoption of this Statement for hybrid financial instruments that had been bifurcated under paragraph 12 of Statement 133 prior to the adoption of this Statement. This states that an entity that initially recognizes a host contract and a derivative instrument may irrevocably elect to initially and subsequently measure that hybrid financial instrument, in its entirety, at fair value with changes in fair value recognized in earnings. SFAS 155 is applicable for all financial instruments acquired or issued in our 2007 fiscal year although early adoption is permitted. we are currently reviewing the impact of this Statement.

      In June 2006, the FASB issued Interpretation No. 48, “Accounting for Uncertainty in Income Taxes — an interpretation of FASB Statement No. 109” (“FIN 48”) which clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, “Accounting for Income Taxes”. FIN 48 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This Interpretation also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition requirements. We are currently reviewing the impact of this Interpretation.

Quantitative and Qualitative Disclosures Regarding Market Risk

Foreign currency risk

      We are subject to currency exchange risk as our 8³/4% senior notes and 9% senior secured notes are denominated in U.S. dollars and all of our revenues and most of our expenses are denominated in Canadian dollars. We have entered into cross currency swap and interest rate swap agreements to manage the foreign currency risk on the 8³/4 % senior notes. The hedging instrument consists of three components: a U.S. dollar interest rate swap; a U.S. dollar-Canadian dollar cross-currency basis swap; and a Canadian dollar interest rate swap that results in us mitigating our exposure to the variability of cash flows caused by currency fluctuations relating to the US$200 million senior notes. The hedges can be cancelled at the counterparty’s option at any time after December 1, 2007 if the counterparty pays a cancellation premium. The premium is equal to 4.375% of the US$200 million if exercised between December 1, 2007 and December 1, 2008; 2.1875% if exercised between December 1, 2008 and December 1, 2009; and 0.000% if cancelled after December 1, 2009. We have not hedged the foreign currency risk on the 9% senior secured notes. Each $0.01 increase or decrease in the U.S. dollar-Canadian dollar exchange rate would change the interest cost on the 9% senior secured notes by $0.05 million per year.

Interest rate risk

      We are subject to interest rate risk in connection with our revolving credit facility. The facility bears interest at variable rates based on the Canadian prime rate plus 2% or Canadian bankers’ acceptance rate plus 3%. Assuming our then-existing revolving credit facility was fully drawn at $40 million, excluding the $18 million of outstanding letters of credit at March 31, 2006, each 1.0% increase or decrease in the applicable interest rate would have changed the interest cost by $0.4 million per year. In the future, we may enter into interest rate swaps involving the exchange of floating for fixed rate interest payments to reduce interest rate volatility.

      We also lease equipment with a variable lease payment tied to prime rates. At March 31, 2006, for each 1.0% annual fluctuation in this rate, annual lease expense will change by $0.3 million.

Inflation

      The rate of inflation has not had a material impact on our operations as many of our contracts contain a provision for annual escalation. If inflation remains at its recent levels, it is not expected to have a material impact on our operations in the foreseeable future if we are able to pass cost increases along to our customers.

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BUSINESS

Our Company

      We are a leading resource services provider to major oil and natural gas and other natural resource companies, with a primary focus in the Canadian oil sands. We provide a wide range of mining and site preparation, piling and pipeline installation services to our customers across the entire lifecycle of their projects. We are the largest provider of contract mining services in the oil sands area, and we believe we are the largest piling foundations installer in western Canada. In addition, we believe that we operate the largest fleet of equipment of any contract resource services provider in the oil sands. Our total fleet includes over 525 pieces of diversified heavy construction equipment supported by over 540 ancillary vehicles. While our expertise covers heavy earth moving, piling and pipeline installation in any location, we have a specific capability operating in the harsh climate and difficult terrain of the oil sands and northern Canada. By understanding the terrain, having skilled personnel and a diverse, well-maintained and well-positioned fleet, we are able to meet the demands of a growing customer base.

      Our core market is the oil sands, where we generated 71% of our fiscal 2006 revenue. The oil sands are located in three regions of northern Alberta: Athabasca, Cold Lake and Peace River. According to the Alberta Energy and Utilities Board, or EUB, Canada’s oil sands are estimated to hold 315 billion barrels of ultimately recoverable oil reserves, with established reserves of almost 174 billion barrels as of the end of 2004, second only to Saudi Arabia. According to the Canadian National Energy Board, or NEB, oil sands production of bitumen is expected to increase from 1.1 million barrels per day, or “bpd,” in 2005 to approximately 3.0 million bpd by 2015 and account for 75% of total Canadian oil output, compared to approximately 50% of output today. In order to achieve this increase in production, the NEB estimates that over $95 billion of capital expenditures by companies operating in the oil sands will be required through 2015.

      Our significant knowledge, experience, equipment capacity and scale of operations in the oil sands differentiates us from our competition. Our principal customers are the major operators in the oil sands, including all three of the producers that currently mine bitumen, being Syncrude Canada Ltd., Suncor Energy Inc. and Albian Sands Energy Inc. (a joint venture among Shell Canada Limited, Chevron Canada Limited and Western Oil Sands Inc.). Canadian Natural Resources Limited, or CNRL, another significant customer, is developing a bitumen-mining project in the oil sands. We provide services to every company in the oil sands that uses surface mining techniques for its production. These surface mining techniques account for over 70% of total oil sands production. We also provide site construction services for in-situ producers, which use horizontally drilled wells to inject steam into deposits and pump bitumen to the surface.

      We have long-term relationships with most of our customers. For example, we have been providing services to Syncrude Canada Ltd. and Suncor Energy Inc. since they pioneered oil sands development over 30 years ago. We believe our customers’ leases have an average remaining productive life of over 35 years. In addition, 34% of our revenues in fiscal 2006 were derived from recurring, long-term contracts, which assists in providing stability in our operations.

      We provide services to our customers through three primary segments:

•  Mining and Site Preparation. Surface mining for oil sands and other natural resources, including overburden removal, hauling sand and gravel and supplying labor and equipment to support customers’ mining operations; construction of infrastructure associated with mining operations and reclamation activities; clearing, stripping, excavating and grading for mining operations and industrial site construction mega-projects; and underground utility installation for plant, refinery and commercial building construction;

•  Piling. Installing all types of driven and drilled piles, caissons and earth retention and stabilization systems for industrial projects primarily focused in the oil sands and related petrochemical or refinery complexes, as well as commercial buildings and infrastructure projects; and

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•  Pipeline Installation. Installing transmission and distribution pipe made of various materials for oil, natural gas and water.

      As a result of our extensive experience and expertise in the oil sands, we are often engaged at an early stage to help our customers plan and estimate costs to develop oil sands projects which may entail the expenditure of several billions of dollars over the three to four year life of project construction. We provide our customers with information about working in the oil sands, including details about the differential in the cost of undertaking various projects in the summer or the winter, constructability, equipment availability and requirements and availability of labor. Our early stage or “first-in” involvement in projects gives us the opportunity to demonstrate our capability and insight into our customers’ plans and schedules, thereby allowing us to achieve greater accuracy in forecasting our future equipment and labor needs. With large trucks costing $3 million to $4 million each, shovels costing up to $20 million each, the global shortage of large truck tires and the lead times for delivery of this equipment extending many months into the future, the insight we gain about future projects facilitates our long-term planning.

      During the year ended March 31, 2006, we generated revenues of $492.2 million and gross profits of $80.3 million. Since the beginning of our fiscal 2002, we have grown revenues and gross profits at a compound annual growth rate of 18% and 25%, respectively.

      The following charts provide our revenues by segment and by end market for the year ended March 31, 2006:

Our Competitive Strengths

      We believe our competitive strengths include:

Leading market position

      We are the largest provider of contract mining services in the oil sands area, and we believe we are the largest piling foundations installer in western Canada. We have operated in western Canada for over 50 years and have participated in every significant oil sands mining project since operators first began working in the oil sands over 30 years ago. We believe we operate the largest fleet of any contract resource services provider in the oil sands. We are one of only a few companies capable of taking on long-term, large-scale projects with the major operators in the oil sands. In addition, we have extensive experience operating in the challenging working conditions created by the harsh climate and difficult terrain of the oil sands and northern Canada. We believe the combination of our significant size, extensive experience and broad service offerings has allowed us to develop our leading market position and reputation as the service provider of choice in the oil sands. For example, we have recently been selected by CNRL to provide substantial services under several contracts, including a 10-year overburden removal contract.

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Large, well-maintained equipment fleet strategically located in the Canadian oil sands

      As of March 31, 2006, we had a heavy equipment fleet of over 350 units located in the oil sands, made up of shovels, excavators, trucks and dozers. Many of these units are among the largest pieces of equipment in the world and are designed for use in the largest earthmoving and mining applications globally. In addition, we had over 270 ancillary vehicles located in the oil sands, including small shovels, excavators and trucks, as well as loaders, graders, scrapers, cranes, pipelayers and drill rigs, which allow us to execute a full range of jobs for our customers. Our large, diverse fleet gives us flexibility in scheduling jobs and allows us to be responsive to our customers’ needs. A well-maintained fleet is critical in the harsh climatic and environmental conditions we encounter. We operate four significant maintenance and repair centers, which are capable of accommodating the largest pieces of equipment in our fleet, on the sites of the major oil sands projects. These factors help us to be more efficient, thereby reducing costs to our customers to further improve our competitive edge, while concurrently increasing our equipment utilization and thereby improving our profitability.

      In addition, we have a major repair facility located at our corporate headquarters near Edmonton, Alberta. This facility can perform the same major maintenance and repair activities as those maintenance centers in the oil sands and therefore acts as a back-up facility in the event of peak maintenance or repair requirements for oil sands equipment.

Broad service offering across a project’s lifecycle

      We provide our customers with resource services to meet their needs across the entire lifecycle of a project. These services include overburden removal, engineering assistance, construction of infrastructure, site grading, piling and pipe installation, day-to-day site maintenance, equipment supply, site upgrading services and land rehabilitation. Given the capital intensive and long-term nature of oil sands projects, our broad service offerings provide us with a competitive advantage and position us to transition from one stage of the project to the next, as we typically have knowledge of a project during its initial planning and budgeting phase. We use this knowledge to help secure contracts during the initial construction of the project as well as plan for recurring and follow-on work. As a result, we have a reputation as a “first-in, last-out” service provider in the oil sands. For example, we have both removed overburden and reclaimed land for Syncrude.

Long-term customer relationships

      We have worked successfully for many years and believe we have well-established relationships with major oil sands and conventional oil and gas producers. These relationships are based on our success in meeting our customers’ requirements, including strong safety and performance records, a well-maintained, highly capable fleet with specific equipment dedicated to individual customers and a staff of well-trained, experienced supervisors, operators and mechanics. Historically, our largest customers by revenue have included Syncrude Canada Ltd., Suncor Energy Inc., Albian Sands Energy Inc. and EnCana Corporation. We have worked with oil sands mining operators Syncrude, Suncor and Albian since they began operations in the oil sands, which in the case of Syncrude and Suncor was over 30 years ago. We also have worked with EnCana for over 20 years, providing pipeline installation services throughout western Canada and, more recently, services to support its new in-situ mining operations in the oil sands.

Experienced management team

      Our management team has well-established relationships with major oil sands producers and other resource industry leaders in our core markets. We believe that our management team’s experience in the resource services and mining industries enhances our ability to accomplish our strategic objectives and effectively manage our transition from a private company to a public company. The entire management team is focused on further developing our culture of performance and accountability and continuing our tradition of offering high quality service to our customers. In addition, our management and operations teams have the local-level knowledge to identify acquisition opportunities.

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Our Strategy

      We intend to pursue the following strategies:

Capitalize on growth opportunities in the Canadian oil sands

      We intend to build on our market leadership position and successful track record with our customers in the oil sands to benefit from the expected rapid growth in this end market. The NEB estimates that between 2006 and 2015 $8.5 billion to $10.9 billion of annual capital expenditures, for a total of over $95 billion, will be required to achieve expected increases in production. We believe that these planned expenditures will not only allow us to increase our business from current projects but also create opportunities to provide our services to new projects. To capitalize on these opportunities, we plan to continue to add to our equipment fleet. This new equipment will be delivered in regular intervals and, together with our existing fleet, will enable us to compete for new business opportunities in the oil sands as they arise.

Leverage our complementary services

      We intend to build on our “first-in” position to cross-sell other services that we provide. Our complementary service segments, including site preparation, pipeline installation, piling and other mining services allow us to compete for many different forms of business. Given our technical capabilities, performance history and on-site presence, we are well positioned to compete for new business in our service segments. For example, either during or after providing site preparation services to customers, we can often use the specific knowledge of the project to provide other services such as underground pipeline installation or piling work. We are often able to provide these additional services seamlessly and quickly, utilizing existing on-site resources. Unplanned work requirements frequently arise with little notice, which we are well-positioned to execute, given our on-site location and complementary service offerings. For example, during a recent site development project, we were asked with short lead time to install a large diameter water pipeline. We were able to coordinate our site development and pipeline projects such that we began installing pipeline on a completed portion of the site without impacting the site development schedule. Furthermore, we intend to pursue selective acquisition growth opportunities that expand our complementary service offerings.

Increase our recurring revenue base

      We provide services both during construction and while the project is in operation. Once the capital expenditures for a project are complete, the operation of that project results in ongoing operating expenditures. Work required as an integral part of an operating project provides us with the opportunity to perform recurring services for our customers. Over the past several years we have increased our recurring revenues from mining services, including overburden removal, reclamation, road construction and maintenance and surface mining, from 20% of revenues in fiscal 2004 to 34% in fiscal 2006. Oil sands operators’ needs for these types of services will increase as they expand their operations and as new oil sands operations come on line. We expect to increase the amount of revenues from recurring services to our existing customers. For our planning purposes, we estimate that there are typically annual outsourced operating expenses of approximately 2% to 10% of the total capital expenditures on a mining project.

Leverage long-term relationships with existing customers

      Several of our oil sands customers have announced intentions to increase their production capacity by expanding the infrastructure at their sites. We intend to continue to build on our relationships with these and other existing oil sands customers to win a substantial share of the mining and site preparation, piling and pipeline services outsourced in connection with these projects. For example, we worked closely with Albian and its largest shareholder, Shell, at the Muskeg River site during its development in 2001 and we were recently awarded new work on the Jackpine expansion project.

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Increase our presence outside of the Canadian oil sands

      Canada has significant reserves of various natural resources, including diamonds, coal and gold. We intend to utilize the expertise we have gained in the oil sands to provide similar services to other natural resource mining companies. For example, we entered into a contract with De Beers in November 2005 to provide site preparation services over a 27-month period at its second diamond mine in Canada. We are actively working with existing customers on additional “planning-stage” opportunities outside the oil sands.

Enhance operating efficiencies to improve revenue and margins

      We have initiated an operational improvement plan focused on implementing systems and process improvements, performance measurement techniques, enhanced communication and improved organizational effectiveness. This plan is designed to enhance our profitability, competitiveness and ability to effectively respond to opportunities in the markets we serve by improving the availability of our equipment through enhanced maintenance, providing the opportunity for increased utilization. Given our large fleet and the industry’s shortage of available machinery, we are implementing strategies to increase the utilization of our fleet by deploying our equipment more efficiently to improve revenues. This initiative will also enhance margins by taking advantage of the fixed-cost nature of our equipment. Our maintenance initiative will further improve margins by improving equipment availability and reducing repair time, thereby enabling us to deploy our fleet for longer periods of time and more frequently.

Our Markets

      Our business is primarily driven by the demand for our services from the development, expansion and operation of oil sands projects. Decisions by oil sands operators to make capital investments are driven by a number of factors, with one of the most important being the expected long-term price of oil.

Canadian Oil Sands

      Oil sands are grains of sand covered by a thin layer of water and coated by heavy oil, or bitumen. Bitumen, because of its structure, does not flow, and therefore requires non-conventional extraction techniques to separate it from the sand and other foreign matter. There are currently two main methods of extraction: open pit mining, where bitumen deposits are sufficiently close to the surface to make it economically viable to recover the bitumen by treating mined sand in a surface plant; and in-situ, where bitumen deposits are buried too deep for open pit mining to be cost effective, and operators instead inject steam into the deposit so that the bitumen can be separated from the sand and pumped to the surface. We currently provide most of our services to companies operating open pit mines to recover bitumen reserves. These customers utilize our services for surface mining, site preparation, piling, pipe installation, site maintenance, equipment and labor supply and land reclamation.

      According to the EUB, the oil sands contained almost 174 billion barrels of established oil reserves as of the end of 2005. This is second only to Saudi Arabia’s 264 billion barrels and approximately six times the recoverable reserves in the United States. Beginning in the mid-1990’s, increasing global energy demand and improvements in mining and in-situ technology resulted in a significant increase in oil sands investments. This increased level of investment was also driven by a revised royalty regime adopted by the Government of Alberta in 1997, which was designed to accelerate investment in the oil sands. Under the revised royalty structure, oil sands operators pay a royalty of 1% of gross revenue until the operator has recovered all its allowed costs in respect of a project plus a return allowance, after which the royalty increases to the greater of 25% of net revenue or 1% of gross revenue.

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Total Oil Reserves by Country

     Source: Oil and Gas Journal, December 19, 2005

    The following maps show the location of the oil sands and the primarily surface mineable leases within the oil sands.

      Outlook. According to CAPP, approximately $36 billion was invested in the oil sands from 1996 through 2004. Oil sands production has grown four-fold since 1990 and exceeded one million barrels per day in 2005. The NEB expects oil sands production to reach approximately 3.0 million barrels per day and account for over 75% of total Canadian oil production by 2015. By comparison, the Ghawar field in Saudi Arabia currently produces 5.0 million barrels per day, representing over 6% of the world’s total production and over 50% of Saudi Arabia’s production.

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Total Bitumen Production From the Oil Sands

      The following chart shows the expected capital expenditures in the oil sands through 2015 according to the NEB’s 2006 Energy Market Assessment.

      The NEB estimates that between 2006 and 2015 $8.5 billion to $10.9 billion of annual capital expenditures, for a total of over $95 billion, will be required to achieve expected increases in production. According to the NEB, as of June 2006, there were 21 mining and upgrader projects in various stages, ranging from announcement to construction, with start-up dates through 2010. If all of these projects proceed as scheduled, the planned investment in new projects for 2006 through 2010 will exceed $38 billion and an additional $17 billion will be invested in project additions or existing projects over the same period. Beyond 2010, several new multibillion dollar projects and a number of smaller multimillion dollar projects are being considered by various oil sands operators. We intend to pursue business opportunities from these projects. According to the NEB, the 21 projects with start up dates through 2010 are as follows:

							Bitumen
					Startup		Capacity
Company	Project Name		Status		Date		(bpd)
Athabasca Oil Sands Project (Albian)	Muskeg River Mine Expansion and Debottleneck			Application		2010		115,000
		Jackpine Mine		Approved		2010		100,000
		Scotford Upgrader Debottleneck		Application		2007		45,000
		Scotford Upgrader Expansion		Application		2009		90,000
CNRL		Horizon Mine and Upgrader		Construction		2008		135,000
Husky	Lloydminster Upgrader Debottleneck			Construction		2006		12,000
Imperial/ ExxonMobil		Kearl Mine		Application		2010		100,000

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							Bitumen
					Startup		Capacity
Company	Project Name		Status		Date		(bpd)
OPTI/ Nexen		Long Lake Upgrader		Construction		2007		72,000
Suncor		Steepbank Debottleneck		Construction		2006		25,000
		Millennium Mine Debottleneck		Construction		2008		23,000
		Millennium Coker Unit		Construction		2008		116,000
		Voyageur Upgrader		Application		2010		156,000
Syncrude		Stage 3 Expansion		Construction		2006		116,300
Synenco		Northern Lights Mine		Disclosure		2009		50,000
		Northern Lights Upgrader		Disclosure		2010		50,000
Total E&P		Joslyn Mine		Application		2010		50,000
		Joslyn/Surmont Upgrader		Announced		2010		50,000
BA Energy		Heartland Upgrader Phase 1		Construction		2008		54,400
		Heartland Upgrader Phase 2		Approved		2010		54,400
North West Upgrading		North West Upgrader		Application		2010		50,000
Peace River Oil Upgrading		Bluesky Upgrader		Announced		2010		25,000

      Pipeline Infrastructure and Construction. To transport the increased production expected from the oil sands and to provide natural gas as an energy source to the oil sands region, significant investment will be required to expand pipeline capacity. To date, there have been significant greenfield and expansion projects announced, including: Kinder Morgan Canada’s proposal to expand the TransMountain pipeline system, which transports oil from the oil sands area to Burnaby, British Columbia; Enbridge Inc.’s proposed Gateway pipeline, which will transport oil from the oil sands area to Kitimat, British Columbia; the proposed Access Pipeline (a joint venture between MEG Energy Corp. and Devon ARL Canada Corp.), which will transport bitumen from the oil sands to refineries in Edmonton, Alberta and diluent from Edmonton, Alberta to the oil sands area; TransCanada Corporation’s proposed Keystone pipeline project, which will transport oil from Hardisty, Alberta to the Chicago area; and the proposed Spirit pipeline system (a joint venture between Kinder Morgan Canada and Pembina Pipeline Corporation), which will transport condensate from Kitimat, British Columbia to Edmonton, Alberta. We are in various stages of discussions to provide services for some of these projects. We believe that our service offerings and pipeline construction experience position us well to compete for the sizeable pipeline opportunities required for the expected growth in oil sands production.

Conventional Oil and Gas

      We provide services to conventional oil and gas producers, in addition to our work in the oil sands. The Canadian Energy Pipeline Association estimates that over $20 billion of pipeline investment in Canada will be required for the development of new long haul pipelines, feeder systems and other related pipeline construction. Conventional oil and gas producers require pipeline installation services in order to connect producing wells to nearby pipeline systems. According to CAPP, Canada is one of the world’s largest producers of oil and gas, producing approximately 2.5 million barrels of oil per day and approximately 17.1 billion cubic feet of natural gas per day. Canadian natural gas production is expected to increase with the development of arctic gas reserves. A producer group has been formed by Imperial Oil Limited, ConocoPhillips Canada Limited, Shell Canada and the Aboriginal Pipeline Group for the purpose of bidding for work on the construction of a pipeline proposed to extend 1,220 kilometers (758 miles) from the MacKenzie River delta in the Beaufort Sea to existing natural gas pipelines in northern Alberta. Under the group’s proposal, Imperial Oil will lead the construction and operate the pipeline. We are actively working with Imperial Oil and have provided it with constructability and planning reviews. We hope to repeat our history of providing initial engineering assistance on projects and then subsequently being awarded contracts on these projects.

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Minerals Mining

      According to the government agency Natural Resources Canada, Canada is also one of the largest mining nations in the world, producing approximately 70 different minerals and metals. In 2004, the mining and minerals industries processing contributed $41.8 billion to the Canadian economy, an amount equal to approximately 4.0% of GDP. The value of minerals produced (excluding petroleum and natural gas) reached $26.4 billion in 2005. According to the EUB, Canada ranks tenth in the world in total proven coal reserves. Alberta contains 70% of Canada’s coal reserves and, by volume, produces approximately half of the coal mined in Canada annually.

      The diamond mining industry in Canada is relatively new, having extracted diamonds for only eight years. According to Natural Resources Canada, the industry has grown from 2.6 million carats of production in 2000 to an estimated 12.3 million carats of production in 2005, representing a compounded annual growth rate of approximately 36%, and establishing Canada as the third largest diamond producing country in the world by value after Botswana and Russia. We believe Canadian diamond mining will continue to grow as existing mines increase production and new mine projects are developed. Outside the oil sands, we have identified the growing Canadian diamond mining industry as a primary target for new business opportunities.

      We intend to build on our core services and strong regional presence to capitalize on the opportunities in the minerals mining industries of Canada. According to Natural Resources Canada’s 2004 estimate, the capital and repair expenditures needed to support the minerals mining industry would be over $5.6 billion in 2005.

Commercial and Public Construction

      According to the government agency Statistics Canada, the Canadian commercial and public construction market was approximately $22 billion in 2005. According to the Alberta government, the commercial and public construction market in Alberta is expected to grow 3% annually through 2009. As a result of the significant activity in the energy sector, western Canada has experienced and is expected to continue to experience strong economic and population growth. The Alberta government has responded to the potential strain that this growth will have on public facilities and infrastructure by allocating approximately $6.5 billion to improvement and expansion projects from 2004 to 2007. This need for infrastructure to support growth, along with historic under investment in infrastructure, provides for a strong infrastructure spending outlook.

      The success of the energy industry in western Canada is also leading to increased commercial development in many urban centers in British Columbia and Alberta. According to the Alberta government, as of June 2006, the inventory of commercial, retail and residential projects in Alberta was valued at approximately $5.1 billion. These large expenditures will be further supplemented by the 2010 Olympic Winter Games, which will be held in the Vancouver area. The Organizing Committee of the Olympic Games estimates that the 2010 Olympic Winter Games will require an additional $3.0 billion in infrastructure and construction spending. The significant resources and capital intensive nature of the core infrastructure and construction services required to meet these demands, along with our strong local presence and significant regional experience, position us to implement our business model to capitalize on the large and growing infrastructure and construction demands of western Canada.

Our Operations

      We provide our services through three primary segments: mining and site preparation, piling and pipeline installation. Over the past 50 years, we have developed an expertise operating in the difficult working conditions created by the climate and terrain of western Canada. We provide these services primarily for our oil and gas and other natural resource customers.

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      The chart below shows the revenues generated by each operating segment for the fiscal years ended March 31, 2002 through March 31, 2006:

		Year Ended March 31,
		2002				2003				2004				2005				2006
		(Dollars in thousands)
Mining and site preparation		$	186,141	74.6	%	$	245,235	71.3	%	$	235,772	62.4	%	$	264,835	74.1	%	$	366,721	74.5	%
Piling			35,132	14.1			61,006	17.7			48,982	12.9			61,006	17.1			91,434	18.6
Pipeline installation			28,078	11.3			37,945	11.0			93,509	24.7			31,482	8.8			34,082	6.9
	Total	$	249,351	100.0	%	$	344,186	100.0	%	$	378,263	100.0	%	$	357,323	100.0	%	$	492,237	100.0	%

Mining and site preparation

      Our mining and site preparation segment encompasses a wide variety of services. Our contract mining business represents an outsourcing of the equipment and labor component of the oil and gas and other natural resources mining business. Our site preparation services include clearing, stripping, excavating and grading for mining operations and other general construction projects, as well as underground utility installation for plant, refinery and commercial building construction. This business unit utilizes the vast majority of our equipment fleet and employs over 800 people. The majority of the employees and equipment associated with this business unit are located in the Canadian oil sands area.

      For the fiscal years ended March 31, 2005 and 2006, revenues from this segment accounted for 74% and 75% of our total revenues, respectively.

      Many oil sands and natural resource mining companies utilize contract services for mine site operations. Our mining services consist of overburden removal; the hauling of sand and gravel; mining of the ore body and delivery of the ore to the crushing facility; supply of labor and equipment to support the owners’ mining operations; construction of infrastructure associated with mining operations; and reclamation activities, which include contouring of waste dumps and placement of secondary materials and muskeg. The major producers outsource mine site operations to contractors such as our company to allow them to focus their resources on exploration and property development and to benefit from a variety of cost efficiencies that we can provide. We believe mining contractors typically have wage rates lower than those of the mining company and more flexible operating arrangements with personnel allowing for improved uptime and performance.

      Oil sands operators use our services to prepare their sites for the construction of the mining infrastructure, including extraction plants and upgrading facilities, and for the eventual mining of the oil sands ore located on their properties. Outside of the oil sands, our site preparation services are used to assist in the construction of roads, natural resource mines, plants, refineries, commercial buildings, dams and irrigation systems. In order to successfully provide these types of services in the oil sands, our operators are required to use heavy equipment to transform barren terrain and difficult soil or rock conditions into a stable environment for site development. Our extensive fleet of equipment is used for clearing the earth of vegetation and removing topsoil that is not usable as a stable subgrade and site grading, which includes grading, leveling and compacting the site to provide a solid foundation for transportation or building. We also provide utility pipe installation for the private and public sectors in western Canada. We are experienced in working with piping materials such as HDPE, concrete, PVC and steel. This work involves similar methods as those used for field, transmission and distribution pipelines in the oil and gas industry, but is generally more intricate and time consuming as the work is typically performed in existing plants with numerous tie-ins to live systems.

Piling

      Our capabilities include the installation of all types of driven and drilled piles, caissons and earth retention and stabilization systems for commercial buildings; private industrial projects, such as plants and refineries; and infrastructure projects, such as bridges. Our piling business employs approximately 100

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people. Oil and gas companies developing the oil sands and related infrastructure represented approximately two-thirds of our piling clients for fiscal 2006. The remaining one-third of our piling clients were primarily commercial construction builders operating in the Edmonton, Calgary, Regina and Vancouver areas.

      In providing piling services, we currently operate a variety of crawler-mounted drill rigs, a fleet of 25- to 100-ton capacity piling cranes and pile driving hammers of all types from our Edmonton, Calgary, Regina, Vancouver and Fort McMurray locations. Piles and caissons are deep foundation systems that extend up to 30 meters below a structure. Piles are long narrow shafts that distribute a load from a supported structure (such as a building or bridge) throughout the underlying soil mass and are necessary whenever the available footing area beneath a structure is insufficient to support the load above it. The foundation chosen for any particular structure depends on the strength of the rock or soil, magnitude of structural loads and depth of groundwater level.

      For the fiscal years ended March 31, 2005 and 2006, revenues from this segment accounted for 17% and 19% of our total revenues, respectively.

Pipeline Installation

      We install field, transmission and distribution pipe made of steel, plastic and fiberglass materials. We employ our fleet of construction equipment and skilled technical operators to build and test the pipelines for the delivery of oil and natural gas from the producing field to the consumer. Our pipeline teams have expertise in hand welding selected grade pipe and in operating in the harsh conditions of remote regions in western and northern Canada.

      For the last five fiscal years virtually all of our revenues in our pipeline business resulted from work performed for EnCana. Despite our limited client base in this segment over the past five years, we believe there are significant opportunities to increase our market share by capitalizing on the projected pipeline expansion in western Canada.

      For the fiscal years ended March 31, 2005 and 2006, revenues from this segment accounted for 9% and 7% of our total revenues, respectively.

Equipment

      We operate and maintain over 525 pieces of diversified heavy equipment, including crawlers, graders, loaders, mining trucks, compactors, scrapers and excavators, as well as over 540 ancillary vehicles, including various service and maintenance vehicles. The equipment is in good condition, normal wear and tear excepted. Our revolving credit facility and our 9% senior secured notes are secured by liens on substantially all of our equipment. See “Description of Certain Indebtedness.” We lease some of this equipment, which leases contain purchase options.

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      The following table sets forth information regarding our fleet of heavy equipment as of March 31, 2006:

		Capacity		Horsepower		Number		Number
Category		Range		Range		in Fleet		Leased
Mining and site preparation:
	Articulating trucks		30-42 tons		305-460		32		—
	Mining trucks		50-330 tons		650-2,700		74		29
	Shovels		36-58 cubic yards		2,600-3,760		4		2
	Excavators		1-20 cubic yards		94-1,350		100		15
	Crawler tractors		N/A		120-1,350		91		14
	Graders		14-24 feet		150-500		20		8
	Scrapers		28-31 cubic yards		450		14		—
	Loaders		1.5-16 cubic yards		110-690		43		1
	Skidsteer loaders		1-2.25 cubic yards		70-150		35		—
	Packers		44,175-68,796 lbs		216-315		29		—
Pipeline:
	Snow cats		N/A		175		3		—
	Trenchers		N/A		165		2		—
	Pipelayers		16,000-140,000 lbs		78-265		34		—
Piling:
	Drill rigs		60-135 feet (drill depth)		210-1,500		33		1
	Cranes		25-100 tons		200-263		13		1
Total							527		71

      For the fiscal years ended March 31, 2006, 2005 and 2004, we incurred expense of $64.8 million, $52.8 million and $57.2 million, respectively, to maintain our equipment in good working condition.

Customers

      We derive a significant amount of our revenues from a small number of oil and gas companies. Our customer base includes major energy companies such as Syncrude, Albian, EnCana, Suncor and CNRL. We have large mining customers outside of the oil sands, including De Beers. We also perform commercial construction-related services for other customers in the public and private sectors. Our largest three customers for the fiscal year ended March 31, 2006, CNRL, Syncrude and Grande Cache Coal Corp., accounted for 32%, 16% and 10% of our revenues, respectively. Collectively, our five largest customers accounted for 69% and 68% of our revenues for the fiscal years ended March 31, 2006 and 2005, respectively. We have relatively few customers in our mining and site preparation and pipeline installation segments and many small customers in our piling segment.

Contracts

      We complete work under the following types of contracts: cost-plus, time-and-materials, unit-price and lump sum. Each contract contains a different level of risk associated with its formation and execution.

      Cost-plus. A cost-plus contract is where all work is completed based on actual costs incurred to complete the work. These costs include all labor, equipment, materials and any subcontractor’s costs. In addition to these direct costs, all site and corporate overhead costs are charged to the job. An agreed upon fee in the form of a fixed percentage is then applied to all costs charged to the project. This type of contract is utilized where the project involves a large amount of risk or the scope of the project cannot be readily determined.

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      Time-and-materials. A time-and-materials contract involves using the components of a cost-plus job to calculate rates for the supply of labor and equipment. In this regard, all components of the rates are fixed and we are compensated for each hour of labor and equipment supplied. The risk associated with this type of contract is the estimation of the rates and incurring expenses in excess of a specific component of the agreed upon rate. Therefore, any cost overrun must come out of the fixed margin included in the rates.

      Unit-price. A unit-price contract is utilized in the execution of projects with large repetitive quantities of work and is commonly utilized for site preparation, mining and pipeline work. We are compensated for each unit of work we perform (for example, cubic meters of earth moved, lineal meters of pipe installed or completed piles). Within the unit price contract, there is an allowance for labor, equipment, materials and any subcontractor’s costs. Once these costs are calculated, we add any site and corporate overhead costs along with an allowance for the margin we want to achieve. The risk associated with this type of contract is in the calculation of the unit costs with respect to completing the required work.

      Lump sum. A lump sum contract is utilized when a detailed scope of work is known for a specific project. Thus, the associated costs can be readily calculated and a firm price provided to the customer for the execution of the work. The risk lies in the fact that there is no escalation of the price if the work takes longer or more resources are required than were estimated in the established price. The price is fixed regardless of the amount of work required to complete the project.

      The mix of contract types varies year-by-year. For the fiscal year ended March 31, 2006, our contracts consisted of 15% cost-plus, 27% time-and-materials, 44% unit-price and 14% lump sum.

      In addition to the contracts listed above, we also use master service agreements for work in the oil and gas sector where the scope of the project is not known and timing is critical to ensure the work gets completed. The master service agreement is a form of a time-and-materials agreement that specifies what rates will be charged for the supply of labor and equipment to undertake work. The agreement does not identify any specific scope or schedule of work. In this regard, the customer’s representative establishes what work is to be done at each location. We use master service agreements with the work we perform for EnCana.

      We also do a substantial amount of work as a subcontractor where we are governed by the contracts with the general contractor to which we are not a party. Subcontracts vary in type and conditions with respect to the pricing and terms and are governed by one specific prime contract that governs a large project generally. In such cases, the contract with the subcontractors contains more specific provisions regarding a specified aspect of a project.

Joint Venture

      We are party to a joint venture operated through a corporation called Noramac Ventures Inc., or Noramac, with Fort McKay Construction Ltd. created for the purpose of performing contracts for the construction, development and operation of open-pit mining projects within a 50 kilometre radius of Fort McKay, Alberta, which require the provision of heavy construction equipment. The affairs of Noramac are managed, and all decisions and determinations with respect to Noramac are made, by a management committee equally represented by us and our partner. The management committee is responsible for determining the percentage of work in relation to each contract that will be performed by us and by our partner, provided that contracts for a duration of less than two years and of a tender value between $10.0 million and $100.0 million which require a parent guarantee or performance bond will be subcontracted to us. The joint venture agreement provides that if the management committee does not tender for a contract, or fails to reach agreement on the terms upon which Noramac will tender for a contract, we or our partner may pursue the contract in our respective capacities without hindrance, interference or participation by the other party. The joint venture agreement does not prohibit or restrict us from undertaking and performing, for our own account, any work for existing customers other than work to be performed by Noramac pursuant to an existing contract between Noramac and such customer. The joint venture is accounted for as a variable interest entity and consolidated in our financial statements.

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Major Suppliers

      We have long-term relationships with the following equipment suppliers: Finning International Inc. (45 years), Wajax Income Fund (20 years) and Brandt Tractor Ltd. (30 years). Finning is a major heavy equipment Caterpillar dealer for Canada. Wajax is a major Hitachi equipment supplier to us for both mining and construction equipment. We purchase or rent John Deere equipment, including excavators, loaders and small bulldozers, from Brandt Tractor. In addition to the supply of new equipment, each of these companies is a major supplier for equipment rentals, parts and service labor.

      We obtain tires for our equipment from local distributors. Tires of the size and specifications we require are generally in short supply. We expect the supply/demand imbalance for certain tires to continue for some time.

Competition

      Our business is highly competitive in each of our markets. Historically, the majority of our new business was awarded to us based on past client relationships without a formal bidding process, in which typically a small number of pre-qualified firms submit bids for the project work. Recently, in order to generate new business with new customers, we have had to participate in formal bidding processes. As new major projects arise, we expect to have to participate in bidding processes on a meaningful portion of the work available to us on these projects. Factors that impact competition include price, safety, reliability, scale of operations, availability and quality of service. Most of our clients and potential clients in the oil sands area operate their own heavy mining equipment fleet. However, these operators have historically outsourced a significant portion of their mining and site preparation operations and other construction services.

      Our principal competitors in the mining and site preparation segment include Cross Construction Ltd., Klemke Mining Corporation, Ledcor Construction Limited, Neegan Development Corporation Ltd., Peter Kiewit Sons Co., Tercon Contractors Ltd., Sureway Construction Ltd. and Thompson Bros. (Constr) Ltd. The main competition to our deep foundation piling operations comes from Agra Foundations Limited and Double Star Co.. The primary competitors in the pipeline installation business include Ledcor Construction Limited, Washcuk Pipe Line Construction Ltd. and Midwest Management (1987) Ltd. Voice Construction Ltd. and I.G.L. Industrial Services are the major competitors in underground utilities installation.

      In the public sector, we compete against national firms, and there is usually more than one competitor in each local market. Most of our public sector customers are local governments that are focused on serving only their home regions. Competition in the public sector continues to increase, and we typically choose to compete on projects only where we can utilize our equipment and operating strengths to secure profitable business.

Properties and Facilities

      We own and lease a number of buildings and properties for use in our business. Our administrative functions are located at our headquarters near Edmonton, Alberta, which also houses a major equipment maintenance facility. Project management and equipment maintenance are also performed at regional facilities in Calgary and Fort McMurray, Alberta; Vancouver, Fort Nelson and Prince George, British Columbia; and Regina, Saskatchewan. We occupy office and shop space in British Columbia, Alberta and Saskatchewan under leases which expire between late 2007 and 2011, subject to various renewal and termination rights. We expect to renew our office lease that expires in 2007 with rates that are competitive with the prevailing markets rates at that time. We also occupy, without charge, some customer-provided lands. Our revolving credit facility and our 9% senior secured notes are secured by liens on substantially all

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of our properties. See “Description of Certain Indebtedness.” The following table describes our primary facilities.

Location	Function	Owned or Leased
Acheson, Alberta	Corporate headquarters and major equipment repair facility	Leased(a)
Calgary, Alberta	Regional office and equipment repair facility – piling operations	Building Owned Land Leased(b)
Syncrude Mine Site, South End Fort McMurray, Alberta	Regional office and major equipment repair facility – earthworks and mining operations	Building Owned Land Provided
Syncrude Plant Site Fort McMurray, Alberta	Satellite office and minor repair facility – all operations	Building Rented(c) Land Provided
CNRL Plant Site Fort McMurray, Alberta	Site office and maintenance facility	Facility Owned Land Provided
Aurora Mine Site Fort McMurray, Alberta	Satellite office and equipment repair facility – all operations	Building Under Construction Land Provided
Albian Sands Mine Site Fort McMurray, Alberta	Satellite office and equipment repair facility – all operations	Building Leased(d) Land Provided
New Westminster, British Columbia	Regional office and equipment repair facility – piling operations	Building Owned Land Leased(e)
Fort Nelson, British Columbia	Satellite office – pipeline operations	Leased(f)
Regina, Saskatchewan	Regional office and equipment repair facility – piling operations	Leased(g)

(a)	Lease expires November 30, 2007.
(b)	Lease expires December 31, 2010.
(c)	Lease expires November 30, 2009.
(d)	Leased on a month-to-month basis.
(e)	Lease expires March 31, 2010.
(f)	Lease expires July 10, 2008.
(g)	Lease expires March 14, 2008.

      Our locations were chosen for their geographic proximity to our major customers. We believe our facilities are sufficient to meet our needs for the foreseeable future.

Law and Regulations and Environmental Matters

      Many aspects of our operations are subject to various federal, provincial and local laws and regulations, including, among others:

      •  permitting and licensing requirements applicable to contractors in their respective trades,

      •  building and similar codes and zoning ordinances,

      •  laws and regulations relating to consumer protection and

      •  laws and regulations relating to worker safety and protection of human health.

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      We believe we have all material required permits and licenses to conduct our operations and are in substantial compliance with applicable regulatory requirements relating to our operations. Our failure to comply with the applicable regulations could result in substantial fines or revocation of our operating permits.

      Our operations are subject to numerous federal, provincial and municipal environmental laws and regulations, including those governing the release of substances, the remediation of contaminated soil and groundwater, vehicle emissions and air and water emissions. These laws and regulations are administered by federal, provincial and municipal authorities, such as Alberta Environment, Saskatchewan Environment, the British Columbia Ministry of Environment, and other governmental agencies. The requirements of these laws and regulations are becoming increasingly complex and stringent, and meeting these requirements can be expensive. The nature of our operations and our ownership or operation of property expose us to the risk of claims with respect to environmental matters, and there can be no assurance that material costs or liabilities will not be incurred with such claims. For example, some laws can impose strict, joint and several liability on past and present owners or operators of facilities at, from or to which a release of hazardous substances has occurred, on parties who generated hazardous substances that were released at such facilities and on parties who arranged for the transportation of hazardous substances to such facilities. If we were found to be a responsible party under these statutes, we could be held liable for all investigative and remedial costs associated with addressing such contamination, even though the releases were caused by a prior owner or operator or third party. We are not currently named as a responsible party for any environmental liabilities on any of the properties on which we currently perform or have performed services. However, our leases typically include covenants which obligate us to comply with all applicable environmental regulations and to remediate any environmental damage caused by us to the leased premises. In addition, claims alleging personal injury or property damage may be brought against us if we cause the release of, or any exposure to, harmful substances.

      Capital expenditures relating to environmental matters during the fiscal years ended March 31, 2006, 2005 and 2004 were not material. We do not currently anticipate any material adverse effect on our business or financial position as a result of future compliance with applicable environmental laws and regulations. Future events, however, such as changes in existing laws and regulations or their interpretation, more vigorous enforcement policies of regulatory agencies or stricter or different interpretations of existing laws and regulations may require us to make additional expenditures which may be material.

Employees and Labor Relations

      As of March 31, 2006, we had over 130 salaried and over 1,200 hourly employees. We also utilize the services of subcontractors in our construction business. Approximately 10% to 15% of the construction work we do is done through subcontractors. Approximately 1,000 employees are members of various unions and work under collective bargaining agreements. The majority of our work is done through employees governed by a collective bargaining agreement with the International Union of Operating Engineers Local 955, the primary term of which expires on October 31, 2009, and under a collective bargaining agreement with the Alberta Road Builders and Heavy Construction Association and the International Union of Operating Engineers Local 955, the primary term of which expires on February 28, 2007. Additionally, we recently signed a 10-year labor agreement for mining work at the CNRL site in the oil sands. We are subject to other industry and specialty collective agreements under which we complete work, the primary terms of all of which are currently in effect. We believe that our relationships with all our employees, both union and non-union, are satisfactory. We have never experienced a strike or lockout.

Legal Proceedings

      In February 2005, certain sisters in the Gouin family sued their brothers and their father. The lawsuit also names us as a defendant. The sisters allege that they maintained beneficial ownership interests in the Gouin family businesses. The assets of those businesses were sold to the equity investors that formed us. The sisters further allege that the proceeds of such ownership interests, including cash and preferred shares of NACG Preferred Corp., our subsidiary, are being wrongfully held by the Gouin brothers. The sisters

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seek, among other things, damages from the Gouin brothers and an ownership interest in us. We have notified the Gouin brothers that we are seeking indemnity from them under the agreement relating to the Acquisition for our cost of defense and any damages arising out of the lawsuit. We have answered the lawsuit and are defending our interests.

      From time to time, we are a party to litigation and legal proceedings that we consider to be a part of the ordinary course of business. While no assurance can be given, we believe that, taking into account reserves and insurance coverage, none of the litigation or legal proceedings in which we are currently involved, including the litigation described above, could reasonably be expected to have a material adverse effect on our business, financial condition or results of operations. We may, however, become involved in material legal proceedings in the future.

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OUR EQUITY SPONSORS

      Our principal shareholders include investment entities affiliated with The Sterling Group, L.P., Genstar Capital, L.P., Perry Strategic Capital Inc. and Stephens Group, Inc., whom we refer to collectively as the “sponsors.”

      The Sterling Group, L.P. is a private equity investment firm which sponsors leveraged buyout and recapitalization transactions primarily in manufacturing, industrial service and distribution industries. Sterling joins with management teams to acquire companies where it has identified specific opportunities to grow and improve the business. Since its founding in 1982, Sterling has completed over 50 acquisitions with a total transaction value of over US$7 billion. Sterling currently manages investment funds totaling approximately US$600 million in commitments.

      Genstar Capital, L.P. is a private equity investment firm focused on making growth, buyout, recapitalization and consolidation transactions. Genstar has completed transactions in the life sciences, business /IT services and industrial technology industries. Genstar’s professionals have extensive backgrounds in operations, finance and consulting, including hands-on experience with more than 45 acquisitions.

      Perry Strategic Capital Inc. is an affiliate of Perry Corp., a private investment firm formed in 1988 to focus on alternative investments. Perry Corp. currently manages approximately US$12 billion allocated across a variety of asset classes including publicly traded equity and debt securities, private equity and real estate. The firm manages dedicated industry-focused portfolios and seeks to develop strong relationships with management of companies in which it invests. Perry employs over 120 professionals and support staff in offices in New York, Hong Kong and London.

      SF Holding Corp. is a privately held, Little Rock, Arkansas based holding company. Pending regulatory approval, it will no longer be the parent of Stephens Inc., an investment banking firm that is a member of the National Association of Securities Dealers and the New York Stock Exchange, and which also conducts extensive merchant banking activities. Investments of SF Holding Corp. include oil and gas, health care, financial services, data processing services and software, publishing, agriculture, manufacturing and retailing. SF Holding Corp. seeks opportunities where management needs capital and desires a knowledgeable and reliable financial partner.

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MANAGEMENT

Directors and Executive Officers

      The following sets forth information about our directors and executive officers. Ages reflected are as of July 1, 2006. Each director is elected for a one-year term or until such person’s successor is duly elected or appointed, unless his office is earlier vacated.

Name and Municipality of Residence		Age		Position
Rodney J. Ruston			55	Director, President and Chief Executive Officer
	Edmonton, Alberta
Vincent J. Gallant			48	Vice President, Corporate
	Edmonton, Alberta
Robert G. Harris			58	Vice President, Human Resources, Health,
	Edmonton, Alberta			Safety & Environment
Christopher J. Hayman			43	Vice President, Finance
	St. Albert, Alberta
William M. Koehn			44	Vice President, Operations and Chief Operating
	Spruce Grove, Alberta			Officer
Miles W. Safranovich			42	Vice President, Business Development and
	Spruce Grove, Alberta			Estimating
Ronald A. McIntosh			63	Chairman of the Board
	Calgary, Alberta
George R. Brokaw			38	Director
	Southampton, New York
John A. Brussa			49	Director
	Calgary, Alberta
Donald R. Getty			73	Director
	Edmonton, Alberta
Martin P. Gouin			45	Director
	Edmonton, Alberta
John D. Hawkins			42	Director
	Houston, Texas
William C. Oehmig			57	Director
	Houston, Texas
Richard D. Paterson			63	Director
	San Francisco, California
Allen R. Sello			67	Director
	West Vancouver, British Columbia
K. Rick Turner			48	Director
	Little Rock, Arkansas

      Rodney J. Ruston became our President and Chief Executive Officer and one of our directors on May 9, 2005. Previously, Mr. Ruston was Managing Director and Chief Executive Officer of Ticor Limited an Australian-based natural resources company with operations throughout Australia and in South Africa and Madagascar, from June 2000 to July 2004. From July 2003 until May 2005 he served as Chairman of the Australian Minerals Tertiary Education Council. Mr. Ruston has spent his entire career in the natural resources industry, holding management positions with Pasminco Ltd., Savage Resources Ltd., Wambo Mining Corporation, Oakbridge Ltd. and Kembla Coal & Coke Pty. Ltd. He also served as a Principal with Ruston Consulting Services Pty. Ltd., a management consulting firm providing business advice to the natural resources industry. Mr. Ruston received his Bachelor of Engineering in Mining from the University of New South Wales and a Master of Business Administration from the University of Wollongong.

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      Vincent J. Gallant was appointed Vice President, Corporate on June 15, 2005. Previously, he served as Vice President, Finance since November 26, 2003. He joined our predecessor company in 1997 as Vice President, Finance. Prior to joining North American, Mr. Gallant held a number of positions, including Comptroller at Alberta Energy Company Ltd. and Controller for Edmonton Telephones. He obtained his Chartered Accountant Designation in 1983 after articling with Peat, Marwick, Mitchell and Company. Mr. Gallant received his Bachelor of Arts in Economics from the University of Alberta. He obtained his Certified Financial Planning designation in 2001.

      Robert G. Harris joined us in June 2006 as Vice President, Human Resources, Health, Safety & Environment. Mr. Harris began his career in 1969 with Chrysler Canada in various personnel and human resources positions before taking on the role of Environmental Health & Safety Manager and subsequently the Labour Relations Supervisor role. In 1982, he accepted a position with IPSCO Inc. where he was responsible for human resources over 6 facilities in Canada and the USA. Since 1987, he has held senior human resources roles at Labatt Breweries of Canada including National Manager, Industrial Relations & Training and Director, Human Resources at both regional and national levels. Mr. Harris graduated in 1969 from the University of Windsor with a Bachelor of Arts in Sociology/ Psychology and has received his Certified Human Resources Professional designation.

      Christopher J. Hayman joined us in January 2005 as Treasurer, a position he held until being appointed Vice President, Finance in June 2005. He will be appointed Vice President, Supply Chain once a new chief financial officer is appointed. Previously he worked for Finning Canada, from November 1998 to January 2005, initially as Assistant Controller and eventually becoming Vice President and Controller. Prior to this he held positions at Enbridge, Telus and Thorne, Ernst and Whinney. Mr. Hayman received his Bachelor of Commerce with an Accounting major from the University of Alberta and is a Canadian Chartered Accountant.

      William M. Koehn became our Vice President, Operations on November 26, 2003 and our Chief Operating Officer on December 8, 2004. Previously, he served as Vice President, Operations for our predecessor company since 2002. He joined our predecessor company in 1989 and became the Fort McMurray Regional Manager in 1997. Prior to this he was a Senior Civil Engineer with Quintette Coal Ltd. Mr. Koehn attended the University of Alberta and received his Bachelor of Science in Civil Engineering and has completed his Masters in Construction Engineering and Management.

      Miles W. Safranovich joined us in November 2004 and held the position of General Manager, Industrial and Heavy Civil until he was appointed Vice President, Contracts and Technical Services in July 2005 and Vice President, Business Development and Estimating in July 2006. He has extensive experience in the construction industry, spending most of his career at Voice Construction Ltd. where he held a variety of positions between 2000 and October 2004, including Operations Manager and Construction Manager. Mr. Safranovich attended the University of Alberta and obtained a Bachelor of Science in Biology in 1986 and a Bachelor of Science in Civil Engineering specializing in Construction Management in 1992.

      Ronald A. McIntosh became the Chairman of our Board of Directors on May 20, 2004. Since January 2004, Mr. McIntosh has been Chairman of NAV Energy Trust, a Calgary-based oil and natural gas investment trust. Between October 2002 and January 2004, he was President and Chief Executive Officer of Navigo Energy Inc. and was instrumental in the conversion of Navigo into NAV Energy Trust. From July 2002 to October 2002, Mr. McIntosh managed his personal investments. He was Senior Vice President and Chief Operating Officer of Gulf Canada Resources Limited from December 2001 to July 2002 and Vice President, Exploration and International of Petro-Canada from April 1996 through November 2001. Mr. McIntosh’s significant experience in the energy industry includes the former positions of Chief Operating Officer of Amerada Hess Canada and Director of Crispin Energy Inc. Mr. McIntosh is on the Board of Directors of Advantage Oil & Gas Ltd. and C1 Energy Ltd.

      George R. Brokaw became one of our Directors on June 28, 2006. Mr. Brokaw joined Perry Capital, L.L.C., an affiliate of Perry Corp., in August 2005 as a Managing Director. Perry Strategic Capital Inc., also an affiliate of Perry Corp., is a private investment firm and provides certain services to us pursuant to

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an advisory services agreement. Investment entities controlled by Perry Corp. are holders of our common shares and Series B preferred shares of the pre-amalgamated North American Energy Partners Inc. See “Related Party Transactions – Advisory Services Agreement” and “Principal and Selling Shareholders.” From January 2003 to May 2005, Mr. Brokaw was Managing Director (Mergers & Acquisitions) of Lazard Frères & Co. LLC, which he joined in 1996. Between 1994 and 1996, he was an investment banking associate for Dillon Read & Co. Mr. Brokaw received a Bachelor of Arts degree from Yale University and a J.D. and M.B.A. from the University of Virginia.

      John A. Brussa became one of our Directors on November 26, 2003. Mr. Brussa is a senior partner and head of the Tax Department at the law firm of Burnet, Duckworth & Palmer LLP, a leading natural resource and energy law firm located in Calgary. He has been a partner since 1987 and has worked at the firm since 1981. Mr. Brussa is Chairman of Penn West Energy Trust, Crew Energy Inc. and Divestco Inc. Mr. Brussa also serves as a director of a number of natural resource and energy companies and mutual fund trusts. He is a member and former Governor of the Executive Committee of the Canadian Tax Foundation. Mr. Brussa attended the University of Windsor and received his Bachelor of Arts in History and Economics in 1978 and his Bachelor of Laws in 1981.

      Donald R. Getty became one of our Directors on November 26, 2003. Since 1992, Mr. Getty has been President and Chief Executive Officer of Sunnybank Investments Ltd., a private investment and consulting firm based in Edmonton, Alberta. Mr. Getty was the 11th Premier of Alberta since the province was formed in 1905, a position he held from 1985 to 1992. As Premier, Mr. Getty’s government was successful in emphasizing development of non-conventional oil projects and diversifying Alberta’s economy, among other initiatives. Before serving as Premier of Alberta, Mr. Getty had a distinguished career in both the public and private sectors. Mr. Getty graduated from the University of Western Ontario with an Honours degree in Business Administration and in 2003 he received an Honourary Degree of Law from the University of Lethbridge. In addition, Mr. Getty was appointed an officer of the Order of Canada in 1998 and a member of the Alberta Order of Excellence in 1994.

      Martin P. Gouin became one of our Directors on November 26, 2003. Mr. Gouin was President and Chief Executive Officer of North American Construction Group Inc. from 1995 until November 2003. Prior to that he held numerous positions at North American, including Vice President of Operations, and has more than 25 years experience in the industry. Since 2002, Mr. Gouin has been the President of Norama Inc., a management and holding company. He is a director of Tirecraft Group Inc., one of the largest wholesale and retail distributors of tires in North America, and Emerge Developments, with holdings in office and commercial real estate. Mr. Gouin is a member of Young Presidents Organization and attended the University of Alberta, majoring in economics.

      John D. Hawkins became one of our Directors on October 17, 2003. Mr. Hawkins joined The Sterling Group, L.P. in 1992 and has been a Principal since 1999. The Sterling Group, a private equity investment firm, provides certain services to us pursuant to an advisory services agreement, and an investment entity affiliated with The Sterling Group is a holder of our common shares and Series B preferred shares of the pre-amalgamated North American Energy Partners Inc. See “Related Party Transactions – Advisory Services Agreement” and “Principal and Selling Shareholders.” Before joining Sterling he was on the professional staff of Arthur Andersen & Co. from 1986 to 1990. Mr. Hawkins previously served on the board of Exopack Holding Corp. He received a Bachelor of Science in Business Administration in Accounting from the University of Tennessee and his M.B.A. from the Owen Graduate School of Management at Vanderbilt University.

      William C. Oehmig served as Chairman of our Board of Directors from November 26, 2003 until passing off this position and assuming the role of Director and chair of the Executive Committee on May 20, 2004. He is a Principal with The Sterling Group, L.P., a private equity investment firm. The Sterling Group provides certain services to us pursuant to an advisory services agreement, and an investment entity affiliated with The Sterling Group is a holder of our common shares and Series B preferred shares of the pre-amalgamated North American Energy Partners Inc. See “Related Party Transactions – Advisory Services Agreement” and “Principal and Selling Shareholders.” Prior to joining

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Sterling in 1984, Mr. Oehmig worked in banking, mergers and acquisitions, and represented foreign investors in purchasing and managing U.S. companies in the oilfield service, manufacturing, distribution, heavy equipment and real estate sectors. He began his career in Houston in 1974 at Texas Commerce Bank. Mr. Oehmig currently serves on the boards of Propex Fabrics Inc. and Panolam Industries International Incorporated. In the past he has served as Chairman of Royster-Clark, Purina Mills, and as a director of Exopack and Sterling Diagnostic Imaging. Mr. Oehmig received his B.B.A. in economics from Transylvania University and his M.B.A. from the Owen Graduate School of Management at Vanderbilt University.

      Richard D. Paterson became one of our Directors on August 18, 2005. Mr. Paterson has been a Managing Director of Genstar Capital since 1988. Genstar Capital provides certain services to us pursuant to an advisory services agreement, and certain investment entities controlled by Genstar are holders of our common shares and Series B preferred shares of the pre-amalgamated North American Energy Partners Inc. See “Related Party Transactions – Advisory Services Agreement” and “Principal and Selling Shareholders.” Before founding Genstar Capital, Mr. Paterson served as Senior Vice President and CFO of Genstar Corporation, a $4 billion NYSE company, where he was responsible for finance, tax, information systems and public reporting. He has been active in corporate acquisitions for more than 25 years. Mr. Paterson started his career in 1984 as an auditor with Coopers & Lybrand in Montreal. He currently serves as Chairman of the Board of New A.C. Inc. and is also a Director of INSTALLS Inc. LLC, American Pacific Enterprises LLC, Propex Fabrics Inc., Woods Equipment Company and Altra Industrial Motion, Inc. Mr. Paterson earned a Bachelor of Commerce from Concordia University and is a Chartered Accountant.

      Allen R. Sello became one of our Directors on January 26, 2006. His career began at Ford Motor Company of Canada in 1964, where he held numerous finance and marketing management positions, including Treasurer. In 1979 Mr. Sello joined Gulf Canada Limited, at which he held various senior financial positions, including Vice President and Controller. He was appointed Vice President, Finance of successor company Gulf Canada Resources Limited in 1987 and Chief Financial Officer in 1988. Mr. Sello then joined International Forest Products Ltd. in 1996 as Chief Financial Officer. From 1999 until his retirement in 2004 he held the position of Senior Vice President and Chief Financial Officer for UMA Group Limited. Mr. Sello is currently Vice-Chair of the Vancouver Board of Trade Government Budget and Finance Committee, a trustee of Sterling Shoes Income Fund and a director of Infowave Software Inc. Mr. Sello received his Bachelor of Commerce from the University of Manitoba and his M.B.A. from the University of Toronto.

      K. Rick Turner became one of our Directors on November 26, 2003. Mr. Turner has been employed by Stephens’ family entities since 1983. SF Holding Corp, formerly Stephens Group, Inc., provides certain services to us pursuant to an advisory services agreement, and an investment entity controlled by SF Holding Corp. is a holder of our common shares and Series B preferred shares of the pre-amalgamated North American Energy Partners Inc. See “Related Party Transactions – Advisory Services Agreement” and “Principal and Selling Shareholders.” Mr. Turner is currently Senior Managing Principal of The Stephens Group, LLC. He first became a private equity principal in 1990 after serving as the Assistant to the Chairman, Jackson T. Stephens. His areas of focus have been oil and gas exploration, natural gas gathering, processing industries and power technology. Mr. Turner currently serves as a director of Atlantic Oil Corporation, SmartSignal Corporation, JV Industrials, LLC, JEBCO Seismic LLC and the general partner of Energy Transfer Partners, LP (ETP) and the general partner of Energy Transfer Equity, LP (ETE). Prior to joining Stephens, he was employed by Peat, Marwick, Mitchell and Company. Mr. Turner earned his B.S.B.A. from the University of Arkansas and is a non-practicing CPA.

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The Board and Board Committees

      Our board supervises the management of our business as provided by Canadian law. The listing requirements of the NYSE require that our board of directors be composed of a majority of independent directors within one year of the listing of our common shares on the NYSE. Accordingly, we intend to adjust the board membership to comply with this requirement following the completion of this offering.

      Our board has established the following committees:

•  The Executive Committee has been delegated all of the powers and authority of the board with respect to the management and direction of our business and affairs, except as limited by Section 115(3) of the Canada Business Corporations Act. The Executive Committee is currently composed of Messrs. Brokaw, Hawkins, McIntosh, Oehmig, Paterson, Ruston and Turner, with Mr. Oehmig serving as Chairman.

•  The Audit Committee recommends independent public accountants to the board, reviews the quarterly and annual financial statements and associated audit reports and reviews the fees paid to our auditors. The Audit Committee reports its findings and recommendations to the board for ratification. Rule 10A-3 under the Securities Exchange Act of 1934, as amended, and the listing requirements of the NYSE and the requirements of the Canadian securities regulatory authorities require that our audit committee be composed of a majority of independent directors within 90 days of the effectiveness of the registration statement of which this prospectus is a part and that it be composed solely of independent directors within one year of such date. Accordingly, we intend to adjust the composition of the audit committee following the completion of this offering. Following this offering, 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 Exchange Act. Our board of directors will adopt a written charter for the audit committee that will be available on our website after the completion of this offering. The Audit Committee is currently composed of Messrs. Brokaw, Brussa, Hawkins, McIntosh, Sello and Turner, with Mr. Sello serving as Chairman.

•  The Compensation Committee is charged with the responsibility for supervising executive compensation policies for us and our subsidiaries, administering the employee incentive plans, reviewing officers’ salaries, approving significant changes in executive employee benefits and recommending to the board such other forms of remuneration as it deems appropriate. The listing requirements of the NYSE require that our compensation committee be composed of a majority of independent directors within 90 days of the listing of our common shares on the NYSE and that it be composed solely of independent directors within one year of such listing. Accordingly, we intend to adjust the composition of the compensation committee following the completion of this offering. Our board of directors will adopt a written charter for the compensation committee that will be available on our website after the completion of this offering. The Compensation Committee is currently composed of Messrs. Brussa, Getty, McIntosh, Oehmig and Paterson, with Mr. Paterson serving as Chairman.

•  The Planning Committee is responsible for identifying and addressing significant issues and opportunities and developing strategic plans for us and making periodic reports to the board of directors on its activities, recommendations and actions. The Planning Committee is currently composed of Messrs. Brokaw, Brussa, Oehmig and Ruston, with Mr. Ruston serving as Chairman.

      The listing requirements of the NYSE require that we establish a nominating and corporate governance committee composed of a majority of independent directors within 90 days of the listing of our common shares on the NYSE and that it be composed solely of independent directors and have at least three members within one year of such listing. Accordingly, we intend to establish this committee

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following the completion of this offering. The principal duties of the nominating and corporate governance committee will be as follows:

•  to recommend to the board of directors proposed nominees for election to the board of directors by the shareholders 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 shareholder 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 that will be available on our website after the completion of this offering.

      The board may also establish other committees.

Compensation Committee Interlocks and Insider Participation

      None of the members of the Compensation Committee is or has been one of our officers or employees, and none of our executive officers served during fiscal 2006 on a board of directors of another entity which has employed any of the members of the Compensation Committee.

Web Access

      We will provide access through our website at www.nacg.ca to current information relating to governance, including a copy of each board committee charter, our Code of Conduct, our corporate governance guidelines and other matters impacting our governance principles. You may also contact our Vice President, Corporate for paper copies of these documents free of charge. The information contained in our website is not a part of this prospectus or the registration statement of which this prospectus forms a part.

Director Compensation

      Our directors, other than Messrs. Gouin, McIntosh and Ruston, each receive an annual aggregate retainer of $32,500 and a fee of $1,500 for each meeting of the board or any committee of the board that they attend, and are reimbursed for reasonable out-of-pocket expenses incurred in connection with their services pursuant to our policies. The chairman of our audit committee receives an additional annual retainer of $10,000. Mr. McIntosh, our Chairman of the Board, receives an annual retainer of $150,000. In addition, Mr. McIntosh received a bonus of $205,000 in June 2005. Messrs. Gouin and Ruston do not receive director compensation.

      In addition, our directors have received grants of stock options under the 2004 Share Option Plan. Effective November 2003, each director, excluding Messrs. Brokaw, Gouin, McIntosh, Paterson, Sello and Ruston, received options to purchase 1,388 common shares. Mr. McIntosh received options to acquire 3,500 common shares in May 2004, Mr. Paterson received options to purchase 1,388 common shares in November 2005, Mr. Sello received options to purchase 1,388 common shares in February 2006 and Mr. Brokaw received options to purchase 1,388 common shares in June 2006. All the options have an exercise price of $100 per share, vest at the rate of 20% per year over five years and expire ten years after their grant date. The vesting of the options granted to Messrs. Brokaw and Paterson has been accelerated as if they had been issued effective November 2003.

      We have offered each director holding stock options, excluding Messrs. McIntosh and Ruston, the option to have all of his options become immediately exercisable on the condition that he exercise all such options by August 31, 2006. The stock options of any director who does not accept this offer will remain unchanged.

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Executive Compensation

      The following summary compensation table sets forth the total value of compensation earned by our Chief Executive Officer and each of the other four most highly compensated officers as of March 31, 2006, collectively called the named executive officers, for services rendered in all capacities to us for the fiscal years ended March 31, 2006, 2005 and 2004.

Summary Compensation Table

												Long-Term
												Compensation
		Annual Compensation
												Securities
		Fiscal							Other Annual			Underlying
Name and Principal Position		Year		Salary		Bonus			Compensation			Options(a)
Rodney J. Ruston			2006	$	536,539	$	300,000			(d	)		27,500
	President and
	Chief Executive Officer
	(Hired May 2005)
William M. Koehn			2006		240,000		241,385	(b)		(d	)		—
	Vice President, Operations		2005		224,000		—			(d	)		—
	and Chief Operating Officer		2004		170,000		1,040,000	(b)(c)		(d	)		5,000
Vincent J. Gallant			2006		204,000		235,350	(b)		(d	)		—
	Vice President, Corporate		2005		204,000		—			(d	)		—
			2004		162,000		1,040,000	(b)(c)		(d	)		5,000
Miles W. Safranovich			2006		195,808		210,384	(b)		(d	)		2,000
	Vice President, Business		2005		61,385		—			(d	)		3,000
	Development & Estimating
	(Hired November 2004)
Christopher J. Hayman			2006		183,641		186,910	(b)		(d	)		2,000
	Vice President, Finance		2005		56,250		—			(d	)		3,000
	(Hired January 2005)

(a)	Consists of options to purchase our common shares.
(b)	Bonus pursuant to our Annual Incentive Plan.
(c)	Includes a $750,000 transaction bonus and a $250,000 performance bonus, both paid by Norama Inc., the parent company of Norama Ltd., upon closing of the Acquisition.
(d)	The amount of other annual compensation does not exceed the lesser of $50,000 and 10% of the salary and bonus for the fiscal year.

Option Grants in Fiscal 2006

	Number of		Percentage of
	Securities		Total Options
	Underlying		Granted to
	Options		Employees in		Exercise				Grant Date
Name	Granted		Fiscal Year		Price		Expiration Date		Value(a)
Rodney J. Ruston		27,500		79.7%	$	100		May 8, 2015	$	2,014,302
William M. Koehn		—		—		—		—		—
Vincent J. Gallant		—		—		—		—		—
Miles W. Safranovich		2,000		5.8%	$	100		November 2, 2015		104,090
Christopher J. Hayman		2,000		5.8%	$	100		November 2, 2015		104,090

(a) Value estimated using the Black-Scholes option-pricing model. For assumptions used, see note 21 to our consolidated financial statements included elsewhere in this prospectus.

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Aggregated Option Exercises in Fiscal 2006 and Fiscal Year End Option Values

					Number of		Value of
					Securities		Unexercised
					Underlying		In-the-Money
					Unexercised Options		Options at
	Shares				at March 31, 2006		March 31, 2006
	Acquired on		Value		(Exercisable/		(Exercisable/
Name	Exercise		Realized		Unexercisable)		Unexercisable)
Rodney J. Ruston		—		—		—/27,500		—/ —
William M. Koehn		—		—		2,000/3,000		—/ —
Vincent J. Gallant		—		—		2,000/3,000		—/ —
Miles W. Safranovich		—		—		600/4,400		—/ —
Christopher J. Hayman		—		—		600/4,400		—/ —

Options to Purchase Common Shares

      The following chart sets forth information as of June 30, 2006, regarding outstanding options granted under our 2004 Share Option Plan.

	Common Shares
	Underlying Options				Exercise
Category	Granted		Exercised		Price
All executive officers and past executive officers		55,300		—	$	100
All directors and past directors who are not also executive officers		15,992		—		100
All other employees or past employees		32,250		—		100

Retirement Benefits for Executive Officers and Directors

      For the fiscal year ended March 31, 2006, the total amount we set aside for pension, retirement and similar benefits for our executive officers and directors was $54,677, consisting of employer matching contributions to our executive officers’ Registered Retirement Savings Plan, a Canadian tax-deferred retirement savings plan, accounts of up to 5% of salary.

Retention Bonus

      Norama Inc., the parent of Norama Ltd., will pay to each of Messrs. Koehn and Gallant a retention bonus of $750,000, plus interest, on November 26, 2006, three years after the closing of the Acquisition, provided they are still employed by us.

Annual Incentive Plan

      We have established a management incentive plan. The incentive plan is administered by the Compensation Committee. The plan has established an annual bonus pool to be paid to participants if a target level of financial performance is achieved. If our actual financial performance exceeds or falls short of the targeted level of performance, the amount of the pool available to be paid will increase or decrease, respectively. The Compensation Committee will recommend to the board of directors the amount of the total pool, the target financial performance, the eligible participants and each participant’s share of the potential pool.

Share Option Plan

      Our board has adopted the 2004 Share Option Plan. The option plan is administered by the Compensation Committee. Option grants under the option plan may be made to directors, officers, employees and service providers selected by the Compensation Committee. The option plan provides for the discretionary grant of options to purchase common shares. The exercise price of stock options must not be less than the fair market value of common shares on the date of grant, as determined by the committee

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in its sole discretion. The committee may provide that the options will vest immediately or in increments over a period of time. We have reserved 105,000 common shares for issuance under the option plan. As of June 30, 2006, there were 103,542 shares issuable upon exercise of outstanding share options and 1,458 were available for issuance.

Profit Sharing Plan

      Our board has established a profit sharing plan covering all full-time salaried and certain hourly employees, excluding executive officers. The profit sharing plan is administered by the compensation committee. Amounts paid under the profit sharing plan will constitute taxable income in the year received and will be based on our financial performance over a period of time to be determined by the compensation committee. The compensation committee will recommend to the board of directors for approval a target level of financial performance to be achieved and an amount to be set aside for profit sharing if the target is met. If financial performance exceeds this minimum level, we may make distributions to employees. The compensation committee may change the amount set aside for profit sharing and the proportion of such amount allocated to an individual employee or group of employees.

Share Ownership of Directors and Executive Officers

      As of June 30, 2006, all of our directors and executive officers, as a group, beneficially own, directly or indirectly, or exercise control or direction over 3.93% of our common shares. See “Principal and Selling Shareholders.”

Written Employment Arrangements

      We have an employment arrangement with Rodney Ruston, our President and Chief Executive Officer. The initial term of Mr. Ruston’s employment is five years, beginning May 2005, unless earlier terminated. If his employment is terminated by us without cause or if his employment is not renewed at the end of the initial five year term, Mr. Ruston will receive a severance payment equal to his then-annual salary plus the amount of his bonus payment in the year preceding the termination date. The arrangement provides for a $600,000 annual salary, to be reviewed annually by the board of directors, plus an initial grant of options to purchase 20,000 common shares, with an exercise price of $100 per share and subject to vesting at the rate of 20% per year. During the term of the arrangement, Mr. Ruston is eligible for an annual cash bonus of up to 50% of his annual salary upon achievement of performance targets approved by the board, receives a monthly vehicle allowance of $800 and receives an annual travel allowance of $25,000 to cover the costs of traveling to and from his home country of Australia.

      We have agreed to the terms of employment with Robert Harris, our new Vice President, Human Resources Health, Safety & Environment. Mr. Harris’ employment will continue until terminated by him or us in accordance with the provisions of the agreement. If his employment is terminated by us without cause, Mr. Harris will receive a payment of three months of salary in lieu of notice, plus a severance payment equal to one year annual base salary and a payment equal to 90% of the amount of his annual bonus payment pro rated to the date of termination. The agreement provides for a $210,000 annual salary, to be reviewed annually by the board of directors, plus an initial grant of options to purchase 5,000 common shares, with an exercise price of $100 per share and subject to vesting at the rate of 20% per year. During the term of the agreement, Mr. Harris is eligible for an annual cash bonus of up to 100% of his annual salary upon achievement of performance targets approved by the board, receives a monthly vehicle allowance of $800 and receives reimbursement of the annual fee for membership in one club.

      We are in the process of negotiating written employment agreements with each of our executive officers.

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RELATED PARTY TRANSACTIONS

Advisory Services Agreement

      Pursuant to an agreement, dated November 21, 2003, among The Sterling Group, L.P., Genstar Capital, L.P., Perry Strategic Capital Inc., and SF Holding Corp., referred to in the agreement as the “sponsors,” and us on each June 30 through June 30, 2013, we will pay the sponsors whose services have not terminated in accordance with the agreement, as a group, an annual management fee in cash totaling the greater of $400,000 or 0.5% of our EBITDA for the previous twelve month period ended March 31. The agreement also provides that we will indemnify the sponsors against liabilities relating to their services and will reimburse the sponsors for their expenses in connection with their services.

      In addition, the agreement provides that if we or any of our subsidiaries determines within ten years of the date of the closing of the Acquisition to acquire any business or assets having a value of US$1.0 million or more, referred to in the agreement as a “future corporate transaction,” or to offer its securities for sale publicly or privately or to otherwise raise any debt or equity financing, referred to in the agreement as a “future securities transaction,” the relevant company will retain one or more of the sponsors, whose services have not been terminated in accordance with the agreement, as a group, as consultants with respect to the transaction. For any future corporate transactions, the relevant sponsors are entitled under the agreement to receive a fee in the amount of 1% of the aggregate consideration paid for the Acquisition plus the aggregate amount of assumed liabilities and, regardless of whether such future corporate transaction is consummated, reimbursement of any expenses or fees incurred by any sponsor in connection therewith. For any future securities transactions, the relevant sponsors are entitled to receive under the agreement a fee in the amount of 0.5% of the aggregate gross proceeds to the companies from such transaction and, regardless of whether such future securities transaction is consummated, reimbursement of any expenses or fees incurred by any sponsor in connection therewith. Actual amounts payable for these services are limited by the terms of our 9% senior secured notes.

      The advisory services agreement will be terminated in connection with this offering for aggregate consideration of $                    million.

Office Leases

      We are party to lease agreements with Acheson Properties Ltd., a company owned, indirectly and in part, by Martin Gouin, one of our directors. Mr. Gouin has a 50% beneficial interest in Acheson Properties Ltd. Pursuant to the agreements, we lease our corporate headquarters in Acheson, Alberta, and our offices in Fort Nelson, British Columbia and Regina, Saskatchewan. See “Business – Properties and Facilities.” For the fiscal years ended March 31, 2005 and 2006, we paid $823,827 and $836,484, respectively, pursuant to these leases. The lease agreements were in place before the Acquisition in November 2003.

Voting and Corporate Governance Agreement

      We are party to a voting agreement, dated November 26, 2003, with affiliates of the sponsors that includes the following provisions:

Directors

      The agreement provides that, as long as a shareholder party to the agreement, along with its affiliates, and various permitted tranferees own at least 50% of the common shares that it initially purchased in our November 2003 offering of common shares, such shareholder may designate one nominee for election to our board of directors. In addition, as long as Sterling Group Partners I, L.P. and various permitted transferees own at least 75% of the common shares that it initially purchased in the offering of common shares, it may designate one additional nominee for election to our board of directors. Each shareholder party to the agreement agrees to vote the common shares held by it for each of the designated director nominees. The shareholder parties to the agreement have also agreed to vote their common shares in favor of the election to the board of directors of independent directors designated by a specified majority of the

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shareholder parties to the agreement or their appointed voting representatives. The voting agreement contains similar provisions for the removal of a director designated for removal by the parties to the agreement. Messrs. Hawkins and Oehmig are the director designees of The Sterling Group. Mr. Paterson is the director designee of Genstar Capital. Mr. Brokaw is the director designee of Perry Strategic Capital. Mr. Turner is the director designee of SF Holding Corp.

Permitted Transactions

      The voting agreement provides that each shareholder party to the agreement will not, and will not permit any of its affiliates to, enter into, renew, extend or be a party to any transaction or series of transactions with us or any of our subsidiaries without the prior written consent of the holders of a specified majority of shares subject to the agreement, other than such holder or its affiliates, except for:

•  issuances of capital shares pursuant to, or the funding of, employment arrangements, share options and share ownership plans approved by the board of directors;

•  the grant of share options or similar rights to employees and directors pursuant to plans approved by the board of directors;

•  loans or advances to executive officers approved by the board of directors;

•  the payment of reasonable fees to our directors and the directors of our subsidiaries who are not our employees or employees of our subsidiaries in their capacities as board members or members of committees of the board as may be approved by the board;

•  any transaction between our subsidiaries; and

•  the registration rights agreement described below, the investor shareholders agreement described in “Description of Share Capital — Shareholders Agreements” and the advisory services agreement described in this “Related Party Transactions” section.

Termination

      The voting agreement will terminate upon the completion of this offering. However, so long as a designated affiliate of each sponsor holds our shares, it will retain the right at its expense

•  to obtain copies of all documents, reports, financial data and other information regarding us,

•  to consult with and advise our management on matters relating to our operations,

•  to discuss our Company’s affairs, finances and accounts with our officers, directors and outside accountants, and

•  to visit and inspect any of our properties and facilities, including but not limited to books of account,

all upon reasonable notice and at such reasonable times during normal business hours as may be requested.

      In addition, so long as a designated affiliate of a sponsor owns 10% of the shares that it initially purchased in our November 2003 offering of common shares, at its request we will deliver to such affiliate all financial information (1) distributed to members of our board of directors and (2) provided pursuant to any senior secured loan agreement or indenture to which we or a subsidiary are a party.

      So long as a designated affiliate of Genstar Capital Partners III, L.P. owns any of our shares, it will have the right to receive all information sent to our board of directors and to have a representative attend all board meetings in a nonvoting observer status.

      All the foregoing rights will be subject to customary confidentiality requirements subject to security clearance requirements imposed by applicable government authorities.

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Shareholders Agreements

      All holders of our common shares who are also our employees or employees of any of our subsidiaries are parties to an employee shareholders agreement. All other holders of our common shares are parties to an investor shareholders agreement. See “Description of Share Capital — Shareholders Agreements.” Both the employee shareholders agreements and the investor shareholders agreement will terminate upon the completion of this offering.

Registration Rights Agreement

      We are party to a registration rights agreement with certain of our shareholders, including affiliates of each of the sponsors, Paribas North America, Inc. and Mr. William Oehmig, one of our directors. After our initial public offering, the shareholders party to the agreement and their permitted transferees are entitled, subject to certain limitations, to include their common shares in a registration of common shares we initiate under the Securities Act of 1933, as amended. In addition, after the 120th day following an initial public offering of the common shares, any one or more shareholders party to the agreement has the right to require us to effect the registration of all or any part of such shareholders’ common shares under the Securities Act, referred to as a “demand registration,” so long as the amount of common shares to be registered has an aggregate fair market value of at least US$5.0 million and, at such time, the SEC has ordered or declared effective fewer than four demand registrations initiated by us pursuant to the registration rights agreement. In the event the aggregate number of common shares which the shareholders party to the agreement request us to include in any registration, together, in the case of a registration we initiate, with the common shares to be included in such registration, exceeds the number which, in the opinion of the managing underwriter, can be sold in such offering without materially affecting the offering price of such shares, the number of shares of each shareholder to be included in such registration will be reduced pro rata based on the aggregate number of shares for which registration was requested. The shareholders party to the agreement have the right to require, after four demand registrations, one registration in which their common shares will not be subject to pro rata reduction with others entitled to registration rights.

      We may opt to delay the filing of a registration statement required pursuant to any demand registration for:

•  up to 120 days if we have

•  decided to file a registration statement for an underwritten public offering of our common equity securities, the net proceeds of which are expected to be at least US$20.0 million, or

•  initiated discussions with underwriters in preparation for a public offering of our common equity securities as to which we expect to receive net proceeds of at least US$20.0 million and the demand registration, in the underwriters’ opinion, would have a material adverse effect on the offering or

•  up to 90 days following a request for a demand registration if we are in possession of material information that we reasonably deem advisable not to disclose in a registration statement.

      Our right to delay the filing of a registration statement if we possess information that we deem advisable not to disclose does not obviate any disclosure obligations which we may have under the Exchange Act or other applicable laws; it merely permits us to avoid filing a registration statement if our management believes that such a filing would require the disclosure of information which otherwise is not required to be disclosed and the disclosure of which our management believes is premature or otherwise inadvisable.

      The registration rights agreement contains customary provisions whereby we and the shareholders party to the agreement indemnify and agree to contribute to each other with regard to losses caused by the misstatement of any information or the omission of any information required to be provided in a registration statement filed under the Securities Act. The registration rights agreement requires us to pay

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the expenses associated with any registration other than sales discounts, commissions, transfer taxes and amounts to be borne by underwriters or as otherwise required by law.

Series B Preferred Shares

      The Series B preferred shares were initially issued by the pre-amalgamated North American Energy Partners Inc. for cash proceeds of $7.5 million on May 19, 2005 to our existing common shareholders, including the sponsors. North American Energy Partners Inc. subsequently offered and sold $0.9 million of Series B preferred shares to certain of our existing common shareholders and used the proceeds from this subsequent sale to repurchase a like amount of Series B preferred shares from the sponsors. All such Series B preferred shares were issued or repurchased, as the case may be, at a price of $100 per share. For additional information on the Series B preferred shares, refer to notes 13(a) and 13(c), respectively, in our consolidated financial statements included elsewhere in this prospectus.

Recent Sales of Securities to Related Parties

      In March 2006, one of our directors was issued 1,000 common shares and 81 Series B preferred shares. In December 2005, three of our officers were issued an aggregate of 2,000 common shares and an aggregate of 163 Series B preferred shares. All such common shares were issued at $100 per share and all such Series B preferred shares were issued at $100 per share.

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PRINCIPAL AND SELLING SHAREHOLDERS

      The following table presents information regarding the beneficial ownership of our common shares as of June 30, 2006, based on information available to us, by:

•  each of the named executive officers;

•  each of our directors;

•  all of our directors and executive officers as a group;

•  each of the selling shareholders, which includes                     ; and

•  each beneficial owner of more than 5% of our outstanding voting common shares.

      The information in this section does not give effect to the Reorganization. As of June 30, 2006, we had 910,380 voting common shares and 20,620 non-voting common shares outstanding. For purposes of this section, “common shares” refers only to the voting common shares. Except as otherwise indicated in the footnotes to the table, each of the beneficial owners listed has, to our knowledge, sole voting and investment power with respect to the indicated common shares. Except as otherwise indicated, the address of each of the beneficial owners is c/o North American Energy Partners Inc., Zone 3, Acheson Industrial Area, 2-53016 Highway 60, Acheson, Alberta, T7X 5A7, Canada.

      The amounts and percentages of shares beneficially owned are reported on the basis of SEC regulations governing the determination of beneficial ownership of securities. Under SEC rules, a person is deemed to be a “beneficial owner” of a security if that person has or shares voting power or investment power, which includes the power to dispose of or to direct the disposition of such security. A person is also deemed to be a beneficial owner of any securities of which that person has a right to acquire beneficial ownership within 60 days. Securities that can be so acquired are deemed to be outstanding for purposes of computing such person’s ownership percentage, but not for purposes of computing any other person’s percentage. Under these rules, more than one person may be deemed to be a beneficial owner of the same securities and a person may be deemed to be a beneficial owner of securities as to which such person has no economic interest.

      Unless otherwise noted, each of the beneficial owners named in the following table is also the shareholder of record with respect to such shares.

									Common Shares
									Beneficially Owned
									After the Offering
	Common Shares					Common	Common Shares		Assuming Full
	Beneficially Owned					Shares	Beneficially Owned		Exercise of Over-
	Prior to the Offering					Offered Hereby	After the Offering		Allotment Option
Name and Address of Beneficial Owner	Number			%		Number	Number	%	Number	%
George R. Brokaw		555	(a)		*
John A. Brussa		4,555	(a)		*
Vincent J. Gallant		7,000	(b)		*
Donald R. Getty		1,555	(a)		*
Martin P. Gouin		—			—
Robert G. Harris		—			—
John D. Hawkins		555	(a)(g)		*
Christopher J. Hayman		1,600	(c)		*
William M. Koehn		7,000	(b)		*
Ronald A. McIntosh		3,400	(d)		*
William C. Oehmig		6,209	(e)(g)		*
Richard D. Paterson		555	(a)(i)		*
Rodney J. Ruston		500			*
Allen R. Sello		1,000			*

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										Common Shares
										Beneficially Owned
										After the Offering
		Common Shares					Common	Common Shares		Assuming Full
		Beneficially Owned					Shares	Beneficially Owned		Exercise of Over-
		Prior to the Offering					Offered Hereby	After the Offering		Allotment Option
Name and Address of Beneficial Owner		Number			%		Number	Number	%	Number	%
Miles W. Safranovich			1,100	(c)		*
K. Rick Turner			555	(a)		*
Directors and executive officers as a group (16 persons)			36,139	(f)		3.93
Sterling Group Partners I, L.P.			272,456	(g)		29.60
	Eight Greenway Plaza, Suite 702 Houston, Texas 77046
Perry Luxco S.A.R.L			104,542	(h)		11.36
	Carré Bonn 20, Rue de la Poste L-2346 Luxembourg
Perry Partners, L.P.			92,707	(h)		10.07
	767 Fifth Avenue 19th Floor New York, New York 10153
Genstar Capital Partners III, L.P.			190,412	(i)		20.69
	Four Embarcadero Center, Suite 1900 San Francisco, California 94111
Stephens-NACG LLC			131,500	(j)		14.29
	111 Center Street Little Rock, Arkansas 72201
Paribas North America, Inc.			45,130	(k)		4.90
	787 Seventh Avenue New York, New York 10019

*	Less than 1%.
(a)	Includes currently exercisable options to purchase 555 shares.
(b)	Includes currently exercisable options to purchase 2,000 shares.
(c)	Includes currently exercisable options to purchase 600 shares.
(d)	Includes currently exercisable options to purchase 1,400 shares.
(e)	Includes 1,842 shares that have been donated by Mr. Oehmig but over which Mr. Oehmig retains sole voting power. Also includes currently exercisable options to purchase 277 shares.
(f)	Includes currently exercisable options to purchase 10,485 shares.
(g)	Sterling Group Partners I GP, L.P. is the sole general partner of Sterling Group Partners I, L.P. Sterling Group Partners I GP, L.P. has five general partners, each of which is wholly-owned by one of Frank J. Hevrdejs, William C. Oehmig, T. Hunter Nelson, John D. Hawkins and C. Kevin Garland. Each of these individuals disclaims beneficial ownership of the shares owned by Sterling Group Partners I, L.P.

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(h)	Richard Perry is the President and sole shareholder of Perry Corp., which is the investment manager of Perry Luxco S.A.R.L. and the managing general partner of Perry Partners, L.P. As such, Mr. Perry may be deemed to have beneficial ownership over the respective common shares owned by Perry Luxco S.A.R.L. and Perry Partners, L.P.; however, Mr. Perry disclaims such beneficial ownership, except to the extent of his pecuniary interest, if any, therein. Perry Corp. is an affiliate of Perry Strategic Capital Inc.
(i)	Genstar Capital III, L.P. is the sole general partner of each of Genstar Capital Partners III, L.P. and Stargen III, L.P., which owns an additional 6,838 shares, and Genstar III GP LLC is the sole general partner of Genstar Capital III, L.P. Jean-Pierre L. Conte, Richard F. Hoskins and Richard D. Paterson are the managing members of Genstar III GP LLC. In such capacity, Messrs. Conte, Hoskins and Paterson may be deemed to beneficially own common shares beneficially owned, or deemed to be beneficially owned, by Genstar III GP LLC, but disclaim such beneficial ownership.
(j)	SF Holding Corp. is the sole manager of Stephens-NACG LLC. No natural person may be deemed to beneficially own the shares owned by Stephens-NACG LLC.
(k)	Paribas North America, Inc. also owns all 20,620 of our non-voting common shares.

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DESCRIPTION OF CERTAIN INDEBTEDNESS

Revolving Credit Facility

      We have an amended and restated credit agreement dated July 19, 2006 with a syndicate of lenders that provides us with a $55.0 million revolving credit facility. The following is a summary of certain provisions of the revolving credit facility.

      General. Our revolving credit facility provides for an original principal amount of up to $55.0 million under which revolving loans may be made and under which letters of credit may be issued. The facility will mature on March 1, 2010.

      Security. The credit facility is secured by a first priority lien on substantially all of our and our subsidiaries’ existing and after-acquired property (tangible and intangible), including, without limitation, all accounts receivable, inventory, equipment, intellectual property and other personal property, and all real property, whether owned or leased, and a pledge of the shares of the pre-amalgamated North American Energy Partners Inc. and the shares of its subsidiaries, subject to various exceptions.

      Interest rates and fees. The facility bears interest at variable rates based on the Canadian prime rate plus 2.0% per annum (1.5% per annum for swing line loans). Interest is payable monthly in arrears and computed on the basis of a 365-day year. Letters of credit are subject to a 3.0% per annum fee and to a fronting fee equal to the greater of $500 or 0.25% per annum of the daily drawable amount paid quarterly in arrears. Canadian bankers’ acceptances are subject to a 3.0% per annum stamping fee calculated on the principal amount at maturity. Commitment fees equal to 0.50% per annum multiplied by the daily average unused portion of the credit facility are computed on the basis of a 365-day year and payable quarterly in arrears. During an event of default, interest rates are increased by 2% per annum in excess of the rate otherwise payable.

      Prepayments and commitment reductions. The credit facility may be prepaid in whole or in part without premium or penalty, except for bankers’ acceptances, which will not be prepayable prior to their maturity. However, the credit facility requires prepayments under various circumstances, such as: (i) 100% of the net cash proceeds of certain asset dispositions, subject to certain reinvestment rights, (ii) 100% of the net cash proceeds from our issuance of debt, subject to certain exceptions, (iii) 100% of the net cash proceeds from our issuance of equity (excluding the proceeds from this offering) and capital contributions to NACG Preferred Corp. in excess of a specified amount, (iv) 100% of all casualty and condemnation proceeds, subject to certain reinvestment rights and (v) such amounts as may be necessary to ensure that the outstanding portion of the credit facility does not exceed the commitments and the outstanding portion of the credit facility, plus total liabilities of North American Energy Partners Inc. and its subsidiaries under hedge agreements with lenders on a mark-to-market basis, does not exceed the borrowing base, as defined below.

      Borrowing Base. The borrowing base is defined in the credit agreement to mean an aggregate amount equal to: (i) 60% of the book value of our consolidated property, plant and equipment, plus (ii) 75% of the value of eligible accounts receivable, as defined in the credit facility, plus (iii) unrestricted cash and cash equivalents in excess of $15.0 million. The sum of borrowings and letters of credit under the credit facility, plus our mark-to-market liabilities under all secured swaps may not exceed the borrowing base. Had this facility been in place as of March 31, 2006, the borrowing base, as defined above, would have been approximately $185.4 million. As of March 31, 2006, the mark-to-market liabilities under existing secured swap agreements was approximately $63.6 million. As a result, the total amount of available borrowings under this revolving credit facility would have been approximately $55.0 million as of such date. After taking into account $18.0 million of issued and outstanding letters of credit, the remaining amount of available borrowings as of that date would have been approximately $37.0 million.

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      Covenants. The credit facility contains restrictive covenants limiting our ability, and the ability of our subsidiaries to, without limitation and subject to various exceptions:

•  incur debt or enter into sale and leaseback transactions or contractual contingent obligations;

•  prepay, purchase or otherwise acquire or retire prior to stated maturity certain debt or amend the indentures;

•  create or allow to exist liens or other encumbrances;

•  transfer assets (including any class of stock or the voting rights of any of our subsidiaries) except for sales and other transfers of inventory or surplus, immaterial or obsolete assets in our ordinary course of business and other exceptions set forth in the credit agreement;

•  enter into mergers, consolidations and asset dispositions of all or substantially all of our, or any of our subsidiaries, properties;

•  make investments, including acquisitions;

•  enter into transactions with related parties other than in the ordinary course of business on an arm’s-length basis on terms no less favorable to us than those available from third parties;

•  make any material change in the general nature of the business conducted by us; and

•  pay dividends or redeem shares of capital stock.

      Under the credit facility, we are required to satisfy certain financial covenants, including a minimum interest coverage ratio, a maximum leverage ratio and a minimum consolidated EBITDA requirement.

      Events of default. The credit facility contains customary events of default, including, without limitation, failure to make payments when due, defaults under other agreements or instruments of indebtedness, noncompliance with covenants, breaches of representations and warranties, bankruptcy, judgments in excess of specified amounts, invalidity of loan documents, impairment of security interest in collateral, and changes of control.

9% Senior Secured Notes due 2010

      General. On May 19, 2005, we issued an aggregate of US$60,481,000 of 9% senior secured notes pursuant to an indenture among us, the subsidiary guarantors and Wells Fargo Bank, N.A., as trustee. These notes will mature on June 1, 2010. Interest on these notes accrues at 9% per annum and is payable in arrears on June 1 and December 1 of each year. All of our subsidiaries jointly and severally guarantee the 9% senior notes.

      Security. The 9% senior secured notes and related guarantees are secured by a lien on substantially all of our assets and the assets of our existing and future restricted subsidiaries (other than any immaterial subsidiaries), including a pledge of the stock of our existing and future subsidiaries. Pursuant to the terms of an intercreditor agreement, the security interest in the assets that secure the 9% senior secured notes and the guarantees are subordinated to prior liens thereon that secure our revolving credit facility and the swap agreements, discussed below.

      Redemption and Repurchase. We may redeem some or all of the 9% senior secured notes at any time on or after June 1, 2008, at specified redemption prices. We may redeem up to 35% of the original aggregate principal amount of the 9% senior secured notes in the event of certain equity sales at any time on or after June 1, 2008 at specified redemption prices. We may redeem all but not part of the 9% senior secured notes in the event of various changes in the laws affecting withholding taxes. We are not required to make mandatory redemption or sinking fund payments with respect to the 9% senior secured notes. We will be required to offer to repurchase the 9% senior secured notes from holders if we undergo a change of control or sell our assets in specified circumstances.

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      Covenants. The indenture governing the 9% senior secured notes restricts, among other things, our ability to pay dividends, redeem capital stock or prepay certain subordinated debt; incur additional debt or issue preferred stock; grant liens; merge, consolidate or transfer substantially all of our assets; enter into certain transactions with affiliates; impose restrictions on any subsidiary’s ability to pay dividends or transfer assets to us; enter into certain sale and leaseback transactions; permit subsidiaries to guarantee debt; and take actions that would materially impair the security interests in favor of the trustee. All of these restrictions are subject to customary exceptions.

8³/4% Senior Notes due 2011

      General. On November 26, 2003, we issued an aggregate of US$200.0 million of 8³/4% senior unsecured notes pursuant to an indenture among us, the subsidiary guarantors and Wells Fargo Bank, N.A., as trustee. These notes will mature on December 1, 2011. Interest on these notes accrues at 8³/4% per annum and is payable in arrears on June 1 and December 1 of each year. All of our subsidiaries jointly and severally guarantee the 8³/4 % senior notes.

      Redemption and Repurchase. We may redeem some or all of the 8³/4% senior notes at any time on or after December 1, 2007, at specified redemption prices. We may redeem up to 35% of the original aggregate principal amount of the 8³/4% senior notes in the event of certain equity sales at any time on or after December 1, 2007 at specified redemption prices. We may redeem all but not part of the notes in the event of various changes in the laws affecting withholding taxes. We are not required to make mandatory redemption or sinking fund payments with respect to the 8³/4% senior notes. We will be required to offer to repurchase the 8³/4 % senior notes from holders if we undergo a change of control or sell our assets in specified circumstances.

      Covenants. The indenture governing the 8³/4 % senior notes restricts, among other things, our ability to pay dividends, redeem capital stock or prepay certain subordinated debt; incur additional debt or issue preferred stock; grant liens; merge, consolidate or transfer substantially all of our assets; enter into certain transactions with affiliates; impose restrictions on any subsidiary’s ability to pay dividends or transfer assets to us; enter into certain sale and leaseback transactions; and permit subsidiaries to guarantee debt. All of these restrictions are subject to customary exceptions.

Swap Agreements

      We have entered into two separate International Swap Dealer Association – Master Agreements, one with BNP Paribas, as counterparty, dated November 23, 2003, and one with HSBC Bank Canada, as counterparty, dated March 26, 2004. These agreements are collectively referred to as the swap agreements. Pursuant to the swap agreements, we have and may enter into one or more interest rate or currency swap transactions governed by the terms of the swap agreements and the confirmations issued by the counterparty in respect of each transaction. The swap agreements contain customary representations and warranties, covenants and events of default. Specifically, each swap agreement contains a provision that an event of default under our existing credit agreement will constitute an event of default under such swap agreement and that the counterparty will be entitled to terminate the swap agreement if our payment obligations to the counterparty cease to be secured pari passu with the obligations under the credit agreement. As of March 31, 2006, the liability, measured at fair value, associated with the swap agreements was approximately $63.6 million.

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DESCRIPTION OF SHARE CAPITAL

General

      After completion of the Reorganization, our articles of amalgamation will authorize us to issue an unlimited number of voting common shares, an unlimited number of non-voting common shares and an unlimited number of Series A preferred shares. After the completion of the Reorganization and prior to this offering, we will have                     common shares outstanding and held of record by 90 shareholders,                     non-voting common shares outstanding and held of record by one shareholder and 35,000 Series A preferred shares, referred to as the “Seller preferred shares,” outstanding and held of record by one shareholder.

      Some of the statements contained herein are summaries of the material provisions of our articles of amalgamation relating to dividends, distribution of assets upon dissolution, liquidation or winding up and are qualified in their entirety by reference to our articles of amalgamation.

Voting Common Shares

      The shares being offered in this offering are our voting common shares. Unless the context requires otherwise, references in this section to “common shares” are to our voting common shares only. Each voting common share has an equal and ratable right to receive dividends to be paid from our assets legally available therefor when, as and if declared by our board of directors. Our ability to declare dividends is restricted by the terms of our revolving credit facility and the indentures that govern the 8³/4 % senior and the 9% senior secured notes. See “Description of Certain Indebtedness.” Additionally, we may not declare any dividends or distributions on our common shares while any Seller preferred shares are outstanding unless all accrued dividends on the Seller preferred shares have been paid in full, subject to certain exceptions.

      In the event of our dissolution, liquidation or winding up, the holders of common shares are entitled to share equally and ratably in the assets available for distribution after payments are made to our creditors and subject to the prior rights of holders of Seller preferred shares. Except as provided by the investor shareholders agreement discussed under “Shareholders Agreements – Preemptive Rights” below, holders of common shares have no preemptive rights or other rights to subscribe for our securities. Each common share entitles the holder thereof to one vote in the election of directors and all other matters submitted to a vote of shareholders, and holders of common shares have no rights to cumulate their votes in the election of directors.

Non-Voting Common Shares

      Regulatory requirements applicable to affiliates of Paribas North America, Inc., an affiliate of BNP Paribas, the lender under our revolving credit facility, limit the amount of our voting shares it may own. Therefore, in addition to our voting common shares that it owns, it also owns all of our non-voting common shares. Except as prescribed by Canadian law and except in limited circumstances, the non-voting common shares have no voting rights and are convertible into voting common shares on a share-for-share basis, subject to various limitations, but are otherwise identical to the common shares in all respects.

Seller Preferred Shares

      Holders of Seller preferred shares are entitled to receive dividends at an annual rate of $80 per share, payable annually. Dividends are payable at the option of our board of directors in cash, additional Seller preferred shares or a combination of cash and additional shares. Dividends in respect of the Seller preferred shares will accrue only if our EBITDA, as defined in the terms of the Seller preferred shares, during any twelve month period ending March 31 is at least $75.0 million. As of March 31, 2006, no dividends had accrued on the Seller preferred shares. The terms of the Seller preferred shares do not grant holders of such shares preemptive rights or other rights to subscribe for our securities.

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      Holders of Seller preferred shares have no voting rights except in limited circumstances. The issuance of additional Seller preferred shares (or of any security convertible or exchangeable into Seller preferred shares), or any shares that rank prior to Seller preferred shares in the payment of dividends or in the distribution of assets upon liquidation, requires the affirmative vote of at least two-thirds of the votes cast by holders of Seller preferred shares. Approval by holders holding Seller preferred shares representing two-thirds of all issued and outstanding Seller preferred shares is also required to amend our articles of amalgamation in any way that will reclassify, increase the authorized number of or decrease the amount of dividends to be paid to the Seller preferred shares or decrease the redemption price of the Seller preferred shares.

      The Seller preferred shares rank senior to our common shares with respect to the distribution of assets upon our liquidation. In the event of any such liquidation, the holders of Seller preferred shares will receive, prior to any payment in respect of the common shares, a per share liquidation payment in an amount of cash equal to $1,000 plus all accrued and unpaid dividends.

      We may, at our option, redeem or cause the purchase of all or part of the Seller preferred shares for a per share redemption payment in an amount of cash equal to $1,000 plus all accrued and unpaid dividends. In addition, on November 26, 2012, we are required to redeem or cause the purchase of all of the then-outstanding Seller preferred shares for a per share redemption payment in an amount of cash equal to $1,000 plus all accrued and unpaid dividends.

Shareholders Agreements

      All holders of our common shares who are also our employees or employees of any of our subsidiaries are parties to an employee shareholders agreement. All other holders of our common shares are parties to an investor shareholders agreement. The shareholders agreements include the following provisions:

Certain Transfers/ Rights of First Refusal and Tag Along Rights

      Except for certain permitted transfers, the investor shareholders agreement permits the shareholders who are parties to that agreement to transfer their common shares or any interest therein only upon receipt of a written bona fide third-party offer and after offering all such shares first to us and then to the other shareholders that are parties to the agreement at the price and on the terms specified in the third-party offer and offering such other shareholders the right to participate in such transfer on a pro rata basis. In the event that we and the other shareholders do not accept all of the shares subject to the offer and the other shareholders expect not to participate in such transfer, the offering shareholder may transfer any remaining shares to the third party on no more favorable terms than those specified in the offer for a limited period of time.

      Except for certain permitted transfers, the employee shareholders agreement permits the shareholders who are parties to that agreement to transfer their common shares or any interest therein only (1) upon receipt of a written bona fide third-party offer, (2) after the shareholder has held such shares for at least two years and (3) after offering all such shares to us at the price and on the terms specified in the third-party offer. In the event that we do not accept all of the shares subject to the offer, the offering shareholder may transfer any remaining shares to the third-party on no more favorable terms than those specified in the offer for a limited period of time. Also, if an employee shareholder is for any reason no longer employed by us or any of our subsidiaries before the two-year anniversary of the date the holder becomes a party to the agreement, the holder must sell all of his or her shares to us at the then fair market value of the shares.

Approved Sales

      Each shareholders agreement contains provisions requiring all shareholders who are parties thereto to join in any control disposition, as defined below, to or with an independent third party, as defined below, or group of independent third parties and requiring their consent to the sale of all or substantially all of our consolidated assets to an independent third party or a group of independent third parties, in either case if

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the transaction is approved by the holders of at least two-thirds of the shares subject to the investor shareholders agreement and if, pursuant to the transaction, all of such holders are entitled to receive the same form and amount of consideration with respect to their shares. Each holder that is a party to either agreement agrees to consent to and raise no objections to such an approved transaction, to waive any dissenter’s rights or similar rights and to sell the common shares held by such holder on the terms and conditions approved. A control disposition is defined as any disposition or class of related dispositions which would have the effect of transferring to any transferee or group beneficial ownership of a number of the common shares (a) that exceeds 40% of the then-outstanding common shares, on a fully-diluted basis, or (b) if thereafter the proposed transferee would directly or indirectly have beneficial ownership of 50% or more of all the then-outstanding common shares, on a fully-diluted basis. An independent third party is defined as any person or entity that does not own more than 5% of the outstanding common shares on an as-if converted basis, and any person or entity that is not affiliated with or associated with any such 5% holder.

Preemptive Rights

      Subject to specified exceptions, the investor shareholders agreement provides the holders of common shares who are parties thereto preemptive rights in the event of an offering of any of our capital shares. These exceptions include an initial public offering; an approved sale; securities issued upon conversion of convertible securities previously issued in compliance with the agreement; issuances to employees, prospective employees, directors and prospective directors, if approved by our board of directors; issuances of shares resulting in net proceeds to us of less than an aggregate of US$5.0 million; issuances as consideration for the acquisition of any business entity if we or any of our subsidiaries owns at least a majority of the voting power of the entity being acquired and the acquisition is approved by our board of directors; issuances to any bank, subordinated debt lender, equipment lessor, landlord or other similar financial institution or investor in connection with a loan transaction or equipment lease or similar commercial transaction provided that any such transaction is approved by our board of directors; and issuances in connection with any stock split, stock dividend, distribution or recapitalization by us. The preemptive rights provided under the agreement expire 10 days after the holders receive written notice of the offering, and we will then have 270 days in which to sell the shares the holders have elected not to purchase.

      The employee shareholders agreement does not provide any preemptive rights.

Public Offerings

      Each shareholders agreement requires that, at any time that we are engaged in an underwritten public offering of our securities, each shareholder who is a party to either agreement shall refrain from making any disposition of common shares on a securities exchange or in the over-the-counter or any other public trading market for a period of time not to exceed 180 days. This provision, however, does not limit any shareholder’s right to include common shares held by it in any such underwritten public offering pursuant to any demand or piggyback registration rights that such shareholder may have.

Material Agreements

      Each shareholders agreement provides that notwithstanding certain other provisions of the respective agreements permitting transfers of shares, no transfer will be made which would cause, in our reasonable judgment, a material breach of or default or acceleration of payments under any agreement to which we or any of our subsidiaries is a party under which the indebtedness or liability of us or any of our subsidiaries is more than $1.0 million.

Termination

      The employee shareholders agreement will terminate upon any of the following events: (i) our dissolution; (ii) after 10 days notice from us to all the holders party to the agreement; or (iii) the

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completion of a registered public offering of common shares (excluding certain offerings) resulting in net proceeds to us of at least $100 million.

      The investor shareholders agreement will terminate upon any of the following events: (i) our dissolution; (ii) any event that reduces the number of shareholders party to the agreement to one in accordance with the terms of the investor shareholders agreement; (iii) the completion of a registered public offering of common shares (excluding certain offerings) resulting in net proceeds to us of at least $100 million; or (iv) the written approval of the holders of 90% of the shares subject to the agreement.

      Both the employee shareholders agreement and the investor shareholders agreement will terminate upon the completion of this offering.

Voting and Corporate Governance Agreement and Registration Rights Agreement

      We are party to a voting agreement and a registration rights agreement with certain of our common shareholders. See “Related Party Transactions.” The voting agreement will terminate upon the completion of this offering, but designated affiliates of the shareholders party to the voting agreement will retain various rights. See “Related Party Transactions — Voting and Corporate Governance Agreement.”

Transfer Agent

      The transfer agent for our common shares is                     .

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SHARES ELIGIBLE FOR FUTURE SALE

      Based on the number of common shares outstanding at                     , 2006, after giving effect to the Reorganization and after this offering, we will have                 common shares outstanding, assuming no exercise of outstanding options. Of the outstanding shares, the shares sold in this offering will be freely tradable without restriction or further registration under the Securities Act, except that any shares held by our “affiliates” as that term is defined in Rule 144 promulgated under the Securities Act may only be sold in compliance with the limitations described below. The remaining                 common shares held by existing security holders are restricted. The common shares under contractual lock-up agreements with us may first be sold at various times after the expiration of the lock-up period described below.

      In general, under Rule 144 as currently in effect, if one year has elapsed since the date of acquisition of restricted stock from us or any of our affiliates, and we have been a reporting company under the Exchange Act for at least 90 days, the holder of such restricted stock can sell the shares, provided that the number of shares sold by such person within any three-month period does not exceed the greater of:

•  1.0% of the total number of common shares then outstanding; or

•  the average weekly trading volume of our common shares during the four calendar weeks preceding the date on which notice of the sale is filed with the SEC.

      Sales under Rule 144 are also subject to certain manner of sale provisions, notice requirements and the availability of certain current public information about us. If two years have elapsed since the date of acquisition of restricted stock from us or any of our affiliates and the holder is not one of our affiliates at any time during the three months preceding the proposed sale, such person can sell such shares in the public market under Rule 144(k) without regard to the volume limitations, manner of sale provisions, public information requirements or notice requirements.

Lock-Up Agreements

      We have agreed that we will not offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, or file with the SEC a registration statement under the Securities Act or a prospectus with a Canadian securities regulatory authority, relating to, any of our common shares or securities convertible into or exchangeable or exercisable for any common shares, or publicly disclose the intention to make any offer, sale, pledge, swap, hedge, disposition or filing, without the prior written consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC for a period of 180 days after the date of this prospectus, subject to extension.

      Our officers and directors and the selling shareholders have agreed that they will not offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, any of our common shares or securities convertible into or exchangeable or exercisable for any common shares, enter into a transaction that would have the same effect, or enter into any swap, hedge or other arrangement that transfers, in whole or in part, any of the economic consequences of ownership of our common shares or publicly disclose the intention to make any offer, sale, pledge or disposition, or enter into any transaction, swap, hedge or other arrangement, without, in each case, the prior written consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC for a period of 180 days after the date of this prospectus, subject to extension.

Form S-8 Registration Statements

      We intend to file one or more registration statements on Form S-8 under the Securities Act following this offering to register our common shares that are issuable pursuant to our stock option plan. These registration statements are expected to become effective upon filing. Shares covered by these registration statements will then be eligible for resale in the public market without restriction, subject to any applicable lock-up agreements and to Rule 144 limitations applicable to affiliates described above.

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Rule 701

      Any of our directors, officers, employees, advisors or consultants who held options to purchase common shares under a written compensatory plan or contract, such as our share option plan, prior to the effective date of the registration statement of which this prospectus is a part may be entitled to rely on the resale provisions of Rule 701. Rule 701 permits affiliates to sell their Rule 701 shares under Rule 144 without complying with the holding period requirements of Rule 144. Rule 701 further provides that non-affiliates may sell such shares under Rule 144 without having to comply with the holding period, public information, volume limitation or notice provisions of Rule 144. All holders of Rule 701 shares are required to wait until 90 days after the effective date of the registration statement of which this prospectus is a part before selling such shares. However, shares held by our directors and officers are subject to lock-up agreements and will only become eligible for sale upon the expiration of the lock-up period applicable to them, unless Credit Suisse Securities (USA) LLC and UBS Securities LLC release all or a portion of any Rule 701 shares subject to the lock-up.

Canadian Resale Restrictions

      The sale of any of our common shares issued to our existing shareholders as a result of the Reorganization in the public market in Canada will be subject to restrictions under applicable Canadian securities laws, including, in certain cases, a lapse of a four-month period since the date we became a reporting issuer under the securities laws of any Canadian province or territory.

      The sale of any of our common shares in Canada which constitutes a “control distribution” under Canadian securities law (generally a sale by a person or a group of persons holding more than 20% of our outstanding voting securities) will be subject to restrictions under applicable Canadian securities laws in addition to those restrictions noted above, unless the sale is qualified under a prospectus filed with Canadian securities regulatory authorities or if prior notice of the sale is filed with the Canadian securities regulatory authorities at least seven days before any sale and there has been compliance with certain other requirements and restrictions regarding the manner of sale, payment of commissions, reporting and availability of current public information about us.

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INCOME TAX CONSIDERATIONS

Material U.S. Income Tax Considerations

      The following discussion addresses the material U.S. federal income tax considerations relating to the purchase, ownership and disposition of our common shares. This discussion is based on the provisions of the Internal Revenue Code of 1986, as amended, the applicable treasury regulations promulgated under the Internal Revenue Code, judicial authority and current administrative rulings and practice. All of these authorities may change without notice, possibly on a retroactive basis. This summary deals only with holders that will hold common shares as capital assets within the meaning of Section 1221 of the Internal Revenue Code. It does not address tax considerations applicable to investors that may be subject to special tax rules, such as banks and other financial institutions; tax-exempt organizations; persons subject to alternative minimum tax; partnerships and other pass-through entities (as determined for U.S. federal income tax purposes); insurance companies; traders or dealers in securities or currencies; custodians, nominees or similar financial intermediaries holding common shares for others; or persons that will hold common shares as a position in a hedging transaction, straddle or conversion transaction for U.S. federal income tax purposes. This summary does not discuss the tax consequences of any conversion of currency into or out of the U.S. dollar as such a conversion relates to the purchase, ownership or disposition of the common shares, nor does it discuss the consequences of any U.S. federal estate and gift tax laws or state, local or foreign tax laws (other than those included under “– Material Canadian Income Tax Considerations”). If a partnership holds our common shares, the tax treatment of a partner will generally depend upon the status of the partner and the activities of the partnership. If you are a partner of a partnership holding our common shares you should consult your tax advisors. We have not sought any ruling from the Internal Revenue Service, or the IRS, with respect to the statements made and the conclusions reached in the following summary. There can be no assurance that the IRS will agree with such statements and conclusions.

      THE SUMMARY OF MATERIAL U.S. INCOME TAX CONSIDERATIONS IS INTENDED TO PROVIDE ONLY A GENERAL SUMMARY AND IS NOT INTENDED TO BE A COMPLETE ANALYSIS OR DESCRIPTION OF ALL POTENTIAL U.S. FEDERAL INCOME TAX CONSEQUENCES. TAX LAWS ARE VERY COMPLICATED. PROSPECTIVE INVESTORS IN THE COMMON SHARES SHOULD CONSULT THEIR OWN TAX ADVISORS WITH RESPECT TO THE APPLICATION OF THE U.S. FEDERAL INCOME TAX LAWS TO THEIR PARTICULAR SITUATIONS AS WELL AS ANY TAX CONSEQUENCES ARISING UNDER THE LAWS OF ANY STATE, LOCAL OR FOREIGN TAXING JURISDICTION OR UNDER ANY APPLICABLE TAX TREATY.

U.S. Holders

      A U.S. Holder is the beneficial owner of a common share that, for U.S. federal income tax purposes, is:

•  an individual citizen or resident of the United States;

•  a corporation (or other entity taxable as a corporation) created or organized under the laws of the United States, any state thereof or the District of Columbia;

•  an estate, the income of which is subject to U.S. federal income taxation regardless of its source; or

•  a trust, if one or more U.S. persons (as defined in Section 7701(a)(30) of the Internal Revenue Code) have the authority to control all substantial decisions of the trust and a court within the United States is able to exercise primary supervision over the administration of the trust.

      A non-U.S. Holder is a beneficial owner of a common share who is not a U.S. Holder.

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Treatment of U.S. Holders

      A U.S. Holder that receives a distribution with respect to our common shares generally must include the amount in gross income as a dividend to the extent attributable to our current and accumulated earnings and profits (as determined under U.S. federal income tax principles). If the distribution is not a dividend because it exceeds the U.S. Holder’s pro rata share of our current and accumulated earnings and profits, the distribution will be treated first as a tax-free return of capital and reduce (but not below zero) the adjusted tax basis of the U.S. Holder’s shares. If the distribution exceeds the adjusted tax basis, the remainder will be taxed as capital gain (see “Sale of Shares” below).

      Dividends received by non-corporate U.S. Holders in taxable years beginning before January 1, 2009 from a qualified foreign corporation are taxed at the same rates as long-term capital gains. A “qualified foreign corporation” includes a foreign corporation that is eligible for the benefits of a comprehensive income tax treaty with the United States. Since we are eligible for the benefits of the tax treaty between Canada and the United States, and the treaty has been determined to be a comprehensive income tax treaty, we are a “qualified foreign corporation.”

      U.S. Holders may deduct any Canadian tax withheld from distributions in computing their U.S. federal taxable income. Alternatively, a U.S. Holder may claim a credit against U.S. federal income tax liability (see “Foreign Tax Credit” below). Corporate U.S. Holders generally will not be allowed a dividends-received deduction with respect to any dividends from us.

Foreign Tax Credit

      Generally, dividends to a U.S. Holder will be treated as passive income (or “passive category income” for taxable years beginning after December 31, 2006) for foreign tax credit purposes. Subject to some limitations, a U.S. Holder may elect to claim a credit against its U.S. federal income tax liability (in lieu of a deduction) for Canadian withholding tax deducted from our distributions. The credit is limited to U.S. federal income tax attributable to a U.S. Holder’s passive income from foreign sources. Since we are a qualified foreign corporation for non-corporate U.S. Holders, our dividends qualify for taxation at the same preferential rates that apply to long-term capital gains. Consequently, the dividend amount that would otherwise be treated as received from foreign sources is reduced by multiplying the dividend by a fraction, the numerator of which is the preferential capital gains rate and the denominator of which is the ordinary income tax rate applicable to the U.S. Holder. The effect of this reduction is to reduce the federal income attributable to foreign source income against which the credit may be claimed. Canadian withholding taxes that cannot be claimed as a credit in the year paid may be carried back to the preceding year and forward ten years, subject to the same limitations.

Sale of Shares

      A U.S. Holder generally will recognize capital gain or loss on the sale of our shares equal to the difference between: (a) the amount of cash plus the fair market value of any property received for the shares and (b) the U.S. Holder’s adjusted tax basis in the shares. The gain or loss will be treated as capital gain or loss from the U.S. sources. It will be long-term capital gain or loss if the U.S. Holder has held the shares for more than 12 months. The top marginal rate applicable to net long-term capital gain for a non-corporate U.S. Holder is 15%. There is no preferential long-term gain rate for corporate U.S. Holders. Any capital gain that is not long-term capital gain is taxed at ordinary income rates. Deduction of capital losses is subject to significant limitations.

Controlled Foreign Corporations

      U.S. Holders that own stock in a foreign corporation that is classified as a “controlled foreign corporation” (“CFC”) may be subject to current taxation on certain earnings of the CFC. A CFC is a foreign corporation more than 50% of whose total voting power or value is owned by U.S. shareholders. For these purposes, a U.S. shareholder is any person or entity that owns, directly or indirectly, 10% or more of the total combined voting power of the foreign corporation. Based on the expected distribution of

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our common shares among U.S. Holders and non-U.S. Holders, we do not expect to be classified as a CFC. However, future ownership changes could cause us to become a CFC. Potential U.S. Holders are advised to consult their tax advisors concerning the potential application of the CFC rules to their particular circumstances.

Non-U.S. Holders

      Non-U.S. Holders should not be subject to U.S. federal income tax with respect to dividends and proceeds received on the sale, exchange or redemption of our common shares.

Information Reporting and Backup Withholding

      In general, holders may be subject to information reporting and backup withholding at a rate of 28% with respect to dividends and proceeds received on the sale, exchange, or redemption of a common share. The information reporting and backup withholding requirements discussed below generally do not apply to payments to corporations, whether domestic or foreign.

      An individual U.S. Holder generally will be subject to backup withholding on payments or proceeds received through a U.S. broker or nominee unless such U.S. Holder provides its taxpayer identification number to the payor on a properly executed Internal Revenue Service Form W-9 or other similar form and the IRS has not notified the payor that backup withholding is required for such U.S. Holder.

      A non-U.S. Holder generally will be subject to backup withholding on payments or proceeds received through a U.S. broker or nominee unless such non-U.S. Holder certifies its foreign status by providing a properly executed Internal Revenue Service Form W-8 BEN, W-8 IMY, W-8 ECI or W-8EXP.

      Backup withholding is not an additional tax, and any amount withheld under the backup withholding rules will be creditable against the U.S. federal tax liability of such holder and may give rise to a refund upon furnishing the required information to the Internal Revenue Service.

Material Canadian Income Tax Considerations

      The following summarizes the main Canadian federal income tax consequences applicable to a holder that acquires common shares pursuant to this offering and who, at all times for purposes of the Income Tax Act (Canada) (the “Act”), is the beneficial owner of the common shares, holds the common shares as capital property, deals at arm’s length with us and with the selling shareholders, is not affiliated with us or a selling shareholder, is not a resident and is not deemed to be a resident of Canada during any taxation year in which it owns the common shares, and does not use or hold the common shares in the course of carrying on, or otherwise in connection with, a business in Canada (a “non-Canadian holder”). This summary does not deal with special situations, such as the particular circumstances of traders or dealers, limited liability companies, partnerships, tax exempt entities, insurers or financial institutions.

      This summary is based on the relevant provisions of the Act and the regulations thereunder (the “Regulations”) and our Canadian counsel’s understanding of the published administrative and assessing practices of the Canada Revenue Agency as of the date hereof. It also takes into account specific proposals to amend the Act and the Regulations publicly announced by the Minister of Finance (Canada) prior to the date hereof but there is no certainty that such proposals will be enacted in the form proposed, if at all. This summary does not otherwise take into account or anticipate any changes in law, whether by way of legislative, judicial or governmental action or interpretation, nor does it address any provincial, territorial or foreign income tax considerations.

      In this summary we do not purport to address all tax considerations that may be important to a particular non-Canadian holder, in light of the holder’s circumstances, concerning the consequences of acquiring, holding or disposing of common shares. We encourage non-Canadian holders to consult their own tax advisors having regard to their particular circumstances.

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Dividends

      A non-Canadian holder will generally be subject to a 25% Canadian withholding tax on dividends we pay or credit, or are deemed to pay or credit, on the common shares. This rate may be reduced under the provisions of an applicable income tax convention between Canada and the non-Canadian holder’s country of residence. A non- Canadian holder who is resident in the United States and entitled to the benefit of the Canada-United States Income Tax Convention (1980) (the “U.S. Treaty”) will generally be entitled to a 15% rate of withholding tax for dividends.

Dispositions

      If a non-Canadian holder disposes of common shares that are “taxable Canadian property” at the time of the disposition, the holder will be subject to tax under the Act on any taxable capital gain realized on the disposition, unless the provisions of an applicable income tax convention exempt the gain from the tax.

      A common share will be “taxable Canadian property” at the time of a disposition if, at that time, it is not listed on a stock exchange that is prescribed in the Regulations. Prescribed stock exchanges include The Nasdaq National Market, The New York Stock Exchange and the Toronto Stock Exchange. A common share that is listed on a prescribed stock exchange will be taxable Canadian property if the non-Canadian holder, persons with whom the non-Canadian holder does not deal at arm’s length, or the non-Canadian holder together with such persons, has owned 25% or more of our issued shares of any class or series at any time during the 60-month period that ends at the time of the disposition. Notwithstanding the foregoing, a common share may be deemed to be taxable Canadian property in certain other circumstances set out in the Act.

      A non-Canadian holder’s taxable capital gain in respect of shares that are taxable Canadian property will be one-half of the amount by which the proceeds of disposition, net of any reasonable costs of disposition, exceed the adjusted cost base of the shares to the holder. The U.S. Treaty provides an exemption from Canadian capital gains tax for a non-Canadian holder who is a resident of the United States for purposes of the U.S. Treaty provided that our common shares do not derive their value principally from real property situated in Canada.

      If a common share is not listed on a prescribed stock exchange at the time of disposition, a non-Canadian holder will be subject to the notification and withholding requirements in section 116 of the Act. A purchaser of unlisted shares will be required to withhold up to 25% of the purchase price otherwise payable to a non-Canadian holder and remit the same to the CRA if the non-Canadian holder has not obtained an acceptable tax clearance certificate in accordance with that section. The notification and withholding requirement in section 116 will apply notwithstanding that any gain may ultimately be exempt from Canadian tax pursuant to an applicable income tax convention, although all or a part of the tax withheld in such circumstances may be refunded upon the non-Canadian holder filing a Canadian income tax return, depending on the holder’s personal circumstances.

      A non-Canadian holder whose shares are taxable Canadian property at the time of a disposition will be required to file a Canadian income tax return for that taxation year, whether or not the holder realizes a taxable capital gain on the disposition or is entitled to an exemption from Canadian tax in respect of such a gain pursuant to an applicable income tax convention.

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UNDERWRITING

      Under the terms and subject to the conditions contained in an underwriting agreement dated                     , 2006, we and the selling shareholders have agreed to sell to the underwriters named below, for whom Credit Suisse Securities (USA) LLC and UBS Securities LLC are acting as representatives, the following respective numbers of common shares:

		Number of
Underwriter		Shares
Credit Suisse Securities (USA) LLC
UBS Securities LLC
Jefferies & Company, Inc.
	Total

      The offering is being made concurrently in the United States and in the provinces and territories of Canada. The common shares will be offered in the United States through Credit Suisse Securities (USA) LLC, UBS Securities LLC and Jefferies & Company, Inc., and such dealers who are registered to offer the common shares for sale in the United States as may be designated by the underwriters. The common shares will be offered in the provinces and territories of Canada through affiliates of the underwriters, including Credit Suisse Securities (Canada), Inc. and UBS Securities Canada Inc., and such dealers who are registered to offer the common shares for sale in such provinces and territories as may be designated by the underwriters.

      The obligations of the underwriters under the underwriting agreement may be terminated at their discretion on the occurrence of certain stated events. The underwriting agreement provides that the underwriters are obligated to purchase all the common shares in the offering if any are purchased, other than those shares covered by the over-allotment option described below. The underwriting agreement also provides that, in the event of a default, the purchase commitments of non-defaulting underwriters may be increased or the offering may be terminated.

      The selling shareholders have granted to the underwriters a 30-day option to purchase on a pro rata basis up to                      additional common shares at the initial public offering price less the underwriting discounts and commissions. The option may be exercised only to cover any over-allotments of common shares.

      The public offering price for common shares offered in the United States and elsewhere outside Canada is payable in U.S. dollars, and the public offering price for common shares sold in Canada is payable in Canadian dollars, except as may otherwise be agreed by the underwriters. The Canadian dollar amount is the approximate equivalent of the U.S. dollar amount based on the prevailing U.S. Canadian dollar exchange rate on the date of the underwriting agreement.

      The underwriters propose to offer the common shares initially at the public offering price on the cover page of this prospectus and to selling group members at that price less a selling concession of US$           per share (or C$          per share for shares sold in Canada). The underwriters and the selling group members may allow a discount of US$           per share (or C$          per share for shares sold in Canada) on sales to other broker/ dealers. After the initial public offering in the United States and elsewhere outside of Canada, the underwriters may change the public offering price and concession and discount to broker/ dealers. In Canada, after the underwriters have made a bona fide effort to sell all of the common shares offered in Canada under this prospectus at the initial public offering price specified above, the offering price may be decreased and thereafter further changed, from time to time, to an amount not greater than the initial public offering price and the concession and reallowance may be changed. In the event of a reduction in the public offering price, the compensation realized by the underwriters will be reduced accordingly.

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      The following table summarizes the compensation and estimated expenses we will pay:

	Per Share		Total
	Without	With	Without	With
	Over-allotment	Over-allotment	Over-allotment	Over-allotment
Underwriting Discounts and Commissions paid by us	US$	US$	US$	US$
Expenses payable by us	US$	US$	US$	US$

      We estimate that our out-of-pocket expenses for this offering will be $                million.

      The underwriters have informed us that the underwriters do not expect sales to accounts over which the underwriters have discretionary authority to exceed 5% of the common shares being offered.

      We have agreed that we will not offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, or file with the SEC a registration statement under the Securities Act or file with the securities regulatory authorities in Canada a prospectus under applicable securities laws relating to, any common shares or securities convertible into or exchangeable or exercisable for any common shares, or publicly disclose the intention to make any offer, sale, pledge, disposition or filing, without the prior written consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC, for a period of 180 days after the date of this prospectus. However, in the event that either (1) during the last 17 days of the “lock-up” period, we release earnings results or material news or a material event relating to us occurs or (2) prior to the expiration of the “lock-up” period, we announce that we will release earnings results during the 16-day period beginning on the last day of the “lock-up” period, then in either case the expiration of the “lock-up” period will be extended until the expiration of the 18-day period beginning on the date of the release of the earnings results or the occurrence of the material news or event, as applicable, unless Credit Suisse Securities (USA) LLC and UBS Securities LLC waive, in writing, such an extension.

      Our directors and executive officers and the selling shareholders have agreed that they will not offer, sell, contract to sell, pledge or otherwise dispose of, directly or indirectly, any common shares or securities convertible into or exchangeable or exercisable for any common shares, enter into a transaction that would have the same effect, or enter into any swap, hedge or other arrangement that transfers, in whole or in part, any of the economic consequences of ownership of our common shares, whether any of these transactions are to be settled by delivery of our common shares or other securities, in cash or otherwise, or publicly disclose the intention to make any offer, sale, pledge or disposition, or to enter into any transaction, swap, hedge or other arrangement, without, in each case, the prior written consent of Credit Suisse Securities (USA) LLC and UBS Securities LLC, for a period of 180 days after the date of this prospectus. However, in the event that either (1) during the last 17 days of the “lock-up” period, we release earnings results or material news or a material event relating to us occurs or (2) prior to the expiration of the “lock-up” period, we announce that we will release earnings results during the 16-day period beginning on the last day of the “lock-up” period, then in either case the expiration of the “lock-up” period will be extended until the expiration of the 18-day period beginning on the date of the release of the earnings results or the occurrence of the material news or event, as applicable, unless Credit Suisse Securities (USA) LLC and UBS Securities LLC waive, in writing, such an extension.

      The underwriters have reserved for sale at the initial public offering price up to               common shares for employees, directors and other persons associated with us who have expressed an interest in purchasing common shares in the offering. The number of shares available for sale to the general public in the offering will be reduced to the extent these persons purchase the reserved shares. Any reserved shares not so purchased will be offered by the underwriters to the general public on the same terms as the other shares.

      We and the selling shareholders have agreed to indemnify the underwriters against liabilities under the Securities Act and the securities laws of the provinces of Canada or contribute to payments that the underwriters may be required to make in that respect.

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      Certain of the underwriters and their respective affiliates have in the past and may in the future perform various financial advisory, investment banking and other services for us, our affiliates and our officers in the ordinary course of business, for which they received and will receive customary fees and expenses. Jefferies & Company, Inc. was the initial purchaser in connection with the offering of our 9% senior secured notes due 2010.

      Prior to the offering, there has been no public market for our common shares. The initial public offering price will be determined by negotiation between us and the representatives and will not necessarily reflect the market price of the common shares following the offering. The principal factors that will be considered in determining the initial public offering price will include:

•  the information presented in this prospectus and otherwise available to the underwriters;

•  the history of and prospects for our industry in which we will compete;

•  an assessment of our management;

•  our present operations;

•  our historical results of operations;

•  our earnings prospects;

•  the general condition of the securities markets at the time of the offering; and

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

      We cannot assure you that the initial public offering price will correspond to the price at which the common shares will trade in the public market subsequent to this offering or that an active trading market for the common shares will develop and continue after this offering.

      In connection with the offering, the underwriters may engage in stabilizing transactions, over-allotment transactions, syndicate covering transactions and penalty bids in accordance with Regulation M under the Exchange Act.

•  Over-allotment involves sales by the underwriters of shares in excess of the number of shares the underwriters are obligated to purchase, which creates a syndicate short position for the underwriters. The short position may be either a covered short position or a naked short position. In a covered short position, the number of shares over-allotted by the underwriters is not greater than the number of shares that they may purchase in the over-allotment option. In a naked short position, the number of shares involved is greater than the number of shares in the over-allotment option. The underwriters may close out any covered short position by either exercising their over-allotment option and/or purchasing shares in the open market.

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

•  Syndicate covering transactions involve purchases of the common shares in the open market after the distribution has been completed in order to cover syndicate short positions. In determining the source of shares to close out the short position, the underwriters will consider, among other things, the price of shares available for purchase in the open market as compared to the price at which they may purchase shares through the over-allotment option. If the underwriters sell more shares than could be covered by the over- allotment option, a naked short position, the position can only be closed out by buying shares in the open market. A naked short position is more likely to be created if the underwriters are concerned that there could be downward pressure on the price of the shares in the open market after pricing that could adversely affect investors who purchase in the offering.

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•  Penalty bids permit the underwriters to reclaim a selling concession from a syndicate member when the common shares originally sold by such syndicate member are purchased in a stabilizing or syndicate covering transaction to cover syndicate short positions.

      Pursuant to rules and policy statements of certain Canadian securities regulators, the underwriters may not, at any time during the period ending on the date the selling process for the common shares ends and all stabilization arrangements relating to the common shares are terminated, bid for or purchase our common shares. The foregoing restrictions are subject to certain exceptions including (a) a bid for or purchase of our common shares if the bid or purchase is made through the facilities of the Toronto Stock Exchange, or TSX, in accordance with the Universal Market Integrity Rules of Market Regulation Services Inc., (b) a bid or purchase on behalf of a client, other than certain prescribed clients, provided that the client’s order was not solicited by the underwriter, or if the client’s order was solicited, the solicitation occurred before the commencement of a prescribed restricted period, and (c) a bid or purchase to cover a short position entered into prior to the commencement of a prescribed restricted period. The underwriters may engage in market stabilization or market balancing activities on the TSX, where the bid for or purchase of our common shares is for the purpose of maintaining a fair and orderly market in such common shares, subject to price limitations applicable to such bids or purchases. Such transactions, if commenced, may be discontinued at any time.

      Subject to the foregoing, in order to facilitate this offering and for a limited period the underwriters may purchase and sell our common shares in the open market. These transactions may include short sales, stabilizing transactions and purchases to cover positions created by short sales. Short sales involve the sale by the underwriters of a greater number of securities than they are required to purchase in this offering. Stabilizing transactions consist of certain bids or purchases made for the purpose of preventing or retarding a decline in the market price of such securities while this offering is in progress. The underwriters also may impose penalty bids, under which selling concessions allowed to syndicate members or other broker-dealers participating in this offering are reclaimed if common shares previously distributed in this offering are repurchased in connection with stabilization transactions or otherwise. These activities by the underwriters may stabilize, maintain or otherwise affect the market price of our common shares. As a result, the price of our common shares may be higher than the price that might otherwise exist in the open market. If these activities are commenced, they may be discontinued by the underwriters at any time and must be discontinued after a limited period. These transactions may be effected on the New York Stock Exchange, the TSX or otherwise.

      A prospectus in electronic format may be made available on the web sites maintained by one or more of the underwriters, or selling group members, if any, participating in this offering and one or more of the underwriters participating in this offering may distribute prospectuses electronically. The representatives may agree to allocate a number of shares to underwriters and selling group members for sale to their online brokerage account holders. Internet distributions will be allocated by the underwriters and selling group members that will make internet distributions on the same basis as other allocations.

      Other than the prospectus in electronic format, the information on any underwriter’s or selling group member’s website is not part of the prospectus or the registration statement of which this prospectus forms a part, has not been approved 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.

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LEGAL MATTERS

      Certain legal matters in connection with the common shares being offered will be passed upon for us by Bracewell & Giuliani LLP, Houston, Texas with respect to matters of U.S. law, and by Borden Ladner Gervais LLP, Toronto, Ontario with respect to matters of Canadian law. Certain members of Bracewell & Giuliani LLP own beneficially less than 1% of the common shares of North American Energy Partners Inc. The underwriters have been represented by Cravath, Swaine & Moore LLP, New York, New York and Bennett Jones LLP, Calgary, Alberta. As of the date hereof, the partners, counsel and associates of each of Borden Ladner Gervais LLP and Bennett Jones LLP beneficially own, directly or indirectly, respectively as a group, none of our common shares.

EXPERTS

      The consolidated balance sheets of NACG Holdings Inc. as at March 31, 2006 and 2005 and the consolidated statements of operations and retained earnings (deficit) and cash flows of NACG Holdings Inc. for the years ended March 31, 2006 and 2005 and the period November 26, 2003 to March 31, 2004 and of Norama Ltd. for the period April 1, 2003 to November 25, 2003 included in this prospectus have been audited by KPMG LLP, Chartered Accountants, as stated in their reports appearing in this prospectus.

WHERE YOU CAN FIND MORE INFORMATION

      This prospectus is part of a registration statement, which term includes all amendments thereto, on Form F-1 that we have filed with the SEC under the Securities Act covering the common shares we are offering. As permitted by the rules and regulations of the SEC, this prospectus omits certain information contained in the registration statement and the exhibits to the registration statement. For further information with respect to us and our common shares, you should refer to the registration statement and to its exhibits and schedules. We make reference in this prospectus to certain of our contracts, agreements and other documents that are filed as exhibits to the registration statement. For additional information regarding those contracts, agreements and other documents, please see the exhibits attached to the registration statement. We also file various reports and other information with the SEC.

      You can read the registration statement and the exhibits and schedules filed with the registration statement or any reports, statements or other information we have filed or file, at the SEC Public Reference Room located at 100 F Street, NE, Room 1580, Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information regarding the Public Reference Room and the SEC’s copying charges. The SEC also maintains an Internet site that contains reports, information statements and other material that are filed through the SEC’s Electronic Data Gathering, Analysis and Retrieval (EDGAR) System. This system can be accessed at http://www.sec.gov. You can find reports and other information that we file electronically with the SEC by reference to our corporate name or to our SEC file number,                     .

      We will provide a copy of any exhibit incorporated by reference in the registration statement of which this prospectus forms a part, without charge, by written or oral request directed to us at the following address and phone number:

North American Energy Partners Inc.
Zone 3 Acheson Industrial Area
Acheson, Alberta
Canada T7X 5A7
Telephone: 780-960-7171
Attention: Vice President, Corporate

      As a foreign private issuer, we are exempt from the rule under the Exchange Act prescribing the furnishing and content of proxy statements to shareholders. Because we are a foreign private issuer, we,

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our directors and our officers are also exempt from the short swing profit recovery provisions of Section 16 of the Exchange Act.

      After this offering, we will also be subject to the informational requirements of the securities commissions in all provinces of Canada. You are invited to read and copy any reports, statements or other information, other than confidential filings, that we file with the Canadian provincial securities commissions. These filings are also electronically available from the Canadian System for Electronic Document Analysis and Retrieval (SEDAR) (http://www.sedar.com), the Canadian equivalent of the SEC’s electronic document gathering and retrieval system. We intend to furnish our shareholders with annual reports containing consolidated financial statements audited by independent registered chartered accountants.

ENFORCEABILITY OF CIVIL LIABILITIES AGAINST FOREIGN PERSONS

      We are a corporation incorporated under the Canada Business Corporations Act. Consequently, we are and will be governed by all applicable provincial and federal laws of Canada. Several of our directors and officers and others named in this prospectus reside principally in Canada. Because these persons are located outside the United States, it may not be possible for you to effect service of process within the United States upon those persons. Furthermore, it may not be possible for you to enforce against us or them, in or outside the United States, judgments obtained in U.S. courts, because substantially all of our assets and the assets of these persons are located outside the United States. We have been advised that there is doubt as to the enforceability, in original actions in Canadian courts, of liabilities based upon the U.S. federal securities laws and as to the enforceability in Canadian courts of judgments of U.S. courts obtained in actions based upon the civil liability provisions of the U.S. federal securities laws. Therefore, it may not be possible to enforce those actions against us, our directors and officers or other persons named in this prospectus.

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INDEX TO FINANCIAL STATEMENTS

Audited Consolidated Financial Statements of NACG Holdings Inc.
	Report of Independent Registered Public Accounting Firm	F-2
	Consolidated Balance Sheets as of March 31, 2005 and 2006	F-3
	Consolidated Statements of Operations and Retained Earnings (Deficit) for the Fiscal Years Ended March 31, 2004, 2005 and 2006	F-4
	Consolidated Statements of Cash Flows for the Fiscal Years Ended March 31, 2004, 2005 and 2006	F-5
	Notes to the Consolidated Financial Statements	F-6

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of NACG Holdings Inc.

      We have audited the consolidated balance sheets of NACG Holdings Inc. as at March 31, 2006 and 2005 and the consolidated statements of operations and retained earnings (deficit) and cash flows of NACG Holdings Inc. for the years ended March 31, 2006 and 2005, the period from November 26, 2003 to March 31, 2004 and of Norama Ltd. (the “Predecessor Company”) for the period April 1, 2003 to November 25, 2003. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

      We 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 an audit to obtain reasonable assurance whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our audit opinion.

      In our opinion, these consolidated financial statements referred to above present fairly, in all material respects, the financial position of NACG Holdings Inc. as of March 31, 2006 and 2005 and the results of operations and cash flows of NACG Holdings Inc. for the years ended March 31, 2005, the period from November 26, 2003 to March 31, 2004, and of the Predecessor Company for the period April 1, 2003 to November 25, 2003 in accordance with Canadian generally accepted accounting principles.

      As discussed in Note 2(c) and 2(q) to the consolidated financial statements, the Company changed its accounting policy with respect to the recognition of revenue on claims and has adopted new accounting pronouncements related to the accounting by a customer (including a reseller) for certain consideration received from a vendor, the accounting for convertible debt instruments, the accounting for non-monetary transactions, the accounting for implicit variable interests and the accounting for conditional asset retirement obligations in 2006.

      Canadian generally accepted accounting principles vary in certain significant respects from accounting principles generally accepted in the United States of America. Information relating to the nature and effect of such differences is presented in note 23 to the consolidated financial statements.

/s/ KPMG llp

Chartered Accountants

Edmonton, Canada

July 19, 2006, except as to note 24(c),

which is as of July 21, 2006

F-2

NACG HOLDINGS INC.

Consolidated Balance Sheets

		March 31,			March 31,
		2005			2006
		(In thousands of
		Canadian dollars)
ASSETS
Current assets:
	Cash and cash equivalents	$	17,924		$	42,804
	Accounts receivable (note 4)		57,745			67,235
	Unbilled revenue (note 5)		41,411			43,494
	Inventory		134			57
	Prepaid expenses		1,862			1,796
	Future income taxes (note 12)		15,100			5,583
			134,176			160,969
Future income taxes (note 12)			13,485			23,367
Plant and equipment (note 6)			177,089			185,566
Goodwill (note 3)			198,549			198,549
Intangible assets, net of accumulated amortization of $17,026 (March 31, 2005 – $16,296) (note 7)			1,502			772
Deferred financing costs, net of accumulated amortization of $6,004 (March 31, 2005 – $3,368) (note 8)			15,354			17,788
		$	540,155		$	587,011
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
	Accounts payable	$	59,090		$	54,085
	Accrued liabilities (note 9)		15,201			24,603
	Billings in excess of costs incurred and estimated earnings on uncompleted contracts (note 5)		1,325			5,124
	Current portion of capital lease obligations (note 10)		1,771			3,046
	Future income taxes (note 12)		15,100			5,583
			92,487			92,441
Senior secured credit facility (note 11(a))			61,257			—
Capital lease obligations (note 10)			5,454			7,906
Senior notes (note 11(b))			241,920			304,007
Derivative financial instruments (note 18(c))			51,723			63,611
Redeemable preferred shares (note 13(a))			35,000			77,568
Future income taxes (note 12)			13,485			23,367
			501,326			568,900
Shareholders’ equity:
	Common shares (authorized – unlimited number of voting and non-voting common shares; issued and outstanding – March 31, 2006 – 910,380 voting common shares and 20,620 non-voting common shares (March 31, 2005 – 907,380 voting common shares and 20,620 non-voting common shares)) (note 13(b))		92,800			93,100
	Contributed surplus (notes 13(c) and 21)		634			1,557
	Deficit		(54,605	)		(76,546	)
			38,829			18,111
Commitments (note 19)
United States generally accepted accounting principles (note 23)
Subsequent events (note 24)
		$	540,155		$	587,011

See accompanying notes to consolidated financial statements.

F-3

NACG HOLDINGS INC.

Consolidated Statements of Operations and Retained Earnings (Deficit)

		Predecessor
		Company
		Period from			Period from
		April 1, 2003 to			November 26, 2003			Year Ended			Year Ended
		November 25,			to March 31,			March 31,			March 31,
		2003			2004			2005			2006
		(In thousands of Canadian dollars)
Revenue		$	250,652		$	127,611		$	357,323		$	492,237
Project costs			156,976			83,256			240,919			308,949
Equipment costs			43,484			13,686			52,831			64,832
Equipment operating lease expense			10,502			1,430			6,645			16,405
Depreciation			6,566			6,674			20,762			21,725
			217,528			105,046			321,157			411,911
Gross profit			33,124			22,565			36,166			80,326
General and administrative (note 17(b))			7,783			6,065			22,873			30,903
(Gain) loss on disposal of property, plant and equipment			(49	)		131			494			(733	)
Amortization of intangible assets			—			12,928			3,368			730
Operating income before the undernoted			25,390			3,441			9,431			49,426
Interest expense (note 14)			2,457			10,079			31,141			68,776
Foreign exchange gain (note 18(c))			(7	)		(661	)		(19,815	)		(13,953	)
Realized and unrealized loss on derivative financial instruments (note 18(c))			—			12,205			43,113			14,689
Financing costs (note 8)			—			—			—			2,095
Other income			(367	)		(230	)		(421	)		(977	)
Management fees (note 17(c))			41,070			—			—			—
			43,153			21,393			54,018			70,630
Loss before income taxes			(17,763	)		(17,952	)		(44,587	)		(21,204	)
Income taxes (note 12):
	Current income taxes		218			1,178			2,711			737
	Future income taxes		(6,840	)		(6,848	)		(4,975	)		—
			(6,622	)		(5,670	)		(2,264	)		737
Net loss for the period			(11,141	)		(12,282	)		(42,323	)		(21,941	)
Retained earnings (deficit), beginning of period			29,817			—			(12,282	)		(54,605	)
Retained earnings (deficit), end of period		$	18,676		$	(12,282	)	$	(54,605	)	$	(76,546	)
Net loss per share – basic and diluted (note 13(d))		$	—		$	(13.28	)	$	(45.66	)	$	(23.62	)

See accompanying notes to consolidated financial statements

F-4

NACG HOLDINGS INC.

Consolidated Statements of Cash Flows

			Predecessor
			Company
			Period from			Period from
			April 1, 2003 to			November 26, 2003			Year Ended			Year Ended
			November 25,			to March 31,			March 31,			March 31,
			2003			2004			2005			2006
			(In thousands of Canadian dollars)
Cash provided by (used in):
Operating activities:
	Net loss for the period		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)
	Items not affecting cash:
		Depreciation		6,566			6,674			20,762			21,725
		Amortization of intangible assets		—			12,928			3,368			730
		Amortization of deferred financing costs		—			814			2,554			3,338
		Financing costs (note 8)		—			—			—			2,095
		(Gain) loss on disposal of plant and equipment		(49	)		131			494			(733	)
		Unrealized foreign exchange gain on senior notes (note 18(c))		—			(740	)		(20,340	)		(14,258	)
		Unrealized loss on derivative financial instruments (note 18(c))		—			11,266			40,457			11,888
		(Decrease) increase in allowance for doubtful accounts		141			(60	)		(69	)		(94	)
		Stock-based compensation expense (note 21)		—			137			497			923
		Change in redemption value and accretion of mandatorily redeemable preferred shares		—			—			—			34,722
		Future income taxes		(6,840	)		(6,848	)		(4,975	)		—
	Net changes in non-cash working capital (note 15(b))			13,832			3,457			(5,258	)		(4,531	)
				2,509			15,477			(4,833	)		33,864
Investing activities:
	Purchase of plant and equipment			(5,234	)		(2,501	)		(25,679	)		(29,015	)
	Net changes in non-cash working capital (note 15(b))			—			—			—			1,391
	Proceeds on disposal of plant and equipment			609			5,765			624			5,456
	Acquisition (note 3)			—			(367,778	)		—			—
				(4,625	)		(364,514	)		(25,055	)		(22,168	)
Financing activities:
	Issuance of 9% senior secured notes (note 11(b))			—			—			—			76,345
	Repayment of senior secured credit facility (note 11(a))			(4,428	)		(1,500	)		(7,250	)		(61,257	)
	Issuance of Series B preferred shares (note 13(a))			—			—			—			8,376
	Repurchase of Series B preferred shares (note 13(a))			—			—			—			(851	)
	Financing costs (note 8)			—			(18,080	)		(642	)		(7,546	)
	Repayment of capital lease obligations			(3,289	)		(288	)		(1,198	)		(2,183	)
	Increase in senior secured credit facility			—			—			20,007			—
	Issuance of 83/4 % senior notes			—			263,000			—			—
	Issuance of common shares			—			92,500			300			300
	Proceeds from term credit facility			—			50,000			—			—
	Advances from Norama Inc.			17,696			—			—			—
	Decrease in cheques issued in excess of cash deposits			(2,496	)		—			—			—
	Decrease in operating line of credit			(516	)		—			—			—
				6,967			385,632			11,217			13,184
Increase (decrease) in cash and cash equivalents				4,851			36,595			(18,671	)		24,880
Cash and cash equivalents, beginning of period				—			—			36,595			17,924
Cash and cash equivalents, end of period			$	4,851		$	36,595		$	17,924		$	42,804

See accompanying notes to consolidated financial statements

F-5

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements

For the year ended March 31, 2006, March 31, 2005, the period from November 26, 2003

to March 31, 2004 and the period from April 1, 2003 to November 25, 2003 of

Norama Ltd. (the “Predecessor Company”)

(Amounts in thousands of Canadian dollars unless otherwise specified)

1. Nature of operations

      NACG Holdings Inc. (the “Company”) was incorporated under the Canada Business Corporations Act on October 17, 2003. The Company had no operations prior to November 26, 2003. After giving effect to the acquisition described in note 3, the Company completes all forms of civil projects including contract mining, industrial and commercial site development, pipeline and piling installations. NACG Holdings Inc. is a holding company with no active business operations. Substantially all of the business activities and assets shown on the Company’s consolidated balance sheet are conducted and held by its subsidiary, North American Energy Partners Inc. (“NAEPI”). Accordingly, the Company’s earnings and cash flow and its ability to pay dividends are largely dependent upon the earnings and cash flows of NAEPI and the distribution or other payment of such earnings to the Company in the form of dividends. The ability of NAEPI to declare dividends to its ultimate parent, NACG Holdings Inc., is restricted by (a) the terms of the NAEPI Series A preferred shares, (b) the terms of the NAEPI Series B preferred shares, (c) the terms of the NACG Preferred Corp. Series A preferred shares, (d)restrictions contained within the revolving credit facility of NAEPI and (e) terms of the indentures related to the U.S. dollar denominated 8³/4 % senior notes of NAEPI and the U.S. dollar denominated 9% senior secured notes of NAEPI. The restricted net assets of the Company are approximately $18.1 million.

2. Significant accounting policies

     (a) Basis of presentation

      These consolidated financial statements are prepared in accordance with Canadian generally accepted accounting principles (“GAAP”). Material inter-company transactions and balances are eliminated on consolidation. Material items that give rise to measurement differences to the consolidated financial statements under United States GAAP are outlined in note 23.

      These consolidated financial statements include the accounts of the Company, its wholly-owned subsidiary, NACG Preferred Corp.; the wholly-owned subsidiary of NACG Preferred Corp., NAEPI; the wholly-owned subsidiaries of NAEPI, NACG Finance LLC and North American Construction Group Inc.

F-6

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

(“NACGI”); the Company’s joint venture, Noramac Ventures Inc. (note 15(c)), and the following subsidiaries of NACGI:

	% Owned
• North American Caisson Ltd.		100%
• North American Construction Ltd.		100%
• North American Engineering Ltd.		100%
• North American Enterprises Ltd.		100%
• North American Industries Inc.		100%
• North American Mining Inc.		100%
• North American Maintenance Ltd.		100%
• North American Pipeline Inc.		100%
• North American Road Inc.		100%
• North American Services Inc.		100%
• North American Site Development Ltd.		100%
• North American Site Services Inc.		100%
• Griffiths Pile Driving Inc.		100%

      In preparation for the acquisition described in Note 3, effective July 31, 2003, all of the issued common shares of NACGI and North American Equipment Ltd. (“NAEL”) were transferred from Norama Inc. to its new wholly-owned subsidiary, Norama Ltd. (the “Predecessor Company”). The consolidated financial statements of Norama Ltd. are depicted in these financial statements as the Predecessor Company and have been prepared using the continuity of interest method of accounting to reflect the combined carrying values of the assets, liabilities and shareholder’s equity as well as the combined operating results of NAEL and NACGI for all comparative periods presented. The consolidated financial statements for periods ended before November 26, 2003 are not comparable in all respects to the consolidated financial statements for periods ended after November 25, 2003.

      The Predecessor Company has been operating continuously in western Canada since 1953.

     (b) Use of estimates:

      The preparation of financial statements in conformity with Canadian GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and disclosures reported in these consolidated financial statements and accompanying notes.

      Significant estimates made by management include the assessment of the percentage of completion on unit-price or lump-sum contracts (including estimated total costs and provisions for estimated losses) and the recognition of claims and change orders on contracts, assumptions used to value derivative financial instruments, assumptions used to determine redemption value of redeemable securities, assumptions used in periodic impairment testing, and estimates and assumptions used in the determination of the allowance for doubtful accounts. Actual results could differ materially from those estimates.

     (c) Revenue recognition:

      The Company performs the majority of its projects under the following types of contracts: time-and-materials; cost-plus; unit-price; and lump sum. For time-and-materials and cost-plus contracts, revenue is recognized as costs are incurred. Revenue on unit-price and lump sum contracts is recognized on the percentage-of-completion method, measured by the ratio of costs incurred to date to estimated total costs.

F-7

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

Excluded from costs incurred to date, particularly in the early stages of the contract, are the costs of items that do not relate to performance of our contracted work.

      The length of the Company’s contracts varies from less than one year on typical contracts to several years for certain larger contracts. Contract project costs include all direct labour, material, subcontract, and equipment costs and those indirect costs related to contract performance such as indirect labour, supplies, and tools. General and administrative costs are charged to expense as incurred. Provisions for estimated losses on uncompleted contracts are made in the period in which such losses are determined. Changes in project performance, project conditions, and estimated profitability, including those arising from contract penalty provisions and final contract settlements, may result in revisions to costs and income that are recognized in the period in which such adjustments are determined. Profit incentives are included in revenue when their realization is reasonably assured.

      Effective April 1, 2005, the Company changed its accounting policy regarding the recognition of revenue on claims. This change in accounting policy has been applied retroactively. Once contract performance is underway, the Company will often experience changes in conditions, client requirements, specifications, designs, materials and work schedule. Generally, a “change order” will be negotiated with the customer to modify the original contract to approve both the scope and price of the change. Occasionally, however, disagreements arise regarding changes, their nature, measurement, timing and other characteristics that impact costs and revenue under the contract. When a change becomes a point of dispute between the Company and a customer, the Company will then consider it as a claim.

      Costs related to change orders and claims are recognized when they are incurred. Change orders are included in total estimated contract revenue when it is probable that the change order will result in a bona fide addition to contract value and can be reliably estimated.

      Prior to April 1, 2005, revenue from claims was included in total estimated contract revenue when awarded or received. After April 1, 2005, claims are included in total estimated contract revenue, only to the extent that contract costs related to the claim have been incurred and when it is probable that the claim will result in a bona fide addition to contract value and can be reliably estimated. Those two conditions are satisfied when (1) the contract or other evidence provides a legal basis for the claim or a legal opinion is obtained providing a reasonable basis to support the claim, (2) additional costs incurred were caused by unforeseen circumstances and are not the result of deficiencies in our performance, (3) costs associated with the claim are identifiable and reasonable in view of work performed and (4) evidence supporting the claim is objective and verifiable. No profit is recognized on claims until final settlement occurs. This can lead to a situation where costs are recognized in one period and revenue is recognized when customer agreement is obtained or claim resolution occurs, which can be in subsequent periods. Historical claim recoveries should not be considered indicative of future claim recoveries.

      The change in policy resulted in an increase in claims revenue and unbilled revenue of approximately $12,862 for the year ended March 31, 2006, but did not result in any adjustments to prior periods. Substantially all of the amounts recognized as claims revenue have been collected subsequent to year end.

      The asset entitled “unbilled revenue” represents revenue recognized in advance of amounts invoiced. The liability entitled “billings in excess of costs incurred and estimated earnings on uncompleted contracts” represents amounts invoiced in excess of revenue recognized.

     (d) Cash and cash equivalents:

      Cash and cash equivalents include cash on hand, bank balances net of outstanding cheques, and short-term investments with maturities of three months or less.

F-8

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (e) Allowance for doubtful accounts:

      The Company evaluates the probability of collection of accounts receivable and records an allowance for doubtful accounts, which reduces the receivables to the amount management reasonably believes will be collected. In determining the amount of the allowance, the following factors are considered: the length of time the receivable has been outstanding, specific knowledge of each customer’s financial condition, and historical experience.

     (f) Inventory:

      Inventory is carried at the lower of cost, on a first-in, first-out basis, and replacement cost, and primarily consists of job materials.

     (g) Plant and equipment:

      Plant and equipment are recorded at cost. Major components of heavy construction equipment in use such as engines, transmissions, and undercarriages are recorded separately. Spare component parts are charged to earnings when they are put into use. Equipment under capital lease is recorded at the present value of minimum lease payments at the inception of the lease. Depreciation is not recorded until an asset is put into service. Depreciation for each category is calculated based on the cost, net of the estimated residual value, over the estimated useful life of the assets on the following bases and annual rates:

Asset	Basis	Rate
Heavy equipment	Straight-line	Operating hours
Major component parts in use	Straight-line	Operating hours
Spare component parts	N/A	N/A
Other equipment	Straight-line	10-20%
Licensed motor vehicles	Declining balance	30%
Office and computer equipment	Straight-line	25%
Leasehold improvements	Straight-line	Lease term
Assets under construction	N/A	N/A

      The cost of period repairs and maintenance is expensed to the extent that the expenditure serves only to restore the asset to its original condition.

     (h) Goodwill:

      Goodwill represents the excess purchase price paid by the Company over the fair value of the tangible and identifiable intangible assets and liabilities acquired. Goodwill is not amortized but instead is tested for impairment annually or more frequently if events or changes in circumstances indicate that the asset might be impaired. The impairment test is carried out in two steps. In the first step, the carrying amount of the reporting unit, including goodwill, is compared with its fair value. When the fair value of the reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired and the second step of the impairment test is unnecessary. The second step is carried out when the carrying amount of a reporting unit exceeds its fair value, in which case, the implied fair value of the reporting unit’s goodwill, determined in the same manner as the value of goodwill is determined in a business combination, is compared with its carrying amount to measure the amount of the impairment loss, if any.

      The Company tested goodwill for impairment at December 31, 2005 and determined that there was no impairment in carrying value. The Company conducts its annual assessment of goodwill on December 31 of each year.

F-9

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (i) Intangible assets:

      Intangible assets acquired include: customer contracts in progress and related relationships, which are being amortized based on the net present value of the estimated period cash flows over the remaining lives of the related contracts; trade names, which are being amortized on a straight-line basis over their estimated useful life of 10 years; a non-competition agreement, which is being amortized on a straight-line basis over the five-year term of the agreement; and employee arrangements, which are being amortized on a straight-line basis over the three-year term of the arrangement.

     (j) Deferred financing costs:

      Costs relating to the issuance of the senior notes and the revolving credit facility have been deferred and are being amortized on a straight-line basis over the term of the related debt. Deferred financing costs related to debt that has been extinguished is written-off in the period of extinguishment.

     (k) Impairment of long-lived assets:

      Long-lived assets and certain identifiable intangibles are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is assessed by a comparison of the carrying amount of an asset to future undiscounted cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment loss is recognized for the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of by sale are reported at the lower of their carrying amount or fair value less costs to sell.

     (l) Foreign currency translation:

      The functional currency of the Company is Canadian dollars. Transactions denominated in foreign currencies are recorded at the rate of exchange prevailing at the transaction date. Monetary assets and liabilities, including long-term debt denominated in U.S. dollars, are translated into Canadian dollars at the rate of exchange prevailing at the balance sheet date.

     (m) Derivative financial instruments:

      The Company uses derivative financial instruments to manage economic risks from fluctuations in exchange rates and interest rates. These instruments include cross-currency swap agreements and interest rate swap agreements. All such instruments are only used for risk management purposes. The Company does not hold or issue derivative financial instruments for trading or speculative purposes. Derivative financial instruments are subject to standard credit terms and conditions, financial controls, management and risk monitoring procedures.

      A derivative financial instrument must be designated and effective, at inception and on at least a quarterly basis, to be accounted for as a hedge. For cash flow hedges, effectiveness is achieved if the changes in the cash flows of the derivative financial instrument substantially offset the changes in the cash flows of the hedged position and the timing of the cash flows is similar. Effectiveness for fair value hedges is achieved if changes in the fair value of the derivative financial instrument substantially offset changes in the fair value of the hedged item attributable to the risk being hedged. In the event that a derivative financial instrument does not meet the designation or effectiveness criteria, the derivative financial instrument is accounted for at fair value and realized and unrealized gains and losses on the derivative are recognized in the Consolidated Statement of Operations and Deficit in accordance with the Canadian Institute of Chartered Accountants (“CICA”) Emerging Issues Committee Abstract No. 128, “Accounting for Trading, Speculative or Non-Hedging Derivative Financial Instruments” (“EIC-128”). If

F-10

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

a derivative financial instrument that previously qualified for hedge accounting no longer qualifies or is settled or de-designated, the fair value on that date is deferred and recognized when the corresponding hedged transaction is recognized. Premiums paid or received with respect to derivatives that are hedges are deferred and amortized to income over the term of the hedge.

     (n) Income taxes:

      The Company uses the asset and liability method of accounting for income taxes. Under the asset and liability method, future income 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. Future income tax assets and liabilities are measured using enacted or substantively enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on future income tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the date of enactment or substantive enactment. A valuation allowance is recorded against any future income tax asset if it is more likely than not that the asset will not be realized.

     (o) Stock–based compensation plan:

      The Company accounts for all stock-based compensation payments in accordance with a fair value based method of accounting. Under this fair value based method, compensation cost is measured using the Black-Scholes model using an expected volatility assumption of nil (the “minimum value” approach) at the grant date and is expensed over the award’s vesting period, with a corresponding increase to contributed surplus.

     (p) Earnings per share:

      Basic earnings per share are computed by dividing net earnings (loss) available to common shareholders by the weighted average number of shares outstanding during the year (see note 13(d)). Diluted per share amounts are calculated using the treasury stock and if-converted methods. The treasury stock method increases the diluted weighted average shares outstanding to include additional shares from the assumed exercise of stock options, if dilutive. The number of additional shares is calculated by assuming that outstanding in-the-money stock options were exercised and that the proceeds from such exercises, including any unamortized stock-based compensation cost, were used to acquire shares of common stock at the average market price during the year. The if-converted method assumes the conversion of convertible securities at the latter of the beginning of the reported period or issuance date, if dilutive.

     (q) Recently adopted Canadian accounting pronouncements:

i.     Hedge relationships:

      Effective November 26, 2003, the Company prospectively adopted the provisions of CICA Accounting Guideline 13, “Hedging Relationships” (“AcG-13”), which specifies the circumstances in which hedge accounting is appropriate, including the identification, documentation, designation, and effectiveness of hedges, and the discontinuance of hedge accounting. The Company determined that all of its then existing derivative financial instruments did not qualify for hedge accounting on the adoption date of AcG-13.

ii.     Generally accepted accounting principles:

      Effective November 26, 2003, the Company adopted CICA Handbook Section 1100, “Generally Accepted Accounting Principles,” which establishes standards for financial reporting in accordance with

F-11

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

Canadian GAAP, and describes what constitutes Canadian GAAP and its sources. This section also provides guidance on sources to consult when selecting accounting policies and determining appropriate disclosures when the primary sources of Canadian GAAP do not provide guidance. The adoption of this standard did not have a material impact on the consolidated financial statements.

iii.     Revenue recognition:

      Effective January 1, 2004, the Company prospectively adopted CICA Emerging Issues Committee Abstract No. 141, “Revenue Recognition,” and CICA Emerging Issues Committee Abstract No. 142, “Revenue Arrangements with Multiple Deliverables,” which incorporate the principles and guidance for revenue recognition provided under United States generally accepted accounting principles (“U.S. GAAP”). No changes to the recognition, measurement or classification of revenue were made as a result of the adoption of these standards.

iv.     Consolidation of variable interest entities:

      Effective January 1, 2005, the Company prospectively adopted the CICA Accounting Guideline 15, “Consolidation of Variable Interest Entities” (“AcG-15”). Variable interest entities (“VIEs”) are entities that have insufficient equity at risk to finance their operations without additional subordinated financial support and/or entities whose equity investors lack one or more of the specified essential characteristics of a controlling financial interest. AcG-15 provides specific guidance for determining when an entity is a variable interest entity (“VIE”) and who, if anyone, should consolidate the VIE. The Company has determined the joint venture in which it has an investment (note 15(c)) qualifies as a VIE and began consolidating this VIE effective January 1, 2005.

v.     Arrangements containing a lease:

      Effective January 1, 2005, the Company adopted the CICA Emerging Issues Committee Abstract No. 150, “Determining Whether an Arrangement Contains a Lease” (“EIC-150”). EIC-150 addresses a situation where an entity enters into an arrangement, comprising a transaction that does not take the legal form of a lease but conveys a right to use a tangible asset in return for a payment or series of payments. The implementation of this standard did not have a material impact on the Company’s consolidated financial statements.

vi.     Vendor rebates:

      In April 2005, the Company adopted the CICA Emerging Issues Committee Abstract No. 144, “Accounting by a Customer (Including a Reseller) for Certain Consideration Received from a Vendor” (“EIC-144”). EIC-144 requires companies to recognize the benefit of non-discretionary rebates for achieving specified cumulative purchasing levels as a reduction of the cost of purchases over the relevant period, provided the rebate is probable and reasonably estimable. Otherwise, the rebates would be recognized as purchasing milestones are achieved. The implementation of this new standard did not have a material impact on the Company’s consolidated financial statements.

vii.     Accounting for convertible debt instruments:

      In October 2005, the CICA issued Emerging Issues Committee Abstract No. 158 “Accounting for Convertible Debt Instruments” (“EIC-158”) which provides guidance on whether an issuer of certain types of convertible debt instruments should classify the instruments as liabilities or equity and, if a liability, when it should be classified as a current liability. EIC-158 was applicable for convertible debt instruments issued after October 17, 2005. The adoption of this standard did not have an impact on the Company’s consolidated financial statements.

F-12

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

viii.     Non-monetary transactions:

      Effective January 1, 2006, the Company adopted the requirements of CICA Handbook Section 3831, “Non-monetary Transactions”. The new standard requires that an asset exchanged or transferred in a non-monetary transaction must be measured at its fair value except when: the transaction lacks commercial substance; the transaction is an exchange of production or property held for sale in the ordinary course of business for production or property to be sold in the same line of business to facilitate sales to customers other than the parties to the exchange; neither the fair value of the assets or services received nor the fair value of the assets or services given up is reliably measurable; or the transaction is a non-monetary, non-reciprocal transfer to owners that represents a spin-off or other form of restructuring or liquidation. In these cases, the transaction must be measured at carrying value. The adoption of this standard did not have a material impact on the Company’s consolidated financial statements.

ix.     Implicit variable interests under AcG-15:

      Effective January 1, 2006, the Company adopted the CICA Emerging Issues Committee Abstract No. 157, “Implicit Variable Interests Under AcG-15” (“EIC-157”). EIC-157 requires a company to assess whether it has an implicit variable interest in a VIE or potential VIE when specific conditions exist. An implicit variable interest acts the same as an explicit variable interest except it involves the absorbing and/or receiving of variability indirectly from the entity (rather than directly). The identification of an implicit variable interest is a matter of judgment that depends on the relevant facts and circumstances. The adoption of this standard did not have a material impact on the Company’s consolidated financial statements.

x.     Conditional asset retirement obligations:

      In November 2005, the CICA issued Emerging Issues Committee Abstract No. 159, “Conditional Asset Retirement Obligations” (“EIC-159”) to clarify the accounting treatment for a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Under EIC-159, an entity is required to recognize a liability for the fair value of a conditional asset retirement obligation if the obligation can be reasonably estimated. The guidance is effective April 1, 2006, although early adoption is permitted, and is to be applied retroactively, with restatement of prior periods. The Company adopted this standard adopted this standard in fiscal 2006, and the adoption did not have a material impact on the Company’s consolidated financial statements.

     (r) Recent Canadian accounting pronouncements not yet adopted:

i.     Financial instruments:

      In January 2005, the CICA issued Handbook Section 3855, “Financial Instruments – Recognition and Measurement”, Handbook Section 1530, “Comprehensive Income”, and Handbook Section 3865, “Hedges”. The new standards are effective for interim and annual financial statements for fiscal years beginning on or after October 1, 2006, specifically April 1, 2007 for the Company. Earlier adoption is permitted. The new standards will require presentation of a separate statement of comprehensive income under specific circumstances. Foreign exchange gains and losses on the translation of the financial statements of self-sustaining subsidiaries previously recorded in a separate section of shareholder’s equity will be presented in comprehensive income. Derivative financial instruments will be recorded in the balance sheet at fair value and the changes in fair value of derivatives designated as cash flow hedges will be reported in comprehensive income. The Company is currently assessing the impact of the new standards.

F-13

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

3. Acquisition

      On November 26, 2003, NACG Preferred Corp. and NACG Acquisition Inc. (“NACG Acquisition”), a wholly-owned subsidiary of NAEPI, acquired from the Predecessor Company all of the outstanding common shares of NACGI. The Predecessor Company sold 30 shares of NACGI to NACG Preferred Corp. in exchange for $35.0 million of NACG Preferred Corp.’s Series A preferred shares. NACG Preferred Corp. then contributed the 30 shares of NACGI to NAEPI in exchange for common shares. NAEPI then contributed the 30 shares of NACGI to NACG Acquisition in exchange for common shares. The Predecessor Company sold the remaining 170 shares of NACGI to NACG Acquisition in exchange for approximately $195.5 million in cash including the impact of various post-closing adjustments. In addition, NACG Acquisition acquired substantially all of the property, plant and equipment, prepaid expenses and accounts payable of NAEL for $175.0 million in cash. NACG Acquisition and NACGI amalgamated on the same day and the successor company continued as NACGI.

      The total purchase price was approximately $230.0 million for the common shares of NACGI and $175.0 million for the property, plant and equipment, prepaid expenses and accounts payable of NAEL. The purchase price was subject to an adjustment of $0.5 million based on the closing working capital of NACGI at November 25, 2003 which has been accounted for as increased goodwill. The total consideration payable by NACG Preferred Corp. and NACG Acquisition to the sellers was approximately $405.5 million including the impact of certain post-closing adjustments. Of the cash consideration, $92.5 million came from the Company’s sale of its equity.

      The Company accounted for the acquisition as a business combination using the purchase method. The results of NACGI’s operations have been included in the consolidated financial statements of the Company since November 26, 2003. The following table summarizes the fair value of the assets acquired and liabilities assumed at the date of acquisition:

Current assets, including cash of $19,642			$	83,910
Property, plant and equipment, including capital leases of $2,131				176,779
Intangible assets				17,798
Goodwill				198,549
	Total assets acquired			477,036
Current liabilities				(40,662	)
Future income taxes				(11,823	)
Capital lease obligations				(2,131	)
	Total liabilities assumed			(54,616	)
		Net assets acquired	$	422,420

F-14

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

      The acquisition was financed as follows:

Proceeds from issuance of 83/4 % senior notes		$	263,000
Proceeds from issuance of share capital			92,500
Proceeds from issuance of Series A preferred shares of NACG Preferred Corp.			35,000
Proceeds from initial borrowing under the new:
	Term credit facility		50,000
	Revolving credit facility		—
Less: deferred financing costs			(18,080	)
		$	422,420

      The net cash cost of the acquisition was:

Net assets acquired	$	422,420
Less: Issuance of Series A preferred shares of NACG Preferred Corp.		(35,000	)
Less: cash acquired from acquisition and financing		(19,642	)
	$	367,778

      The intangible assets relate to customer contracts in progress and related relationships, trade names, a non-competition agreement, and employee arrangements and are subject to amortization.

      The goodwill was assigned to mining and site preparation, piling and pipeline segments in the amounts of $125,447, $40,349, and $32,753, respectively. None of the goodwill is deductible for income tax purposes.

      Transaction costs of $25,080 were incurred on the acquisition, $7,000 of which were accounted for as increased goodwill and $18,080 of which were recorded as deferred financing costs.

      The current assets included $19,642 in cash acquired, of which $15,623 was surplus cash from the financing.

4. Accounts receivable

	March 31,			March 31,
	2005			2006
Accounts receivable – trade	$	45,379		$	55,666
Accounts receivable – holdbacks		12,476			10,748
Accounts receivable – other		54			891
Allowance for doubtful accounts		(164	)		(70	)
	$	57,745		$	67,235

      Accounts receivable – holdbacks represent amounts up to 10% under certain contracts that the customer is contractually entitled to withhold until completion of the project. The customer is obligated to retain this amount in a lien fund to ensure that subcontractors are paid and to ensure that any remedial or warranty work is performed.

F-15

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

5. Costs incurred and estimated earnings net of billings on uncompleted contracts

		March 31,			March 31,
		2005			2006
	Costs incurred and estimated earnings on uncompleted contracts	$	885,301		$	610,006
Less: billings to date			(845,215	)		(571,636	)
		$	40,086		$	38,370

      Costs incurred and estimated earnings net of billings on uncompleted contracts is presented in the consolidated balance sheets under the following captions:

		March 31,			March 31,
		2005			2006
Unbilled revenue		$	41,411		$	43,494
	Billings in excess of costs incurred and estimated earnings on uncompleted contracts		(1,325	)		(5,124	)
		$	40,086		$	38,370

6. Plant and equipment

			Accumulated		Net Book
March 31, 2006	Cost		Depreciation		Value
Heavy equipment	$	174,042	$	31,347	$	142,695
Major component parts in use		4,922		2,091		2,831
Spare component parts		1,170		—		1,170
Other equipment		13,074		4,186		8,888
Licensed motor vehicles		18,223		8,410		9,813
Office and computer equipment		3,362		1,493		1,869
Leasehold improvements		2,959		247		2,712
Assets under construction		15,588		—		15,588
	$	233,340	$	47,774	$	185,566

			Accumulated		Net Book
March 31, 2005	Cost		Depreciation		Value
Heavy equipment	$	165,296	$	17,966	$	147,330
Major component parts in use		4,659		1,182		3,477
Spare component parts		841		—		841
Other equipment		12,088		2,473		9,615
Licensed motor vehicles		16,043		4,670		11,373
Office and computer equipment		2,088		791		1,297
Assets under construction		3,156		—		3,156
	$	204,171	$	27,082	$	177,089

      The above amounts include $14,559 (March 31, 2005 – $8,637) of assets under capital lease and accumulated depreciation of $4,479 (March 31, 2005 – $1,968) related thereto. During the year ended March 31, 2006, additions of property, plant and equipment included $5,910 of assets that were acquired by means of capital leases (year ended March 31, 2005 – $5,385; November 26, 2003 to March 31, 2004 –

F-16

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

$1,195; April 1, 2003 to November 25, 2003 – $nil). Depreciation of equipment under capital leases of $2,545 (year ended March 31, 2005 – $1,659; November 26, 2003 to March 31, 2004 – $320; April 1, 2003 to November 25, 2003 – $677) is included in depreciation expense.

7. Intangible assets

			Accumulated		Net Book
March 31, 2006	Cost		Amortization		Value
Customer contracts in progress and related relationships	$	15,323	$	15,323	$	—
Trade names		350		81		269
Non-competition agreement		100		47		53
Employee arrangements		2,025		1,575		450
	$	17,798	$	17,026	$	772

			Accumulated		Net Book
March 31, 2005	Cost		Amortization		Value
Customer contracts in progress and related relationships	$	15,323	$	15,323	$	—
Trade names		350		47		303
Non-competition agreement		100		26		74
Employee arrangements		2,025		900		1,125
	$	17,798	$	16,296	$	1,502

      Amortization of intangible assets of $730 was recorded for the year ended March 31, 2006 (year ended March 31, 2005 – $3,368; November 26, 2003 to March 31, 2004 – $12,928; April 1, 2003 to November 25, 2003 – $nil).

      The estimated amortization expense for the next five years is as follows:

For the year ending March 31,
2007	$	505
2008		55
2009		48
2010		35
2011 and thereafter		129
	$	772

8. Deferred financing costs

      For the year ended March 31, 2006, financing costs of $7,546 were incurred in connection with the issuance of the 9% senior secured notes and revolving credit facility and were recorded as deferred financing costs. In addition, financing costs of $321 were incurred in connection with the issuance of the NAEPI Series A redeemable preferred shares and expensed in the current year.

      In connection with the repayment of the senior secured credit facility on May 19, 2005, the Company wrote off deferred financing costs of $1,774 (note 11(a)).

      Amortization of deferred financing costs of $3,338 was recorded for the year ended March 31, 2006 (year ended March 31, 2005 – $2,554; November 26, 2003 to March 31, 2004 – $814; April 1, 2003 to November 25, 2003 – $nil).

F-17

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

9. Accrued liabilities

	March 31,		March 31,
	2005		2006
Accrued interest payable	$	9,127	$	10,878
Payroll liabilities		2,283		7,423
Income and other taxes payable		1,679		1,241
Liabilities related to equipment leases		2,112		5,061
	$	15,201	$	24,603

10. Capital lease obligations

      The Company leases a portion of its licensed motor vehicles for which the minimum lease payments due in each of the next five fiscal years are as follows:

	2007	$	3,766
	2008		3,620
	2009		2,963
	2010		2,090
	2011		224
			12,663
Less: amount representing interest – weighted average rate of 6.57%			1,711
Present value of minimum capital lease payments			10,952
Less: current portion			3,046
		$	7,906

11. Long-term debt

     (a) Senior secured credit facility:

	March 31,		March 31,
	2005		2006
Revolving credit facility	$	20,007	$	—
Term credit facility		41,250		—
	$	61,257	$	—

      The Company refers to the revolving credit facility and the term loan collectively as the “senior secured credit facility.”

      On May 19, 2005, the Company repaid its entire indebtedness under the senior secured credit facility using the net proceeds from the issuance of the 9% senior secured notes (note 11(b)) and the NAEPI Series B redeemable preferred shares (note 13(a)).

F-18

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (b) Senior notes:

	March 31,		March 31,
	2005		2006
83/4 % senior unsecured notes due 2011	$	241,920	$	233,420
9% senior secured notes due 2010		—		70,587
	$	241,920	$	304,007

      The 8³/4% senior notes were issued on November 26, 2003 in the amount of US$200 million (Canadian $263 million) by NAEPI. These notes mature on December 1, 2011 and bear interest at 8³/4 % payable semi-annually on June 1 and December 1 of each year.

      The 8³/4 % senior notes are unsecured senior obligations and rank equally with all other existing and future unsecured senior debt and senior to any subordinated debt that may be issued by NAEPI or any of its subsidiaries. NACG Holdings Inc. is not a guarantor of this debt. The notes are effectively subordinated to all secured debt to the extent of the value of the assets securing such debt.

      The 8³/4% senior notes are redeemable at the option of NAEPI, in whole or in part, at any time on or after: December 1, 2007 at 104.375% of the principal amount; December 1, 2008 at 102.188% of the principal amount; December 1, 2009 at 100.00% of the principal amount; plus, in each case, interest accrued to the redemption date. At any time, or from time to time, on or before December 1, 2006 NAEPI may, at its option, use the net cash proceeds of one or more public equity offerings, to redeem up to 35% of the principal amount of the 8³/4% senior notes at a redemption price equal to 108.75% of the principal amount of the 8³/4% senior notes redeemed plus accrued and unpaid interest, if any, to the date of redemption; provided that: at least 65% of the principal amount of 8³/4% senior notes remains outstanding immediately after any such redemption; and NAEPI makes such redemption within 90 days after the closing of any such public equity offering. If a change of control occurs, NAEPI will be required to offer to purchase all or a portion of each holder’s 8³/4 % senior notes, at a purchase price in cash equal to 101% of the principal amount of notes repurchased plus accrued interest to the date of purchase.

      The 9% senior secured notes were issued on May 19, 2005 in the amount of US$60.481 million (Canadian $76.345 million) by NAEPI. These notes mature on June 1, 2010 and bear interest at 9% payable semi-annually on June 1 and December 1 of each year.

      The 9% senior secured notes are senior secured obligations and rank equally with all other existing and future secured debt and senior to any subordinated debt that may be issued by NAEPI or any of its subsidiaries. NACG Holdings Inc. is not a guarantor of this debt. The notes are effectively senior to all existing and future unsecured senior debt including the 8³/4 % senior notes and are effectively subordinated to NAEPI’s swap agreements and new revolving credit facility to the extent of the value of the assets securing such debt.

      The 9% senior secured notes are redeemable at the option of NAEPI, in whole or in part, at any time on or after: June 1, 2008 at 104.50% of the principal amount; June 1, 2009 at 102.25% of the principal amount; June 1, 2010 at 100.00% of the principal amount; plus, in each case, interest accrued to the redemption date. At any time, or from time to time, on or before June 1, 2007 NAEPI may, at its option, use the net cash proceeds of one or more public equity offerings, to redeem up to 35% of the principal amount of the 9% senior secured notes at a redemption price equal to 109.0% of the principal amount of the 9% senior secured notes redeemed plus accrued and unpaid interest, if any, to the date of redemption; provided that: at least 65% of the principal amount of 9% senior secured notes remains outstanding immediately after any such redemption; and NAEPI makes such redemption within 90 days after the closing of any such public equity offering. If a change of control occurs, NAEPI will be required to offer

F-19

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

to purchase all or a portion of each holder’s 9% senior secured notes, at a purchase price in cash equal to 101% of the principal amount of notes repurchased plus accrued interest to the date of purchase.

     (c) Revolving credit facility:

      On May 19, 2005, NAEPI entered into a revolving credit facility with a syndicate of lenders. The revolving facility provided for borrowings of up to $40.0 million, subject to borrowing base limitations, under which revolving loans may have been made and letters of credit, up to a limit of $30.0 million, may have been issued. The facility bore interest at the Canadian prime rate plus 2% per annum or Canadian bankers’ acceptance stamping fee of 3% per annum. The indebtedness under the revolving credit facility was secured by substantially all of NAEPI’s assets and those of its subsidiaries, including accounts receivable, inventory and property, plant and equipment, and a pledge of the NAEPI’s capital stock and that of its subsidiaries.

      In connection with that revolving credit facility, NAEPI was required to amend its existing swap agreements to increase the effective rate of interest on its 8³/4 % senior notes from 9.765% to 9.889% (note 18(c)) and issue to one of the counterparties to the swap agreements $1.0 million of NAEPI Series A redeemable preferred shares (note 13(a)).

      As of March 31, 2006, NAEPI had no outstanding borrowings under the revolving credit facility and had issued $18.0 million in letters of credit to support bonding requirements and performance guarantees associated with customer contracts and operating leases. NAEPI’s borrowing availability under the facility, after taking into account the borrowing base limitations, was $9.3 million at March 31, 2006.

      On July 19, 2006, NAEPI amended and restated the revolving credit facility (note 24).

F-20

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

12. Income taxes

      Income tax provision (recovery) differs from the amount that would be computed by applying the Federal and provincial statutory income tax rate to income from continuing operations. The reasons for the differences are as follows:

		Predecessor
		Company
					Period from
		Period from			November 26,
		April 1, 2003 to			2003 to			Year Ended			Year Ended
		November 25,			March 31,			March 31,			March 31,
		2003			2004			2005			2006
Net loss before income taxes		$	(17,763	)	$	(17,952	)	$	(44,587	)	$	(21,204	)
Statutory tax rate			36.60	%		35.20	%		33.62	%		33.62	%
Expected recovery at statutory tax rate		$	(6,501	)	$	(6,319	)	$	(14,990	)	$	(7,129	)
Increase (decrease) related to:
	Change in future income tax liability, resulting from substantially enacted change in future statutory income tax rates		(669	)		(342	)		—			—
	Change in redemption value and accretion of redeemable preferred shares		—			—			—			11,674
	Change in future income tax liability, resulting from valuation allowance		—			—			12,189			(4,097	)
	Large corporations tax		137			319			871			716
	Other		411			672			(334	)		(427	)
Income tax provision (recovery)		$	(6,622	)	$	(5,670	)	$	(2,264	)	$	737

F-21

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

      The income tax effects of temporary differences that give rise to future income tax assets and liabilities are as follows:

		March 31,			March 31,
		2005			2006
Future income tax assets:
	Non-capital losses carried forward	$	30,538		$	22,312
	Derivative financial instruments		8,068			6,843
	Unrealized foreign exchange on senior notes		—			2,299
	Billings in excess of costs on uncompleted contracts		—			1,723
	Capital lease obligations		—			1,631
	Total future income tax assets		38,606			34,808
	Less valuation allowance		(9,955	)		(5,858	)
	Net future income tax assets		28,651			28,950
Future income tax liabilities:
	Unbilled revenue and uncertified revenue included in accounts receivable		10,972			1,970
	Accounts receivable – holdbacks		4,194			3,613
	Property, plant and equipment		12,432			20,263
	Deferred financing costs		548			1,038
	Intangible assets		505			130
	Unrealized foreign exchange on senior notes		—			1,936
	Total future income tax liabilities		28,651			28,950
Net future income taxes		$	—		$	—

      Classified as:

	March 31,			March 31,
	2006			2005
Current asset	$	5,583		$	15,100
Long-term asset		23,367			13,485
Current liability		(5,583	)		(15,100	)
Long-term liability		(23,367	)		(13,485	)
	$	—		$	—

      At March 31, 2006, the Company has non-capital losses for income tax purposes of approximately $66,375 which expire as follows:

2007	$	1
2009		10
2011		312
2012		57,035
2013		9,017

F-22

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

13. Shares

     (a) Redeemable preferred shares:

	March 31,		March 31,
	2005		2006
NACG Preferred Corp. Series A redeemable preferred shares(i)	$	35,000	$	35,000
NAEPI Series A preferred shares (ii)		—		375
NAEPI Series B preferred shares (iii)		—		42,193
	$	35,000	$	77,568

     i. NACG Preferred Corp. preferred shares

Issued:

	Number of
	Shares		Amount
Outstanding at November 26, 2003		—	$	—
Issued		35,000		35,000
Redeemed		—		—
Outstanding at March 31, 2004		35,000	$	35,000
Issued		—		—
Redeemed		—		—
Outstanding at March 31, 2005		35,000	$	35,000
Issued		—		—
Redeemed		—		—
Outstanding at March 31, 2006		35,000	$	35,000

      NACG Preferred Corp. is authorized to issue an unlimited number of Series A preferred shares. The NACG Preferred Corp. Series A preferred shares accrue dividends at a rate of $80.00 per share annually if earnings before interest, taxes, depreciation and amortization (“EBITDA”) for NAEPI is in excess of $75.0 million for the year. The dividends are payable in cash, additional NACG Preferred Corp. Series A preferred shares, or any combination of cash and shares as determined by the Company. The number of shares issuable is .001 of a whole NACG Preferred Corp. Series A preferred share for each $1.00 of dividend declared.

      The NACG Preferred Corp. Series A preferred shares, which were issued in connection with the acquisition described in note 3 and were recorded at their guaranteed redemption amount, are redeemable at any time at the option of the Company, and are required to be redeemed on or before November 26, 2012. The redemption price is $1,000.00 per share plus all accrued and unpaid dividends.

      In the event of a change in control, each holder of NACG Preferred Corp. Series A preferred shares has the right to require the Company to redeem all or any part of such holder’s shares.

F-23

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     ii. NAEPI Series A preferred shares

Issued:

	Number of
	Shares		Amount
Outstanding at November 26, 2003		—	$	—
Issued		—		—
Redeemed		—		—
Outstanding at March 31, 2004		—		—
Issued		—		—
Redeemed		—		—
Outstanding at March 31, 2005		—		—
Issued		1,000		321
Accretion		—		54
Outstanding at March 31, 2006		1,000	$	375

      NAEPI is authorized to issue an unlimited number of Series A preferred shares. The NAEPI Series A preferred shares are non-voting and are not entitled to any dividends. The NAEPI Series A preferred shares are mandatorily redeemable at $1,000 per share on the earlier of (1) December 31, 2011 and (2) an Accelerated Redemption Event, specifically (i) the occurrence of a change of control, or (ii) if there is an initial public offering of common shares, the later of (a) the consummation of the initial public offering or (b) the date on which all of the Company’s 8³/4 % senior notes and the Company’s 9% senior secured notes are no longer outstanding. NAEPI may redeem the NAEPI Series A preferred shares, in whole or in part, at $1,000 per share at any time.

      The NAEPI Series A preferred shares were issued to one of the counterparties to NAEPI’s swap agreements on May 19, 2005 in connection with the amendment of NAEPI’s revolving credit facility. These shares are not entitled to accrue or receive dividends and are required to be redeemed on or before December 31, 2011 for $1.0 million.

      The NAEPI Series A preferred shares were initially recorded at their fair value on the date of issuance, which was estimated to be $321 based on the present value of the required cash flows using the rate implicit at inception. Each reporting period, the Company will accrete the carrying value to the present value of the redemption amount at the balance sheet date and record the accretion as interest expense. For the year ended March 31, 2006, the Company recognized $54 of accretion as interest expense.

F-24

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     iii. NAEPI Series B preferred shares

Issued:

	Number of
	Shares			Amount
Outstanding at November 26, 2003		—		$	—
Issued		—			—
Redeemed		—			—
Outstanding at March 31, 2004		—			—
Issued		—			—
Redeemed		—			—
Outstanding at March 31, 2005		—		$	—
Issued		83,462			8,376
Repurchased		(8,218	)		(851	)
Change in redemption amount		—			34,668
Outstanding at March 31, 2006		75,244		$	42,193

      NAEPI is authorized to issue an unlimited number of Series B preferred shares. The NAEPI Series B preferred shares are non-voting and are entitled to cumulative dividends at an annual rate of 15% of the issue price of each share. No dividends are payable on NAEPI common shares or other classes of preferred shares (defined as Junior Shares) unless all cumulative dividends have been paid on the NAEPI Series B preferred shares and NAEPI declares a NAEPI Series B preferred share dividend equal to 25% of the Junior Share dividend (except for dividends paid as part of employee and officer arrangements, intercompany administrative charges of up to $1 million annually and tax sharing arrangements). As long as any NAEPI Series A preferred shares remain outstanding and subject to the restrictions contained within the 8³/4% senior notes and the 9% senior secured notes, dividends shall not be paid (but shall otherwise accrue) on the NAEPI Series B preferred shares. Subject to the prior redemption of the NAEPI Series A preferred shares, the NAEPI Series B preferred shares are mandatorily redeemable on the earlier of (1) December 31, 2011 and (2) an Accelerated Redemption Event, specifically (i) a change of control or (ii) if there is an initial public offering of common shares, the later of (a) the consummation of the initial public offering or (b) the date on which all of the Company’s 8³/4% senior unsecured notes and the Company’s 9% senior secured notes are no longer outstanding. Subject to the restrictive covenants contained within the indenture agreement for the 9% senior secured notes, the indenture agreement for the 8³/4 % senior notes and the revolving credit facility agreement, NAEPI may redeem the NAEPI Series B preferred shares, in whole or in part, at any time.

      The payment of dividends and the redemption of the NAEPI Series B preferred shares are prohibited by NAEPI’s revolving credit facility agreement. The payment of dividends and the redemption of the NAEPI Series B preferred shares is also restricted by the indenture agreements governing NAEPI’s 9% senior secured notes and 8³/4 % senior notes. Cumulative undeclared dividends on the NAEPI Series B preferred shares amounted to $938 at March 31, 2006.

      The NAEPI Series B preferred shares were issued to existing non-employee shareholders of the Company for cash proceeds of $7.5 million on May 19, 2005. The NAEPI Series B preferred shares were initially issued to certain non-employee shareholders with the agreement that an offer to purchase these NAEPI Series B preferred shares would also be extended to other existing shareholders of the Company on a pro rata basis to their interest in the common shares of the Company. On August 31, 2005, NAEPI issued 8,218 NAEPI Series B preferred shares for consideration of $851 to certain shareholders of the

F-25

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

Company as a result of this offering. On November 1, 2005, NAEPI repurchased and cancelled 8,218 of the NAEPI Series B preferred shares held by the original non-employee shareholders for cash consideration of $851.

      On June 15, 2005, the NAEPI Series B preferred shares were split 10-for-1.

      Subsequent to initial issuance, an additional 244 NAEPI Series B preferred shares were issued for cash consideration of $24.

      Initially, the redemption price of the NAEPI Series B preferred shares was an amount equal to the greatest of (i) two times the issue price, less the amount, if any, of dividends previously paid in cash on the NAEPI Series B preferred shares; (ii) an amount, not to exceed $100 million which, after taking into account any dividends previously paid in cash on such NAEPI Series B preferred shares, provides the holder with a 40% rate of return, compounded annually, on the issue price from the date of issuance; and (iii) an amount, not to exceed $100 million, which is equal to 25% of the arm’s length fair market value of NAEPI’s common shares without taking into account the NAEPI Series B preferred shares.

      On March 30, 2006, the terms of the NAEPI Series B preferred shares were amended to eliminate option (iii) from the calculation of the redemption price of the shares.

      Prior to the amendment to the terms of the NAEPI Series B preferred shares on March 30, 2006, the NAEPI Series B preferred shares were considered mandatorily redeemable and the Company was required to measure the NAEPI Series B preferred shares at the amount of cash that would be paid under the conditions specified in the contract if settlement occurred at each reporting date prior to the amendment. At March 30, 2006, management estimated the redemption amount to be $42,193. As a result, the Company has recognized the increase in the carrying value of $34,668 as an increase in interest expense for the year ended March 31, 2006.

      Concurrent with the amendment to the NAEPI Series B preferred shares, the Company entered into a Put/ Call Agreement with the holders of the NAEPI Series B preferred shares. The Put/ Call Agreement grants to each holder of the NAEPI Series B preferred shares the right (the “Put/ Call Right”) to require the Company to exchange each of the holder’s NAEPI Series B preferred shares for five common shares of the Company. The Put/ Call Right may only be exercised upon delivery by the Company of an “Event Notice”, being either: (i) a redemption or purchase call for the redemption or purchase of the NAEPI Series B preferred shares in connection with (A) a redemption on December 31, 2011, or (B) an Accelerated Redemption Event; or (ii) a notice in connection with a Liquidation Event (defined as a liquidation, winding-up or dissolution of NAEPI, whether voluntary or involuntary).

      The Put/ Call Agreement also grants the Company the right to require the holders of the NAEPI Series B preferred shares to exchange each of their NAEPI Series B preferred shares for 5 common shares in the capital of the Company upon delivery of a call notice to shareholders within five business days of an Event Notice.

      As a result of the March 30, 2006 amendment to the terms of the NAEPI Series B preferred shares, and the concurrent execution of the Put/ Call Agreement, the Company has accounted for the amendment as a related party transaction at carrying amount. No value was ascribed to the equity classified Put/Call Right as it was a related party transaction. The NAEPI Series B preferred shares will now be accreted from their carrying value of $42.2 million on the date of amendment to their redemption value of $69.6 million on December 31, 2011 through a charge to interest expense using the effective interest method over the period until December 31, 2011.

F-26

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (b) Common shares:

Authorized:

      Unlimited number of common voting shares

      Unlimited number of common non-voting shares

Issued:

	Number of
	Shares		Amount
Common voting shares
Outstanding at November 26, 2003		—	$	—
Issued		904,380		90,438
Redeemed		—		—
Outstanding at March 31, 2004		904,380		90,438
Issued		3,000		300
Redeemed		—		—
Outstanding at March 31, 2005		907,380		90,738
Issued		3,000		300
Redeemed		—		—
Outstanding at March 31, 2006		910,380	$	91,038
Common non-voting shares
Outstanding at November 26, 2003		—	$	—
Issued		20,620		2,062
Redeemed		—		—
Outstanding at March 31, 2004		20,620		2,062
Issued		—		—
Redeemed		—		—
Outstanding at March 31, 2005		20,620		2,062
Issued		—		—
Redeemed		—		—
Outstanding at March 31, 2006		20,620	$	2,062
Total common shares		931,000	$	93,100

      During the period from November 26, 2003 to March 31, 2004, 904,380 common voting shares and 20,620 common non-voting shares were issued for cash consideration of $92.5 million. During the year ended March 31, 2005, 3,000 common voting shares were issued for cash consideration of $300. During the year ended March 31, 2006, 3,000 common voting shares were issued for cash consideration of $300.

F-27

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (c) Contributed surplus:

Balance, November 26, 2003	$	—
Stock-based compensation (note 21)		137
Balance, March 31, 2004		137
Stock-based compensation (note 21)		497
Balance, March 31, 2005		634
Stock-based compensation (note 21)		923
Balance, March 31, 2006	$	1,557

     (d) Net loss per share:

      Basic net loss per share is computed on the basis of the weighted average number of common shares outstanding. Diluted net loss per share is computed on the basis of the weighted average number of common shares outstanding plus the effect of outstanding stock options using the treasury stock method and the dilutive effect of convertible securities using the if-converted method. For the years ending March 31, 2006 and March 31, 2005, and the period from November 26, 2003 to March 31, 2004, the effect of outstanding stock options and convertible securities on net loss per share was anti-dilutive as the Company was in a loss position. As such, the effect of outstanding stock options and convertible securities used to calculate the diluted net loss per share has not been disclosed.

	Period from
	November 26,
	2003 to			Year ended			Year ended
	March 31,			March 31,			March 31,
	2004			2005			2006
Net loss	$	(12,282	)	$	(42,323	)	$	(21,941	)
Weighted average number of common shares outstanding		925,000			926,986			928,740
Net loss per common share — basic and diluted	$	(13.28	)	$	(45.66	)	$	(23.62	)

14. Interest expense

	Predecessor
	Company
			Period from
	Period from		November 26,
	April 1, 2003 to		2003 to		Year Ended		Year Ended
	November 25,		March 31,		March 31,		March 31,
	2003		2004		2005		2006
Interest on senior notes	$	—	$	8,096	$	23,189	$	28,838
Interest on senior secured credit facility		599		1,089		3,274		564
Interest on capital lease obligations		294		56		230		457
Change in redemption value of Series B preferred shares		—		—		—		34,668
Accretion of Series A preferred shares		—		—		—		54
Interest on advances from Norama Inc.		1,468		—		—		—
Interest on long-term debt		2,361		9,241		26,693		64,581
Amortization of deferred financing costs		—		814		2,554		3,338
Other interest		96		24		1,894		857
	$	2,457	$	10,079	$	31,141	$	68,776

F-28

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

15. Other information

     (a) Supplemental cash flow information:

		Predecessor
		Company
				Period from
		Period from		November 26,
		April 1, 2003 to		2003 to		Year Ended		Year Ended
		November 25,		March 31,		March 31,		March 31,
		2003		2004		2005		2006
Cash paid during the period for:
	Interest	$	2,431	$	1,736	$	31,398	$	28,978
	Income taxes		325		269		3,588		617
Cash received during the period for:
	Interest		100		177		362		530
	Income taxes		—		18		—		2
Non-cash transactions:
	Acquisition of plant and equipment by means of capital leases		—		1,195		5,385		5,910
	Issuance of Series A preferred shares		—		—		—		321

     (b) Net change in non-cash working capital:

		Predecessor
		Company
					Period from
		Period from			November 26,
		April 1, 2003 to			2003 to			Year Ended			Year Ended
		November 25,			March 31,			March 31,			March 31,
		2003			2004			2005			2006
Operating activities:
	Accounts receivable	$	3,338		$	19,556		$	(24,029	)	$	(9,396	)
	Unbilled revenue		15,289			(17,528	)		(13,735	)		(2,083	)
	Inventory		—			(1,609	)		1,475			77
	Prepaid expenses		(544	)		(295	)		(590	)		66
	Accounts payable		(2,794	)		(2,839	)		29,789			(6,209	)
	Accrued liabilities		(1,457	)		6,172			507			9,215
	Billings in excess of costs incurred and estimated earnings on uncompleted contracts		—			—			1,325			3,799
		$	13,832		$	3,457		$	(5,258	)	$	(4,531	)
Investing activities:
	Accounts payable	$	—		$	—		$	—		$	1,204
	Accrued liabilities		—			—			—			187
		$	—		$	—		$	—		$	1,391

     (c) Investment in joint venture:

      The Company has determined that the joint venture in which it participates is a variable interest entity as defined by AcG-15 and that the Company is the primary beneficiary. Accordingly, the joint venture has been consolidated on a prospective basis effective January 1, 2005. During the fourth quarter

F-29

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

of 2005, the arrangement of this joint venture was amended such that the Company is responsible for all of its activities and revenues. As a result, no minority interest has been recorded.

      The Company’s transactions with the joint venture eliminate on consolidation.

      Details of the Company’s proportionate share of the results of operations and cash flows of the joint venture, prior to its consolidation, that are included in the consolidated financial statements are as follows:

	Predecessor
	Company
				Period from
	Period from			November 26,			Nine Months
	April 1, 2003 to			2003 to			Ended
	November 25,			March 31,			December 31,
	2003			2004			2004
Revenue	$	340		$	4		$	7,631
Project costs		(308	)		21			(8,840	)
General and administrative		(5	)		(37	)		—
Net income (loss)	$	27		$	(12	)	$	(1,209	)

		Predecessor
		Company
					Period from
		Period from			November 26,			Nine Months
		April 1, 2003 to			2003 to			Ended
		November 25,			March 31,			December 31,
		2003			2004			2004
Cash provided by:
	Operating activities	$	(49	)	$	61		$	(4,668	)
	Investing activities		—			—			—
	Financing activities		49			(59	)		5,061
		$	—		$	(2	)	$	393

16. Segmented information

     (a) General overview:

      The Company conducts business in three business segments: Mining and Site Preparation, Piling and Pipeline.

•  Mining and Site Preparation:

The Mining and Site Preparation segment provides mining and site preparation services, including overburden removal and reclamation services, project management and underground utility construction, to a variety of customers throughout Western Canada.

•  Piling:

The Piling segment provides deep foundation construction and design build services to a variety of industrial and commercial customers throughout Western Canada.

•  Pipeline:

The Pipeline segment provides both small and large diameter pipeline construction and installation services to energy and industrial clients throughout Western Canada.

F-30

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (b) Results by business segment:

	Mining and Site
For the Year Ended March 31, 2006	Preparation		Piling		Pipeline		Total
Revenues from external customers	$	366,721	$	91,434	$	34,082	$	492,237
Depreciation of plant and equipment		10,118		2,543		1,352		14,013
Segment profits		50,730		22,586		8,996		82,312
Segment assets		327,850		84,117		48,804		460,771
Expenditures for segment plant and equipment		25,090		880		82		26,052

	Mining and Site
For the Year Ended March 31, 2005	Preparation		Piling		Pipeline		Total
Revenues from external customers	$	264,835	$	61,006	$	31,482	$	357,323
Depreciation of plant and equipment		10,308		2,335		218		12,861
Segment profits		11,617		13,319		4,902		29,838
Segment assets		315,740		74,975		48,635		439,350
Expenditures for segment plant and equipment		16,888		202		774		17,864

	Mining and Site
For the Period from November 26, 2003 to March 31, 2004	Preparation		Piling		Pipeline		Total
Revenues from external customers	$	53,404	$	9,565	$	64,642	$	127,611
Depreciation of plant and equipment		3,116		465		383		3,964
Segment profits		8,154		2,501		12,892		23,547
Segment assets		264,822		76,896		68,751		410,469
Expenditures for segment plant and equipment		61		30		1,671		1,762

Predecessor Company
	Mining and Site
For the Period from April 1, 2003 to November 25, 2003	Preparation		Piling		Pipeline		Total
Revenues from external customers	$	182,368	$	39,417	$	28,867	$	250,652
Depreciation of plant and equipment		3,590		1,256		158		5,004
Segment profits		17,745		8,330		5,054		31,129
Segment assets		77,906		31,792		15,904		125,602
Expenditures for segment plant and equipment		2,591		417		—		3,008

     (c) Reconciliations:

     i. Loss before income taxes:

	Predecessor
	Company
				Period from
	Period from			November 26,
	April 1, 2003 to			2003 to			Year Ended			Year Ended
	November 25,			March 31,			March 31,			March 31,
	2003			2004			2005			2006
Total profit for reportable segments	$	31,129		$	23,547		$	29,838		$	82,312
Unallocated corporate expenses		(41,300	)		(40,437	)		(80,219	)		(102,190	)
Unallocated equipment revenue (costs)		(7,592	)		(1,062	)		5,794			(1,326	)
Loss before income taxes	$	(17,763	)	$	(17,952	)	$	(44,587	)	$	(21,204	)

F-31

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     ii. Total assets:

	March 31,		March 31,
	2005		2006
Total assets for reportable segments	$	439,350	$	460,771
Corporate assets		100,805		126,240
Total assets	$	540,155	$	587,011

      The Company’s goodwill was assigned to the Mining and Site Preparation, Piling and Pipeline segments in the amounts of $125,447, $40,349, and $32,753, respectively.

      Substantially all of the Company’s assets are located in Western Canada and the activities are carried out throughout the year.

     (d) Customers:

      The following customers accounted for 10% or more of total revenues:

	Predecessor
	Company
				Period from
	Period from			November 26,
	April 1, 2003 to			2003 to			Year Ended		Year Ended
	November 25,			March 31,			March 31,		March 31,
	2003			2004			2005		2006
Customer A		—			—			12%		32%
Customer B		64	%		27	%		26%		16%
Customer C		—			—			9%		10%
Customer D		12	%		51	%		10%		6%
Customer E		9	%		11	%		8%		5%
Customer F		—			4	%		11%		2%

      This revenue by major customer was earned in all three segments: Mining and Site Preparation, Pipeline and Piling.

17. Related party transactions

      All related party transactions described below are measured at the exchange amount of consideration established and agreed to by the related parties.

     (a) Transactions with Sponsors:

      The Sterling Group, L.P. (“Sterling”), Genstar Capital, L.P., Perry Strategic Capital Inc., and SF Holding Corp. (formerly Stephens Group, Inc.), (the “Sponsors”), entered into an agreement with the Company and certain of its subsidiaries to provide consulting and advisory services with respect to the organization of the companies, employee benefit and compensation arrangements, and other matters. As compensation for these services an advisory fee of $400 for the year ended March 31, 2006 (year ended March 31, 2005 – $400; November 26, 2003 to March 31, 2004 – $133; April 1, 2003 to November 25, 2003 – $ nil) is payable to the Sponsors, as a group. Additionally, 7,500 NAEPI Series B preferred shares were issued to the above Sponsor group in exchange for cash of $7.5 million (see note 13(a)).

F-32

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (b) Office rent:

      Pursuant to several office lease agreements, for the year ended March 31, 2006 the Company paid $836 (year ended March 31, 2005 – $824; November 26, 2003 to March 31, 2004 – $292; April 1, 2003 to November 25, 2003 – $387) to a company owned, indirectly and in part, by a member of its Board of Directors.

     (c) Predecessor company transactions:

      Norama Inc., the parent company of Norama Ltd., charged a fee for management services provided to NACGI. The management fee was paid in reference to taxable income.

18. Financial instruments

      The Company is exposed to market risks related to interest rate and foreign currency fluctuations. To mitigate these risks, the Company uses derivative financial instruments such as foreign currency and interest rate swap contracts.

     (a) Fair value:

      The fair values of the Company’s cash and cash equivalents, accounts receivable, unbilled revenue, accounts payable and accrued liabilities approximate their carrying amounts.

      The fair value of the senior secured credit facility, senior notes and capital lease obligations (collectively “the debt”) are based on management estimates which are determined by discounting cash flows required under the debt at the interest rate currently estimated to be available for loans with similar terms. Based on these estimates, the fair value of the Company’s senior secured credit facility and capital lease obligations as at March 31, 2006 and March 31, 2005 are not significantly different than their carrying values as they bear interest at floating rates. The market value of the 9% senior secured notes as at March 31, 2006 is $74,646 compared to a carrying value of $70,587. The market value of the 8³/4 % notes as at March 31, 2006 is $228,752 (March 31, 2005 – $216,750) compared to a carrying value of $233,420 (March 31, 2005 – $241,920).

     (b) Interest rate risk:

      The Company is subject to interest rate risk on the revolving credit facility and capital lease obligations. At March 31, 2006, for each 1% annual fluctuation in the interest rate, the annual cost of financing will change by approximately $94 (March 31, 2005 – $635).

      The Company also leases equipment with a variable lease payment component that is tied to prime rates. At March 31, 2006, for each 1% annual fluctuation in these rates, annual lease expense will change by approximately $244 (March 31, 2005 – $293).

     (c) Foreign currency risk and derivative financial instruments:

      The Company has 8³/4% senior notes denominated in U.S. dollars in the amount of US$200 million. In order to reduce its exposure to changes in the U.S. to Canadian dollar exchange rate, the Company, concurrent with the closing of the acquisition on November 26, 2003, entered into a cross-currency swap agreement to manage this foreign currency exposure for both the principal balance due on December 1, 2011 as well as the semi-annual interest payments through the whole period beginning from the issuance date to the maturity date. In conjunction with the cross-currency swap agreement, the Company also entered into a U.S. dollar interest rate swap and a Canadian dollar interest rate swap with the net effect of converting the 8.75% rate payable on the 8³/4 % senior notes into a fixed rate of 9.765% for the duration

F-33

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

that the 8³/4 % senior notes are outstanding. On May 19, 2005 in connection with the amendment of the Company’s revolving credit facility, this fixed rate was increased to 9.889%. These derivative financial instruments do not qualify for hedge accounting. The Company’s derivative financial instruments are carried on the consolidated balance sheets at their fair value of $63,611 (March 31, 2005 – $51,723). The fair value of the Company’s cross-currency and interest rate swap agreements are based on values quoted by the counterparties to the agreements.

      At March 31, 2006, the notional principal amount of the cross-currency swap was US$200 million. The notional principal amounts of the interest rate swaps were US$200 million and Canadian $263 million.

      The Company has not hedged its exposure to changes in the U.S. to Canadian dollar exchange rate resulting from the issuance of the 9% senior secured notes.

     (d) Operating leases:

      The Company is subject to foreign currency risk on U.S. dollar operating lease commitments as the Company has not entered into a cross-currency swap agreement to hedge this foreign currency exposure.

     (e) Credit risk:

      Reflective of its normal business, a majority of the Company’s accounts receivable are due from large companies operating in the resource sector. The Company regularly monitors the activity and balances in these accounts to manage its credit risk and provides an allowance for any doubtful accounts.

      At March 31, 2006 and March 31, 2005, the following customers represented 10% or more of accounts receivable and unbilled revenue:

	March 31,		March 31,
	2005		2006
Customer A		33%		21%
Customer B		9%		11%
Customer C		11%		9%

19. Commitments

      The annual future minimum lease payments in respect of operating leases for the next five years and thereafter are as follows:

For the year ending March 31,
	2007	$	21,176
	2008		16,506
	2009		9,587
	2010		8,148
	2011 and thereafter		2,232
		$	57,649

20. Employee contribution plans

      The Company and its subsidiaries match voluntary contributions made by the employees to their Registered Retirement Savings Plans to a maximum of 5% of base salary for each employee. Contributions made by the Company during the year ended March 31, 2006 were $409 (year ended March 31, 2005 – $305; November 26, 2003 to March 31, 2004 – $68; April 1, 2003 to November 25, 2003 – $122).

F-34

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

21. Stock-based compensation plan

      Under the 2004 Share Option Plan, Directors, Officers, employees and service providers to the Company are eligible to receive stock options to acquire common shares in the Company. The stock options expire ten years from the grant date or on termination of employment. Options may be exercised at a price determined at the time the option is awarded, and vest as follows: no options vest on the award date and twenty per cent vest on each of the five following award date anniversaries. The maximum number of common shares issuable under this plan may not exceed 105,000, of which 1,682 are still available for issue as at March 31, 2006. The Predecessor Company did not have any stock-based compensation plans.

				Weighted Average
	Number of			Exercise Price
	Options			$ Per Share
Outstanding at November 26, 2003		—		$	—
Granted		54,130			100.00
Exercised		—			—
Forfeited		—			—
Outstanding at March 31, 2004		54,130			100.00
Granted		24,112			100.00
Exercised		—			—
Forfeited		(2,000	)		(100.00	)
Outstanding at March 31, 2005		76,242			100.00
Granted		37,276			100.00
Exercised		—			—
Forfeited		(10,200	)		(100.00	)
Outstanding at March 31, 2006		103,318		$	100.00

      At March 31, 2006, the weighted average remaining contractual life of outstanding options is 8.4 years (March 31, 2005 – 10 years). The Company recorded $923 of compensation expense related to the stock options in the year ended March 31, 2006 (year ended March 31, 2005 – $497; period from November 26, 2003 to March 31, 2004 – $137) with such amount being credited to contributed surplus.

      The fair value of each option granted by the Company was estimated on the grant date using the Black-Scholes option-pricing model with the following assumptions:

		Period from
		November 26,
		2003 to			Year Ended			Year Ended
		March 31,			March 31,			March 31,
		2004			2005			2006
Number of options granted			54,130			24,112			37,276
Weighted average fair value per option granted($)			37.71			68.50			68.13
Weighted average assumptions
	Dividend yield		nil	%		nil	%		nil	%
	Expected volatility		nil	%		nil	%		nil	%
	Risk-free interest rate		4.79	%		4.25	%		4.13	%
	Expected life (years)		10			10			10

F-35

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

22. Comparative figures

      Certain of the comparative figures have been reclassified to conform to the current year’s presentation. The current year’s presentation was changed to conform the financial statements to the method of presentation used by NAEPI in its financial statements as well as to adopt certain public company presentation and disclosure requirements.

23. United States generally accepted accounting principles

      These consolidated financial statements have been prepared in accordance with Canadian GAAP, which differs in certain material respects from U.S. GAAP. If U.S. GAAP were employed, the Company’s net loss would be adjusted as follows:

		Predecessor
		Company
					Period from
		Period from			November 26,
		April 1, 2003 to			2003 to			Year Ended			Year Ended
		November 25,			March 31,			March 31,			March 31,
		2003			2004			2005			2006
Net loss (as reported)		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(21,941	)
Capitalized interest(a)			—			—			—			847
Amortization using effective interest method(b)			—			—			—			590
Realized and unrealized loss on derivative financial instruments(e)			—			—			—			(484	)
Income (loss) before income taxes			(11,141	)		(12,282	)		(42,323	)		(20,988	)
Income taxes:
	Deferred income taxes		—			—			—			—
Net loss – U.S. GAAP		$	(11,141	)	$	(12,282	)	$	(42,323	)	$	(20,988	)
Net loss per share– basic and diluted– U.S. GAAP		$	—		$	(13.28	)	$	(45.66	)	$	(22.60	)

      The cumulative effect of material differences between Canadian and U.S. GAAP on the consolidated shareholder’s equity of the Company is as follows:

	March 31,		March 31,
	2005		2006
Shareholders’ equity (as reported) – Canadian GAAP	$	38,829	$	18,111
Capitalized interest(a)		—		847
Amortization using effective interest method(b)		—		590
Realized and unrealized loss on derivative financial instruments(e)		—		(484	)
Excess of fair value of amended NAEPI Series B preferred shares over carrying value of original NAEPI Series B preferred shares(f)		—		(3,707	)
Shareholders’ equity – U.S. GAAP	$	38,829	$	15,357

F-36

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

      The areas of material difference between Canadian and U.S. GAAP and their impact on the Company’s consolidated financial statements are described below:

     (a) Capitalization of interest:

      U.S. GAAP requires capitalization of interest costs as part of the historical cost of acquiring certain qualifying assets that require a period of time to prepare for their intended use. This is not required under Canadian GAAP.

     (b) Deferred charges:

      Under Canadian GAAP, the Company defers and amortizes debt issuance costs on a straight-line basis over the stated term of the related debt. Under U.S. GAAP, the Company is required to amortize financing costs over the stated term of the related debt using the effective interest method resulting in a consistent interest rate over the term of the debt in accordance with Accounting Principles Board Opinion No. 21 (“APB 21”).

     (c) Reporting comprehensive income:

      Statement of Financial Accounting Standards No. 130, “Reporting Comprehensive Income” (“SFAS 130”) establishes standards for the reporting and display of comprehensive income and its components in a full set of general purpose financial statements. Comprehensive income equals net income (loss) for the period as adjusted for all other non-owner changes in shareholders’ equity. SFAS 130 requires that all items that are required to be recognized under accounting standards as components of comprehensive income be reported in a financial statement. The only component of comprehensive income (loss) is the net income (loss) for the period.

     (d) Stock-based compensation:

      The Company uses the fair value method of accounting for all stock-based compensation payments under Canadian GAAP. As a result, there are no significant differences between Canadian GAAP and Statement of Financial Accounting Standards No. 123 (“SFAS 123”).

     (e) Derivative financial instruments:

      Statement of Financial Accounting Standard No. 133, Accounting for Derivative Instruments and Hedging Activities (“SFAS 133”) establishes accounting and reporting standards requiring that every derivative instrument (including certain derivative instruments embedded in other contracts and debt instruments) be recorded in the balance sheet as either an asset or liability measured at its fair value. On November 26, 2003, the Company issued 8³/4 % senior notes for US$200 million (Canadian $263 million) and on May 19, 2005 the Company issued 9% senior secured notes for US$60.4 million (Canadian $76.3 million). Both of these issuances included certain contingent embedded derivatives which provided for the acceleration of redemption by the holder at a premium in certain instances. These embedded derivatives met the criteria for bifurcation from the debt contract and separate measurement at fair value. The embedded derivatives have been measured at fair value and classified as part of the carrying amount of the Senior Notes on the consolidated balance sheet, with changes in the fair value being recorded in net income as realized and unrealized (gain) loss on derivative financial instruments for the period under U.S. GAAP. Under Canadian GAAP, separate accounting of embedded derivatives from the host contract is not permitted by EIC-117.

F-37

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

     (f) NAEPI Series B Preferred Shares:

      Prior to the modification of the terms of the NAEPI Series B preferred shares, there were no differences between Canadian GAAP and U.S. GAAP related to the NAEPI Series B preferred shares. As a result of the modification of terms of NAEPI’s Series B preferred shares on March 30, 2006, under Canadian GAAP, the Company continues to classify the NAEPI Series B preferred shares as a liability and accretes the carrying amount to the December 31, 2011 redemption value of $69.6 million using the effective interest method. Under U.S. GAAP, the Company recognized the fair value of the NAEPI Series B preferred shares as minority interest as such amount was recognized as temporary equity in the accounts of NAEPI in accordance with EITF Topic D-98 and recognized a charge of $3.7 million to retained earnings for the difference between the fair value and the carrying amount of the Series B preferred shares on the modification date. Under U.S. GAAP, the Company accretes the initial fair value of the NAEPI Series B preferred shares of $45.9 million to the December 31, 2011 redemption value of $69.6 million using the effective interest method, which is consistent with the treatment of the NAEPI Series B preferred shares as temporary equity in the financial statements of NAEPI. The accretion charge is recognized as a charge to minority interest as opposed to retained earnings in the accounts of NAEPI under U.S. GAAP and interest expense in the Company’s financial statements under Canadian GAAP.

     (g) Investment in joint venture:

      The Company has determined that the joint venture in which it participates is a VIE and that the Company is the primary beneficiary. Accordingly the joint venture has been consolidated on a prospective basis effective January 1, 2005. Prior to its consolidation, the joint venture was accounted for using the proportionate consolidation method under Canadian GAAP. Under U.S. GAAP, investments in joint ventures are accounted for using the equity method. The different accounting treatment affects only the display and classification of financial statement items and not net earnings or shareholders’ equity. Rules prescribed by the Securities and Exchange Commission of the United States permit the use of the proportionate consolidation method in the reconciliation to U.S. GAAP provided the joint venture is an operating entity and the significant financial operating policies are, by contractual agreement, jointly controlled by all parties having an interest in the joint venture. In addition, the Company disclosed in note 15(c) the major components of its financial statements resulting from the use of the proportionate consolidation method to account for its interest in the joint venture prior to its consolidation.

     (h) Other Matters:

      The tax effects of temporary differences under Canadian GAAP are described as future income taxes in these financial statements whereas such amounts are described as deferred income taxes under U.S. GAAP.

     (i) United States accounting pronouncements recently adopted:

      In December 2003, the U.S. Financial Accounting Standards Board (the “FASB”) issued FASB Interpretation No. 46 (revised December 2003), “Consolidation of Variable Interest Entities” (“FIN 46R”), which addresses how a business enterprise should evaluate whether it has a controlling financial interest in an entity through means other than voting rights and accordingly should consolidate the entity. FIN 46R replaces FASB Interpretation No. 46, “Consolidation of Variable Interest Entities,” which was issued in January 2003. The Company is required to apply FIN 46R to variable interests in VIEs created after December 31, 2003. With respect to entities that do not qualify to be assessed for consolidation based on voting interests, FIN 46R generally requires a company that has a variable interest(s) that will absorb a majority of the VIE’s expected losses if they occur, receive a majority of the entity’s expected residual returns if they occur, or both, to consolidate that VIE. For variable interests in

F-38

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

VIEs created before January 1, 2004, the Interpretation was applied beginning on January 1, 2005. For any VIEs that must be consolidated under FIN 46R that were created before January 1, 2004, the assets, liabilities and noncontrolling interests of the VIE initially would be measured at their carrying amounts with any difference between the net amount added to the balance sheet and any previously recognized interest being recognized as the cumulative effect of an accounting change. If determining the carrying amounts is not practicable, fair value at the date FIN 46R first applies may be used to measure the assets, liabilities and noncontrolling interest of the VIE. The Company has determined the joint venture in which it has an investment (note 15(c)) qualifies as a VIE.

      Statement of Financial Accounting Standards No. 150, “Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity,” was issued in May 2003. This Statement establishes standards for the classification and measurement of certain financial instruments with characteristics of both liabilities and equity. The Statement also includes required disclosures for financial instruments within its scope. For the Company, the Statement was adopted as of January 1, 2004, except for certain mandatorily redeemable financial instruments. For certain mandatorily redeemable financial instruments, the Statement was adopted by the Company on January 1, 2005. The adoption of the standard required the Company to reclassify the carrying value of the NACG Preferred Corp. Series A preferred shares from minority interest to redeemable preferred shares. After the adoption of the standard, the Company issued other mandatorily redeemable preferred shares that were within the scope of the standard, which have been disclosed in note 13(a) to the consolidated financial statements.

      In November 2004, the FASB issued Statement of Financial Accounting Standards No. 151, “Inventory Costs”. This standard requires the allocation of fixed production overhead costs be based on the normal capacity of the production facilities and unallocated overhead costs recognized as an expense in the period incurred. In addition, other items such as abnormal freight, handling costs and wasted materials require treatment as current period charges rather than being considered an inventory cost. This standard was effective for fiscal 2006 for the Company. The adoption of this standard did not have a material impact on the Company’s financial statements.

      In March 2005, the FASB issued FASB Interpretation No. 47, “Accounting for Conditional Asset Retirement Obligations, an interpretation of FASB Statement No. 143” (“FIN 47”), which requires an entity to recognize a liability for the fair value of a conditional asset retirement obligation when incurred if the liability’s fair value can be reasonably estimated. FIN 47 is effective for fiscal years ending after December 15, 2005. The adoption of this standard did not have a material impact on the Company’s financial statements.

      Statement of Financial Accounting Standards No. 153, “Exchanges of Non-monetary Assets – an Amendment of APB Opinion 29” (“SFAS 153”), was issued in December 2004. Accounting Principles Board (“APB”) Opinion 29 is based on the principle that exchanges of non-monetary assets should be measured based on the fair value of assets exchanged. SFAS 153 amends APB Opinion 29 to eliminate the exception for non-monetary exchanges of similar productive assets and replaces it with a general exception for exchanges of non-monetary assets that do not have commercial substance. The standard is effective for the Company for non-monetary asset exchanges occurring in fiscal periods beginning after June 15, 2005, beginning July 1, 2005 for the Company. The adoption of this standard did not have a material impact on the Company’s financial statements.

      In March 2005, FASB Staff Position FIN 46R-5, “Implicit Variable Interests under FASB Interpretation No. 46(R), Consolidation of Variable Interest Entities”, to address whether a company has an implicit variable interest in a VIE or potential VIE when specific conditions exist. The guidance describes an implicit variable interest as an implied financial interest in an entity that changes with changes in the fair value of the entity’s net assets exclusive of variable interests. An implicit variable interest acts the same as an explicit variable interest except that it involves the absorbing and/or receiving

F-39

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

of variability indirectly from the entity (rather than directly). This guidance was adopted in 2006 and did not have a material impact on the Company’s consolidated financial statements.

     (j) Recent United States accounting pronouncements not yet adopted:

      Statement of Financial Accounting Standards No. 123R, “Share-Based Payment” (“SFAS 123R”) requires companies to recognize in the income statement, the grant-date fair value of stock options and other equity-based compensation issued to employees. The fair value of liability-classified awards is remeasured subsequently at each reporting date through the settlement date, while the fair value of equity-classified awards is not subsequently remeasured. The revised standard is effective for non-public companies beginning with the first annual reporting period that begins after December 15, 2005, which in the case of the Company is the period beginning April 1, 2006. The Company has used the fair value method under Statement 123 since its inception. The Company will be required to adopt SFAS 123R prospectively since the Company uses the minimum value method for purposes of complying with Statement 123. The Company is currently evaluating the other impacts of the revised standard.

      In May 2005, the FASB issued Statement of Financial Accounting Standards No. 154, “Accounting Changes and Error Corrections” (“SFAS 154”) which replaces Accounting Principles Board Opinions No. 20 “Accounting Changes” and Statement of Financial Accounting Standards No. 3, “Reporting Accounting Changes in Interim Financial Statements – An Amendment of APB Opinion No. 28.” SFAS 154 provides guidance on the accounting for and reporting of accounting changes and error corrections. It establishes retrospective application, or the latest practicable date, as the required method for reporting a change in accounting principle and the reporting of a correction of an error. SFAS 154 is effective for accounting changes and corrections of errors made in fiscal years beginning after December 15, 2005 and is required to be adopted by the Company in its fiscal year beginning on April 1, 2006. The Company is currently evaluating the effect that the adoption of SFAS 154 will have on its consolidated results of operations and financial position but does not expect it to have a material impact.

      Statement of Financial Accounting Standards No. 155, “Accounting for Certain Hybrid Financial Instruments – an amendment of FASB Statements No. 133 and 140” (“SFAS 155”) was issued February 2006. This Statement is effective for all financial instruments acquired, issued, or subject to a remeasurement (new basis) event occurring after the beginning of an entity’s first fiscal year that begins after September 15, 2006. The fair value election provided for in paragraph 4(c) of this Statement may also be applied upon adoption of this Statement for hybrid financial instruments that had been bifurcated under paragraph 12 of Statement 133 prior to the adoption of this Statement. This states that an entity that initially recognizes a host contract and a derivative instrument may irrevocably elect to initially and subsequently measure that hybrid financial instrument, in its entirety, at fair value with changes in fair value recognized in earnings. SFAS 155 is applicable for all financial instruments acquired or issued in the Company’s 2007 fiscal year although early adoption is permitted. The Company is currently reviewing the impact of this statement.

      In June 2006, the FASB issued Interpretation No. 48, “Accounting for Uncertainty in Income Taxes — An Interpretation of FASB Statement No. 109” (“FIN 48”) which clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, “Accounting for Income Taxes”. FIN 48 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This Interpretation also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition requirements. The Company is currently reviewing the impact of this Interpretation.

F-40

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

24. Subsequent events

      (a) On April 24, 2006, the Company reached an agreement with a customer to settle outstanding claims arising from a mining and site preparation project. The Company received a cash payment of $7,600, of which $6,059 has not previously been recognized as revenue.

      (b) On July 19, 2006, the Company entered into a new credit agreement that provides for borrowings of up to $55.0 million, subject to borrowing base limitations, under which revolving loans and letters of credit may be issued. Prime rate revolving loans under the agreement will bear interest at the Canadian prime rate plus 2.0% per annum and swing line revolving loans will bear interest at the Canadian prime rate plus 1.5% per annum. Canadian bankers’ acceptances have stamping fees equal to 3.0% per annum and letters of credit are subject to a fee of 3.0% per annum.

      Advances under the agreement are margined with a borrowing base calculation defined as the aggregate of 60.0% of the net book value of the Company’s plant and equipment, 75.0% of eligible accounts receivable and un-pledged cash in excess of $15.0 million. The sum of all borrowings (including issued letters of credit) and the mark-to-market value of the Company’s liability under existing swap agreements must not exceed the borrowing base. The credit facility is secured by a first priority lien on substantially all the Company’s existing and after-acquired property.

      The facility contains certain restrictive covenants including, but not limited to, incurring additional debt, transferring or selling assets, making investments including acquisitions or to pay dividends or redeem shares of capital stock. The Company is also required to meet certain financial covenants.

      (c) On July 21, 2006, the Company filed an initial registration statement with the U.S. Securities and Exchange Commission and a preliminary prospectus with securities commissions in every jurisdiction in Canada relating to the initial public offering of voting common shares.

      Prior to, or concurrent with, the consummation of the proposed offering, the Company, NACG Preferred Corp. and NAEPI are planning to amalgamate into one new entity, North American Energy Partners Inc. In addition, the Company is planning a share split prior to the proposed offering being completed. The voting common shares of the new entity, North American Energy Partners Inc., will be the shares offered in the proposed offering.

      Prior to the amalgamation referred to above, it is the Company’s intention to repurchase the NAEPI Series A preferred shares for their redemption value of $1.0 million and cancel the consulting and advisory services agreement with the Sponsors. The consideration to be paid for the cancellation of the consulting and advisory services agreement is still to be negotiated between the parties. In addition, it is planned that each holder of NAEPI Series B preferred shares will, for each NAEPI Series B preferred share held, receive five common shares (the number of common shares will be adjusted for the planned share split) in the amalgamated North American Energy Partners Inc. As part of the amalgamation, existing common and non-voting common shareholders of the Company will receive common and non-voting common shares of the amalgamated North American Energy Partners Inc.

      The anticipated net proceeds from the offering, after deducting underwriting fees and estimated offering expenses, are being proposed to be used to purchase certain equipment currently under operating leases and tender for all or a portion of the outstanding principal of and accrued interest on NAEPI’s 9% senior secured notes due 2010. The balance of the anticipated net proceeds would be available for general corporate purposes.

F-41

NACG HOLDINGS INC.

Notes to the Consolidated Financial Statements — (Continued)

      The completion of the proposed offering, including the planned reorganization described above, is subject to a number of approvals by the shareholders (including preferred shareholders of NACG Preferred Corp. and NAEPI), NAEPI lenders under its revolving credit facility and the approval of the registration statement and prospectus by securities regulatory authorities in the United States and Canada.

      In conjunction with the amalgamation, the Company has offered to immediately vest all stock options held by certain directors, on the condition that the options are exercised prior to August 31, 2006. The vesting period for stock options held by directors that do not accept the offer will remain unchanged.

F-42

PART II

INFORMATION NOT REQUIRED IN PROSPECTUS

Item 6. Indemnification of Directors and Officers

Applicable Laws of Canada

      Section 124 of the Canada Business Corporations Act provides that a corporation may indemnify a present or former director or officer of the corporation, or another individual who acts or acted at the corporation’s request as a director or officer, or an individual acting in a similar capacity, of another entity, against all costs, charges and expenses, including an amount paid to settle an action or satisfy a judgment, reasonably incurred by the individual in respect of any civil, criminal, administrative, investigative or other proceeding in which the individual is involved because of that association with the corporation or other entity, provided that the individual (a) acted honestly and in good faith with a view to the best interests of the corporation or, as the case may be, the other entity; and (b) in the case of a criminal or administrative action or proceeding that is enforced by a monetary penalty, had reasonable grounds for believing that the individual’s conduct was lawful.

      Section 124 of the Canada Business Corporations Act also provides that a corporation may advance moneys to a director, officer or other individual for the costs, charges and expenses of a proceeding referred to above. The individual shall repay the moneys if the individual does not fulfill the conditions set out in set out in subsections (a) and (b) above.

      A corporation may, with the approval of a court, indemnify an individual referred to above, or advance moneys as set out above, in respect of an action by or on behalf of the corporation or other entity to procure a judgment in its favour, to which the individual is made a party because of the individual’s association with the corporation or other entity against all costs, charges and expenses reasonably incurred by the individual in connection with such action, if the individual fulfills the conditions set out in subsections (a) and (b) above.

      Notwithstanding the above, an individual is entitled to indemnity from the corporation in respect of all costs, charges and expenses reasonably incurred by the individual in connection with the defense of any civil, criminal, administrative, investigative or other proceeding to which the individual is subject because of the individual’s association with the corporation or other entity as described above, if the individual seeking indemnity (a) was not judged by the court or other competent authority to have committed any fault or omitted to do anything that the individual ought to have done; (b) acted honestly and in good faith with a view to the best interests of the corporation, or, as the case may be, to the best interests of the other entity for which the individual acted as director or officer or in a similar capacity at the corporation’s request; and (c) in the case of a criminal or administrative action or proceeding that is enforced by a monetary penalty, had reasonable grounds for believing that the individual’s conduct was lawful.

By-laws

      NACG Holdings Inc.’s by-laws provide that, subject to the limitations contained in the Canada Business Corporations Act, the corporation shall indemnify a director or officer, a former director or officer, or another individual who acts or acted at the corporation’s request as a director or officer, or an individual acting in a similar capacity, of another entity, against all costs, charges and expenses, including an amount paid to settle an action or satisfy a judgment, reasonably incurred by the individual in respect of any civil, criminal, administrative, investigative or other action or proceeding in which the individual is involved because of such individual’s association with the corporation or other entity, if the individual (a) acted honestly and in good faith with a view to the best interests of the corporation, or, as the case may be, to the best interests of the other entity for which the individual acted as director or officer or in a similar capacity at the request of the corporation; and (b) in the case of a criminal or administrative action or proceeding that is enforced by a monetary penalty, the individual had reasonable grounds for believing that the individual’s conduct was lawful. The by-laws also provide that the corporation may

II-1

advance moneys to an individual entitled to indemnification for the costs, charges and expenses of such proceedings.

      NACG Holdings Inc.’s by-laws also provide that the corporation may purchase and maintain insurance for the benefit of any individual referred to above against any liability incurred by the individual in the individual’s capacity as a director or officer, or similar capacity, of the corporation or of another entity, if the individual acts or acted at the request of the corporation.

Indemnity Agreements

      NACG Holdings Inc. has entered into indemnity agreements with each of its officers and directors pursuant to which the corporation is obligated to indemnify such officer or director to the full extent permitted by applicable law. The form of such indemnity agreement is filed as an exhibit to this registration statement.

Other

      NACG Holdings Inc. maintains liability insurance policies covering its officers and directors against some liabilities, including certain liabilities under the Securities Act of 1933 and Canadian securities laws, that may be incurred by them.

      The underwriting agreement filed as Exhibit 1.1 to this registration statement provides that the underwriters are obligated, under certain circumstances, to indemnify our officers and directors and their respective controlling persons against certain liabilities, including liabilities under the Securities Act of 1933.

Item 7. Recent Sales of Unregistered Securities

      In the three years prior to the filing of this registration statement, the registrant and its subsidiaries sold the following securities which were not registered under the Securities Act:

NACG Holdings Inc.

      On October 17, 2003, NACG Holdings Inc. issued 10 common shares to Sterling Group Partners I, L.P. in exchange for $4,000 in cash in connection with the formation of NACG Holdings Inc. This sale was exempt from registration pursuant to Section 4(2) of the Securities Act as a transaction not involving a public offering.

      On November 26, 2003, NACG Holdings Inc. issued an aggregate of 904,380 common shares and 20,620 non-voting common shares to investment entities controlled by the sponsors, its executive officers and directors and certain affiliates of the sponsors in exchange for an aggregate of $92.5 million in cash in connection with the Acquisition. These sales were exempt from registration pursuant to Section 4(2) of the Securities Act as transactions not involving a public offering.

      On January 15, 2004, NACG Holdings Inc. issued an aggregate of 17,408 common shares to its directors, officers and employees and affiliates of the sponsors in exchange for an aggregate of $1.7 million in cash. NACG Holdings Inc. used the net proceeds from these sales to repurchase a like amount of its common shares from Sterling Group Partners I, L.P. These sales met the conditions of Rule 506 under the Securities Act and were therefore exempt from registration pursuant to Section 4(2) of the Securities Act.

      On December 31 2005, NACG Holdings Inc. issued an aggregate of 2,000 common shares to its executive officers in exchange for an aggregate of $200,000 in cash. On March 30, 2006, NACG Holdings Inc. issued 1,000 of its common shares to one of its directors in exchange for $100,000 in cash. These sales were exempt from registration pursuant to Section 4(2) of the Securities Act as transactions not involving a public offering.

II-2

NACG Preferred Corp.

      On November 26, 2003, NACG Preferred Corp. issued 35,000 of its Series A preferred shares to Norama Ltd. as partial consideration for the Acquisition. This sale was exempt from registration pursuant to Section 4(2) of the Securities Act as a transaction not involving a public offering.

North American Energy Partners Inc.

      On November 26, 2003, North American Energy Partners Inc. issued a total of US$200.0 million of 8³/4 % senior notes due 2011 to Qualified Institutional Buyers in a transaction that met the conditions of Rule 144A and to offshore buyers in a transaction that met the conditions of Regulation S under the Securities Act.

      On May 19, 2005, North American Energy Partners Inc. issued US$60.5 million of 9% senior secured notes due 2010 to Qualified Institutional Buyers in a transaction that met the conditions of Rule 144A and to offshore buyers in a transaction that met the conditions of Regulation S under the Securities Act.

      On May 19, 2005, North American Energy Partners Inc. issued 75,000 (adjusted for a subsequent 10-for-1 share split) of its Series B preferred shares to investment entities controlled by the sponsors in exchange for $7.5 million in cash. This sale was exempt from registration pursuant to Section 4(2) of the Securities Act as a transaction not involving a public offering.

      On May 19, 2005, North American Energy Partners Inc. issued 1,000 of its Series A preferred shares to BNP Paribas, the lender under North American Energy Partners Inc.’s revolving credit facility, as partial consideration for entering into a new revolving credit facility. This sale was exempt from registration pursuant to Section 4(2) of the Securities Act as a transaction not involving a public offering.

      On August 31, 2005, North American Energy Partners Inc. issued an aggregate of 8,218 of its Series B preferred shares to existing common shareholders of NACG Holdings Inc. in exchange for an aggregate of $821,800 in cash. North American Energy Partners Inc. used the net proceeds from these sales to repurchase a like amount of Series B preferred shares from investment entities controlled by the sponsors on a pro rata basis in accordance with their percentage ownership of Series B preferred shares. These sales met the conditions of Rule 506 under the Securities Act and were therefore exempt from registration pursuant to Section 4(2) of the Securities Act.

      On December 31, 2005, North American Energy Partners Inc. issued an aggregate of 163 of its Series B preferred shares to its executive officers in exchange for $16,300 in cash. On March 30, 2006, North American Energy Partners Inc. issued 81 of its Series B preferred shares to one of its directors in exchange for $8,100 in cash. These sales were exempt from registration pursuant to Section 4(2) of the Securities Act as transactions not involving a public offering.

Item 8. Exhibits and Financial Statement Schedules

(a) Exhibits

Exhibit
Number				Description
	1	.1*	—	Form of underwriting agreement.
	3	.1	—	Articles of Incorporation of NACG Holdings Inc., as amended.
	3	.2	—	By-law No. 1 of NACG Holdings Inc.
	4	.1	—	Registration Rights Agreement, dated as of November 26, 2003, among NACG Holdings Inc. and the shareholders party thereto.
	4	.2*	—	2004 Share Option Plan.
	5	.1*	—	Opinion of Bracewell & Giuliani LLP.
	5	.2*	—	Opinion of Borden Ladner Gervais LLP.

II-3

Exhibit
Number				Description
	10	.1	—	First Amended and Restated Credit Agreement, dated as of July 19, 2006, among North American Energy Partners Inc., the lenders named therein and BNP Paribas (Canada), as Administrative Agent and Collateral Agent.
	10	.2	—	Intercreditor Agreement, dated as of May 19, 2005, between GE Finance Canada Holding Company, Wells Fargo Bank, N.A. and Computershare Trust Company of Canada, and consented to by North American Energy Partners Inc. and its subsidiaries (filed as Exhibit 10.2 to North American Energy Partners Inc.’s registration statement on Form F-4, Registration No. 333-125610 (the “2005 Registration Statement”), and incorporated herein by reference).
	10	.3	—	Form of Indemnity Agreement between NACG Holdings Inc., NACG Preferred Corp., North American Energy Partners Inc., North American Construction Group Inc. and their respective officers and directors (filed as Exhibit 10.3 to the 2005 Registration Statement and incorporated herein by reference).
	10	.4	—	Indenture, dated as of November 26, 2003, among North American Energy Partners Inc., the guarantors named therein and Wells Fargo Bank, N.A., as Trustee (filed as Exhibit 4.1 to North American Energy Partners Inc.’s registration statement on Form F-4, Registration No. 333-111396, and incorporated herein by reference).
	10	.5	—	Indenture, dated as of May 19, 2005, among North American Energy Partners Inc., the guarantors named therein and Wells Fargo Bank, N.A., as Trustee (filed as Exhibit 4.1 to the 2005 Registration Statement and incorporated herein by reference).
	10	.6*	—	Employment Agreement with Rodney J. Ruston.
	10	.7*	—	Employment Agreement with Vincent J. Gallant.
	10	.8*	—	Employment Agreement with Robert G. Harris.
	10	.9*	—	Employment Agreement with Christopher J. Hayman.
	10	.10*	—	Employment Agreement with William M. Koehn.
	10	.11*	—	Employment Agreement with Miles W. Safranovich.
	21	.1	—	Subsidiaries of NACG Holdings Inc.
	23	.1*	—	Consent of Bracewell & Giuliani LLP (included in their opinion filed as Exhibit 5.1).
	23	.2*	—	Consent of Borden Ladner Gervais LLP (included in their opinion filed as Exhibit 5.2).
	23	.3	—	Consent of KPMG LLP.
	24	.1	—	Powers of attorney.

*  To be filed by amendment.

      (b) Financial Statement Schedules

Schedule II — Valuation And Qualifying Accounts

Allowance for doubtful accounts receivable

	Balance,		Charged to
	Beginning of		Costs and						Balance,
	Period		Expense(1)			Deductions(2)			End of Period
April 1, 2003 to November 25, 2003 (Predecessor)	$	152,000	$	141,000		$	—		$	293,000
November 26, 2003 to March 31, 2004		293,000		47,836			(12,164	)		233,000
April 1, 2004 to March 31, 2005		233,000		(40,376	)		(109,789	)		163,589
April 1, 2005 to March 31, 2006		163,589		(93,830	)		(187,661	)		69,758

(1)	Represents increase (decrease) in allowance for doubtful accounts receivable charged to expense.
(2)	Represents the accounts receivable written-off against the allowance for doubtful accounts receivable.

II-4

Future income tax asset valuation allowance

	Balance,		Charged to
	Beginning of		Costs and					Balance,
	Period		Expense(1)			Deductions		End of Period
April 1, 2003 to November 25, 2003 (Predecessor)	$	—	$	—		$	—	$	—
November 26, 2003 to March 31, 2004		—		—			—		—
April 1, 2004 to March 31, 2005		—		9,955			—		9,955
April 1, 2005 to March 31, 2006		9,955		(4,097	)		—		5,858

(1)  Represents increase (decrease) in valuation allowance charged to provision for future income taxes.

Item 9. Undertakings

      The undersigned registrant hereby undertakes to provide to the underwriters at the closing specified in the underwriting agreement certificates in such denominations and registered in such names as required by the underwriters to permit prompt delivery to each purchaser.

      Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to directors, officers and controlling persons of the registrant pursuant to the foregoing provisions, or otherwise, the registrant has been advised that in the opinion of the Securities and Exchange Commission such indemnification is against public policy as expressed in the Securities Act of 1933 and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the registrant of expenses incurred or paid by a director, officer or controlling person of the registrant in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, the registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Securities Act of 1933 and will be governed by the final adjudication of such issue.

      The undersigned registrant hereby undertakes that:

      (1) For purposes of determining any liability under the Securities Act of 1933, the information omitted from the form of prospectus filed as part of this registration statement in reliance upon Rule 430A and contained in a form of prospectus filed by the registrant pursuant to Rule 424(b)(1) or (4) or 497(h) under the Securities Act shall be deemed to be part of this registration statement as of the time it was declared effective.

      (2) For the purpose of determining any liability under the Securities Act of 1933, each post-effective amendment that contains a form of prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

II-5

SIGNATURES

      Pursuant to the requirements of the Securities Act of 1933, the registrant certifies that it has reasonable grounds to believe that it meets all of the requirements for filing on Form F-1 and has duly caused this registration statement, or amendment thereto, to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Acheson, Alberta, Canada, on July 21, 2006.

NACG Holdings Inc.

By:  /s/ Vincent J. Gallant

Vincent J. Gallant

Vice President, Corporate

      Pursuant to the requirements of the Securities Act of 1933, this registration statement, or amendment thereto, has been signed by the following persons in the capacities indicated on July 21, 2006.

Name		Title
/s/ Rodney J. Ruston Rodney J. Ruston		Director, President and Chief Executive Officer (Principal Executive Officer)
/s/ Christopher J. Hayman Christopher J. Hayman		Vice President, Finance (Principal Financial and Accounting Officer)
* George R. Brokaw		Director
* John A. Brussa		Director
* Donald R. Getty		Director
* Martin P. Gouin		Director
/s/ John D. Hawkins John D. Hawkins		Director and authorized representative in the United States
/s/ Ronald A. McIntosh Ronald A. McIntosh		Chairman
* William C. Oehmig		Director
* Richard D. Paterson		Director
* Allen R. Sello		Director
* K. Rick Turner		Director
Constituting all of the Board of Directors
*By:	/s/ Vincent J. Gallant  Vincent J. Gallant Attorney-in-fact for persons indicated

II-6

EXHIBIT INDEX

Exhibit
Number				Description
	1	.1*	—	Form of underwriting agreement.
	3	.1	—	Articles of Incorporation of NACG Holdings Inc., as amended.
	3	.2	—	By-law No. 1 of NACG Holdings Inc.
	4	.1	—	Registration Rights Agreement, dated as of November 26, 2003, among NACG Holdings Inc. and the shareholders party thereto.
	4	.2*	—	2004 Share Option Plan.
	5	.1*	—	Opinion of Bracewell & Giuliani LLP.
	5	.2*	—	Opinion of Borden Ladner Gervais LLP.
	10	.1	—	First Amended and Restated Credit Agreement, dated as of July 19, 2006, among North American Energy Partners Inc., the lenders named therein and BNP Paribas (Canada), as Administrative Agent and Collateral Agent.
	10	.2	—	Intercreditor Agreement, dated as of May 19, 2005, between GE Finance Canada Holding Company, Wells Fargo Bank, N.A. and Computershare Trust Company of Canada, and consented to by North American Energy Partners Inc. and its subsidiaries (filed as Exhibit 10.2 to North American Energy Partners Inc.’s registration statement on Form F-4, Registration No. 333-125610 (the “2005 Registration Statement”), and incorporated herein by reference).
	10	.3	—	Form of Indemnity Agreement between NACG Holdings Inc., NACG Preferred Corp., North American Energy Partners Inc., North American Construction Group Inc. and their respective officers and directors (filed as Exhibit 10.3 to the 2005 Registration Statement and incorporated herein by reference).
	10	.4	—	Indenture, dated as of November 26, 2003, among North American Energy Partners Inc., the guarantors named therein and Wells Fargo Bank, N.A., as Trustee (filed as Exhibit 4.1 to North American Energy Partners Inc.’s registration statement on Form F-4, Registration No. 333-111396, and incorporated herein by reference).
	10	.5	—	Indenture, dated as of May 19, 2005, among North American Energy Partners Inc., the guarantors named therein and Wells Fargo Bank, N.A., as Trustee (filed as Exhibit 4.1 to the 2005 Registration Statement and incorporated herein by reference).
	10	.6*	—	Employment Agreement with Rodney J. Ruston.
	10	.7*	—	Employment Agreement with Vincent J. Gallant.
	10	.8*	—	Employment Agreement with Robert G. Harris.
	10	.9*	—	Employment Agreement with Christopher J. Hayman.
	10	.10*	—	Employment Agreement with William M. Koehn.
	10	.11*	—	Employment Agreement with Miles W. Safranovich.
	21	.1	—	Subsidiaries of NACG Holdings Inc.
	23	.1*	—	Consent of Bracewell & Giuliani LLP (included in their opinion filed as Exhibit 5.1).
	23	.2*	—	Consent of Borden Ladner Gervais LLP (included in their opinion filed as Exhibit 5.2).
	23	.3	—	Consent of KPMG LLP.
	24	.1	—	Powers of attorney.

*  To be filed by amendment.