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As filed with the Securities and Exchange Commission on August 31, 2011

Registration No. 333-            

 

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM S-1

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

 

 

Forum Energy Technologies, Inc.

(Exact name of registrant as specified in its charter)

 

Delaware		3533		61-1488595
(State or other jurisdiction of incorporation or organization)		(Primary Standard Industrial Classification Code Number)		(I.R.S. Employer Identification No.)

920 Memorial City Way, Suite 800

Houston, Texas 77024

(281) 949-2500

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

James L. McCulloch

Senior Vice President, General Counsel and Secretary

Forum Energy Technologies, Inc.

920 Memorial City Way, Suite 800

Houston, Texas 77024

(281) 949-2500

(Name, address, including zip code, and telephone number, including area code, of agent for service)

 

 

Copies to:

 

W. Matthew Strock Sarah K. Morgan Vinson & Elkins L.L.P. 1001 Fannin, Suite 2500 Houston, Texas 77002-6760 (713) 758-2222				J. David Kirkland, Jr. Tull R. Florey Baker Botts L.L.P. 910 Louisiana Houston, Texas 77002-4995 (713) 229-1234

 

 

Approximate date of commencement of proposed sale 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: ¨

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

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

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

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

 

Large accelerated filer ¨		Accelerated filer  ¨		Non-accelerated filer x		Smaller reporting company ¨
				(Do not check if a smaller reporting company)

CALCULATION OF REGISTRATION FEE

 

Title of Each Class of Securities to Be Registered		Proposed maximum aggregate offering price (1)(2)		Amount of registration fee
Common Stock, par value $0.01 per share		$300,000,000		$34,830

 

(1)

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

 

(2)

Estimated solely for the purpose of calculating the registration fee pursuant to Rule 457(o) under the Securities Act of 1933.

The registrant hereby amends this Registration Statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until this Registration Statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.

 

 

 

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The information in this prospectus is not complete and may be changed. We and the selling stockholders 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 we and the selling stockholders are not soliciting offers to buy these securities in any state where the offer or sale is not permitted.

 

Subject to completion, dated August 31, 2011

Prospectus

            shares

Forum Energy Technologies, Inc.

Common stock

Forum Energy Technologies, Inc. is offering         shares of its common stock and the selling stockholders are offering         shares of common stock. This is an initial public offering of our common stock. We anticipate that the initial public offering price of our common stock will be between $         and $         per share.

We intend to apply to list our common stock on the New York Stock Exchange under the symbol “FET.”

 

		Per share				Total
Initial public offering price		$				$
Underwriting discounts and commissions		$				$
Proceeds to Forum Energy Technologies, Inc., before expenses		$				$
Proceeds to selling stockholders, before expenses		$				$

Forum Energy Technologies, Inc. has granted the underwriters an option for a period of 30 days to purchase up to additional         shares of common stock and the selling stockholders have granted the underwriters an option for a period of 30 days to purchase up to additional          shares of common stock. We will not receive any proceeds from the sale of shares by the selling stockholders.

Delivery of the shares of common stock is expected to be made on or about                     , 2011.

Investing in our common stock involves risks. See “Risk factors” beginning on page 21.

Neither the Securities and Exchange Commission nor any other 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.

J.P. Morgan

                    , 2011

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Prospectus summary			1
The offering			15
Risk factors			21
Cautionary note regarding forward-looking statements			40
Use of proceeds			42
Stock split			43
Dividend policy			43
Capitalization			44
Dilution			45
Unaudited pro forma condensed combined financial data			47
Selected historical consolidated financial data			56
Management’s discussion and analysis of financial condition and results of operations			59
Business			86
Management			125
Executive compensation and other information			133
Certain relationships and related party transactions			161
Principal and selling stockholders			168
Description of capital stock			170
Shares eligible for future sale			175
Material U.S. federal income and estate tax considerations to non-U.S. holders			177
Underwriting (conflicts of interest)			181
Legal matters			189
Experts			189
Where you can find more information			190
Index to consolidated financial statements			F-1
Glossary			A-1

You should rely only on the information contained in this prospectus and any free writing prospectus prepared by or on behalf of us or to which we have referred you. Neither we nor any of the selling stockholders has authorized anyone to provide you with information different from that contained in this prospectus and any free writing prospectus. We and the selling stockholders are offering to sell shares of common stock and seeking offers to buy shares of common stock only in jurisdictions where offers and sales are permitted. The information in this prospectus is accurate only as of the date of this prospectus, regardless of the time of delivery of this prospectus or any sale of the common stock.

Until                     , 2011, all dealers that buy, sell or trade our common stock, whether or not participating in this offering, may be required to deliver a prospectus. This requirement is in addition to the dealers’ obligation to deliver a prospectus when acting as underwriters and with respect to their unsold allotments or subscriptions.

 

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Industry and market data

The market data and certain other statistical information used throughout this prospectus are based on independent industry publications, government publications or other published independent sources. Some data is also based on our good faith estimates and our management’s understanding of industry conditions.

 

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Risk factors

You should carefully consider the risks described below before making an investment decision. Our business, financial condition, results of operations or cash flow could be materially adversely affected by any of these risks. The trading price of our common stock could decline due to any of these risks, and you may lose all or part of your investment.

Risks related to our business

We derive a substantial portion of our revenues from companies in or affiliated with the oil and natural gas industry, a historically cyclical industry, with levels of activity that are significantly affected by the levels and volatility of oil and natural gas prices. As a result, this cyclicality may cause fluctuations in our revenues and results of our operations.

We have experienced, and expect to continue to experience, fluctuations in revenues and operating results due to economic and business cycles. The willingness of oil and natural gas operators to make capital expenditures to explore for and produce oil and natural gas and the willingness of oilfield service companies to invest in capital equipment depends largely upon prevailing industry conditions that are influenced by numerous factors over which we have no control, such as:

 

•

the supply of and demand for oil and natural gas;

 

•

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

 

•

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

 

•

the level of drilling activity and drilling day rates;

 

•

the expected decline rates of current and future production;

 

•

the discovery rates of new oil and natural gas reserves;

 

•

the ability of our customers to access new markets or areas of production or to continue to access current markets;

 

•

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

 

•

more stringent restrictions in environmental regulation on activities that may impact the environment;

 

•

moratoriums on drilling activity resulting in a cessation or disruption of operations;

 

•

domestic and worldwide economic conditions;

 

•

political instability in oil and natural gas producing countries;

 

•

conservation measures and technological advances affecting energy consumption;

 

•

the price and availability of alternative fuels; and

 

•

merger and divestiture activity among oil and natural gas producers and drilling contractors.

 

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The oil and natural gas industry historically has experienced significant volatility. For example, since January 1, 2008, the WTI Cushing crude oil spot price has ranged from a low of $30.52 per Bbl on December 23, 2008 to a high of $146.30 per Bbl on July 11, 2008. Since January 1, 2008, the Henry Hub natural gas spot price has ranged from a low of $1.64 per Mcf on September 4, 2009 to a high of $13.41 per Mcf on July 2, 2008. The Henry Hub natural gas spot price on August 30, 2011 was $3.86 per Mcf, while the WTI Cushing crude oil spot price on August 26, 2011 was $88.90 per barrel.

Any prolonged reduction in the overall level of exploration and development activities, whether resulting from changes in oil and natural gas prices or otherwise, could adversely impact our business in many ways by negatively affecting:

 

•

revenues, cash flows, and profitability;

 

•

the ability to maintain or increase borrowing capacity;

 

•

the ability to obtain additional capital to finance our business and the cost of that capital; and

 

•

the ability to attract and retain skilled personnel needed in the event of an upturn in the demand for services.

Our inability to control the inherent risks of acquiring and integrating businesses could disrupt our business, dilute stockholder value and adversely affect our operating results going forward.

We have pursued and intend to continue to pursue strategic acquisitions of complementary assets and businesses in the future, which could distract management from day-to-day tasks. Acquisitions involve numerous risks, including:

 

•

unanticipated costs and exposure to unforeseen liabilities;

 

•

difficulty in integrating the operations and assets of the acquired businesses;

 

•

potential loss of key employees and customers of the acquired company;

 

•

potential inability to properly establish and maintain effective internal controls over an acquired company; and

 

•

risk of entering markets in which we have limited prior experience.

Our failure to achieve consolidation savings, to incorporate the acquired businesses and assets into our existing operations successfully or to minimize any unforeseen operational difficulties could have a material adverse effect on our business. In addition, we may incur indebtedness to finance future acquisitions and also may issue equity securities in connection with such acquisitions. Debt service requirements could represent a burden on our results of operations and financial condition and the issuance of additional equity securities could be dilutive to our existing stockholders.

In addition to potential future acquisitions, the ongoing integration of our business in connection with the Combination and the eight acquisitions we have completed since the Combination presents a number of risks that could affect our results of operations. In particular, integrating the businesses from the Combination and our subsequent acquisitions is difficult and involves a number of special risks, including the diversion of management’s attention to the assimilation of the operations, the unpredictability of costs related to the Combination and our subsequent acquisitions and the difficulty of integration of the businesses, products, services,

 

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technology and employees. The ability to achieve the anticipated benefits of the Combination and each of our other recent acquisitions will depend, in part, upon whether the integration of the various businesses, products, services, technology and employees is accomplished in an efficient and effective manner, and there can be no assurance that this will occur.

The difficulties of such integration may be increased by the geographic breadth of the combined operations and the necessity of integrating and combining different corporate cultures. The inability of management to successfully integrate any one or all of the businesses could have a material adverse effect on our business, operating results and financial condition. Moreover, there can be no assurance that we will be able to gain market share or penetrate new markets successfully or that we will obtain the anticipated or desired benefits of the Combination and our other recent or future acquisitions. Despite management’s belief that each of our products, services and operations will provide an increased breadth of services and sufficient “critical mass” in key operating areas, there can be no assurance that each of the services will gain acceptance by our other business segments or our current customers or that they will enable us to gain market share or penetrate new markets. If we fail to manage these risks successfully, our results of operations could be adversely affected.

Our operating history may not be sufficient for investors to evaluate our business and prospects.

We are a recently combined company with a short combined operating history. In addition, we have completed eight acquisitions since the Combination. These factors may make it more difficult for investors to evaluate our business and prospects and to forecast our future operating results. The historical consolidated financial statements included in this prospectus are based on the separate businesses of FOT, Global Flow, Triton, Allied and Subsea for the periods prior to the Combination. The unaudited pro forma condensed combined financial statements included in this prospectus are based on the separate financial statements of our company and the eight businesses we have acquired prior to the dates of such acquisitions. As a result, the historical and pro forma financial data may not give you an accurate indication of what our actual results would have been if the Combination or the 2011 Acquisitions had been completed at the beginning of the periods presented or of what our future results of operations are likely to be. Our future results will depend on our ability to efficiently manage our combined operations and execute our business strategy.

If we cannot continue operating our manufacturing facilities at current levels, our results of operations could be adversely affected.

We operate a number of manufacturing facilities. The equipment and management systems necessary for such operations may break down, perform poorly or fail, resulting in fluctuations in manufacturing efficiencies. Such fluctuations may affect our ability to deliver products to our customers on a timely basis.

Growing our business organically through the expansion of our existing product lines and facilities subjects us to risks of construction delays and cost overruns.

One of the ways that we grow our businesses is through the construction of new facilities and expansions to our existing facilities. These projects, and any other capital asset construction projects which we may commence, are subject to similar risks of delay or cost overrun inherent in any construction project resulting from numerous factors, including the following:

 

•

difficulties or delays in obtaining land;

 

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•

shortages of key equipment, materials or skilled labor;

 

•

unscheduled delays in the delivery of ordered materials and equipment;

 

•

unanticipated cost increases;

 

•

weather interferences; and

 

•

difficulties in obtaining necessary permits or in meeting permit conditions.

We may be unable to employ a sufficient number of skilled and qualified workers.

The delivery of our products and services requires personnel with specialized skills and experience. Our ability to be productive and profitable will depend upon our ability to employ and retain skilled workers. In addition, our ability to expand our operations depends in part on our ability to increase the size of our skilled labor force. The demand for skilled workers is high, the supply is limited and the cost to attract and retain qualified personnel has increased over the past few years. A significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force, increases in the wage rates that we must pay, or both. If either of these events were to occur, our capacity and profitability could be diminished and our growth potential could be impaired.

The current pace of spending for drilling rigs and other capital intensive equipment may not be sustainable over time, and our financial results may suffer to the extent they are dependent on sales of such equipment.

In various segments of the energy industry there is significantly increased demand for construction of capital intensive equipment, some of which has a long life once introduced into the industry. This could produce excess supply of equipment for many years, reducing dayrates and undermining the economics for new capital equipment orders. In addition, many oil field products manufacturers have increased manufacturing capacity to accommodate the increased demand for capital intensive equipment. If these levels of activity do not continue, an increased competitive environment for capital equipment could result, which could lead to lower prices and utilization for our customers and a decreased demand for capital equipment products. Similarly, excess manufacturing capacity in our industry could lead to increased competition. Our strategy is to serve a variety of segments and spend cycles, but to the extent our financial results are impacted by capital equipment construction, our results may decline should an excess supply of capital equipment materialize.

Our business depends upon our ability to obtain key raw materials and specialized equipment from suppliers. Increased costs of raw materials and other components may result in increased operating expenses.

Should our current suppliers be unable to provide the necessary raw materials or finished products or otherwise fail to deliver such materials and products timely and in the quantities required, resulting delays in the provision of products or services to customers could have a material adverse effect on our business. In particular, because many of our products are manufactured out of steel, we are particularly susceptible to fluctuations in steel prices. Our results of operations may be adversely affected by our inability to manage the rising costs and availability of raw materials and components used in our products.

 

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If suppliers cannot provide adequate quantities of materials to meet customers’ demands on a timely basis or if the quality of the materials provided does not meet established standards, we may lose customers or experience lower profitability.

Some of our customer contracts require us to compensate customers if we do not meet specified delivery obligations. We expect to rely on numerous suppliers to provide required materials and in many instances these materials must meet certain specifications. Managing a geographically diverse supply base inherently poses significant logistical challenges. Furthermore, the ability of third party suppliers to deliver materials to our specifications may be affected by events beyond our control. As a result, there is a risk that we could experience diminished supplier performance resulting in longer than expected lead times and/or product quality issues. For example, we have in the past experienced issues with the quality of certain forgings used to produce materials that are used in our products. As a result, we were required to seek alternative suppliers for those forgings, which resulted in increased costs and a disruption in our supply chain. We have also been required in certain circumstances to provide better economic terms to some of our suppliers in exchange for their agreement to increase their capacity in order to satisfy our supply needs. The occurrence of any of the foregoing factors could have a negative impact on our ability to deliver products to customers within committed time frames.

We are subject to the risk of supplier concentration.

Certain of our product lines depend on a limited number of third party suppliers and vendors. As a result of this concentration in some of our supply chains, our business and operations could be negatively affected if our key suppliers were to experience significant disruptions affecting the price, quality, availability or timely delivery of their products. For example, we have a limited number of vendors for our bearings product lines. The partial or complete loss of any one of our key suppliers, or a significant adverse change in the relationship with any of these suppliers, through consolidation or otherwise, would limit our ability to manufacture and sell certain of our products.

Our operations and our customers’ operations are subject to a variety of governmental laws and regulations that may increase our costs, limit the demand for our products and services or restrict our operations.

Our business and our customers’ businesses may be significantly affected by:

 

•

federal, state and local and non-U.S. laws and other regulations relating to oilfield operations, worker safety and protection of the environment;

 

•

changes in these laws and regulations; and

 

•

the level of enforcement of these laws and regulations.

In addition, we depend on the demand for our products and services from the oil and gas industry. This demand is affected by changing taxes, price controls and other laws and regulations relating to the oil and gas industry in general. For example, the adoption of laws and regulations curtailing exploration and development drilling for oil and gas for economic or other policy reasons could adversely affect our operations by limiting demand for our products. In addition, some non-U.S. countries may adopt regulations or practices that give advantage to indigenous oil companies in bidding for oil leases, or require indigenous companies to perform oilfield services currently supplied by international service companies. To the extent that such

 

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companies are not our customers, or we are unable to develop relationships with them, our business may suffer. We cannot determine the extent to which our future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.

Because of our non-U.S. operations and sales, we are also subject to changes in non-U.S. laws and regulations that may encourage or require hiring of local contractors or require non-U.S. contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. If we fail to comply with any applicable law or regulation, our business, results of operations or financial condition may be adversely affected.

If we are unable to accurately predict customer demand or if customers cancel their orders on short notice, we may hold excess or obsolete inventory, which would reduce gross margins. Conversely, insufficient inventory would result in lost revenue opportunities and potentially in loss of market share and damaged customer relationships.

Customers can generally cancel or defer purchase orders on short notice without incurring a significant penalty. As a result, we cannot accurately predict what or how many products such customers will need in the future. Anticipating demand is difficult because our customers face unpredictable demand for their own products and are increasingly focused on cash preservation and tighter inventory management.

Orders are placed with our suppliers based on forecasts of customer demand and, in some instances, we may establish buffer inventories to accommodate anticipated demand. These forecasts are based on multiple assumptions, each of which may introduce errors into the estimates. In addition, many of our supplies require a longer lead time to provide products than our customers demand for delivery of our finished products. If we overestimate customer demand, we may allocate resources to the purchase of material or manufactured products that we may not be able to sell when we expect to, if at all. As a result, we would hold excess or obsolete inventory, which would reduce gross margin and adversely affect financial results. Conversely, if we underestimate customer demand or if insufficient manufacturing capacity is available, we would miss revenue opportunities and potentially lose market share and damage our customer relationships. In addition, any future significant cancellations or deferrals of product orders or the return of previously sold products could materially and adversely affect profit margins, increase product obsolescence and restrict our ability to fund our operations.

The markets in which we operate are highly competitive, and some of our competitors hold substantial market share and have substantially greater resources than we do. We may not be able to compete successfully in this environment and, in particular, against a much larger competitor.

The markets in which we operate are highly competitive and our products and services are subject to competition from significantly larger businesses. One competitor in particular holds substantial market share in our largest product line’s market and has substantially greater resources than we do. We have several other competitors that also are large national and multi-national companies that have longer operating histories, greater financial, technical and other resources and greater name recognition than we do. Some of our competitors may be able to respond more quickly to new or emerging technologies and services and changes in customer requirements. In addition, several of our competitors provide a much broader array of services and have a stronger presence in more geographic markets. Our larger competitors may be able to use their size and purchasing power to seek economies of scale and pricing concessions.

 

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Furthermore, some of our customers are also our competitors and they may cease buying from us. We also have competitors outside the United States with lower structural costs due to labor and raw material cost in and around their manufacturing centers.

New competitors also could enter these markets. We consider product quality, performance, price, distribution capabilities and breadth of product offerings to be the primary competitive factors. Competitors may be able to offer more attractive pricing, duplicate strategies, or develop enhancements to products that could offer performance features that are superior to our products. In addition, we may not be able to retain key employees of entities that we acquire in the future and those employees may choose to compete against us. Competitive pressures, including those described above, and other factors could adversely affect our competitive position, resulting in a loss of market share or decreases in prices. In addition, some competitors are based in foreign countries and have cost structures and prices based on foreign currencies. Accordingly, currency fluctuations could cause U.S. dollar-priced products to be less competitive than our competitors’ products that are priced in other currencies. For more information about our competitors, please read “Business—Competition.”

Our operations are subject to hazards inherent in the oil and gas industry and, as a result, we are exposed to potential liabilities that may affect our financial condition and reputation.

Risks inherent to our industry, such as equipment malfunctions and failures, equipment misuse and defects, explosions and uncontrollable flows of oil, natural gas or well fluids and natural disasters, can cause personal injury, loss of life, suspension of operations, damage to formations, damage to facilities, business interruption and damage to or destruction of property, equipment and the environment. These risks could expose us to substantial liability for personal injury, wrongful death, property damage, loss of oil and gas production, pollution and other environmental damages. The frequency and severity of such incidents will affect operating costs, insurability and relationships with customers, employees and regulators. In particular, our customers may elect not to purchase our services if they view our safety record as unacceptable, which could cause us to lose customers and substantial revenues. In addition, these risks may be greater for us because we may acquire companies that have not allocated significant resources and management focus to safety and have a poor safety record requiring rehabilitative efforts during the integration process.

Our customers could seek damages for losses associated with these errors, defects or other performance problems. Our insurance policies may not be adequate to cover all liabilities. Further, insurance may not be generally available in the future or, if available, insurance premiums may make such insurance commercially unjustifiable. Moreover, even if we are successful in defending a claim, it could be time-consuming and costly to defend.

Our operations are subject to environmental and operational safety laws and regulations that may expose us to significant costs and liabilities.

Our operations are subject to numerous stringent and complex laws and regulations governing the discharge of materials into the environment, health and safety aspects of our operations, or otherwise relating to human health and environmental protection. These laws and regulations may, among other things, regulate the management and disposal of hazardous and non-hazardous wastes; require acquisition of environmental permits related to our operations; restrict the types, quantities, and concentrations of various materials that can be released into the environment; limit or prohibit operational activities in certain ecologically sensitive and other

 

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protected areas; regulate specific health and safety criteria addressing worker protection; require compliance with operational and equipment standards; impose testing, reporting and record- keeping requirements; and require remedial measures to mitigate pollution from former and ongoing operations. Failure to comply with these laws and regulations or to obtain or comply with permits may result in the assessment of administrative, civil and criminal penalties, imposition of remedial or corrective action requirements and the imposition of injunctions to prohibit certain activities or force future compliance. Certain environmental laws may impose joint and several liability, without regard to fault or legality of conduct, on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment.

The trend in environmental regulation has been to impose increasingly stringent restrictions and limitations on activities that may impact the environment. The implementation of new laws and regulations could result in materially increased costs, stricter standards and enforcement, larger fines and liability and increased capital expenditures and operating costs, particularly for our customers.

Our executive officers and certain key personnel are critical to our business and these officers and key personnel may not remain with us in the future.

Our future success depends in substantial part on our ability to hire and retain our executive officers and other key personnel. We may not be able to enforce all of the provisions in any employment agreement we have entered into with certain of our executive officers and such employment agreements may not otherwise be effective in retaining such individuals. In addition, we may not be able to retain key employees of entities that we acquire in the future. This may impact our ability to successfully integrate or operate the assets we acquire.

The industry in which we operate is undergoing continuing consolidation that may impact results of operations.

Some of our largest customers have consolidated and are using their size and purchasing power to achieve economies of scale and pricing concessions. This consolidation may result in reduced capital spending by such customers or the acquisition of one or more of our other primary customers, which may lead to decreased demand for our products and services. If we cannot maintain sales levels for customers that have consolidated or replace such revenues with increased business activities from other customers, this consolidation activity could have a significant negative impact on results of operations or financial condition. We are unable to predict what effect consolidations in the industries may have on prices, capital spending by customers, selling strategies, competitive position, ability to retain customers or ability to negotiate favorable agreements with customers.

If we are unable to continue operating successfully overseas or to successfully expand into new international markets, our revenues may decrease.

For the year ended December 31, 2010, we derived approximately 43% of our pro forma revenue from sales outside the United States (based on product destination). In addition, one of our key growth strategies is to market products in international markets. We may not succeed in marketing, developing a recognized brand, selling, distributing products and generating revenues in these new international markets.

 

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Our non-U.S. operations will subject us to special risks.

We are subject to the various risks inherent in conducting business operations in locations outside the United States. These risks may include changes in regional, political or economic conditions, local laws and policies, including taxes, trade protection measures, and unexpected changes in regulatory requirements governing the operations of companies that operate outside of the United States. From time to time, fluctuations in currency exchange rates could be material to us depending upon, among other things, our manufacturing locations and the sourcing for our raw materials and components. In particular, we are sensitive to fluctuations in currency exchange rates between the United States dollar and each of the Canadian dollar, the British pound sterling, and, to a lesser degree, the Mexican Peso, the Euro, the Chinese Yuan and the Singapore dollar. There may be instances in which costs and revenue will not be matched with respect to currency denomination. As a result, to the extent that we continue our expansion on a global basis, management expects that increasing portions of revenue, costs, assets and liabilities will be subject to fluctuations in foreign currency valuations. We may experience economic loss and a negative impact on earnings or net assets solely as a result of foreign currency exchange rate fluctuations. Further, the markets in which we operate could restrict the removal or conversion of the local or foreign currency, resulting in our inability to hedge against these risks.

In addition, if a dispute arises from international operations, courts outside the United States may have exclusive jurisdiction over the dispute, or we may not be able to subject persons outside the United States to the jurisdiction of U.S. courts.

Local laws and customs in many countries differ significantly from those in the United States. In many countries, particularly in those with developing economies, it is common to engage in business practices that are prohibited by U.S. regulations applicable to us. The United States Foreign Corrupt Practices Act (“FCPA”) and similar anti-bribery laws in other jurisdictions, including the UK Bribery Act 2010, prohibit corporations and individuals, including us and our employees, from engaging in certain activities to obtain or retain business or to influence a person working in an official capacity. We are responsible for any violations by our employees, contractors and agents, whether based within or outside the United States, for violations of the FCPA. In addition, our non-U.S. competitors that are not subject to the FCPA or similar laws may be able to secure business or other preferential treatment in such countries by means that such laws prohibit with respect to us. The UK Bribery Act 2010 is broader in scope than the FCPA and applies to public and private sector corruption and contains no facilitating payments exception. A violation of any of these laws, even if prohibited by our policies, could have a material adverse effect on our business. Actual or alleged violations could damage our reputation, be expensive to defend, and impair our ability to do business.

Compliance with U.S. regulations on trade sanctions and embargoes administered by the United States Department of the Treasury’s Office of Foreign Assets Control (“OFAC”) also pose a risk to us. We cannot provide products or services to certain countries subject to U.S. trade sanctions. Furthermore, the laws and regulations concerning import activity, export recordkeeping and reporting, export control and economic sanctions are complex and constantly changing. Any failure to comply with applicable legal and regulatory trading obligations could result in criminal and civil penalties and sanctions, such as fines, imprisonment, debarment from governmental contracts, seizure of shipments and loss of import and export privileges.

 

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Unionization efforts and labor regulations in certain areas in which we operate could materially increase our costs or limit our flexibility.

We are not a party to any collective bargaining agreements, other than in our Monterrey, Mexico facility. We operate in certain states within the United States and in international areas that have a history of unionization and we may become the subject of a unionization campaign. If some or all of our workforce were to become unionized and collective bargaining agreement terms, including any renegotiation of our Monterrey, Mexico collective bargaining agreement, were significantly different from our current compensation arrangements or work practices, our costs could be increased, our flexibility in terms of work schedules and reductions in force could be limited, and we could be subject to strikes or work slowdowns among other things.

We may incur liabilities to customers as a result of warranty claims.

We provide warranties as to the proper operation and conformance to specifications of the products we manufacture or install. Failure of our products to operate properly or to meet specifications may increase costs by requiring additional engineering resources and services, replacement of parts and equipment or monetary reimbursement to a customer. We have in the past received warranty claims, and we expect to continue to receive them in the future. To the extent that we incur substantial warranty claims in any period, our reputation, ability to obtain future business and earnings could be adversely affected.

We are subject to litigation risks that may not be covered by insurance.

In the ordinary course of business, we become the subject of various claims, lawsuits and administrative proceedings seeking damages or other remedies concerning our commercial operations, products, employees and other matters, including occasional claims by individuals alleging exposure to hazardous materials as a result of our products or operations. Some of these claims relate to the activities of businesses that we have acquired, even though these activities may have occurred prior to our acquisition of such businesses. Our insurance does not cover all of our potential losses, and we are subject to various self-insured retentions and deductibles under our insurance. A judgment may be rendered against us in cases in which we could be uninsured or beyond the amounts that we currently have reserved or anticipate incurring for such matters.

The number and cost of our current and future asbestos claims could be substantially higher than we have estimated and the timing of payment of claims could be sooner than we have estimated.

One of our subsidiaries has been and continues to be named as a defendant in asbestos related product liability actions. The actual amounts expended on asbestos-related claims in any year may be impacted by the number of claims filed, the volume of pre-trial proceedings, and the number of trials and settlements. As of December 31, 2010, our subsidiary had a recorded liability of $250,000 net of anticipated insurance recoveries of $750,000, for the estimated indemnity cost associated with the resolution of its current open claims and future claims anticipated to be filed during the next five years.

Due to a number of uncertainties that may result in significant changes in the current estimate, the actual costs of resolving these pending claims could be substantially higher than the current estimate. Among these are uncertainties as to the ultimate number and type of claims filed, the amounts of claim costs, the impact of bankruptcies of other companies with asbestos claims and potential legislative changes and uncertainties surrounding the litigation process from jurisdiction to jurisdiction and from case to case. In addition, future claims beyond the five-year

 

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forecast period are possible, but the accrual does not cover losses that may arise from such additional future claims and, therefore, we have not accrued a liability for such additional future claims.

Significant costs are incurred in defending asbestos claims and these costs are recorded at the time incurred. Receipt of reimbursement from our insurers may be delayed for a variety of reasons. In particular, if our primary insurer claims that certain policy limits have been exhausted, we may be delayed in receiving reimbursement as a result of the transition from one set of insurers to another. The excess insurer may also dispute the claim of exhaustion, or may rely on certain policy requirements to delay or deny claims. Furthermore, the various per occurrence and aggregate limits in different insurance policies may result in extended negotiations or the denial of reimbursement for particular claims. For more information on the cost sharing agreements related to this risk, please read “Business—Legal proceedings.”

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

As of August 29, 2011, we had approximately $687 million of borrowings under our credit agreement and capacity to borrow an additional $58 million under our credit agreement. Our level of indebtedness may adversely affect our operations and limit our growth, and we may have difficulty making debt service payments on our indebtedness as such payments become due. Our level of indebtedness may affect our operations in several ways, including the following:

 

•

our indebtedness may increase our vulnerability to general adverse economic and industry conditions;

 

•

the covenants contained in the agreements that govern our indebtedness limit our ability to borrow funds, dispose of assets, pay dividends and make certain investments;

 

•

our debt covenants also affect our flexibility in planning for, and reacting to, changes in the economy and in its industry;

 

•

any failure to comply with the financial or other covenants of our indebtedness could result in an event of default, which could result in some or all of our indebtedness becoming immediately due and payable;

 

•

our indebtedness could impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions or other general corporate purposes; and

 

•

our business may not generate sufficient cash flows from operations to enable us to meet our obligations under our indebtedness.

If we fail to develop or maintain an effective system of internal controls, we may not be able to accurately report our financial results or prevent fraud.

Effective internal controls over financial processes and reporting are necessary for us to provide reliable financial reports and effectively prevent fraud and to operate successfully. Our efforts to continue to develop and maintain internal controls may not be successful and we may be unable to maintain adequate controls in the future. In addition, the entities that we acquire in the future may not maintain effective systems of internal controls or we may encounter difficulties integrating our system of internal controls with those of acquired entities. If we are unable to

 

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maintain effective internal controls and, as a result, provide reliable financial reports and effectively prevent fraud, our reputation and operating results would be harmed.

We may be impacted by disruptions in the political, regulatory, economic and social conditions of the foreign countries in which we are expected to conduct business.

Instability and unforeseen changes in the international markets in which we conduct business, including economically and politically volatile areas such as North Africa, the Middle East, Latin America and the Asia Pacific region, could cause or contribute to factors that could have an adverse effect on the demand for the products and services we provide.

In addition, worldwide political, economic, and military events have contributed to oil and natural gas price volatility and are likely to continue to do so in the future. Depending on the market prices of oil and natural gas, oil and natural gas exploration and development companies may cancel or curtail their drilling programs, thereby reducing demand for our products and services.

Climate change legislation or regulations restricting emissions of greenhouse gases could increase our operating costs or reduce demand for our products.

Environmental advocacy groups and regulatory agencies in the United States and other countries have focused considerable attention on the emissions of carbon dioxide, methane and other greenhouse gases and their potential role in climate change. The U.S. Environmental Protection Agency (the “EPA”) has already begun to regulate greenhouse gas emissions under the federal Clean Air Act. The adoption of additional legislation or regulatory programs to reduce emissions of greenhouse gases could require us to incur increased operating costs to comply with new emissions-reduction or reporting requirements. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, hydrocarbons that our customers produce. Consequently, legislation and regulatory programs to reduce emissions of greenhouse gases could have an adverse effect on our business, financial condition and results of operations. Finally, some scientists have concluded that increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events.

Adverse weather conditions adversely affect demand for services and operations.

Adverse weather conditions, such as hurricanes, tornadoes, ice or snow may damage or destroy our facilities, interrupt or curtail our operations, or our customers’ operations, cause supply disruptions and result in a loss of revenue, which may or may not be insured. During the first and fourth quarters winter weather conditions, and during the second and third quarters tornadoes and tropical weather conditions in the Northern Hemisphere, may interrupt or curtail our operations, or our customers’ operations, in those areas.

A natural disaster, catastrophe or other event could result in severe property damage, which could curtail our operations.

Some of our operations involve risks of, among other things, property damage, which could curtail our operations. For example, damage to a manufacturing plant could reduce our ability to produce products and satisfy customer demand. If one or more plants we own are damaged by severe weather or any other disaster, accident, catastrophe or event, our operations could be

 

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significantly interrupted. Similar interruptions could result from damage to production or other facilities that provide supplies or other raw materials to our plants or other stoppages arising from factors beyond our control. These interruptions might involve significant damage to, among other things, property and repairs might take from a week or less for a minor incident to many months or more for a major interruption.

Potential legislation or regulations restricting the use of hydraulic fracturing could reduce demand for our products.

Hydraulic fracturing is an important and common practice in the oil and gas industry, which involves the injection of water, sand and chemicals under pressure into a formation to fracture the surrounding rock and stimulate production of hydrocarbons. Certain environmental advocacy groups have suggested that additional federal, state and local laws and regulations may be needed to more closely regulate the hydraulic fracturing process, and have made claims that hydraulic fracturing techniques are harmful to surface water and drinking water resources. The EPA has already begun to regulate certain hydraulic fracturing operations involving diesel under the auspices of the Underground Injection Control program under the federal Safe Drinking Water Act. Legislation has been proposed at the federal, state and local levels to restrict or further regulate certain hydraulic fracturing activities, and the EPA is conducting a study to determine if additional regulation of hydraulic fracturing is warranted. The adoption of legislation or regulatory programs that restrict hydraulic fracturing could adversely affect, reduce or delay well drilling and completion activities, increase the cost of drilling and production, and thereby reduce demand for our products and services.

Our financial results could be adversely impacted by the Macondo well incident and the resulting changes in regulation of offshore oil and natural gas exploration and development activity.

The United States Department of the Interior has issued Notices to Lessees and Operators (NTLs), implemented additional safety and certification requirements applicable to drilling activities in the U.S. Gulf of Mexico, imposed additional requirements with respect to exploration, development and production activities in U.S. waters and delayed the approval of drilling plans and well permits in both deepwater and shallow-water areas. The delays caused by new regulations and requirements have and will continue to have an overall negative effect on Gulf of Mexico drilling activity, and to a certain extent, our financial results.

The Macondo well incident and resulting moratorium on drilling has caused offshore drilling delays, and is expected to result in increased state, federal and international regulation of our and our customers’ operations that could negatively impact our earnings, prospects and the availability and cost of insurance coverage. There have been a variety of proposals to change existing laws and regulations that could affect offshore development and production, including proposals to significantly increase the minimum financial responsibility demonstration required under the federal Oil Pollution Act of 1990. Any increased regulation of the exploration and production industry as a whole that arises out of the Macondo well incident or otherwise could result in fewer companies being financially qualified to operate offshore in the United States, result in higher operating costs for our customers and reduce demand for our products and services. Additionally, a similar incident in another region could result in increased regulation in that market or in other offshore markets and could have a similar effect.

 

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Our success depends on our ability to implement new technologies and services.

Our success depends on the ongoing development and implementation of new product designs and improvements, and on our ability to protect and maintain critical intellectual property assets related to these developments. If we are not able to obtain patent or other intellectual property protection of our technology, we may not be able to recoup development costs or fully exploit systems, services and technologies in a manner that allows us to meet evolving industry requirements at prices acceptable to our customers. In addition, some of our competitors are large national and multinational companies that may be able to devote greater financial, technical, manufacturing and marketing resources to research and development of new systems, services and technologies than we are able to do.

Our success will be affected by the use and protection of our proprietary technology. There are limitations to our intellectual property rights in our proprietary technology, and thus our right to exclude others from the use of such proprietary technology.

Our success will be affected by our development and implementation of new product designs and improvements and by our ability to protect and maintain critical intellectual property assets related to these developments. Although in many cases our products are not protected by any registered intellectual property rights, we rely on a combination of patents and trade secret laws to establish and protect this proprietary technology.

We currently hold multiple U.S. and international patents and have multiple pending patent applications, for products and processes. Patent rights give the owner of a patent the right to exclude third parties from making, using, selling, and offering for sale the inventions claimed in the patents in the applicable country. Patent rights do not necessarily grant the owner of a patent the right to practice the invention claimed in a patent, but merely the right to exclude others from practicing the invention claimed in the patent. It may also be possible for a third party to design around our patents. Furthermore, patent rights have strict territorial limits. Some of our work will be conducted in international waters and would, therefore, not fall within the scope of any country’s patent jurisdiction. We may not be able to enforce our patents against infringement occurring in international waters and other “non-covered” territories. Also, we do not have patents in every jurisdiction in which we conduct business and our patent portfolio will not protect all aspects of our business and may relate to obsolete or unusual methods, which would not prevent third parties from entering the same market.

In addition, by customarily entering into confidentiality and/or license agreements with our employees, customers and potential customers and suppliers, we attempt to limit access to and distribution of our technology. Our rights in our confidential information, trade secrets, and confidential know-how will not prevent third parties from independently developing similar information. Publicly available information (e.g. information in expired issued patents, published patent applications, and scientific literature) can also be used by third parties to independently develop technology. We cannot provide assurance that this independently developed technology will not be equivalent or superior to our proprietary technology.

Our competitors may infringe upon, misappropriate, violate or challenge the validity or enforceability of our intellectual property and we may not able to adequately protect or enforce our intellectual property rights in the future.

 

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We may be adversely affected by disputes regarding intellectual property rights and the value of our intellectual property rights is uncertain.

As discussed above, we may become involved in legal proceedings from time to time to protect and enforce our intellectual property rights. Third parties from time to time may initiate litigation against us by asserting that the conduct of our business infringes, misappropriates or otherwise violates intellectual property rights. We may not prevail in any such legal proceedings related to such claims, and our products and services may be found to infringe, impair, misappropriate, dilute or otherwise violate the intellectual property rights of others. Any legal proceeding concerning intellectual property could be protracted and costly and is inherently unpredictable and could have a material adverse effect on our business, regardless of its outcome. Further, our intellectual property rights may not have the value that management believes them to have and such value may change over time as we and others develop new product designs and improvements.

In the past we have incurred certain impairment charges. We may incur additional impairment charges in future years.

We evaluate our long-lived assets, including property and equipment, for potential impairment whenever events or changes in circumstances indicate that the carrying amount of a long-lived asset may not be recoverable. In performing our review for impairment, future cash flows expected to result from the use of the asset and its eventual value upon disposal are estimated. If the undiscounted future cash flows are less than the carrying amount of the assets, the asset is impaired. The amount of the impairment is measured as the difference between the carrying value and the estimated fair value of the asset. The fair value is determined either through the use of an external valuation, or by means of an analysis of discounted future cash flows based on expected utilization. The impairment loss recognized represents the excess of the asset’s carrying value as compared to its estimated fair value.

For goodwill and intangible assets with indefinite lives, an assessment for impairment is performed annually or whenever an event indicating impairment may have occurred. Goodwill is reviewed for impairment by comparing the carrying value of each reporting unit’s net assets, including allocated goodwill, to the estimated fair value of the reporting unit. We have four reporting units. We determine the fair value of our reporting units using a discounted cash flow approach. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. If the reporting unit’s carrying value is greater than its fair value, a second step is performed whereby the implied fair value of goodwill is estimated by allocating the fair value of the reporting unit in a hypothetical purchase price allocation analysis. We recognize a goodwill impairment charge for the amount by which the carrying value of goodwill exceeds its reassessed fair value. For the year ended December 31, 2010, no impairment loss was recorded, but for the years ended December 31, 2008 and 2009, we recorded impairment charges of $44.0 million and $7.0 million, respectively.

If we determine that the carrying value of our long-lived asset, goodwill or intangible assets is less than their fair value, we may be required to record additional charges in the future.

 

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Risks related to our common stock

The initial public offering price of our common stock may not be indicative of the market price of our common stock after this offering. In addition, an active liquid trading market for our common stock may not develop and our common stock price may be volatile.

Prior to this offering, our common stock was not traded on any market. An active and liquid trading market for our common stock may not develop or be maintained after this offering. Liquid and active trading markets usually result in less price volatility and more efficiency in carrying out investors’ purchase and sale orders. The market price of our common stock could vary significantly as a result of a number of factors, some of which are beyond our control. In the event of a drop in the market price of our common stock, you could lose a substantial part or all of your investment in our common stock. The initial public offering price will be negotiated between us and representatives of the underwriters, based on numerous factors which we discuss in the “Underwriting (conflicts of interest)” section of this prospectus, and may not be indicative of the market price of our common stock after this offering. Consequently, you may not be able to sell shares of our common stock at prices equal to or greater than the price paid by you in the offering.

The following factors could affect our common stock price:

 

•

our operating and financial performance;

 

•

quarterly variations in the rate of growth of our financial indicators, such as net income per share, net income, EBITDA and revenues;

 

•

changes in revenue or earnings estimates or publication of reports by equity research analysts;

 

•

speculation in the press or investment community;

 

•

sales of our common stock by us or other stockholders, or the perception that such sales may occur;

 

•

general market conditions, including fluctuations in commodity prices; and

 

•

domestic and international economic, legal and regulatory factors unrelated to our performance.

The trading markets in general have experienced extreme volatility that has often been unrelated to the operating performance of particular companies. These broad market fluctuations may adversely affect the trading price of our common stock.

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

As a privately held company, we have not been responsible for the corporate governance and financial reporting practices and policies required of a publicly traded company. As a publicly traded company with listed equity securities we will need to comply with new laws, regulations and requirements, including corporate governance provisions of the Sarbanes-Oxley Act of 2002, and rules and regulations of the SEC and the NYSE. Complying with these statutes, regulations and requirements will occupy a significant amount of time of our board of directors and management and will significantly increase our costs and expenses. We will need to:

 

•

institute a more comprehensive compliance function;

 

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•

design, establish, evaluate and maintain a system of internal controls over financial reporting in compliance with the requirements of Section 404 of the Sarbanes-Oxley Act of 2002 and the related rules and regulations of the SEC and the Public Company Accounting Oversight Board, or “PCAOB”;

 

•

comply with rules promulgated by the NYSE;

 

•

prepare and distribute periodic public reports in compliance with our obligations under the federal securities laws;

 

•

establish new internal policies, such as those relating to disclosure controls and procedures and insider trading;

 

•

involve and retain to a greater degree outside counsel and accountants in the above activities; and

 

•

establish an investor relations function.

In addition, we also expect that being a public company subject to these rules and regulations will require us to accept less director and officer liability insurance coverage than we desire or to incur substantial costs to obtain coverage. These factors could also make it more difficult for us to attract and retain qualified members of our board of directors, particularly to serve on our Audit Committee, qualified executive officers and key personnel.

Future sales of our common stock in the public market could lower our stock price, and any additional capital raised by us through the sale of equity may dilute your ownership in us.

We may sell additional shares of common stock in subsequent public offerings. After the completion of this offering, we will have          outstanding shares of common stock (assuming the full exercise of the underwriters’ over-allotment option). Following the completion of this offering, SCF will own              shares, or approximately     % of our total outstanding shares (assuming the full exercise of the underwriters’ over-allotment option), all of which are subject to a lock-up agreement between SCF and the underwriters described in “Underwriting (conflicts of interest),” but may be sold into the market in the future. SCF is a party to a registration rights agreement with us which requires us to effect the registration of its shares in certain circumstances no earlier than the expiration of the lock-up period contained in the underwriting agreement entered into in connection with this offering.

As soon as practicable after this offering, we intend to file a registration statement with the SEC on Form S-8 providing for the registration of              shares of our common stock issued or reserved for issuance under our stock incentive plan. Subject to the satisfaction of vesting conditions and the expiration of lock-up agreements, shares registered under this registration statement on Form S-8 will be available for resale immediately in the public market without restriction.

We cannot predict the size of future issuances of our common stock or the effect, if any, that future issuances and sales of shares of our common stock will have on the market price of our common stock. Sales of substantial amounts of our common stock (including shares issued in connection with an acquisition), or the perception that such sales could occur, may adversely affect prevailing market prices of our common stock.

 

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Provisions in our organizational documents and under Delaware law could delay or prevent a change in control of our company, which could adversely affect the price of our common stock.

The existence of some provisions in our organizational documents and under Delaware law could delay or prevent a change in control of our Company that a stockholder may consider favorable, which could adversely affect the price of our common stock. The provisions in our amended and restated certificate of incorporation and amended and restated bylaws that could delay or prevent an unsolicited change in control of our Company include board authority to issue preferred stock without stockholder approval, advance notice provisions for director nominations or business to be considered at a stockholder meeting and similar provisions. These provisions may also discourage acquisition proposals, which could harm our stock price.

Purchasers of common stock will experience immediate and substantial dilution.

Assuming an initial public offering price of $             per share (the mid-point of the price range set forth on the cover page of this prospectus), purchasers of our common stock in this offering will experience an immediate and substantial dilution of $             per share in the net tangible book value per share of common stock from the initial public offering price, and our pro forma net tangible book value as of June 30, 2011, after giving effect to this offering, would be $             per share. You will incur further dilution if outstanding options to purchase common stock are exercised. In addition, our certificate of incorporation allows us to issue significant numbers of additional shares, including shares that may be issued under our long-term incentive plans. Please read “Dilution” for a complete description of the calculation of net tangible book value.

We have no current intention to pay future dividends.

We do not currently anticipate declaring or paying any cash dividends to holders of our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to fund the development and growth of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our results of operations, financial condition, capital requirements and investment opportunities. In addition, our revolving credit facility prohibits us from paying cash dividends prior to January 1, 2012, and also restricts us from paying any dividend after such date unless all the following conditions are met: (i) no default exists under our revolving credit facility or would result from the payment of such dividends; (ii) after giving effect to the payment of such dividends, we have a pro forma leverage ratio that is less than or equal to 2.50 to 1.0 and the borrowing availability under our revolving credit facility is at least $40 million; (iii) the aggregate amount of cash dividends paid in any fiscal quarter does not exceed 50% of our consolidated EBITDA for the prior four fiscal quarters; and (iv) the aggregate amount of cash dividends paid in any four consecutive fiscal quarters does not exceed 50% of our consolidated EBITDA for the prior four fiscal quarters. Please read “Dividend policy.”

Risks related to our relationship with SCF

L.E. Simmons & Associates, Incorporated (“LESA”), through SCF, will control the outcome of stockholder voting and may exercise this voting power in a manner adverse to you.

After the offering, SCF will hold approximately          shares of our common stock (or     % of the outstanding common stock if the over-allotment option is exercised in full). LESA is the ultimate general partner of SCF and will be in a position to control the outcome of most matters requiring

 

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a stockholder vote, including the election of directors, adoption of amendments to our charter and bylaws and approval of transactions involving a change of control. LESA’s interests may differ from yours, and SCF may vote its common stock in a manner that may adversely affect you.

Certain of our directors may have conflicts of interest because they are also directors or officers of SCF. The resolution of these conflicts of interest may not be in our or your best interests.

Certain of our directors, namely David C. Baldwin and Andrew L. Waite, are currently officers of LESA. In addition, a trust in which the children of our Chief Executive Officer, C. Christopher Gaut, are primary beneficiaries will continue to hold an ownership interest in the general partner of each of SCF-VI, L.P. and SCF-VII, L.P. after the offering. These positions may create conflicts of interest because these directors and Mr. Gaut have an ownership interest in SCF-VI, L.P. and SCF-VII, L.P. and/or responsibilities to SCF and its owners. Duties as directors or officers of LESA may conflict with such individuals’ duties as one of our directors or officers regarding business dealings and other matters between SCF and us. The resolution of these conflicts may not always be in our or your best interest.

We have renounced any interest in specified business opportunities, and SCF and its director nominees on our board of directors generally have no obligation to offer us those opportunities.

SCF has investments in other oilfield service companies that may compete with us, and SCF and its affiliates, other than our Company, may invest in other such companies in the future. We refer to SCF and its other affiliates and its portfolio companies as the SCF group. Our certificate of incorporation provides that, so long as we have a director or officer who is affiliated with SCF (an “SCF Nominee”) and for a continuous period of one year thereafter, we renounce any interest or expectancy in any business opportunity in which any member of the SCF group participates or desires or seeks to participate in and that involves any aspect of the energy equipment or services business or industry, other than (i) any business opportunity that is brought to the attention of an SCF Nominee solely in such person’s capacity as a director or officer of our Company and with respect to which no other member of the SCF group independently receives notice or otherwise identifies such opportunity and (ii) any business opportunity that is identified by the SCF group solely through the disclosure of information by or on behalf of our Company. We are not prohibited from pursuing any business opportunity with respect to which we have renounced any interest.

 

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Cautionary note regarding forward-looking statements

This prospectus contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. All statements, other than statements of historical fact included in this prospectus, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this prospectus, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.

Forward-looking statements may include statements about:

 

•

business strategy;

 

•

cash flows and liquidity;

 

•

the volatility of oil and natural gas prices;

 

•

our ability to successfully manage our growth, including risks and uncertainties associated with integrating and retaining key employees of the businesses we acquire;

 

•

the availability of raw materials and specialized equipment;

 

•

availability of skilled and qualified labor;

 

•

our ability to accurately predict customer demand;

 

•

competition in the oil and gas industry;

 

•

governmental regulation and taxation of the oil and natural gas industry;

 

•

environmental liabilities;

 

•

political and social issues affecting the countries in which we do business;

 

•

our ability to deliver our backlog in a timely fashion;

 

•

our ability to implement new technologies and services;

 

•

availability and terms of capital;

 

•

general economic conditions;

 

•

benefits of the Combination and our acquisitions;

 

•

availability of key management personnel;

 

•

operating hazards inherent in our industry;

 

•

the continued influence of SCF;

 

•

the ability to establish and maintain effective internal controls over financial reporting;

 

•

the ability to operate effectively as a public traded company;

 

•

financial strategy, budget, projections and operating results;

 

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•

uncertainty regarding our future operating results; and

 

•

plans, objectives, expectations and intentions contained in this prospectus that are not historical.

All forward-looking statements speak only as of the date of this prospectus; we disclaim any obligation to update these statements unless required by law and we caution you not to place undue reliance on them. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this prospectus are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved. We disclose important factors that could cause our actual results to differ materially from our expectations under “Risk factors” and “Management’s discussion and analysis of financial condition and results of operations” and elsewhere in this prospectus. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.

 

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Use of proceeds

We will receive net proceeds of approximately $         million from the sale of the common stock by us, assuming an initial public offering price of $         per share (the midpoint of the price range set forth on the cover page of this prospectus) and after deducting estimated expenses and underwriting discounts and commissions of approximately $         million. If the over-allotment option is exercised in full, we estimate that our net proceeds will be approximately $         million. We will not receive any of the proceeds from any sale of shares of our common stock by the selling stockholders.

We intend to use the net proceeds from this offering and any proceeds from any exercise of the underwriters’ over-allotment option to repay outstanding borrowings under our revolving credit facility. Our revolving credit facility matures in August 2014 and bore interest at a rate of 2.75% per annum as of August 29, 2011. Our outstanding borrowings under our revolving credit facility were incurred to fund acquisitions and other capital expenditures. Affiliates of the underwriters are lenders under our revolving credit facility and, accordingly, will receive a portion of the proceeds of this offering. See “Underwriting (conflicts of interest).”

We estimate that the selling stockholders will receive net proceeds of approximately $         million from the sale of          shares of common stock in this offering based upon the assumed initial offering price of $         per share, after deducting underwriting discounts and commissions. If the underwriters’ over-allotment option to purchase additional shares is exercised in full, we estimate that the selling stockholders’ net proceeds will be approximately $         million. We will pay all expenses related to this offering, other than underwriting discounts and commissions related to the shares sold by the selling stockholders.

An increase or decrease in the initial public offering price of $1.00 per share of common stock would cause the net proceeds that we will receive from the offering, after deducting estimated expenses and underwriting discounts and commissions, to increase or decrease by approximately $         million or by approximately $         million if the underwriters’ over-allotment option is exercised in full.

 

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Stock split

Prior to the completion of this offering, we expect the majority of our stockholders to approve, by written consent, an amendment to our certificate of incorporation to effect a stock split on a          for          basis. The stock split is expected to be effected simultaneously for all our then-existing common stock and the exchange ratio will be the same for all of our shares of issued and outstanding common stock. The stock split will affect all of our stockholders uniformly and will not affect any stockholder’s percentage ownership interests in us. Shares of common stock issued pursuant to the stock split will remain fully paid and nonassessable.

Dividend policy

We do not anticipate declaring or paying any cash dividends to holders of our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to fund the development and growth of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our results of operations, financial condition, capital requirements and investment opportunities. In addition, our revolving credit facility prohibits us from paying any cash dividends prior to January 1, 2012, but after such date cash dividends may be paid if all the following conditions are met: (i) no default exists under our revolving credit facility or would result from the payment of such dividends, (ii) after giving effect to the payment of such dividends, we have a pro forma leverage ratio that is less than or equal to 2.50 to 1.0 and the borrowing availability under our revolving credit facility is at least $40 million, (iii) the aggregate amount of cash dividends paid in any fiscal quarter does not exceed 50% of our consolidated EBITDA (as defined in the credit agreement) for the prior four fiscal quarters and (iv) the aggregate amount of cash dividends paid in any four consecutive fiscal quarters does not exceed 50% of our consolidated EBITDA for the prior four fiscal quarters.

 

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Capitalization

The following table sets forth our capitalization as of June 30, 2011:

 

•

on an actual basis;

 

•

on a pro forma basis to give effect to the five acquisitions completed subsequent to June 30, 2011 (the Cannon Acquisition, the SVP Acquisition, the AMC Acquisition, the P-Quip Acquisition and the Davis-Lynch Acquisition); and

 

•

on a pro forma, as adjusted basis to give effect to the acquisitions described in the preceding bullet, this offering and the application of the net proceeds as set forth under “Use of proceeds.”

You should read the following table in conjunction with “Use of proceeds,” “Unaudited pro forma condensed combined financial data,” “Selected historical consolidated financial data,” “Management’s discussion and analysis of financial condition and results of operations” and our historical consolidated financial statements and related notes thereto appearing elsewhere in this prospectus.

 

		As of June 30, 2011
		Actual				Pro forma				Pro forma, as adjusted
		(in thousands)
Cash and cash equivalents(1)		$	66,137			$	76,881			$
Long-term debt, including current maturities:
Revolving credit facility(1)(2)		$	279,615			$	732,505			$
Other long-term debt			53				53
Total long-term debt			279,668				732,558
Stockholders’ equity:
Common stock, $0.01 par value;          shares authorized (actual, pro forma for anticipated          for          stock split); shares issued and outstanding (as adjusted)			18				18
Additional paid-in capital(1)			397,411				416,467
Warrants			27,097				27,097
Retained earnings			176,906				176,906
Treasury stock			(25,877	)			(25,877	)
Accumulated other comprehensive loss			(3,884	)			(3,884	)
Total stockholders’ equity(1)			571,671				590,727
Total capitalization(1)		$	851,339			$	1,323,285			$

 

(1)

Each $1.00 increase or decrease in the assumed initial public offering price of $         per share, the midpoint of the range set forth on the cover page of this prospectus, would increase or decrease the amount of borrowings outstanding under our revolving credit facility, additional paid-in capital, total stockholders’ equity and total capitalization by approximately $ 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 commissions and estimated expenses payable by us.

 

(2)

Effective August 2, 2010, we entered into a revolving credit facility with an initial commitment of $450 million. In July 2011, we amended our revolving credit facility to, among other things, increase the commitment to $750 million. As of August 29, 2011, we had $687 million of indebtedness outstanding under our credit facility.

 

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Dilution

Purchasers of the common stock in this offering will experience immediate and substantial dilution in the net tangible book value per share of the common stock for accounting purposes. Our net tangible book value as of June 30, 2011, after giving pro forma effect to the transactions described under “Stock split,” was approximately $         million, or $         per share of common stock. Pro forma net tangible book value per share is determined by dividing our pro forma tangible net worth (tangible assets less total liabilities) by the total number of outstanding shares of common stock that will be outstanding immediately prior to the closing of this offering. After giving effect to our anticipated stock split and the sale of the shares in this offering and assuming the receipt of the estimated net proceeds (after deducting estimated discounts and expenses of this offering), our adjusted pro forma net tangible book value as of June 30, 2011 would have been approximately $         million, or $         per share. This represents an immediate increase in the net tangible book value of $         per share to our existing stockholders and an immediate dilution (i.e., the difference between the offering price and the adjusted pro forma net tangible book value after this offering) to new investors purchasing shares in this offering of $         per share. The following table illustrates the per share dilution to new investors purchasing shares in this offering:

 

Assumed initial public offering price per share		$
Pro forma net tangible book value per share as of June 30, 2011 (after giving effect to our stock split)
Increase per share attributable to new investors in this offering
As adjusted pro forma net tangible book value per share after giving effect to our stock split and this offering
Dilution in pro forma net tangible book value per share to new investors in this offering		$

The following table summarizes, on an adjusted pro forma basis as of June 30, 2011, the total number of shares of common stock owned by existing stockholders and to be owned by new investors, the total consideration paid, and the average price per share paid by our existing stockholders and to be paid by new investors in this offering at $        , the midpoint of the range of the initial public offering prices set forth on the cover page of this prospectus, calculated before deduction of estimated discounts and commissions:

 

Shares acquired

Total consideration

Average price per share

Number Percent

Amount

Percent

Existing stockholders(1)

%

$

%

$

New investors

—

—

—

—

Total

%

$

%

$

 

(1)

The number of shares disclosed for the existing stockholders includes          shares being sold by the selling stockholders in this offering. The number of shares disclosed for the new investors does not include the          shares being purchased by the new investors from the selling stockholders in this offering.

Assuming the underwriters’ over-allotment option is exercised in full, sales by us in this offering will reduce the percentage of shares held by existing stockholders to     % and will increase the number of shares held by new investors to         , or     % on an adjusted pro forma basis as of June 30, 2011.

 

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A $1.00 increase or decrease in the assumed initial public offering price of $         per share, which is the midpoint of the range set forth on the cover page of this prospectus, would increase or decrease our as adjusted pro forma net tangible book value as of June 30, 2011 by approximately $         million, the as adjusted pro forma net tangible book value per share after this offering by $         per share and the dilution in pro forma as adjusted net tangible book value per share to new investors in this offering by $         per share, 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 commissions and estimated offering expenses payable by us.

 

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Unaudited pro forma condensed combined financial data

We have completed the following acquisitions since the Combination in August 2010:

 

Name of acquisition		Date completed
Wood Flowline Products, LLC			February 4, 2011
Phoinix Global LLC			April 29, 2011
Specialist ROV Tooling Services, Ltd.			May 16, 2011
Cannon Services LP			July 1, 2011
SVP Products Inc.			July 1, 2011
AMC Global Group Ltd.			July 1, 2011
P-Quip Ltd.			July 5, 2011
Davis-Lynch LLC			July 29, 2011

The unaudited pro forma condensed combined statement of income for the year ended December 31, 2010 gives effect to the eight acquisitions completed in 2011 as if each had occurred on January 1, 2010. Under the rules and regulations of the SEC, the Davis-Lynch Acquisition was individually significant and the Wood Flowline Acquisition, the Phoinix Acquisition, the Specialist Acquisition, the Cannon Acquisition, the SVP Acquisition, the AMC Acquisition and the P-Quip Acquisition were each individually insignificant but, in the aggregate, are significant. Regulation S-X requires the presentation of audited financials for any significant acquisitions and for a substantial majority of the individually insignificant acquisitions when acquired businesses are individually insignificant, but significant in the aggregate. The unaudited pro forma condensed combined financial data has been prepared from our historical consolidated financial statements and related notes, the audited financials statements of Davis-Lynch, Wood Flowline, AMC Global, P-Quip and Cannon Services and the unaudited interim financial statements of Davis-Lynch and Cannon Services, each as included elsewhere in this prospectus, and the unaudited financial statements of Wood Flowline, AMC Global, P-Quip, Phoinix, Specialist and SVP not included in this prospectus.

The pro forma financial data for the year ended December 31, 2010 also gives effect to the issuance by us of shares of common stock pursuant to this offering and the application of the net proceeds therefrom as described in “Use of proceeds,” in each case as if each such transaction had occurred on January 1, 2010. The pro forma condensed combined financial data for the six months ended June 30, 2011 gives effect to the 2011 Acquisitions, the issuance by us of shares of common stock pursuant to this offering and the application of the net proceeds therefrom as described in “Use of proceeds,” in each case as if each such transaction had occurred on January 1, 2010. The pro forma balance sheet as of June 30, 2011 gives effect to the Cannon Acquisition, the SVP Acquisition, the AMC Acquisition, the P-Quip Acquisition and the Davis-Lynch Acquisition, each completed in July 2011, the issuance by us of shares of common stock pursuant to this offering and the application of the net proceeds therefrom as described in “Use of proceeds,” in each case as if each such transaction had occurred on June 30, 2011.

The unaudited pro forma condensed combined financial data included in this prospectus is not intended to represent what our financial position is or results of operations would have been if the acquisitions had occurred on any particular date or to project our results of operations for any future period. Since the Company and each of the acquired businesses were not under common control or management for some of or any period presented, the unaudited pro forma condensed combined financial results may not be comparable to, or indicative of, future performance.

 

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The unaudited pro forma condensed combined statements of operations included herein have been prepared pursuant to the rules and regulations of the SEC. Certain information and certain footnote disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to these rules and regulations; however, management believes that the disclosures are adequate to make the information presented not misleading.

The unaudited pro forma condensed combined financial data does not reflect any cost savings, operating synergies or revenue enhancements that the combined company may achieve as a result of the acquisition, the costs to combine our operations and the acquisitions or the costs necessary to achieve these cost savings, operating synergies and revenue enhancements.

You should read the following tables in conjunction with the historical financial statements and related notes thereto appearing elsewhere in this prospectus.

 

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Pro forma condensed combined statement of income

Year ended December 31, 2010

 

		Forum				Acquisitions(a)				Pro forma				Offering adjustments(c)				Pro forma, as adjusted
		(In thousands, except per share data)
		(Unaudited)
Net sales		$	747,335			$	208,114			$	955,449			$	—			$	955,449
Costs of sales			533,078				103,982				637,060				—				637,060
Gross profit			214,257				104,132				318,389				—				318,389
Selling, general and administrative expenses			141,441				45,474				186,915				—				186,915
Contingent consideration			—				—				—				—				—
Transaction expenses			—				—				—				—				—
(Gain) Loss on sale of assets			(461	)			—				(461	)			—				(461	)
Operating income			73,277				58,658				131,935				—				131,935
Interest expense, net			18,189				26,214				44,403				(12,834	)			31,569
Expenses related to the Combination			6,968				—				6,968				—				6,968
Deferred loan costs written off			6,082				—				6,082				—				6,082
Other (income), net			(2,308	)			(178	)			(2,486	)			—				(2,486	)
Income before income taxes			44,346				32,622				76,968				12,834				89,802
Income tax expense			20,297				10,536				30,833				4,492				35,325
Net income		$	24,049			$	22,086			$	46,135			$	8,342			$	54,477
Less: Income attributable to noncontrolling interests			(111	)			—				(111	)			—				(111	)
Net income attributable to common stockholders		$	23,938			$	22,086			$	46,024			$	8,342			$	54,366
Earnings per share:
Basic		$	16.46
Diluted		$	16.31
Weighted average shares:
Basic			1,454
Diluted			1,468

 

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Six months ended June 30, 2011

 

		Forum				Acquisitions(b)				Pro forma				Offering adjustments(c)				Pro forma, as adjusted
		(In thousands, except per share data)
		(Unaudited)
Net Sales		$	460,506			$	110,002			$	570,508							$	570,508
Costs of sales			324,517				48,023				372,540								372,540
Gross profit			135,989				61,979				197,968				—				197,968
Selling, general and administrative expenses			78,880				21,593				100,473				—				100,473
Contingent consideration			5,800								5,800								5,800
Transaction expenses			2,616				(2,616	)			—								—
(Gain) Loss on sale of assets			(420	)							(420	)							(420	)
Income from operations			49,113				43,002				92,115				—				92,115
Interest expense, net			7,689				12,170				19,859				(7,115	)			12,744
Other, net			751				(275	)			476				—				476
Income before income taxes			40,673				31,107				71,780				7,115				78,895
Income tax expense			14,383				10,162				24,545				2,490				27,035
Net income			26,290				20,945				47,235				4,625				51,860
Less: Income attributable to noncontrolling interests			(187	)			—				(187	)			—				(187	)
Net income attributable to common stockholders		$	26,103			$	20,945			$	47,048			$	4,625			$	51,673
Earnings per share:
Basic		$	16.41
Diluted		$	15.74
Weighted average shares:
Basic			1,591
Diluted			1,658

 

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Note 1. Pro forma adjustments related to the statements of income

(a) The following schedule presents pro forma adjustments related to the inclusion of the acquisitions described above in the unaudited pro forma condensed combined financial data for the year ended December 31, 2010.

 

		Year ended December 31, 2010
		Davis- Lynch				Wood Flowline				AMC Global(i)(j)				P-Quip(i)(j)				Cannon services				Other individual acquisitions				Acquisition adjustments				Ref.				Acquisitions combined
		(In thousands)
Revenue		$	89,152			$	28,524			$	17,103			$	11,116			$	29,684			$	46,926			$	(14,391	)			(d	)		$	208,114
Cost of sales			37,381				18,739				9,496				4,977				16,039				30,783				(14,391	)			(d	)			103,982
																											958				(e	)
Gross profit			51,771				9,785				7,607				6,139				13,645				16,143				(958	)							104,132
Selling, general and administrative expenses			13,943				1,576				2,002				1,469				5,869				7,124				13,491				(f	)			45,474
Operating income (loss)			37,828				8,209				5,605				4,670				7,776				9,019				(14,449	)							58,658
Interest expense			—				81				—				—								105				26,028				(g	)			26,214
Other expense (income), net			(477	)			4				(17	)			(8	)			(38	)			358												(178	)
Income before income taxes			38,305				8,124				5,622				4,678				7,814				8,556				(40,477	)							32,622
Income tax expense			1,570				2,843				1,574				1,310				2,735				2,834				(2,330	)			(h	)			10,536
Net Income		$	36,735			$	5,281			$	4,048			$	3,368			$	5,079			$	5,722			$	(38,147	)						$	22,086

 

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(b) The following schedule presents the pro forma adjustments related to the inclusion of the acquisitions described above in the unaudited pro forma condensed combined financial data for the six months ended June 30, 2011.

 

		One month ended January 31, 2011				Four months ended April 30, 2011				Five months ended May 31, 2011				Six months ended June 30, 2011
		Wood Flowline				Phoinix				Specialist				Davis- Lynch				AMC Global(i)(j)				P-Quip(i)(j)				Cannon services				SVP				Acquisition adjustments				Ref.				Acquisitions combined
		(In thousands)
Revenue		$	4,259			$	14,621			$	1,855			$	50,353			$	12,927			$	9,495			$	13,544			$	16,162			$	(13,214	)			(d	)		$	110,002
Cost of sales			2,559				9,933				993				19,393				4,200				5,406				5,633				12,668				(13,214	)			(d	)			48,023
																																			452				(e	)
Gross profit			1,700				4,688				862				30,960				8,727				4,089				7,911				3,494				(452	)							61,979
Selling, general and administrative expenses			253				1,231				244				6,186				2,063				831				3,472				1,262				6,051				(f	)			21,593
Transaction expenses																																			(2,616	)			(f	)			(2,616	)
Operating income (loss)			1,447				3,457				618				24,774				6,664				3,258				4,439				2,232				(3,887	)							43,002
Interest expense			16				—								—				—				—												12,154				(g	)			12,170
Other expense (income), net			—				24								(301	)			2				—																				(275	)
Income before income taxes			1,431				3,433				618				25,075				6,662				3,258				4,439				2,232				(16,041	)							31,107
Income tax expense			501				1,202				172				238				1,865				912				1,554				794				2,924				(h	)			10,162
Net Income			930				2,231				446				24,837				4,797				2,346				2,885				1,438				(18,965	)							20,945
Less: income attributable to noncontrolling interests																																											—
Net income attributable to common stockholders		$	930			$	2,231			$	446			$	24,837			$	4,797			$	2,346			$	2,885			$	1,438			$	(18,965	)						$	20,945

(c) The offering adjustments in the unaudited pro forma condensed combined statements of income for the year ended December 31, 2010 and the six months ended June 30, 2011 assume the application of $279 million of net proceeds from this offering to repay a portion of the outstanding indebtedness under our revolving credit facility. The resulting reduction of interest expense from the repayment of our revolving credit facility was $12.8 million and $7.1 million for the year ended December 31, 2010 and the six months ended June 30, 2011, respectively. This resulting reduction of interest expense was calculated using the weighted average of the interest rates applicable to the borrowings under the various tranches of our credit facility as of December 31, 2010 and June 30, 2011, which were 4.6% and 5.1%, respectively. If the net proceeds from the offering of our common stock increases or decreases by $10 million, we would accordingly repay $289 million or $269 million of outstanding indebtedness under our revolving credit facility, which would change pro forma interest expense by $0.5 million for the year ended December 31, 2010 and $0.3 million for the six months ended June 30, 2011. A one-eighth percentage point change in the interest rate would change pro forma interest expense by $0.3 million for the year ended December 31, 2010 and $0.2 million for the six months ended June 30, 2011.

(d) Intercompany revenue and cost of sales have been eliminated in the consolidation of the pro forma results. Certain acquired businesses have had sales to other entities within our Company prior to their

 

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acquisition by us. In the pro forma results, these sales are treated as intercompany sales and therefore have been eliminated in the consolidated total.

(e) Depreciation reflects the adjusted fixed assets assuming the acquisitions occurred January 1, 2010. Asset values were determined based upon third-party and internal appraisals. We estimated the average useful lives of the fixed assets to range from 7 to 30 years. The amount of depreciation related to this adjustment was approximately $1.0 million and $0.5 million for the pro forma condensed combined statements of income for the year ended December 31, 2010 and the six months ended June 30, 2011, respectively.

(f) Amortization of intangible assets has been reflected as if the intangible assets purchased as part of the business combinations had been acquired on January 1, 2010. The intangible assets include noncompete agreements, customer-related intangibles, backlog, patents and tradenames. For our significant acquisitions, asset values were determined based upon third-party appraisals. We estimated the remaining useful lives, ranging from 5 to 15 years, of all acquired intangible assets and amortized those assets over their estimated remaining useful lives. The amount of amortization related to this adjustment was approximately $13.5 million and $6.1 million for the pro forma condensed combined statements of income for the year ended December 31, 2010 and the six months ended June 30, 2011, respectively. Non-recurring transaction expenses related to acquisitions have been eliminated.

(g) Interest expense reflects the estimated interest related to the debt incurred for the acquisitions as if the acquisitions occurred January 1, 2010. The interest rate used in the pro forma adjustments for the year ended December 31, 2010 and six months ended June 30, 2011 was the interest rate in effect at the time of each acquisition. The pro forma amount of interest expense for the debt related to the acquisitions for the year ended December 31, 2010 and six months ended June 30, 2011 was approximately $26.0 million and $12.2 million, respectively. A 1/8% change in the variable rate of interest for the year ended December 31, 2010 and six months ended June 30, 2011 would have reduced or increased net income by approximately $0.4 million and $0.2 million, respectively.

(h) In preparing the pro forma condensed combined statements of income for the year ended December 31, 2010 and six months ended June 30, 2011, we used the statutory tax rate in effect for the applicable jurisdiction at the time of each acquisition.

(i) The historical profit and loss accounts and balance sheet of AMC and P-Quip have been prepared in accordance with generally accepted accounting principles in the United Kingdom (“UK GAAP”). Such principles differ in certain respects from generally accepted accounting principles in the United States (“US GAAP”). There were no significant differences between UK GAAP and US GAAP that would require adjustments within this pro forma financial data. Additionally, for the purpose of presenting the unaudited pro forma condensed combined financial data, the adjusted income statements of AMC and P-Quip for the periods ended December 31, 2010 and June 30, 2011 have been translated into U.S. dollars at the average rates for the periods ended December 31, 2010 and June 30, 2011, respectively.

(j) The pro forma statement of income of the AMC Acquisition for the year ended December 31, 2010 was derived from the audited financial statements for the fiscal year ended April 30, 2011, minus the results of operations for the four months ended April 30, 2011, plus the results of operations for the four months ended April 30, 2010, as shown in the schedule below. The currency exchange rates used to convert AMC’s results of operations from British pound sterling

 

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to U.S. dollars for the twelve months ended December 31, 2010 and the six months ended June 30, 2011 were 1.55 and 1.62, respectively.

 

AMC		Twelve months Ended April 30, 2011				Four months ended April 30, 2011				Four months ended April 30, 2010				Twelve months ended December 31, 2010
(in 000’s of British sterling pound)
Net Sales		£	12,833			£	4,691			£	2,922			£	11,064
Cost of Sales			5,756				1,324				1,711				6,143
Gross Profit			7,077				3,367				1,211				4,921
Selling, general and administrative expenses			1,920				880				255				1,265
Income from operations			5,157				2,487				956				3,626
Interest, expense, net
Other, net			(2	)			4				(5	)			(11	)
Income before income taxes			5,159				2,483				961				3,637
Income tax expense			1,522				695				269				1,018
Net income		£	3,637			£	1,788			£	692			£	2,619

The pro forma statement of income of the P-Quip Acquisition for the year ended December 31, 2010 was derived from the audited financial statements for the fiscal year ended May 31, 2011, minus the results of operations for the five months ended May 31, 2011, plus the results of operations for the five months ended May 31, 2010, as shown in the schedule below. The currency exchange rates used to convert P-Quip’s results of operations from British pound sterling to U.S. dollars for the twelve months ended December 31, 2010 and the six months ended June 30, 2011 were 1.55 and 1.62, respectively.

 

P-QUIP		Twelve months ended May 31, 2011				Five months ended May 31, 2011				Five months ended May 31, 2010				Twelve months ended December 31, 2010
(in 000’s of British sterling pound)
Net Sales		£	9,097			£	4,898			£	2,992			£	7,191
Cost of Sales			4,659				2,753				1,314				3,220
Gross Profit			4,438				2,145				1,678				3,971
Selling, general and administrative expenses			1,122				495				323				950
Income from operations			3,316				1,650				1,355				3,021
Interest, expense, net
Other, net			(5	)											(5	)
Income before income taxes			3,321				1,650				1,355				3,026
Income tax expense			579				374				200				847
Net income		£	2,742			£	1,276			£	1,155			£	2,179

 

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Pro forma condensed combined balance sheet

As of June 30, 2011

 

		Forum				Companies acquired after June 30, 2011(a)				Acquisition adjustments(b)				Proforma combined				Offering adjustments(c)				Pro forma combined
		(In thousands) (Unaudited)
Cash		$	66,137			$	82,648			$	(71,904	)		$	76,881			$	—			$	76,881
Accounts receivable			159,395				42,209				—				201,604				—				201,604
Inventories			217,024				51,250				—				268,274				—				268,274
Other current assets			39,034				1,488				—				40,522				—				40,522
Total current assets			481,590				171,208				(71,904	)			587,282				—				587,282
Property and equipment, net			104,496				3,204				12,870				120,570				—				120,570
Deferred loan costs			7,749				—				—				7,749				—				7,749
Intangible assets, net			111,613				—				110,061				221,674				—				221,674
Goodwill			358,433				4,728				256,784				619,945				—				619,945
Other long-term assets			4,630				16				—				4,646				—				4,646
Total long-term assets			586,921				7,948				379,715				974,584				—				974,584
Total assets		$	1,068,511			$	185,544			$	307,811			$	1,561,866			$	—			$	1,561,866
Accounts payable			81,044				14,363				—				95,407				—				95,407
Other current liabilities			115,644				7,047				—				122,691				—				122,691
Total current liabilities			196,688				21,410				—				218,098				—				218,098
Notes payable			279,668				102				452,788				732,558				(279,000	)			453,558
Other noncurrent liabilities			19,784				—				—				19,784				—				19,784
Total liabilities			496,140				21,512				452,788				970,440				(279,000	)			691,440
Common stock			18				1				(1	)			18				—				18
Additional paid-in capital related to issued stock for recent acquisitions			—				—				19,056				19,056				—				19,056
Retained earnings			176,906				149,135				(149,135	)			176,906				—				176,906
Other stockholders’ equity			394,747				14,897				(14,897	)			394,747				279,000				673,747
Total stockholders’ equity			571,671				164,033				(144,977	)			590,727				279,000				869,727
Noncontrolling interest			700				—				—				700				—				700
Total liabilities and stockholders’ equity		$	1,068,511			$	185,544			$	307,811			$	1,561,866			$	—			$	1,561,866

Note 1. Pro forma and offering adjustments to the balance sheet as of June 30, 2011

(a) The pro forma consolidated balance sheet reflects those acquisitions that occurred after June 30, 2011 as if they had occurred on June 30, 2011.

(b) The debt incurred for these acquisitions was approximately $452.8 million and stock issued related to these acquisitions was valued at $19.1 million. Preliminary estimates have been used to value property and equipment, intangible assets and goodwill. The preliminary allocation of the purchase price was based upon initial valuations. The estimates and assumptions used in these preliminary valuations are subject to change upon the receipt of the final valuations prepared by independent appraisers. The primary area of the purchase price yet to be finalized relates to intangible and identifiable assets and working capital adjustments. The adjustment to cash relates to the cash not included as part of the purchase.

(c) The pro forma consolidated balance sheet as of June 30, 2011 assumes offering proceeds of $279 million, net of $21 million in estimated offering expenses, and assumes the application of these net proceeds from this offering to repay all of the outstanding indebtedness under our revolving credit facility.

 

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Selected historical consolidated financial data

You should read the following selected historical financial data in conjunction with “Unaudited pro forma condensed combined financial data,” “Management’s discussion and analysis of financial condition and results of operations” and our historical consolidated financial statements and related notes thereto included elsewhere in this prospectus. We believe that the assumptions underlying the preparation of our financial statements are reasonable. The financial data included in this prospectus may not be indicative of our future results of operations, financial position and cash flows.

The selected historical financial data as of December 31, 2009 and 2010 and for the years ended December 31, 2008, 2009 and 2010 are derived from our historical consolidated financial statements and related notes thereto included elsewhere in this prospectus. The selected historical financial data as of December 31, 2006, 2007 and 2008 and for the years ended December 31, 2006 and 2007 have been derived from our unaudited consolidated financial statements, which are not included in this prospectus. The historical financial data as of June 30, 2011 and for the six months ended June 30, 2010 and 2011 are derived from our unaudited consolidated financial statements and related notes thereto included elsewhere in this prospectus and have been prepared on a basis consistent with the audited financial statements and the notes thereto and include all adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of the financial data.

 

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		Year ended December 31,																				Six months ended June 30,
		2006				2007				2008				2009				2010				2010				2011
		(unaudited)																				(unaudited)
		(in thousands, except per share information)
Income Statement Data:
Net sales		$	230,607			$	635,077			$	972,551			$	677,378			$	747,335			$	349,290			$	460,506
Cost of sales			144,762				444,769				691,824				491,463				533,078				245,957				324,517
Gross profit			85,845				190,308				280,727				185,915				214,257				103,333				135,989
Operating expenses
Selling, general and administrative expenses			43,896				93,694				146,943				128,562				141,441				64,597				78,880
Contingent consideration			—				—				—				—				—				—				5,800
Transaction expenses			—				—				—				—				—				—				2,616
Impairment of goodwill and other intangible assets			—				—				44,015				7,009				—				—				—
(Gain) loss on sale of assets			(2,018	)			—				(619	)			137				(461	)			(123	)			(420	)
Total operating expenses			41,878				93,694				190,339				135,708				140,980				64,474				86,876
Income from operations			43,967				96,614				90,388				50,207				73,277				38,859				49,113
Other expense (income)
Expenses related to the Combination			—				—				—				—				6,968				—				—
Deferred loan costs written off			—				—				—				—				6,082				—				—
Interest expense			6,712				21,718				24,704				19,451				18,189				9,242				7,689
Other, net			33				1,201				(2,065	)			(1,088	)			(2,308	)			(981	)			751
Total other expense (income)			6,745				22,919				22,639				18,363				28,931				8,261				8,440
Income from continuing operations before income taxes			37,222				73,695				67,749				31,844				44,346				30,598				40,673
Provision for income tax expense			13,104				28,282				32,938				11,011				20,297				10,235				14,383
Income from continuing operations			24,118				45,413				34,811				20,833				24,049				20,363				26,290
Loss from discontinued operations, net of taxes			—				—				(396	)			(1,342	)			—				—				—
Net income			24,118				45,413				34,415				19,491				24,049				20,363				26,290
Less: Income attributable to noncontrolling interest			(55	)			(95	)			(39	)			(155	)			(111	)			(73	)			(187	)
Net income attributable to common stockholders		$	24,063			$	45,318			$	34,376			$	19,336			$	23,938			$	20,290			$	26,103
Weighted average shares outstanding
Basic			463				1,023				1,232				1,304				1,454				1,309				1,591
Diluted			476				1,043				1,261				1,322				1,468				1,322				1,658
Earnings per share
Basic		$	51.97			$	44.30			$	27.90			$	14.83			$	16.46			$	15.50			$	16.41
Diluted		$	50.55			$	43.45			$	27.26			$	14.63			$	16.31			$	15.35			$	15.74

 

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		As of December 31,																				As of June 30,
		2006				2007				2008				2009				2010				2011
(in thousands)		(unaudited)				(unaudited)				(unaudited)												(unaudited)
Balance Sheet Data:
Cash and cash equivalents		$	7,227			$	32,687			$	19,941			$	26,894			$	20,348			$	66,137
Net property, plant and equipment			23,497				72,479				109,194				96,747				90,632				104,496
Total assets			266,745				822,400				961,022				840,226				818,332				1,068,511
Long-term debt			110,952				326,696				321,962				236,937				204,715				279,668
Total stockholders’ equity			94,414				306,052				376,961				401,927				462,523				571,671

 

		Year ended December 31,																				Six months ended June 30,
		2006				2007				2008				2009				2010				2010				2011
(in thousands)		(unaudited)				(unaudited)																(unaudited)				(unaudited)
Other financial data:
Net cash provided by operating activities		$	13,770			$	40,198			$	112,463			$	107,751			$	65,981			$	25,861			$	1,906
Net cash used in investing activities		$	(88,224	)		$	(388,350	)		$	(160,937	)		$	(10,914	)		$	(19,216	)		$	(5,045	)		$	(84,825	)
Net cash provided by / (used in) financing activities		$	72,985			$	369,770			$	58,871			$	(94,532	)		$	(54,265	)		$	(21,370	)		$	126,057

 

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Management’s discussion and analysis of

financial condition and results of operations

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with “Selected historical consolidated financial data” and our financial statements and related notes appearing elsewhere in this prospectus. This discussion contains forward-looking statements based on our current expectations, estimates and projections about our operations and the industry in which we operate. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of a variety of risks and uncertainties, including those described in this prospectus under “Cautionary note regarding forward-looking statements” and “Risk factors.” We assume no obligation to update any of these forward-looking statements.

Overview

We are a global oilfield products company, serving the subsea, drilling, completion, production and process sectors of the oil and natural gas industry. We design and manufacture products, and engage in aftermarket services, parts supply and related services that complement our product offering. Our product offering and related services include a mix of highly engineered capital products and frequently replaced items that are consumed in the exploration and development of oil and natural gas reserves. We seek to design, manufacture and supply reliable, cost effective products that create value for our broad and diverse customer base, which includes oil and gas operators, land and offshore drilling contractors, well intervention service providers, subsea construction and service companies, pipeline operators and refinery and petrochemical plant operators, among others. We believe that we differentiate ourselves from our competitors on the basis of the quality of our products, the level of related service and support we provide and the collaborative approach we take with our customers to help them solve critical problems.

On August 2, 2010, we completed the Combination, through which FOT, Global Flow, Triton, Allied and Subsea were combined and became Forum Energy Technologies, Inc. Prior to the Combination, SCF Partners, through two of its private equity funds, controlled a majority of the voting interests in each of FOT, Global Flow, Triton and Subsea. SCF also held a controlling position with respect to Allied by virtue of its ownership of a substantial portion of Allied’s issued and outstanding common stock and its contractual right to fill a majority of the directors’ seats comprising the Allied Board of Directors. As a result, the mergers consummated in connection with the Combination are accounted for using the reorganization accounting method for entities under common control. Under this method of accounting, the consolidated financial statements and the discussions herein include the operating results of FOT, Global Flow, Triton, Allied and Subsea from the date on which each became controlled by SCF, which was May 2005, June 2005, February 2007, August 2007 and January 2007, respectively.

We operate in two business segments:

 

•

Drilling and Subsea Segment.    We design and manufacture products and provide related services to the drilling, well construction, completion, intervention and subsea construction and services markets. Through this segment, we offer drilling products, including capital equipment and a broad line of products consumed in the drilling process; downhole products, including cementing and casing tools and a range of downhole protection solutions; and subsea products, including capital equipment, specialty components and tooling, and applied products for subsea pipelines. We also provide a broad suite of complementary subsea technical services and rental items.

 

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•

Production and Infrastructure Segment.    We design and manufacture products and provide related equipment and services to the well stimulation, completion, production and infrastructure markets. Through this segment, we supply surface production and process equipment, specialty pipeline construction equipment, a broad range of industrial and process valves and well stimulation and flow equipment, as well as provide related support services.

Recent acquisitions

We have made eight acquisitions this year, three of which are now included in the Production and Infrastructure Segment and five in the Drilling and Subsea Segment. The three Production and Infrastructure acquisitions comprise our new consumable flow equipment product line. For Drilling and Subsea, two of the acquisitions form our new downhole products line, two are additions to our drilling products offering, and one is an addition to subsea products offering.

We established our flow equipment platform in 2011 through the completion of three acquisitions. In February 2011, we acquired Wood Flowline Products, LLC (“WFP”), based out of Davis, Oklahoma, which sells flow equipment components used in fracturing and flowback operations and provides related inspection, recertification and refurbishment services. In April 2011, we acquired Phoinix Global LLC (“Phoinix”), based in Alice, Texas, which offers fluid-ends for frac pressure pumps, plug valves, relief valves, chokes, manifolds, manifold trailers and flow equipment transport trucks. In July 2011, we acquired SVP Products (“SVP”), based in Odessa, Texas, which provides recertification and refurbishment of flow equipment used in the well stimulation and flowback processes. SVP added access to critical growth basins in North America and had previously served as a channel to market for WFP and Phoinix products. The SVP Acquisition helps tie WFP and Phoinix into a stronger single product line, and provides a broader geographic footprint and critical customer relationships.

We formed our downhole products platform in July 2011 through the acquisition of Cannon Services Ltd. (“Cannon”), based in Stafford, Texas, which provides standard and customized clamp and stamped metal protection systems used to shield downhole control lines and gauges during their installation and to provide protection during production enhancement operations.

We considerably strengthened our newly established position in the downhole market in July 2011 through the acquisition of Davis-Lynch LLC (“Davis-Lynch”), based in Pearland, Texas which increases our ability to offer the mission critical products used during the completion phase of oil and natural gas well construction. Davis-Lynch is a 64 year old market leading manufacturer of proprietary downhole cementing and casing products which designs, manufactures and provides a full range of centralizers, float equipment, stage cementing tools, inflatable packers, flotation collars, cementing plugs, fill and circulation tools for running casing, casing hangars and surge reduction equipment.

We have made two acquisitions this year to add to our drilling products capabilities. In July 2011, we acquired AMC Global Group, Ltd. (“AMC”), based in Aberdeen, Scotland, which designs and manufactures specialized torque equipment for tubular connections, including high torque stroking units, fully rotational torque units, portable torque units for field deployment and related control systems, and provides aftermarket service. Simultaneously, we acquired P-Quip, Ltd. (“P-Quip”), based in Kilbirnie, Scotland, which is a manufacturer of proprietary mud pump fluid end assemblies, mud pump rod systems, liner retention systems, valve cover retention systems and other drilling flow control products. Both the AMC and P-Quip product lines serve to

 

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enhance the safety and efficiency of modern drilling operations. They are complementary to our focus on tubular handling and drilling flow control products.

In May 2011, we completed the Specialist Acquisition, which enhanced our subsea products offering. Specialist designs and manufactures or assembles specialized ROV tooling for sale and rental and is based in Aberdeen, Scotland.

For additional information regarding our recent acquisitions, please read Note 16 to our audited consolidated financial statements included elsewhere in this prospectus.

Evaluation of operations

We manage our operations through the two business segments described above. We have focused on implementing financial reporting and controls at all of our operations to accelerate the availability of critical information necessary to support informed decision making. We use a number of financial and non-financial measures to routinely analyze and evaluate, on a segment and corporate level, the performance of our business, including the following:

 

•

Safety;

•

Revenue growth;

•

Gross margin percentage;

•

Selling, general and administrative expenses as a percentage of total revenue;

•

Operating income and operating margin percentage;

•

Earnings per share; and

•

Free cash flow.

At the beginning of each year, we establish annual, quarterly and monthly plans for each product line based on our assessment of market conditions and opportunities. We re-evaluate and update these plans on at least a quarterly basis.

Safety.    We measure safety by tracking the total recordable incident rate (“TRIR”), which is reviewed on a monthly basis. TRIR is a measure of the rate of recordable workplace injuries, defined below, normalized and stated on the basis of 100 workers for an annual period. The factor is derived by multiplying the number of recordable injuries in a calendar year by 200,000 (i.e., the total hours for 100 employees working 2,000 hours per year) and dividing this value by the total hours actually worked in the year. A recordable injury includes occupational death, nonfatal occupational illness and other occupational injuries that involve loss of consciousness, restriction of work or motion, transfer to another job, or medical treatment other than first aid.

Revenue growth.    We compare actual revenue achieved each month to the most recent estimate for that month and to the annual plan for the month established at the beginning of the year. We monitor our revenue to analyze trends in the relative performance of each of our product lines as compared to standard revenue drivers or market metrics applicable to that product. We are particularly interested in identifying positive or negative trends and investigating to understand the root causes. We also evaluate changes in the mix of products sold and the resultant impact on reported gross margins.

Gross margin percentage.    We define gross margin percentage as our gross margin, or net sales minus cost of sales, divided by our net sales. Our management continually evaluates our consolidated gross margin percentage and our gross margin percentage by segment to determine how each segment and the individual product lines within those segments are performing. This metric aids management in capital resource allocation and pricing decisions.

 

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Selling, general and administrative expenses as a percentage of total revenue.    Selling, general and administrative expenses include payroll related costs for sales, marketing, administrative, accounting, information technology, certain engineering and human resources functions; audit, legal and other professional fees; insurance; franchise taxes not based on income; travel and entertainment; advertising and promotions; bad debt expense; and other office and administrative related costs. Our management continually evaluates the level of our selling, general and administrative expenses in relation to our revenue and makes appropriate changes in light of activity levels to preserve and improve our profitability while meeting the on-going support and regulatory requirements of the business.

Operating income and operating margin percentage.    We define operating income as revenue less cost of goods sold less selling, general and administrative expenses. We define our operating margin percentage as operating income divided by revenue. These metrics assist management in evaluating the performance of each segment as a whole, especially to determine whether the amount of administrative burden is appropriate to support current business activity levels.

Earnings per share.    We calculate fully-diluted earnings per share as prescribed under GAAP, that is net income divided by common shares outstanding, giving effect for the assumed exercise of all outstanding options and warrants with a strike price less than the average fair value of the shares over the period covered for the calculation. We believe this measure is important as it reflects the sum total of operating results and all attendant capital decisions, showing in one number the amount earned for the stockholders of our Company.

Free cash flow.    We define free cash flow as net income, increased by non-cash charges included in net income (e.g., depreciation and amortization and deferred income taxes), increased or decreased by changes in net working capital, less capital expenditures. We believe that this measure is important because it encompasses both profitability and capital management in evaluating results. Free cash flow represents the business’ contribution in the generation of funds available to pay debt outstanding, invest in other areas, or return funds to our stockholders.

General trends and outlook

Sales of our products and services are driven primarily by traditional energy industry activity indicators, which include current and expected commodity prices, drilling rig counts, well completions and workover activity, geological characteristics of producing wells, which determine the intensity of services provided per well, oil and gas production levels, and customers’ capital budgets. Oil and gas prices and the level of customer activity have been characterized by significant volatility in recent years. Oil and gas prices fell from previously historic levels beginning in mid-2008 and continued into 2009. As a result of the economic downturn that began in 2008 and the resulting decrease in commodity prices, customers significantly curtailed capital spending throughout 2009. Global economies generally improved and stabilized in 2010 and, as a result of rising expectations for energy demand and steady increases in oil prices from the depressed levels witnessed in 2009, our customers substantially increased their capital spending in 2010 and the first half of 2011.

We believe drivers of industry demand should remain favorable in most of our geographic markets. In addition to increased capital spending in the oil and gas industry generally, we have also identified the following trends in the oil and gas industry that we believe will positively affect our business in the coming years: (i) the increasing complexity of well construction, (ii) the

 

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growing service intensity associated with unconventional resources, (iii) the increasing investment in subsea equipment and related services, (iv) the heightened focus on product maintenance and certification, (v) the recovery in global drilling activity and new rig replacement cycle and (vi) the development of heavy oil reserves in Canada. For more information regarding these industry trends, see “Business—Current trends in our industry.” Our customer targeting efforts, product development projects, aftermarket service offerings and mergers and acquisitions initiatives are focused on enhancing our exposure to these trends.

Any decrease in commodity prices or in the capital spending programs of our customers would adversely impact our business, financial condition or results of operations. Please see “Risk factors—We derive a substantial portion of our revenues from companies in or affiliated with the oil and natural gas industry, a historically cyclical industry, with levels of activity that are significantly affected by the levels and volatility of oil and natural gas prices. As a result, this cyclicality may cause fluctuations in our revenues and results of our operations.”

Factors affecting the comparability of our pro forma and our future results of operations to our historical results of operations

Our pro forma results of operations and our future results of operations may not be comparable to our historical results of operations for the periods presented, primarily for the reasons described below:

 

•

The historical consolidated financial statements included in this prospectus are based on the separate businesses of FOT, Global Flow, Triton, Allied and Subsea for the periods prior to the Combination. As a result, the historical financial data may not give you an accurate indication of what our actual results would have been if the Combination had been completed at the beginning of the periods presented or of what our future results of operations are likely to be.

 

•

Since the Combination, we have grown our business both organically and through strategic acquisitions. We have expanded and diversified our product portfolio and business lines with the acquisition of eight businesses in 2011 for a total consideration of approximately $586 million. These acquisitions accounted for 41% of our pro forma net income and 39% of our pro forma Adjusted EBITDA for the six months ended June 30, 2011. The historical financial data for prior years does not include the results of any of the acquired companies for the periods presented and, as such, does not give you an accurate indication of what our future results are likely to be.

 

•

As we integrate the acquired companies and further implement controls, processes and infrastructure to operate in compliance with the regulatory requirements applicable to companies with publicly traded shares, it is likely that we will incur incremental selling, general and administrative expenses relative to historical periods.

Our future results will depend on our ability to efficiently manage our combined operations and execute our business strategy.

 

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Results of operations

 

		Year ended December 31,												Six months ended June 30,
		2008				2009				2010				2010				2011
														(unaudited)
(in thousands of dollars, except per share information)
Revenue:
Drilling and Subsea		$	658,804			$	455,019			$	474,306			$	221,949			$	267,965
Production and Infrastructure			313,747				222,359				273,029				127,341				192,541
Total revenue		$	972,551			$	677,378			$	747,335			$	349,290			$	460,506
Cost of sales:
Drilling and Subsea		$	454,129			$	325,147			$	327,848			$	150,869			$	185,263
Production and Infrastructure			237,695				166,316				205,230				95,088				139,254
Total cost of sales		$	691,824			$	491,463			$	533,078			$	245,957			$	324,517
Gross profit:
Drilling and Subsea		$	204,675			$	129,872			$	146,458			$	71,080			$	82,702
Production and Infrastructure			76,052				56,043				67,799				32,253				53,287
Total gross profit		$	280,727			$	185,915			$	214,257			$	103,333			$	135,989
Selling, general and administrative expenses:
Drilling and Subsea		$	98,395			$	86,101			$	92,924			$	42,762			$	42,636
Production and Infrastructure			48,548				42,461				45,186				21,835				26,261
Corporate			—				—				3,331				—				9,983
Total selling, general and administrative expenses		$	146,943			$	128,562			$	141,441			$	64,597			$	78,880
Impairment of goodwill and intangible assets
Drilling and Subsea		$	39,239			$	5,545			$	—			$	—			$	—
Production and Infrastructure			4,776				1,464				—				—				—
Total impairment of goodwill and intangible assets		$	44,015			$	7,009			$	—			$	—			$	—
Operating income:
Drilling and Subsea		$	67,041			$	38,226			$	53,534			$	28,318			$	40,066
Production and Infrastructure			22,728				12,118				22,613				10,418				27,026
Corporate			—				—				(3,331	)			—				(9,983	)
Total segment operating income			89,769				50,344				72,816				38,736				57,109
Contingent consideration		$	—			$	—			$	—			$	—			$	5,800
Transaction expenses			—				—				—				—				2,616
Gain/(loss) on sale of assets			619				(137	)			461				123				420
Income from operations			90,388				50,207				73,277				38,859				49,113
Interest expense, net			24,704				19,451				18,189				9,242				7,689
Expenses related to the Combination			—				—				6,968				—				—
Deferred loan costs written off			—				—				6,082				—				—
Other (income) expense, net			(2,065	)			(1,088	)			(2,308	)			(981	)			751
Income before income taxes			67,749				31,844				44,346				30,598				40,673
Income tax expense			32,938				11,011				20,297				10,235				14,383
Loss from discontinued operations, net of taxes			396				1,342				—				—				—
Net income			34,415				19,491				24,049				20,363				26,290
Income (loss) attributable to non-controlling interest			(39	)			(155	)			(111	)			(73	)			(187	)
Income attributable to common stockholders		$	34,376			$	19,336			$	23,938			$	20,290			$	26,103
Weighted average shares outstanding
Basic			1,232				1,304				1,454				1,309				1,591
Diluted			1,261				1,322				1,468				1,322				1,658
Earnings per share
Basic		$	27.90			$	14.83			$	16.46			$	15.50			$	16.41
Diluted			27.26				14.63				16.31				15.35				15.74

 

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Six months ended June 30, 2011 compared to six months ended June 30, 2010

Revenue

Our revenue for the six months ended June 30, 2011 increased $111.2 million, or 31.8%, compared to the six months ended June 30, 2010. For the six months ended June 30, 2011, our Drilling and Subsea Segment and our Production and Infrastructure Segment comprised 58.2% and 41.8% of our total revenue, respectively, compared to 63.5% and 36.5%, respectively, for the six months ended June 30, 2010. The revenue increase by operating segment was comprised as follows:

Drilling and Subsea Segment—Revenue increased $46.0 million, or 20.7%, to $267.9 million during the six months ended June 30, 2011 compared to the six months ended June 30, 2010. The increase in revenue over the 2010 period was primarily due to the following:

 

•

Approximately $26.1 million of this increase was from drilling products sales attributable to higher drilling activity in the United States and Canada as reflected by the 24% increase in the average North American drilling rig count between the two periods. The higher revenue related to land rigs was in line with the higher rig count, partially offset by an $8.9 million decrease in sales of capital equipment for new offshore rig construction.

 

•

Approximately $19.9 million of this increase was from higher subsea product sales. We completed a significant project in Australia during the first half of 2011, which almost doubled our offshore pipeline services revenue with an increase of $8.8 million, compared to the lower demand for these services experienced in the first half of 2010. Late in the fourth quarter of 2010, we introduced ROVDrill™, a new subsea sampling and data acquisition system, which produced $4.3 million in revenue in the first half of 2011. Our offshore rental products business achieved 50% higher revenue, reporting $5.4 million more in the first half of 2011 than the first half of 2010 due to increased demand for these products. One month of revenue of $0.6 million was recognized in 2011 after completion of the Specialist Acquisition.

Production and Infrastructure Segment—Revenue increased $65.2 million, or 51.2%, to $192.5 million during the six months ended June 30, 2011 compared to the six months ended June 30, 2010. The increase in revenue over the 2010 period was primarily due to the following:

 

•

$32.5 million from the Wood Flowline Acquisition and the Phoinix Acquisition.

 

•

Approximately $21.0 million for incremental production equipment sales, from a combination of higher capital spending by existing customers and the addition of sales to new customers.

 

•

Approximately $12.0 million from valve solutions due to more project orders and an increase in our Canadian market presence.

Cost of sales and gross margin percentage

Our overall cost of sales increased $78.6 million, or 32.0%, for the six months ended June 30, 2011 compared to the six months ended June 30, 2010. Overall gross margin percentage for the six months ended June 30, 2011 was 29.5% compared to 29.6% for the six months ended June 30, 2010.

Drilling and Subsea Segment—Cost of sales increased $34.4 million, or 22.8%, for the six months ended June 30, 2011 compared to the six months ended June 30, 2010 primarily due to increased

 

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shipments. Drilling and Subsea gross margin percentage for the six months ended June 30, 2011 was 30.9% compared to 32.0% for the six months ended June 30, 2010. The decrease in gross margin percentage resulted from (1) costs associated with manufacturing initiatives to improve quality and reliability for tubular handling tools, (2) lower margins on the Australian offshore pipe joint services project caused by higher labor costs in that region, and (3) lower margins on ROV system components purchased from third parties.

Production and Infrastructure Segment—Cost of sales increased $44.2 million, or 46.4%, for the six months ended June 30, 2011 compared to the six months ended June 30, 2010 due to increased shipments, including $20.1 million attributable to the Wood Flowline Acquisition and the Phoinix Acquisition. Gross margin percentage improved for the six months ended June 30, 2011 to 27.7% from 25.3% for the six months ended June 30, 2010. The increase in segment gross margin percentage resulted from efficiencies achieved on higher production volumes and the acquisition of the higher margin flow equipment businesses.

Selling, general and administrative expenses

Selling, general and administrative expenses increased $14.3 million, or 22.1%, for the six months ended June 30, 2011 compared to the six months ended June 30, 2010. As a percentage of revenue, selling, general and administrative expenses declined to 17.1% for the six months ended June 30, 2011 from 18.5% for the six months ended June 30, 2010. The increase in selling, general and administrative expenses by segment and for corporate was as follows:

Drilling and Subsea Segment—Selling, general and administrative expenses for this segment was approximately the same for the six months ended June 30, 2011 compared to the six months ended June 30, 2010. As a percentage of revenue, these expenses declined to 15.9% for the six months ended June 30, 2011 from 19.3% in the six months ended June 30, 2010, the reduction achieved by keeping administrative costs effectively constant during a period of increased production.

Production and Infrastructure Segment—Selling, general and administrative expenses for this segment increased $4.4 million, or 20.3%, for the six months ended June 30, 2011, compared to the six months ended June 30, 2010. As a percentage of revenue, these expenses declined to 13.6% for the six months ended June 30, 2011 from 17.1% in the six months ended June 30, 2010. The increase in expenses was due to payroll related costs incurred to support higher activity levels, especially for production equipment, and approximately $2.2 million was attributable to expenses incurred by the newly acquired flow equipment businesses.

Corporate—Selling, general and administrative expenses for Corporate were $10.0 million for the six months ended June 30, 2011. Corporate costs are not shown separately in the prior period as these similar costs prior to the Combination were imbedded in the segment results of the legacy companies that combined. Corporate costs included, among other items, payroll related costs for general management and management of finance and administration, legal, human resources and information technology; professional fees for legal, accounting and related services; and marketing costs.

Operating income and operating margin percentage

Drilling and Subsea Segment—Operating income increased $11.7 million, or 41.5%, for the six months ended June 30, 2011, compared to the six months ended June 30, 2010. Operating margin percentage increased to 15.0% for the six months ended June 30, 2011 from 12.7% for

 

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the six months ended June 30, 2010. Operating margin percentage increased primarily because of lower selling, general and administrative expenses as a percentage of revenue offset by the lower gross profit margins between periods.

Production and Infrastructure Segment—Operating income increased $16.6 million, or 159%, for the six months ended June 30, 2011, compared to the six months ended June 30, 2010. Operating margin percentage increased to 14.0% for the six months ended June 30, 2011 from 8.2% for the six months ended June 30, 2010. The increased operating income and operating margin percentage was due to the higher gross margins achieved and from the acquired flow equipment businesses.

Interest expense

We incurred $7.7 million of interest expense during the six months ended June 30, 2011, a decrease of $1.6 million from the six months ended June 30, 2010. The decrease in interest was attributable to the reduction in debt levels between the periods as total debt decreased from $271.9 million at January 1, 2010 to $207.9 million at December 31, 2010. This lower debt level remained during most of the second quarter of 2011 resulting in lower interest expense. Debt did increase during the six month period related to the acquisitions, but this debt was not outstanding for the entire period. Also, interest is lower than in the prior year period due to the interest paid on the mandatorily redeemable preferred stock that was fully redeemed in 2010.

Taxes

Tax expense includes current income taxes expected to be due based on taxable income to be reported during the periods in the various jurisdictions in which we conduct business, and deferred income taxes based on changes in the tax effect of temporary differences between the bases of assets and liabilities for financial reporting and tax purposes at the beginning and end of the respective periods. The effective tax rate, calculated by dividing total tax expense by income before income taxes, was 35.4% and 33.4% for the six months ended June 30, 2011 and 2010, respectively. The tax provision for the first half of 2011 is higher than the comparable period in 2010 primarily because our proportion of U.S. earnings, which are subject to a higher rate, and because the applicable U.S. statutory rate for 2011 for the combined companies is 35% while in 2010 several of the legacy companies in the Combination qualified for the lower statutory rate of 34% due to the size of the respective companies.

Year ended December 31, 2010 compared to year ended December 31, 2009

Revenue

Our revenue for the year ended December 31, 2010 increased $70.0 million, or 10.3%, compared to the year ended December 31, 2009. For the year ended December 31, 2010, our Drilling and Subsea Segment and our Production and Infrastructure Segment comprised 63.5% and 36.5% of our total revenue, respectively, compared to 67.2% and 32.8%, respectively, for the year ended December 31, 2009. The revenue increase by operating segment was as follows:

Drilling and Subsea Segment—Revenue increased $19.3 million, or 4.2%, to $474.3 million during the year ended December 31, 2010 compared to the year ended December 31, 2009. Revenue in the drilling product lines increased by approximately $22.1 million, primarily as a result of the approximately 45% increase in the average North American drilling rig count between the two

 

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periods. Orders for drilling products to be used on land rigs did not accelerate until the second half of 2010, as customers exhausted their existing consumables inventories in the first half of the year and as their ability to use equipment and supplies from previously stacked rigs diminished in the face of higher rig utilization. This revenue increase attributable to improvements in the land rig market was partially offset by a reduction in sales of manifolds and cranes used on offshore rigs.

Production and Infrastructure Segment—Revenue increased $50.7 million, or 22.8%, to $273.0 million during the year ended December 31, 2010 compared to the year ended December 31, 2009. The increase in revenue from sales of production equipment and valve products was approximately $37.9 million and $12.8 million, respectively. The increase in revenue was attributable to improved market conditions, the successful addition of several new customers and expansion into new geographic markets in the United States for production equipment products.

Cost of sales and gross margin percentage

Our overall cost of sales increased $41.6 million, or 8.5%, for the year ended December 31, 2010 compared to the year ended December 31, 2009. Overall gross margin percentage for the year ended December 31, 2010 was 28.7% compared to 27.4% for the year ended December 31, 2009.

Drilling and Subsea Segment—Cost of sales increased $2.7 million, or 0.8%, for the year ended December 31, 2010 compared to the year ended December 31, 2009 due to increases in shipments as reflected in higher revenue. Gross margin percentage for the year ended December 31, 2010 was 30.9% compared to 28.5% for the year ended December 31, 2009. The increase in gross margin percentage resulted primarily from efficiencies achieved on increased production of our drilling products and from implementation of manufacturing process improvements for certain of our drilling products, in particular our catwalk systems and blowout preventers.

Production and Infrastructure Segment—Cost of sales increased $38.9 million, or 23.4%, for the year ended December 31, 2010 compared to the year ended December 31, 2009 due to increases in shipments as reflected in higher revenue. Gross margin percentage was down slightly for the year ended December 31, 2010 to 24.8% compared to 25.2% for the year ended December 31, 2009. The slight decrease was attributable to lower margins on the mix of valves sold during 2010, partially offset by cost controls implemented in 2009, that remained in place during 2010.

Selling, general and administrative expenses

Selling, general and administrative expenses increased $12.9 million, or 10.0%, for the year ended December 31, 2010 compared to the year ended December 31, 2009. As a percentage of revenue, selling, general and administrative expenses decreased slightly to 18.9% for the year ended December 31, 2010 from 19.0% for the year ended December 31, 2009. The increase in selling, general and administrative expenses by segment and for corporate was as follows:

Drilling and Subsea Segment—Selling, general and administrative expenses increased $6.8 million, or 7.9%, for the year ended December 31, 2010, compared to the year ended December 31, 2009. As a percentage of revenue, these expenses increased to 19.6% for the year ended December 31, 2010 from 18.9% in the year ended December 31, 2009. The increase in these expenses exceeded revenue growth due to: (1) costs incurred to close the Jupiter, Florida ROV manufacturing facility; and (2) additional stock-based compensation expense related to the Combination.

 

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Production and Infrastructure Segment—Selling, general and administrative expenses increased $2.7 million, or 6.4%, for the year ended December 31, 2010, compared to the year ended December 31, 2009. As a percentage of revenue, these expenses declined to 16.5% for the year ended December 31, 2010 from 19.1% in the year ended December 31, 2009. The increase in dollar costs was due to increased payroll-related expenses to support activity, especially for production equipment as this product line was introduced into new geographic locations.

Corporate—Selling, general and administrative expenses for corporate was $3.3 million for the year ended December 31, 2010. Corporate costs are not shown separately prior to the Combination as these similar costs were imbedded in the segment results of the legacy companies before August 2, 2010.

Operating income and operating margin percentage

Drilling and Subsea Segment—Operating income increased $15.3 million, or 40.0%, during the year ended December 31, 2010 compared to the year ended December 31, 2009. Operating margin percentage increased to 11.3% for 2010 compared to 8.4% for 2009. The increases in operating income and operating margins primarily resulted from higher gross margins during 2010 as compared to 2009, offset slightly by the increase in selling, general and administrative costs for the same period. Additionally, a loss of $5.5 million was recognized during the year ended December 31, 2009 for impairment of goodwill caused by the change in market conditions and declining operating results and outlook related to certain subsea product lines.

Production and Infrastructure Segment—Operating income increased $10.5 million, or 86.6%, during the year ended December 31, 2010 compared to the year ended December 31, 2009 primarily due to the increased revenue as discussed above. Operating margin percentage increased to 8.3% in the year ended December 31, 2010 from 5.4% in 2009 as a result of efficiencies achieved on the higher activity levels and overall selling, general and administrative costs rising at a lesser rate than revenue. Further, a loss of $1.5 million was recognized during the year ended December 31, 2009 for impairment of certain trademark intangible assets.

Interest expense

We incurred $18.2 million of interest expense during the year ended December 31, 2010, a decrease of $1.3 million from the year ended December 31, 2009. This decrease was attributable to a reduction in total debt from approximately $289.9 million at the end of 2009 to $208.0 million at the end of 2010, partially offset by increased amortization of approximately $1.8 million of upfront loan costs in connection with the execution of our new revolving credit facility.

Taxes

The effective tax rate, calculated by dividing total tax expense by income before income taxes, was 45.8% for the year ended December 31, 2010 and 34.6% for the year ended December 31, 2009. The tax rate for 2010 is higher than for 2009 primarily due to certain expenses incurred as part of the Combination included in profit before taxes not being deductible for tax purposes. In addition, our U.S. statutory rate in 2010 is 35% while several of the legacy companies in the Combination were taxed at a statutory rate of 34% in 2009 due to the size of their respective operations.

 

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Year ended December 31, 2009 compared to year ended December 31, 2008

Revenue

Our revenue for the year ended December 31, 2009 decreased $295.2 million, or 30.4%, compared to the year ended December 31, 2008. For the year ended December 31, 2009, our Drilling and Subsea Segment and our Production and Infrastructure Segment comprised 67.2% and 32.8% of our total revenue, respectively, compared to 67.7% and 32.3%, respectively, for the year ended December 31, 2008. The revenue decrease by operating segment was as follows:

Drilling and Subsea Segment—Revenue decreased $203.8 million, or 30.9%, to $455.0 million during the year ended December 31, 2009 compared to the year ended December 31, 2008. Approximately $136.0 million of this decrease resulted from a decline in drilling product sales due to the sudden and steep reduction in drilling activity reflected by the 42% drop in North American rig count over the periods. As a result of the economic downturn that began in 2008 and the decrease in commodity prices, customers significantly curtailed drilling and completion spending throughout 2009. Consumable products sales and repair services experienced the largest declines in revenue with certain capital products such as manifolds and catwalks remaining more resilient as they worked off 2008 backlog. The remaining decrease resulted from a decline in subsea product sales, primarily because the economic downturn negatively impacted the number of ROVs sold in 2009 and other products and services related to subsea activity.

Production and Infrastructure Segment—Revenue decreased $91.4 million, or 29.1%, to $222.4 million during the year ended December 31, 2009 compared to the year ended December 31, 2008. The decrease in revenue resulted from our customers’ reduced activity levels in the face of the economic downturn that began in 2008 and the resulting lower commodity prices.

Cost of sales and gross margin percentage

Our overall cost of sales decreased $200.4 million, or 29.0%, for the year ended December 31, 2009 compared to the year ended December 31, 2008. Overall gross margin percentage for the year ended December 31, 2009 decreased to 27.4% compared to 28.9% for the year ended December 31, 2008.

Drilling and Subsea Segment—Cost of sales decreased $129.0 million, or 28.4%, for the year ended December 31, 2009 compared to the year ended December 31, 2008 due to decreases in shipments as reflected in lower revenue. Gross margin percentage for the year ended December 31, 2009 was 28.5% compared to 31.1% for the year ended December 31, 2008. The decrease in gross margin percentage was caused by the severe reduction in production levels in our manufacturing facilities due to decreased customer demand. In response to the economic downturn, our business reacted early and swiftly to preserve margins by closing four North American facilities and significantly reducing its worldwide workforce.

Production and Infrastructure Segment—Cost of sales decreased $71.4 million, or 30.0%, for the year ended December 31, 2009 compared to the year ended December 31, 2008 due to decreases in shipments as reflected in lower revenue. Gross margin percentage for the year ended December 31, 2009 improved to 25.2% compared to 24.2% for the year ended December 31, 2008. The improvement in gross margin percentage year over year was achieved as a result of management’s focus on controlling costs. We also achieved better margins from our Gainesville, Texas production equipment manufacturing facility in 2009 as it began operations in mid-2008 and reached full production levels by late 2008.

 

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Selling, general and administrative expenses

Selling, general and administrative expenses decreased $18.4 million, or 12.5%, for the year ended December 31, 2009 compared to the year ended December 31, 2008. As a percentage of revenue, selling, general and administrative expenses increased to 19.0% for the year ended December 31, 2009 from 15.1% for the year ended December 31, 2008. The decrease in selling, general and administrative expenses by each segment was as follows:

Drilling and Subsea Segment—Selling, general and administrative expenses decreased $12.3 million, or 12.5%, for the year ended December 31, 2009, compared to the year ended December 31, 2008. As a percentage of revenue, these expenses increased to 18.9% for the year ended December 31, 2009 from 14.9% in the year ended December 31, 2008. The dollar decrease in these expenses was a result of cutting costs across the Drilling and Subsea Segment in 2009. Costs were eliminated by closing several facilities, reducing headcount for sales and administrative support personnel, reducing commissions on lower sales volumes and decreasing marketing costs.

Production and Infrastructure Segment—Selling, general and administrative expenses decreased $6.1 million, or 12.5%, for the year ended December 31, 2009, compared to the year ended December 31, 2008. As a percentage of revenue, these expenses increased to 19.1% for the year ended December 31, 2009 from 15.5% in the year ended December 31, 2008. The dollar decrease was a result of implementing cost saving measures, such as reducing headcount and eliminating certain incentive bonuses.

Operating income and operating margin percentage

Drilling and Subsea Segment—Operating income decreased $28.8 million, or 43.0%, during the year ended December 31, 2009 compared to the year ended December 31, 2008. Operating income includes an impairment loss of $39.2 million in 2008 and $5.5 million in 2009. Operating margin percentage, excluding these impairment charges, was 9.6% and 16.1% in 2009 and 2008, respectively. The decrease in this adjusted operating income amount and margin percentage was due to the reduction in revenue and gross margins as discussed above, the increased selling, general and administrative expenses as a percentage of revenue also discussed above and a $5.5 million loss incurred in 2009 due to an impairment of goodwill related to the change in market conditions and declining operating results related to certain subsea product lines, partially offset by a $39.2 million loss incurred by this segment during 2008 due to an impairment of goodwill and the intangible assets of customer relationships and non-compete contracts. The 2008 impairment loss was as a result of the change in market conditions for the repair and refurbishment business and the business’ declining operating results.

Production and Infrastructure Segment—Operating income decreased $10.6 million, or 46.7%, during the year ended December 31, 2009 compared to the year ended December 31, 2008, primarily due to the decreased revenue as discussed above. Operating margin percentage decreased to 5.4% for 2009 from 7.2% in 2008. Furthermore, we incurred a $1.5 million loss during the year ended December 31, 2009 for the impairment of certain trademark intangible assets, and a $4.8 million loss during the year ended December 31, 2008 for the impairment of goodwill and certain trademarks, both losses caused by declining economic conditions and operating results.

 

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Interest expense

We incurred $19.5 million of interest expense during the year ended December 31, 2009, a decrease of $5.3 million from the year ended December 31, 2008. This decrease is attributable to the substantial reduction in debt levels as all of the businesses focused on reducing investments in working capital and curtailing capital spending. Over the course of the year, debt levels were reduced from approximately $371.8 million at the beginning of 2009 to $289.9 million at the end of the year.

Taxes

The effective tax rate was 34.6% for the year ended December 31, 2009 and 48.6% for the year ended December 31, 2008. The tax rate for 2009 is lower than for 2008 primarily due to the impairment of goodwill recorded in 2008 for which there was no tax benefit.

Liquidity and capital resources

Sources and uses of liquidity

Our internal sources of liquidity are cash on hand and cash flows from operations, while our primary external sources include our revolving credit facility described below, trade credit and sales of our common stock. Our primary uses of capital have been for acquisitions, on-going maintenance or growth capital expenditures, inventories and sales on credit to our customers. We continually monitor potential capital sources, including equity and debt financing, in order to meet our investment and target liquidity requirements. Our future success and growth will be highly dependent on our ability to continue to access outside sources of capital.

Our total 2011 capital expenditure budget is $60.2 million, which consists of, among other items, investments in expanding our rental fleet of subsea equipment, expanding certain manufacturing facilities and purchasing of machinery and equipment. This budget does not include expenditures for potential business acquisitions.

While we have budgeted $60.2 million for the year ending December 31, 2011, the actual amount of capital expenditures may fluctuate based on market conditions. For the first six months of 2011, we have incurred $20.3 million for capital expenditures, which has been funded from borrowings under our revolving credit facility and internally generated funds. We believe the net proceeds from this offering, together with cash flows from operations and additional borrowings under our revolving credit facility, should be sufficient to fund our requirements for the remainder of 2011 and for 2012.

Although we do not budget for acquisitions, pursuing growth through acquisitions is a significant part of our business strategy. We have expanded and diversified our product portfolio and business lines with the acquisition of eight businesses in 2011 for a total consideration of approximately $586 million. We used cash on hand and borrowings under our revolving credit facility to finance these acquisitions. We continue to actively review acquisition opportunities on an ongoing basis. Our ability to make significant additional acquisitions for cash will require us to obtain additional equity or debt financing, which we may not be able to obtain on terms acceptable to us or at all.

On August 2, 2010, we entered into a senior secured credit facility, under which we may borrow up to $450 million. Effective June 29, 2011, we amended our senior secured revolving credit

 

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facility to, among other things, increase the commitment to $750 million. As of June 30, 2011, we had $279.6 million of indebtedness outstanding under our revolving credit facility. We have incurred an additional $452.8 million of indebtedness under our revolving credit facility in connection with our five acquisitions completed after June 30, 2011. For more information regarding our revolving credit facility, see “—Our senior secured credit facility.”

Our cash flows for the years ended December 31, 2008, 2009 and 2010 and for the six months ended June 30, 2010 and 2011 are presented below (in millions):

 

		Year ended December 31,												Six months ended June 30,
		2008				2009				2010				2010				2011
Net cash provided by operating activities		$	112.5			$	107.8			$	66.0			$	25.9			$	1.9
Net cash used in investing activities			(160.9	)			(10.9	)			(19.2	)			(5.0	)			(84.8	)
Net cash provided by/(used in) financing activities			58.9				(94.5	)			(54.3	)			(21.4	)			126.1
Net increase (decrease) in cash and cash equivalents			(12.7	)			7.0				(6.5	)			(1.2	)			45.8
Free cash flow (unaudited)			72.9				92.7				46.4				21.1				(18.6	)

A reconciliation of free cash flow to cash flow from operating activities is as follows:

 

		Year ended December 31,												Six months ended June 30,
		2008				2009				2010				2010				2011
Free cash flow—Reconciliation:
Cash flow from operating activities		$	112.5			$	107.8			$	66.0			$	25.9			$	1.9
Capital expenditures for property and equipment			(39.6	)			(15.1	)			(19.6	)			(4.8	)			(20.5	)
Free cash flow		$	72.9			$	92.7			$	46.4			$	21.1			$	(18.6	)

Cash flows provided by operating activities

Net cash provided by operating activities was $66.0 million for the year ended December 31, 2010 and $107.8 million for the year ended December 31, 2009. This $41.8 million reduction in operating cash flow was primarily due to the significant changes in market conditions, with our business contracting during the global economic downturn in 2009, allowing for reductions in our investments in working capital, and a return to growth with modest investments in working capital during 2010 as the economy recovered. Net cash provided by operating activities was $1.9 million for the six months ended June 30, 2011, and net cash provided by operations was $25.9 million for the six months ended June 30, 2010. This change in cash flows was also driven by our investment in working capital due to higher business activity levels as we strategically stocked inventories in our regional distribution centers in order to meet the increased demand.

Net cash provided by operating activities was $112.5 million for the year ended December 31, 2008 and $107.8 million for the year ended December 31, 2009. This $4.7 million reduction in operating cash flow was primarily due to the significant changes in market conditions, with our business contracting during the global economic downturn in 2009, partially offset by a reduction in working capital investments in the year ended December 31, 2009.

Our operating cash flows are sensitive to a number of variables, the most significant of which is the level of drilling and production activity for oil and natural gas reserves. These activity levels

 

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are in turn impacted by the volatility of oil and natural gas prices, regional and worldwide economic activity and its effect on demand for hydrocarbons, weather, infrastructure capacity to reach markets and other variable factors. These factors are beyond our control and are difficult to predict. For additional information on the impact of changing prices on our financial position, see “— Quantitative and qualitative disclosures about market risk” below.

Cash flows used in investing activities

Net cash used in investing activities of $19.2 million for the year ended December 31, 2010 was $8.3 million higher than for the year ended December 31, 2009. The increase was primarily attributable to investing in property and equipment as market conditions improved. Other than capital required for acquisitions, we expect to fund all maintenance and other growth capital expenditures from our current cash on hand and from internally generated funds. Net cash used in investing activities was $84.8 million and $5.0 million for the six months ended June 30, 2011 and June 30, 2010, respectively, a $79.8 million increase. Of this increase, $32.7 million was for the Wood Flowline Acquisition, $23.6 million was for the Phoinix Acquisition and $9.0 million was for the Specialist Acquisition, while the remaining amount was primarily attributable to increased investments in property and equipment.

Net cash used in investing activities was $160.9 million for the year ended December 31, 2008 compared to $10.9 million for the year ended December 31, 2009. This change was primarily due to $134.0 million of cash used for acquisitions of businesses for the year ended December 31, 2008 compared to $1.7 million in the year ended December 31, 2009.

Cash flows provided by financing activities

Net cash used in financing activities was $54.3 million and $94.5 million for the years ended December 31, 2010 and December 31, 2009, respectively. For the year ended December 31, 2010, we used a net of $83.4 million to pay down our long-term debt, and in conjunction with the Combination we repurchased $25 million of our common stock, and we issued $64.9 million in new shares for cash. The remaining use of cash was primarily for debt issue costs. For the year ended December 31, 2009, we paid down long-term debt by $94.5 million from internally generated cash flows from operations. Net cash provided by financing activities was $126.1 million for the six months ended June 30, 2011, primarily from draws on our credit facility and proceeds from stock issuances, and cash used in financing activities was $21.4 million for the six months ended June 30, 2010, primarily for the repayment of long-term debt.

Net cash used in financing activities was $58.9 million for the year ended December 31, 2008 compared to cash provided by financing activities of $94.5 million for the year ended December 31, 2009. This change was due to $94.1 million in net payments on long-term debt for the year ended December 31, 2009, compared to $36.3 million in net borrowings in the year ended December 31, 2008. Also, we received an insignificant amount of proceeds from stock issuances in the year ended December 31, 2009, but we received $25.7 million in proceeds from stock issuances in the year ended December 31, 2008.

Our senior secured credit facility

We have a senior secured credit facility (as amended, the “credit agreement”) with Wells Fargo Bank, National Association, as Administrative Agent, and certain other financial institutions. The credit agreement provides for a $750.0 million revolving credit facility, including up to $75.0 million for letters of credit and up to $25.0 million in swingline loans, and matures in August 2014.

 

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As of June 30, 2011, we had borrowings of $279.6 million under the credit agreement. We had undrawn availability under our credit facility of approximately $210 million at December 31, 2010 and approximately $292 million at June 30, 2011. Effective June 29, 2011, we amended our senior secured credit facility to, among other things, increase the commitment to $750 million and have incurred an additional $452.8 million of indebtedness under our credit facility in connection with our five acquisitions completed after June 30, 2011. As of August 29, 2011 we had borrowings of approximately $687 million and undrawn availability of approximately $58 million under our amended credit facility.

It is anticipated that future borrowings under the credit agreement will be available for working capital and general corporate purposes, for permitted mergers and acquisitions, and for permitted distributions. It is anticipated that the revolving credit facility under the credit agreement will be available to be drawn on and repaid during the term thereof so long as we are in compliance with the terms of the credit agreement, including certain financial covenants.

The credit agreement contains various covenants that, among other things, limit our ability to grant certain liens, make certain loans and investments, to make capital expenditures above a threshold amount, make distributions, enter into mergers or acquisitions unless certain conditions are satisfied, enter into hedging transactions, change our lines of business, prepay certain indebtedness, enter into certain affiliate transactions or engage in certain asset dispositions. Additionally, the credit agreement limits our ability to incur additional indebtedness with certain exceptions.

The credit agreement also contains financial covenants, which, among other things, require us, on a consolidated basis, to maintain specified financial ratios or conditions summarized as follows:

 

•

Total funded debt to adjusted EBITDA (as defined as the “Leverage Ratio” in the credit agreement) of not more than 3.75 to 1.0 for fiscal quarters ending through December 31, 2011, 3.50 to 1.0 for fiscal quarters ending from January 1, 2012 through December 31, 2012, 3.25 to 1.0 for fiscal quarters ending from January 1, 2013 through December 31, 2013 and 3.00 to 1.0 for fiscal quarters ending thereafter;

 

•

Adjusted EBITDA to interest expense (as defined as the “Interest Coverage Ratio” in the credit agreement) of not less than 3.0 to 1.0; and

 

•

Balance sheet debt to total capitalization (as defined as the “Capitalization Ratio” in the credit agreement) of not more than 0.65 to 1.0.

We were in compliance with the aforementioned financial covenants at December 31, 2010 and June 30, 2011.

Under the credit agreement, EBITDA is defined to generally exclude the effect of non-cash items, and to give pro forma effect to acquisitions and non-ordinary course asset sales (with adjustments to EBITDA of the acquired businesses or related to the sold assets to be made in accordance with the guidelines for pro forma presentations set forth by the SEC or in a manner otherwise reasonably acceptable to the Administrative Agent under the credit agreement). All of the obligations under the credit agreement are secured by first priority liens (subject to permitted liens) on substantially all of the assets of the Company and its domestic restricted subsidiaries, with exceptions for real property and certain other assets set forth in the credit agreement. Additionally, all of the obligations under the credit agreement are guaranteed by the wholly-owned domestic subsidiaries of the Company.

 

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We have the ability to elect the interest rate applicable to borrowings under the credit agreement. Interest under the credit agreement may be determined by reference to (1) the London interbank offered rate, or LIBOR, plus an applicable margin between 2.0% and 3.75% per annum (with the applicable margin depending upon our ratio of total funded debt to adjusted EBITDA) or (2) the Adjusted Base Rate plus an applicable margin between 0.5% and 2.25% per annum (with the applicable margin depending upon our ratio of total funded debt to adjusted EBITDA). The Adjusted Base Rate will be equal to the highest of (1) the Federal Funds Rate, as published by the Federal Reserve Bank of New York, plus one half of 1.0%, (2) the prime rate of Wells Fargo Bank, National Association, as established from time to time at its principal U.S. office and (3) daily LIBOR for an interest period of one-month plus 1.5%. The weighted average interest rates at June 30, 2011 and December 31, 2010 on all outstanding principal amounts of indebtedness under the credit agreement were 4.5% and 3.0%, respectively.

Interest is payable quarterly for base rate loans and at the end of applicable interest periods for LIBOR loans, except that if the interest period for a LIBOR loan is longer than three months, interest is paid at the end of each three-month period.

If an event of default exists under the credit agreement, the lenders have the right to accelerate the maturity of the obligations outstanding under the credit agreement and exercise other rights and remedies. Each of the following constitutes an event of default under the credit agreement:

 

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Failure to pay any principal when due or any interest, fees or other amount within certain grace periods;

 

•

Representations and warranties in the credit agreement or other loan documents being incorrect or misleading in any material respect;

 

•

Failure to perform or otherwise comply with the covenants in the credit agreement or other loan documents, subject, in certain instances, to grace periods;

 

•

Impairment of security under the loan documents affecting collateral having a fair market value in excess of $5.0 million;

 

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The actual or asserted invalidity of any material provisions of the guarantees of the indebtedness under the credit agreement;

 

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Default by us or our restricted subsidiaries on the payment of any other indebtedness with a principal amount in excess of $20.0 million, any default in the performance of any obligation or condition with respect to such indebtedness beyond the applicable grace period if the effect of the default is to permit or cause the acceleration of the indebtedness, or such indebtedness will be declared due and payable prior to its scheduled maturity;

 

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Bankruptcy or insolvency events involving us or our restricted subsidiaries;

 

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The entry, and failure to pay, of one or more adverse judgments in excess $20.0 million, upon which enforcement proceedings are commenced or that are not stayed pending appeal; and

 

•

The occurrence of a change in control (as defined in the credit agreement).

This offering will not constitute a change in control so long as no “person” or “group” (as such terms are used in Sections 13(d) and 14(d) of the Securities Exchange Act of 1934 with certain exclusions) other than SCF becomes the beneficial owner, directly or indirectly, of 33% or more of our voting stock.

 

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We have entered into derivative contracts to hedge our exposure to interest rate fluctuations on $158.1 million of the debt outstanding at June 30, 2011. See “—Quantitative and qualitative disclosures about market risk” below for details regarding these contracts.

Obligations and commitments

Our debt, lease and financial obligations as of December 31, 2010 will mature and become due and payable according to the following table (amounts in thousands of U.S. dollars):

 

		2011				2012-2014				2015				After 2015				Total
Revolving credit facilities		$	—			$	204,000			$	—			$	—			$	204,000
Other debt			3,209				715				—				—				3,924
Derivative liability			2,194				2,162				—				—				4,356
Operating leases			10,033				13,424				1,403				6,236				31,096
Letters of credit			8,260				1,169				—				—				9,429
Total		$	23,696			$	221,470			$	1,403			$	6,236			$	252,805

Critical accounting policies and estimates

The discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of our financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. Certain accounting policies involve judgments and uncertainties to such an extent that there is a reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our consolidated financial statements. We provide expanded discussion of our more significant accounting policies, estimates and judgments below. We believe that these accounting policies reflect our more significant estimates and assumptions used in preparation of our consolidated financial statements.

Revenue recognition

The substantial majority of our revenue is recognized when the associated goods are shipped and title passes to the customer or when services have been rendered, as long as all of the criteria for recognition described in Note 2 to our consolidated financial statements have been met. The only revenue recognition criteria requiring judgment on these sales is assurance of collectability. We carefully evaluate credit worthiness of our customers before extending payment terms other than cash upfront, and historically we have not incurred significant losses for bad debt.

Revenue generated from long-term contracts, typically longer than six months in duration, is recognized on the percentage-of-completion method of accounting. Approximately 14% of our 2010 revenue was accounted for on this basis. There are significant estimates and judgments involved in recognizing revenue over the term of the contract. We generally recognize revenue

 

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and cost of goods sold each period based upon the advancement of the work-in-progress. The percentage complete is determined based on the ratio of costs incurred to-date to total estimated costs for the project. The percentage-of-completion method requires management to calculate reasonably dependable estimates of progress towards completion and total contract costs. Each period these long-term contracts are re-evaluated and may result in upward or downward revisions in estimated total costs, which are accounted for in the period of the change to reflect a catch up adjustment for the cumulative impact from inception of the contract to date in the period of the revision. Whenever revisions of estimated contract costs and contract value indicates that the contract costs will exceed estimated revenue, thus creating a loss, a provision for the total estimated loss is recorded in that period.

Revenue from the rental of equipment or providing of services is recognized over the period when the asset is rented or services are rendered and collectability is reasonably assured. Rates for asset rental and service provision are priced on a per day, per man hour, or similar basis. There are typically delays in receiving some field tickets reporting utilization of equipment or personnel requiring us to make estimates for revenue recognition in the period. In the following period, these estimates are adjusted to actual field tickets received late.

Fair value of common stock

In connection with the Combination, the fair value of FOT’s common stock was determined using common market pricing principles. This valuation was reviewed by an independent valuation firm utilizing similar principles which rendered fairness opinions in connection with the approval of the Combination by the boards of directors or independent special committees, as applicable, of each of the combining companies. Following the completion of the Combination, we developed a methodology to consistently value our stock on a regular basis to support a variety of corporate and strategic activities. Among these activities are public company benchmarking, accounting for share-based compensation awards and valuing the total purchase price for acquisitions when our shares comprise a part of the consideration. We use the same fair value for our common stock in effect at any particular time across each of these corporate and strategic activities. The methodology we developed used common market pricing principles to produce a fair value per share of common stock that reflects equity market pricing fundamentals, industry activity levels, our business and financial performance and our organizational maturity. This methodology was designed to be robust enough to be applied in a consistent manner at each evaluation point to reflect developments in our industry, while at the same time being simple enough so as to minimize management judgment or bias in the calculation of the fair value of our stock.

Our management presented this methodology and the resulting fair value of our common stock to our board of directors at its first regularly scheduled meeting following the Combination for its review and approval. Since the approval of this methodology by the board of directors, management has presented the calculation of the fair value using the same methodology to the board of directors for its review and approval at each subsequent regularly scheduled board meeting, and in July 2011 after we completed a number of acquisitions simultaneously. Management and our board of directors monitor developments at our company and are prepared to re-evaluate and modify the fair value of our common stock in the event that other such significant developments warrant such a re-evaluation and modification between regularly scheduled board meetings.

 

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The basic tenets of our methodology are as follows:

 

•

General concept.    We use normalized comparable public company trading multiples and apply those multiples to our corresponding financial results and financial projections in order to calculate an implied equity value. We then apply an illiquidity discount to that implied equity value and use that adjusted implied equity value to calculate the fair value per share.

 

•

Use of public company comparables.    Our board of directors reviewed and approved a group of comparable public companies whose equity market pricing reflected the market’s view on key sector, geographic and product type exposure fundamentals similar to those that drive our business. Our board of directors regularly reviews with management the group of comparable companies used for purposes of this analysis and has made modifications to the group of comparable public companies when, in its discretion, such companies were no longer valid comparables or when market data about a company is no longer available. Otherwise, we use the same group of public company comparables each time we perform the fair value methodology.

 

•

Normalization.    In order to mitigate short term volatility, our methodology averages four identical sets of trading multiples of the comparable public companies over different periods of time. The four periods of time include a current set of multiples and a set from each of the prior three quarters. This helps mitigate short term volatility of the underlying multiples and the resulting impact on the fair value of our common stock while still taking into account changes in the perceptions of the public markets of the fair value of other companies in our industry.

 

•

Selected multiples and weighting.    Our methodology uses a weighted mix of EBITDA and book value multiples from our public company comparables. We further average the following time periods for each EBITDA-based multiple: (1) prior calendar year; (2) trailing twelve months; (3) current calendar year forecast; and (4) forward two calendar year forecasts. We also average the following book value multiples: (1) enterprise value to adjusted book value; (2) enterprise value to tangible adjusted book value; and (3) market value of equity to book value of equity. Each of these sets of multiples are averaged across the normalization periods described above to produce a time series average multiple for the applicable metric across the applicable period and applied against our corresponding financial results.

 

•

Illiquidity discount.    Because our common stock is not publicly traded, common valuation practice dictates that we apply an illiquidity discount to the implied equity value produced by the public company multiples we use in our fair value methodology. Historically we utilized an illiquidity discount of 30% through the February 2011 board meeting. Our board of directors approved this illiquidity discount on the basis of its belief that, in a sale of our common stock in an arms-length transaction, such a discount to the value of our common stock would be applied by the buyer due to the lack of liquidity in the stock and the low prospects for liquidity of that stock in the near term. Commencing with the fair value determination at the meeting of our board of directors in May 2011, the illiquidity discount was reduced to 20%. This reflected our board of directors belief that the prospects for the creation of a liquid market in the near to medium term had been enhanced as a result of our consideration of this offering and our increased organizational maturity. At the same time, our board of directors recognized that there were substantial risks associated with the completion of a transaction that provided liquidity to the holders of our common stock. Thus, our board of directors concluded that it was still appropriate to apply a liquidity discount to the implied equity value of our company.

 

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At the board of directors meeting in August 2011, the illiquidity discount was returned to 30%. This was decided in order to reflect: (1) the uncertainty over the timing of this offering due to heightened concerns over the possibility of a return to recession in the world economy, and (2) our assessment that potential public investors of companies like ours were becoming more risk averse, which we believed could impact the valuations of less seasoned companies with a less liquid flotation of shares.

We have applied this methodology consistently since the Combination.

Share-based compensation

We account for awards of share-based compensation at fair value on the date granted to employees and recognize the compensation expense in the financial statements over the requisite service period. Fair value of the share-based compensation was measured using the Black-Scholes model for most of the outstanding options and a binomial model for certain share-based compensation instruments issued by one of the legacy companies. These models require assumptions and estimates for inputs, especially the estimate of the volatility in the value of the underlying share price, that affect the resultant values and hence the amount of compensation expense recognized. We determine the estimate of volatility periodically based on the averages for the stocks of comparable publicly traded companies.

Inventories

Inventory, consisting of finished goods and materials and supplies held for resale, is carried at the lower of cost or market. We continuously evaluate our inventories, based on an analysis of stocking levels, historical sales experience and future sales forecasts, to determine obsolete, slow-moving and excess inventory. While we have policies for calculating and recording reserves against inventory carrying values, we exercise judgment in establishing and applying these policies.

Business combinations, goodwill and other intangible assets

Goodwill acquired in connection with business combinations represents the excess of consideration over the fair value of net assets acquired. Certain assumptions and estimates are employed in determining the fair value of assets acquired, evaluating the fair value of liabilities assumed, as well as in determining the allocation of goodwill to the appropriate reporting unit. These estimates may be affected by factors such as changing market conditions, technological advances in the oil and natural gas industry or changes in regulations governing that industry. The most significant assumptions requiring the most judgment involve identifying and estimating the fair value of intangible assets and the associated useful lives for establishing amortization periods. To finalize purchase accounting for significant acquisitions, we utilize the services of independent valuation specialists to assist in the determination of the fair value of acquired intangible assets.

There are also significant judgments involved in estimating the value of any contingent purchase consideration, for example, additional cash or stock consideration to be earned based on the future results of the acquired business. The value of this potential additional consideration is required to be estimated and recorded as part of the purchase accounting for the acquisition in the period when the transaction is effective. Each quarter these estimates must be re-evaluated based on actual results achieved and changes in circumstances, and the contingent consideration marked-to-market with any change in value reflected in profit and loss for the period.

 

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For goodwill and intangible assets with indefinite lives, an assessment for impairment is performed annually or whenever an event indicating impairment may have occurred. We typically complete our annual impairment test for goodwill and other indefinite-lived intangibles using an assessment date of December 31. Goodwill is reviewed for impairment by comparing the carrying value of each reporting unit’s net assets, including allocated goodwill, to the estimated fair value of the reporting unit. As of December 31, 2010, we had four reporting units. We determine the fair value of our reporting units using a discounted cash flow approach. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. Such estimates and assumptions include revenue growth rates, future operating margins, the weighted average cost of capital, and future market conditions, among others. We believe that the estimates and assumptions used in our impairment assessments are reasonable. If the reporting unit’s carrying value is greater than its fair value, a second step is performed whereby the implied fair value of goodwill is estimated by allocating the fair value of the reporting unit in a hypothetical purchase price allocation analysis. We recognize a goodwill impairment charge for the amount by which the carrying value of goodwill exceeds its reassessed fair value.

In the third quarter of 2010, we implemented a change in accounting estimate to adjust the useful lives of certain of our customer relationship and distributor relationship intangible assets. This change resulted in an approximately $2.2 million reduction in the amortization expense in the year ended December 31, 2010, and an increase to net income of $1.4 million (or $1.00 per diluted share). We extended the useful lives of these intangible assets based on positive changes in customer attrition rates and due to several factors pursuant to the Combination which further strengthen these relationships.

Income taxes

We follow the liability method of accounting for income taxes. Under this method, deferred income tax assets and liabilities are determined based upon temporary differences between the carrying amounts and tax bases of our assets and liabilities at the balance sheet date, and are measured using enacted tax rates and laws that will be in effect when the differences are expected to reverse. We record a valuation reserve whenever management believes that it is more likely than not that any deferred tax asset will not be realized. We must apply judgment in assessing the realizability of deferred tax assets, including estimating our future taxable income, to predict whether a future cash tax reduction will be realized from the deferred tax asset. Any changes in the valuation allowance due to changes in circumstances and estimates are recognized in income tax expense in the period the change occurs.

The accounting guidance for income taxes requires that we recognize the financial statement benefit of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. If a tax position meets the “more likely than not” recognition criteria, the accounting guidance requires the tax position be measured at the largest amount of benefit greater than 50% likely of being realized upon ultimate settlement. If management determines that likelihood of sustaining the realization of the tax benefit is less than or equal to 50%, then the tax benefit is not recognized in the financial statements.

We have operations in countries other than the United States. Consequently, we are subject to the jurisdiction of a number of taxing authorities. The final determination of tax liabilities involves the interpretation of local tax laws, tax treaties, and related authorities in each

 

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jurisdiction. Changes in the operating environment, including changes in tax law or interpretation of tax law and currency repatriation controls, could impact the determination of our tax liabilities for a given tax year.

Property and equipment

Property and equipment is stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method based on the estimated useful lives of assets, generally 3 to 19 years. We have established standard lives for certain classes of assets.

We review long-lived assets for potential impairment whenever events or changes in circumstances indicate that the carrying amount of a long-lived asset may not be recoverable. In performing the review for impairment, future cash flows expected to result from the use of the asset and its eventual disposal are estimated. If the undiscounted future cash flows are less than the carrying amount of the assets, the asset is impaired. The amount of the impairment is measured as the difference between the carrying value and the estimated fair value of the asset. The fair value is determined either through the use of an external valuation, or by means of an analysis of discounted future cash flows based on expected utilization. The impairment loss recognized represents the excess of the assets carrying value as compared to its estimated fair value.

Effective January 1, 2010, we implemented a change in accounting estimate to adjust the useful lives of marine electronic survey equipment held for rent. This change resulted in an approximately $3.2 million reduction in the depreciation expense in the year ended December 31, 2010, an increase to net income of $2.1 million (or $1.43 per diluted share). We extended the useful lives of these long-lived assets based on our review of their historical service lives, technological improvements in the assets and proven longer useful mechanical and technical lives.

Recognition of provisions for contingencies

In the ordinary course of business, we are subject to various claims, suits and complaints. We, in consultation with internal and external advisors, will provide for a contingent loss in the consolidated financial statements if it is probable that a liability has been incurred at the date of the consolidated financial statements and the amount can be reasonably estimated. If it is determined that the reasonable estimate of the loss is a range and that there is no best estimate within the range, provision will be made for the lower amount of the range. Legal costs are expensed as incurred.

An assessment is made of the areas where potential claims may arise under the contract warranty clauses. Where a specific risk is identified and the potential for a claim is assessed as probable and can be reasonably estimated, an appropriate warranty provision is recorded. Warranty provisions are eliminated at the end of the warranty period except where warranty claims are still outstanding. The liability for product warranty is included in other accrued liabilities on the consolidated balance sheet.

Recent accounting pronouncements

In January 2010, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2010-06 “Improving Disclosures about Fair Value Measurements” (“ASU No. 2010-06”) as an update to Accounting Standards Codification Topic 820, “Fair Value

 

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Measurements and Disclosures” (“ASC Topic 820”). ASU No. 2010-06 requires additional disclosures about transfers between Levels 1 and 2 of the fair value hierarchy and disclosures about purchases, sales, issuances and settlements in the roll forward of activity in Level 3 fair value measurements. ASU No. 2010-06 is effective for interim and annual reporting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances, and settlements in the rollforward of activity in Level 3 fair value measurements. Those disclosures are effective for fiscal years beginning after December 15, 2010, and for interim periods within those fiscal years. We adopted the required provisions of ASU No. 2010-06. There was no significant impact to our consolidated financial statements.

In June 2011, the FASB issued an update to ASC 220, Presentation of Comprehensive Income. This ASU provides that an entity that reports items of other comprehensive income has the option to present comprehensive income in either 1) a single statement that presents the components of net income and total net income, the components of other comprehensive income and total other comprehensive income, and a total for comprehensive income; or 2) a two-statement approach which presents the components of net income and total net income in a first statement, immediately followed by a financial statement that presents the components of other comprehensive income, a total for other comprehensive income, and a total for comprehensive income. The option in current GAAP that permits the presentation of other comprehensive income in the statement of changes in equity was eliminated. The guidance will be applied retrospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is permitted. The adoption of this guidance will not have a material impact on our consolidated financial statements.

In December 2010, the FASB issued FASB ASU 2010-28, which affects entities evaluating goodwill for impairment under FASB ASC 350-20. ASU 2010-28, among other things, requires entities with a zero or negative carrying value to assess, considering qualitative factors, whether it is more likely than not that goodwill impairment exists. If an entity concludes that it is more likely than not that goodwill impairment exists, the entity must perform step 2 of the goodwill impairment test. ASU 2010-28 is effective for impairment tests performed during an entity’s fiscal year beginning after December 15, 2010, with early adoption not permitted. We do not believe the adoption of this ASU will have a material impact on the Company’s financial position or results of operations.

Off-balance sheet arrangements

As of December 31, 2010 and June 30, 2011, we had no off-balance sheet instruments or financial arrangements, other than operating leases entered into in the ordinary course of business.

Inflation

Global inflation has been relatively low in recent years and did not have a material impact on our results of operations during 2009 and 2010. Although the impact of inflation has been insignificant in recent years, it is still a factor in the global economy and we tend to experience inflationary pressure on the cost of raw materials and components used in our products.

Quantitative and qualitative disclosures about market risk

We are currently exposed to market risk from changes in foreign currency and changes in interest rates. From time to time, we may enter into derivative financial instrument transactions to manage or reduce our market risk, but we do not enter into derivative transactions for speculative purposes. A discussion of our market risk exposure in financial instruments follows.

 

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Non-U.S. currency exchange rates

In certain regions, we conduct our business in currencies other than the U.S. dollar and the functional currency is the applicable local currency. We operate primarily in the U.S., Canadian and UK markets, and as a result our primary exposure to fluctuations in currency exchange rates relates to fluctuations between the U.S. dollar and each of the Canadian dollar, the British pound sterling, and, then, to a lesser degree, the Mexican Peso, the Euro and the Singapore dollar. In countries in which we operate in the local currency, the effects of currency fluctuations are largely mitigated because local expenses of such operations are also generally denominated in the local currency. However, there may be instances in which costs and revenue will not be matched with respect to currency denomination and we may experience economic loss and a negative impact on earnings or net assets solely as a result of foreign currency exchange rate fluctuations. To the extent that we continue our expansion on a global basis, management expects that increasing portions of revenue, costs, assets and liabilities will be subject to fluctuations in foreign currency valuations.

Assets and liabilities for which the functional currency is the local currency are translated using the exchange rates in effect at the balance sheet date, resulting in translation adjustments that are reflected as accumulated other comprehensive income in the stockholders’ equity section on our balance sheet. We recorded an adjustment of approximately $7.8 million to increase our equity account for the six months ended June 30, 2011 to reflect the net impact of the strengthening of other applicable currencies against the U.S. dollar, most of which reflected the relative strengthening of the Canadian dollar and the British pound sterling.

Interest rates

We are subject to interest rate risk on our floating interest rate borrowings. Floating rate debt, where the interest rate fluctuates periodically, exposes us to short-term changes in market interest rates.

While all of the long-term debt outstanding under our credit facilities is structured on floating interest rate terms, approximately only 43% of our long-term debt outstanding as of June 30, 2011 was effectively subject to fully floating interest rate terms after giving effect to derivative hedging arrangements. A one percentage point increase in the interest rates on our $279.6 million of indebtedness outstanding as of June 30, 2011 would cause a $1.2 million pre-tax annual increase in interest expense.

Hedging and use of derivative instruments

We utilize interest rate derivative instruments to hedge our exposure to variable cash flows on a portion of our floating rate debt (i.e., cash flow hedges). These instruments are not used for trading or speculative purposes. We record the fair value of these interest rate derivative instruments on our balance sheet as either derivative assets or derivative liabilities, as applicable. Fair value was estimated using a discounted cash flow approach.

Of these derivative instruments, $54 million qualify for hedge accounting as they reduce the interest rate risk of the underlying hedged item and were formally designated by us as cash flow hedges at inception. These derivative instruments result in financial impacts that are inversely correlated to those of the items being hedged. Since the terms of the hedged item and the instruments substantially coincide, the hedge is expected to offset changes in expected cash flows

 

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due to fluctuations in the variable rate and, therefore, we currently do not expect any ineffectiveness. Changes in the fair value of the instruments designated as cash flow hedges are deferred in accumulated other comprehensive income, net of tax, to the extent the contracts are effective as hedges, until settlement of the underlying hedged transaction. If the necessary correlation ceases to exist or if physical delivery of the hedged item becomes improbable, we would discontinue hedge accounting and apply mark-to-market accounting, with any changes in the fair values of the derivative instruments then recognized in earnings. Amounts paid or received from interest rate derivative instruments are charged or credited to interest expense and matched with the cash flows and interest expense of the debt being hedged, resulting in an adjustment to the effective interest rate.

As of June 30, 2011, we had an interest rate swap agreement to convert variable interest payments related to $34 million of debt to fixed interest payments. This swap expires in November 2011 and has a fixed rate of 4.9%, plus the applicable margin. As of June 30, 2011, we also had an interest rate collar arrangement to reduce the variability in interest payments related to $20 million of floating rate debt. This interest rate collar instrument expires in November 2011 and has a floor interest rate of 4.4%, plus the applicable margin, and a cap interest rate of 5.4%, plus the applicable margin. After giving effect to all the derivative instruments we had as of June 30, 2011, the net effective interest rate under our outstanding credit facilities as of June 30, 2011 was 5.1%. Our balance sheet at June 30, 2011 included a current derivative liability of $0.9 million related to these interest rate swap agreements.

Approximately $104 million of our derivative instruments were not identified and designated for hedge accounting at inception. Of these swaps, $75.0 million expire in August 2013 and have a fixed rate of 1.83% plus the applicable margin and $29 million of the swaps expire in March 2012 and has a fixed rate of 1.99%, plus the applicable margin. These derivatives are recorded at fair value, which is measured using the market approach valuation technique. At December 31, 2010 and June 30, 2011, the fair value of these swap agreements was recorded as a long-term liability of $2.2 million and $2.2 million, respectively. Related to these swaps, we recorded $0.9 million of interest expense and $1.0 million as interest income in the year ended December 31, 2010 and 2009, respectively.

The counterparties to our interest rate derivative instruments are major international financial institutions with investment grade credit ratings.

 

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Business

Our company

We are a global oilfield products company, serving the subsea, drilling, completion, production and process sectors of the oil and natural gas industry. We design and manufacture products and also engage in aftermarket services, parts supply and related services that complement our product offering. Our product offering and related services include a mix of highly engineered capital products and frequently replaced items that are consumed in the exploration and development of oil and natural gas reserves. In 2010, approximately 41% of our pro forma revenue was derived from the sale of capital products, while approximately 52% was derived from consumable products, spare parts or aftermarket services, with the balance of the revenue coming from rental or other sources. Our capital products are directed at drilling rig new build, upgrade and refurbishment projects; subsea construction and development services; the placement of production equipment on a per well basis and downstream capital projects. Our highly engineered systems are critical components used on drilling rigs or in the course of subsea operations, while our consumable products are vital to maintaining efficient and safe operations at well sites, within the supporting infrastructure and at processing centers and refineries. Our revenues are generated throughout land and offshore markets and across several international regions, with 43% of our 2010 pro forma revenue derived outside the United States.

We seek to design, manufacture and supply reliable, cost effective products that create value for our broad and diverse customer base, which includes oil and gas operators, heavy oil producers, land and offshore drilling contractors, well intervention service providers, subsea construction and service companies, land and offshore pipeline construction companies, pipeline operators and refinery and petrochemical plant operators. Other customers include land and offshore mining companies, telecommunication companies, offshore renewable wind farm operators, government agencies and scientific research organizations. We believe that we differentiate ourselves from our competitors on the basis of the quality of our products, the level of related service and support we provide and the collaborative approach we take with our customers to help them solve critical problems. Our goal is to be the supplier of choice for our customers by offering innovative, reliable and cost effective products, and by investing in long-term relationships that add value to our customers’ operations.

Our business consists of two segments:

Drilling and Subsea Segment.    We design and manufacture products and provide related services to the drilling, well construction, completion, intervention and subsea construction and services markets. This segment contributed $626 million, or 66% to our 2010 pro forma revenue.

 

•

Subsea solutions.    We design and manufacture subsea capital equipment; specialty components and tooling; and applied products for subsea pipelines; and we also provide a broad suite of complementary subsea technical services and rental items. We have a core focus on the design and manufacture of unmanned submarines known in the industry as ROVs as well as other specialty subsea vehicles. We believe that our Perry™ and Sub-Atlantic™ vehicle brands are among the most respected in the industry. Our related technical services complement our vehicle offering by providing the market with a broad selection of critical product solutions and rental items that enhance our customers’ ability to operate in harsh subsea environments. We have a long tradition of working with customers to develop innovative product solutions to address the increasingly complex challenges of deepwater operations.

 

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•

Downhole products.    We design and manufacture downhole products that serve the well construction and production enhancement markets. Among the products we supply are proprietary Davis-Lynch™ cementing and casing tools, such as float equipment, stage tools and inflatable packers, as well as Cannon™ downhole protection solutions for permanent gauges, SSSV control lines, ESP cabling and other downhole control lines and flatpacks.

 

•

Drilling products.    We provide both drilling consumables and capital equipment, including powered and manual tubular handling equipment, specialized torque equipment, customized offline crane systems, drilling data acquisition management systems, pumps, valves, manifolds, drilling fluid-end components, pressure control equipment for both coiled tubing and wireline well intervention operations and a broad line of items consumed in the drilling process. We have a core focus on products that enhance our customers’ handling of tubulars on the drilling rig. Our drilling capital equipment offering is concentrated on targeted, high value added products and equipment where we have identified a clear market opportunity, such as our Wrangler™ branded catwalks and iron roughnecks.

Production and Infrastructure Segment.    We design and manufacture products and provide related equipment and services to the well stimulation, completion, production and infrastructure markets. This segment contributed $329 million, or 34% to our 2010 pro forma revenue.

 

•

Flow equipment.    We design, manufacture and provide flow equipment to the well stimulation, testing and flowback markets. Our product offering includes the critical components typically found in the flow equipment train from the well stimulation pressure pump to the manifold at the wellhead. These components routinely encounter high pressures, requiring frequent refurbishment or replacement. We also provide related flow equipment recertification and refurbishment services, which are critical to the safe and reliable operation of completion activities.

 

•

Surface process and pipeline equipment.    We design, manufacture and provide engineered process systems and related field services from the wellhead to inside the refinery fence. Once a well has been drilled, completed and brought on stream, we provide the well operator-producer with the process equipment necessary to make the oil or gas ready for transmission. Our engineered product offering includes a broad range of separators, packaged production systems, tanks, pressure vessels, skidded vessels with gas measurement, modular process plants, headers and manifolds. We also provide specialty pipeline construction equipment on a rental basis.

 

•

Valve solutions.    We design, manufacture and provide a wide range of industrial valves that principally serve the upstream, midstream and downstream markets of the oil and gas value chain. We provide a comprehensive suite of ball, gate, globe, check and butterfly valves across a wide range of sizes and applications. Our manufacturing and supply chain systems enable us to design and produce high-quality, engineered valves, as well as provide standardized products, while maintaining competitive pricing and minimizing capital requirements.

 

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Current trends in our industry

We are currently focused on the following trends that we believe will positively affect our business in the coming years. The majority of these are secular growth trends that we believe will outpace general industry growth.

 

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Increasing complexity of well construction.    As conventional sources of oil and gas are depleted, our industry continues to develop new well construction technologies and techniques that allow operators to recover more hydrocarbons from each well and make previously uneconomic reservoirs profitable. These techniques, most pronounced in the North American market, include drilling deeper, more highly deviated well paths, increasing the number of hydraulic fracturing stages and generally employing more complex completion practices on the surface and downhole. This trend is driving demand for new products and equipment that are specifically designed to address these new requirements. As these practices mature and spread to international markets, we believe that the market for the associated products and technologies could significantly expand.

 

•

Growing service intensity associated with unconventional resources.    The dramatic growth in the development of unconventional shale and tight sand formations, principally in North America, is placing increasing demands on the service equipment. In the U.S., 58% of the active land rigs, as of August 26, 2011, are drilling horizontal wells, the well path best suited to developing shale and tight sands, compared to 18% of the active land rigs as of five years ago, according to data from Baker Hughes. This change in development activity requires investment in new equipment to address the unique demands of these resource plays and places a much greater strain on drilling and completion equipment, which results in shorter replacement cycles for capital equipment and consumables, and drives greater demand for maintenance and refurbishment activity. The demands often vary from basin to basin, which we believe affords us opportunities to develop localized products solutions through close working relationships with service companies and operators. As the industry adapts to these increased demands, we believe that there will be significant opportunities to bring new products and equipment to market that have been designed and engineered with these new challenges in mind.

    Source: Baker Hughes Incorporated

 

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•

Increasing investment in subsea equipment and related services.    As the industry develops more deepwater fields, the amount of subsea infrastructure is expected to continue to increase and the ability of service companies and producers to control operations in a safe and effective manner will become more challenging. Demand for subsea equipment and systems is increasing in response to large exploration discoveries in frontier offshore areas. There is also a growing inclination among offshore producers to develop and tie back smaller satellite fields in mature offshore basins to existing production infrastructure. To accommodate the increase in satellite tie-backs in mature fields, a significant number of multi-service vessels have been built or are under construction that are capable of tree installation, small diameter pipelay and operations in ROV support mode. As offshore exploration activities continue to push into ultra deepwater, a new generation of work class ROVs will be required for subsea construction activities. Concurrently, the industry is exploring ways to move certain equipment and processes from production platform topsides to the seabed to save space and enhance flow rates from subsea wells. This growing complexity is expected to result in greater demand for technologies and products that are specifically designed to help service companies and producers gain situational awareness and preserve operational effectiveness. In addition, maintaining and servicing this additional subsea infrastructure is expected to become a larger market as the number of subsea well completions increases and the population of producing subsea wells ages.

    Source: Infield Systems Limited

 

•

Heightened focus on product maintenance and certification.    Our customers and the relevant regulatory authorities are increasingly focused on product and equipment integrity, particularly in applications or environments in which products are exposed to high pressure, high temperature or corrosive elements. In many of our product areas, our customers require recertification of products on a periodic or per use basis. Depending on the product, our recertification process tests certify a variety of measurable factors, such as integrity of metallurgy, wall thickness and pressure tests. We have observed many of our customers implementing more regular and rigorous maintenance and recertification programs for equipment with long useful lives, which we believe could increase the demand for aftermarket services and parts across many product categories. We believe that the demand from our service customers stems from a desire to increase utilization, and that they welcome a reliable

 

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supplier who can coordinate maintenance and recertification cycles to increase utilization of their equipment. Importantly, we have also observed that operator producers encourage service companies to obtain third party recertification to help increase the level of safety on the well site.

 

•

Increased capital spending in the oil and gas industry.    The growing global demand for energy has resulted in substantial capital spending increases by oil and natural gas producers. According to Spears & Associates, annual global oilfield capital spending has increased from $85 billion in 2000 to $259 billion in 2010, representing a compounded annual growth rate of 12%. Spears & Associates projects capital expenditures will rise to $275 billion in 2011.

    Source: Spears & Associates

 

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•

Recovery in global drilling activity and new rig replacement cycle.    As global drilling activity has steadily recovered since the 2009 economic downturn, there has been a corresponding increase in new build rig activity as operators require newer technology to meet increasingly challenging drilling conditions, with a focus on mobility, drilling efficiency, power and safety. According to RigLogix, 94 new offshore rigs have been ordered since January 2010, with an aggregate price of over $35 billion. Additionally, over 60% of all currently deployed offshore rigs were commissioned prior to 1990, generating a need for replacement rigs that employ the latest drilling and safety equipment. We believe this trend will continue to fuel a high level of capital investment in drilling rigs, which presents an opportunity for capital equipment manufacturers and value added component suppliers.

    Source: RigLogix

 

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•

Development of heavy oil reserves in Canada.    Canadian heavy oil reserves offer a large, stable and reliable source of oil for North America. Recent advances in technologies and development practices have lowered both the cost of producing these reserves and the environmental impact of these operations. The lowered cost of production, combined with a stable and robust outlook for oil prices, have enabled the heavy oil producers to undertake long-term development initiatives. CAPP has estimated total Canadian heavy oil crude production, including oils sands, will increase from 1,845 Mbpd in 2010 to 3,981 Mbpd by 2015, representing a compound annual growth rate of 5%. We believe that this trend will continue, and that opportunities to provide reliable severe service products used in the heavy oil development process will offer a long-term growth market.

    Source: Canadian Association of Petroleum Producers

While we believe that these trends will benefit us, our markets may be adversely affected by industry conditions that are beyond our control. Any prolonged substantial reduction in oil and gas prices would likely affect oil and gas drilling and production levels and therefore would affect demand for the products and services we provide. For more information on this and other risks to our business and our industry, please read “Risk factors—Risks related to our business.”

Our business strategy

Our objective is to build a leading global oilfield products company that supplies high quality, mission critical products and related aftermarket services, serving customers globally across the oil and gas value chain. We intend to accomplish this through organic growth of our existing product capability and by disciplined acquisition of small to medium sized companies to strengthen our current offering or fill targeted product gaps. Our intent is to offer a broad range of capital equipment, replacement parts and consumable items that support the drilling, completion and production phases of the well development cycle, as well as the related land and subsea infrastructure requirements. A core part of our strategy is to preserve and enhance our current business mix of onshore and offshore products; our balanced exposure to a variety of attractive global markets; and our broad range of capital equipment and consumable products that support the development of oil, gas, heavy oil, and other natural resources.

We intend to be our customers’ supplier of choice by offering safer, more effective products and by investing in long-term relationships that add value to our Company and our customers’

 

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operations. We design and manufacture products and engage in aftermarket services, parts supply and related services that complement our product offering. Our offering is enhanced by designing, manufacturing and providing the highest quality products, and not by competing with purchasers of our equipment by operating our equipment in a services capacity. We measure our success in terms of customer satisfaction, safety and financial performance.

We intend to accomplish our strategic objectives and capitalize on the key long-term industry growth trends through the execution of the following elements:

Tailor our product offering and capacity to customer spending.    On an annual basis, we conduct a bottoms-up analysis of the sources and drivers of our revenue. Our analysis is focused on various types of revenue splits and exposures, including: (1) phases of the life of the well; (2) geographic exposure by shipment destination; (3) land or offshore application; (4) product purchase cycles; and (5) commodity mix. This process relies on a combination of financial analysis and management estimation. Our analysis of our 2010 pro forma revenues is as follows:

 

As part of the bottoms-up analysis described above, we also estimate the broad industry drivers of our business. We believe that our 2010 pro forma revenue was strongly driven by North American unconventional resource developments, global deepwater development activity, shallow offshore activity and international land activity, with lesser contributions from Canadian

 

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heavy oil developments and downstream activity. Although acquisitions may cause fluctuations in our business mix, we intend to preserve and enhance the diversity of our business as a core part of our strategy. We believe this diversity reduces the impact of the volatility of any single well cycle phase or equipment spend cycle on our financial performance. A description of how we define each of the categories within each revenue split above is included in the “Glossary” beginning on page A-1 of this prospectus.

Leverage our product lines’ strengths across our platform.    Each of our respective product lines has particular strengths that can be leveraged across the entire platform. We intend to cross-fertilize technologies, share research and development initiatives and leverage key geographic, supply chain and customer strengths to grow and improve the profitability of our overall business. For example, we have an ongoing effort to leverage our sophisticated subsea ROV controls systems and engineers to improve our control system offering associated with our drilling capital equipment. In addition, we are using our surface production equipment distribution footprint to accelerate our ability to serve completion product customers in new geographies. We are also leveraging our relationships with oil and natural gas producers through other product lines to pull through our valve brands from their traditional distribution channels.

Expand our geographic presence.    We intend to enhance our access to key global markets and to grow or establish our presence across the North American unconventional resource basins. We also plan to build upon our existing presence in the North American, North Sea, Middle East, South American and Asia Pacific regions through deployment of sales, distribution, service and manufacturing resources. We have recently established sales offices in Brazil and Australia, and we are actively expanding these locations. In new international markets, we often build critical mass through a sales, service and marketing focused presence, which we follow with more significant manufacturing investments. We believe this expansion strategy provides more points of contact with our customers, allowing us to respond more quickly to their needs. Within North America, some of the largest products we offer through our Production and Infrastructure Segment are most effectively manufactured in close proximity to these unconventional resource plays. For example, our surface production and process equipment achieves a significant shipping cost advantage if we manufacture it in the target basin. It also affords us the opportunity to help manage our customer’s inventory of production and process equipment to ensure timely installation when a well comes on stream. For this reason, we are in the process of opening two new pressure vessel and tank manufacturing facilities in Pennsylvania to provide equipment and installation service in the developing Marcellus resource play. Our pipeline equipment, flow equipment business and related recertification and refurbishment service benefit from this type of expanded geographical footprint by providing a local presence for customers operating in this area.

Invest in manufacturing capacity and excellence.    We focus on the continuous improvement of our manufacturing processes and quality controls, which are vital to ensuring product reliability. We also continue to invest in expanding our manufacturing capacity by increasing output, upgrading machinery or adding “roofline” in strategically important geographies. We believe that in certain product lines, particularly those sold into the North American unconventional resource plays, locating manufacturing and service capabilities in close proximity to field locations improves response time, reduces freight costs and enhances customer service.

Pursue disciplined growth through acquisitions.    We have a track record of successfully growing our earnings and product offerings by making attractive acquisitions. We intend to continue to

 

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selectively pursue acquisitions that increase our exposure to the most important growth trends in the oil and gas industry, fill critical product gaps and expand our geographic scope. With a strong balance sheet and sufficient financial resources, we believe that we can continue to acquire companies in high growth product areas and expose the acquired product lines to new customers and distribution channels, while preserving the entrepreneurial attributes that made them attractive on a stand-alone basis.

Develop new products.    We conduct strategic reviews to identify underserved market opportunities and invest in continuous product development efforts. We believe this process allows us to enhance our exposure to key secular trends and serve our customers’ needs more effectively. We have developed strong working relationships with our major customers, several of which routinely approach us with requests for solutions to specific application challenges. We plan to continue to invest in new product engineering capabilities and leverage our expertise to address customer needs. Recent examples include the land and offshore versions of our Wrangler Roughneck™, a critical makeup and breakout tool for tubulars on a drilling rig, and our subsea ROVDrill™, a unique tool designed to perform subsea drilling functions independent of the support vessel while using only the associated ROV for power and control.

Focus on product quality and customer service.    We have a track record of providing innovative, reliable, fit-for-purpose products at competitive prices while remaining responsive to the needs of our customers. We work closely and flexibly with our customers on delivery timing and service after the sale. We seek to ensure that our businesses have the facilities and personnel to maintain the highest level of quality and service as we grow around the world.

Our competitive strengths

We believe that we are well positioned to execute our strategy based on the following competitive strengths:

Broad product offering with exposure to key long-term industry trends and a diverse customer base.    Our exposure to a mix of consumable products, capital products and aftermarket parts and services enables us to participate in the construction, capacity expansion, maintenance, upgrade and refurbishment phases of the energy cycle. In addition, we have exposure to multiple sectors of the oil and gas industry and a diverse mix of customers across the full oil and gas value chain. We believe our broad product offering, diversified exposure to industry trends and extensive customer base reduces our dependence on any one phase, purchase cycle, segment or region and should result in more stable financial results.

Focus on critical peripheral products.    Many of our products, particularly those serving the drilling and well stimulation markets, are non-discretionary components that represent a small percentage of the life cycle cost associated with large capital equipment. We believe that focusing on specialized, peripheral products affords us full exposure to the most powerful investment trends in the oil and gas industry while insulating us from the intense competitive environment and construction risks often associated with selling the largest capital equipment packages.

Solid base of recurring revenues from consumable products.    In 2010, we generated approximately 52% of our pro forma revenues from consumable products, spare parts or aftermarket parts and services, which are critical to large capital equipment or energy infrastructure. In some cases, these products must be replaced multiple times throughout the life

 

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cycle of the related capital equipment or infrastructure installations. These products have replacement cycles ranging from a few months to a few years, resulting in a stable base of recurring revenues. We often complement these products with a recertification and refurbishment service, which helps us preserve strong customer relations. We have also observed that our customers often return to the same vendors for replacement parts, lending further revenue stability and visibility.

Experienced management team with proven public company track record.    Our executive officers and senior operational managers have an average of over 30 years of experience in the oilfield manufacturing and service industry. Each of our top three operational executives served as the chief operational officer of one or more large publicly held oilfield service companies or of a significant division thereof. We believe their collective background provides our management team with an in-depth understanding of our customers’ needs, enhances our ability to deliver customer-driven solutions and allows us to operate effectively throughout industry cycles. Several members of our management team were executives or directors at one of the five companies that combined to form Forum Energy Technologies, Inc. in August 2010.

Multiple avenues for growth and strong cash flows.    We are focused on a core set of product platforms that we believe offer strong long-term growth. The breadth of our product offering affords us multiple organic growth avenues in which to deploy our capital, and we invest in the highest value opportunities that meet our return objectives and further our strategic goals. Similarly, we believe the scope of available acquisition opportunities will be enhanced by the numerous strategic directions available to us. In the face of particularly strong competition for acquisitions in a specific sector, we can deploy capital to other areas of our Company that afford better relative value. We also believe that our breadth and size allows us to meaningfully change our financial profile and business composition with modestly sized acquisitions. Finally, our manufacturing operations are not capital intensive to maintain or expand, which allows us to generate strong cash flow. This provides us with capacity to finance organic growth opportunities with internally generated resources.

Proven ability to grow earnings and improve product offering through a focused acquisition strategy.    We have a strong track record of strategically targeting key product opportunities, completing accretive transactions, and effectively integrating these businesses. We have a disciplined acquisition strategy that allows us to develop proprietary deal flow by identifying emerging industry trends, identifying existing platforms positioned to capitalize on these trends, and in some cases isolating acquisition opportunities that are largely missed by our competitors due to smaller size and scale. Each of the original five companies that combined to form Forum Energy Technologies, Inc. was itself the result of a similar acquisition strategy focused on a specific industry growth theme. Our current acquisition strategy is a continuation of that successful model. For example, shortly after the Combination, we undertook a focused effort to target key product lines that enhanced our existing offerings. We consummated three acquisitions, including Specialist, which complements our existing subsea products offering, and AMC and P-Quip, both of which enhance our drilling product offering. After the Combination, we also undertook a strategic effort to identify two new product areas that provide exposure to targeted growth markets: (1) downhole products, and (2) flow equipment related to well stimulation. In the downhole market, we focused on proprietary and niche consumable products related to the well construction, completion and production enhancement processes, which included Davis-Lynch and Cannon Services. We successfully completed these two acquisitions in 2011 to form our new downhole products line. Similarly, in the well stimulation market we

 

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developed and executed an acquisition strategy focused on consumable flow equipment used in well fracturing and flowback processes. We have made three acquisitions in 2011 in this area, including WFP, Phoinix and SVP Products. Combined with the follow-on deployment of organic growth capital, our flow equipment product line is our fastest growing.

Customer responsive product innovation.    We have grown our business by being responsive to customer needs and developing strong relationships at multiple levels of our customers’ organizations. We believe our ability to develop new products is enhanced because of these customer relationships. Our experienced engineering and technical staff has partnered with our customers to design and develop new products that add value to their operations or reduce their total cost of doing business. As a result, we have developed and commercialized a number of new products that have improved the efficiency and safety of our customers’ operations including our powered Wrangler™ catwalk and iron roughnecks, powered mousehole tool, Perry ROVDrill™, low profile urban gas processing unit and others.

Business segments

We operate two business segments: Drilling and Subsea and Production and Infrastructure. The table below provides a summary of the proportional revenue contributions from our two business segments and our primary geographic markets over the last three years.

 

		Percentage of revenue year ended December 31,
		2008				2009				2010				Pro forma 2010
Drilling and Subsea			68%				67%				63%				66%
Production and Infrastructure			32%				33%				37%				34%
Total			100%				100%				100%				100%
United States			56%				52%				55%
Canada			11%				8%				9%
Other International			33%				40%				36%
Total			100%				100%				100%

Drilling and Subsea Segment

We design and manufacture products and provide related services to the drilling, well construction, completion, intervention and subsea construction and services markets. The top five customers in our Drilling and Subsea Segment together accounted for approximately 27.8% of that segment’s revenue during the year ended December 31, 2010, with no single customer representing as much as 10% of our consolidated revenue during this same period. We offer these products and related services through three primary business lines.

Subsea solutions

We design and manufacture subsea capital equipment, specialty components and applied products for subsea pipelines, and also provide a broad suite of complementary subsea technical services and rental items. We have a core focus on the design and manufacture of ROVs as well as other specialty subsea vehicles. We believe that our vehicle brands are among the most respected

 

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in the industry. Our related technical services complement our vehicle offering by providing the market with a broad selection of critical product solutions and rental items that enhance our customers’ ability to operate in harsh subsea environments. We have a long tradition of working with customers to develop innovative product solutions to address the increasingly complex challenges of deepwater operations.

The primary drivers impacting our subsea business are global offshore activity, subsea construction spending, subsea pipeline construction, and growth in deepwater resource developments. A majority of our subsea sales are driven by capital projects, with a smaller portion associated with field development activity and general offshore operations expenditures. We believe that the increasing complexity of deepwater developments will create demand for our full range of subsea products and related services.

Subsea vehicles

We are a leading designer and manufacturer of a wide range of ROVs to the offshore subsea construction, observation and related service markets. The market for subsea ROVs can be segmented into three broad classes of vehicles based on size and category of operations: (1) large work-class vehicles for subsea construction activities, (2) drilling-class vehicles for use around an offshore rig and (3) observation-class vehicles for inspection and light manipulation. We are a leading provider of work-class and observation-class vehicles.

We believe that our Perry and Sub-Atlantic branded ROVs are among the most reliable, best performing and well-known in the industry. We design and manufacture large work-class ROVs through our Perry brand. These vehicles are among the heaviest duty, most powerful subsea ROVs in the market and are principally used in deepwater construction applications. Throughout its over 50 year history, Perry has delivered over 500 such systems. The largest vehicles, our Triton^® series of work-class ROVs, weigh as much as five and one-half tons, provide up to 250 horsepower, have payload capacities exceeding 500 pounds and are capable of working in depths exceeding 4,000 meters. Our Sub-Atlantic branded vehicles have served the observation class market since 1997. Among the smallest class of ROVs in the industry, these all-electrical vehicles are principally used for inspection, survey, and light manipulation and serve a wide range of industries. We currently offer six sub-classes of all-electric ROVs with a broad range of capabilities.

In addition to ROVs, we design and manufacture specialty vehicles that are primarily used in subsea trenching operations. Larger than a work-class ROV, these vehicles travel along the sea floor conducting digging, installation and burial operations. Providing over 1,200 horsepower, the largest of these subsea trenchers can cut over three meters deep into the seafloor to lay pipelines, power cables or communications cables. Our Perry branded specialty vehicles have dug and buried a significant amount of the existing subsea communications cables that exist around the world today. In addition to ROVs and trenchers, we also design, engineer and manufacture small submarines used to perform rescue operations for large military submarines.

As the complexity of subsea architecture has increased with operating depths, the subsea industry has come to rely increasingly on ROVs to conduct complex tasks to ensure safe, reliable and efficient operations. Underpinning the reliability of the most sophisticated ROVs that operate in the harsh deepwater environment is the ROV control system. The Perry branded ICE™ Real Time Control System is an advanced ROV control system designed for deepwater, work class

 

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ROV applications. ICE™ is a proprietary, all-in-one solution offering onboard processing, data communication, sensor circuitry, advanced diagnostics and power regulation. Similarly, as the demands have increased on our smaller, observation class ROVs, we have engineered and developed a robust, user-friendly control system to serve this growing market. For use with our Sub-Atlantic branded vehicles, we have developed the new subCAN™ control system, which connects to standard topside equipment running a Windows^® based graphical user interface. This enables control of, and communication with, both the ROV and associated equipment. To preserve our competitiveness in the subsea sector, we believe we must be a leader in the core control systems associated with ROVs because we believe that the market for sophisticated subsea control and manipulation is growing and will extend beyond ROVs to other critical seafloor equipment.

Our subsea vehicle customers are primarily large offshore construction companies, but also include a range of non-oil and gas industry entities, such as navies, fire departments, maritime science and geosciences research organizations, offshore wind power companies and other industries operating in marine environments. Subsea vehicle sales are principally driven by large subsea construction spending cycles, and capital build programs at the offshore and subsea services companies. Our large installed base, combined with the 50-year track record of the Perry brand and our strong customer service orientation, are key factors in our ability to compete successfully in this sector.

Subsea products

In addition to subsea vehicles, we are a leading manufacturer of unique subsea products and components. Our suite of subsea products leverages our core strength in vehicles, but also provides a broad selection of niche subsea product solutions that result from our many years of experience with vehicles.

We design and manufacture a group of important products that are used in and around vehicles. For example, we manufacture key ROV components, such as a wide range of Sub-Atlantic branded ROV thrusters. We design and manufacture thrusters for incorporation into our own vehicles as well for sale to other ROV manufacturers. We also design and manufacture a tether management system (“TMS”). The TMS stores and deploys the ROV tether, thus decoupling the ROV from the motion of the surface vessel and enabling operations within a larger radius. The TMS is critical to the reliable and safe operation of subsea vehicles, and we have a long history of manufacturing these systems for use across our entire range of ROVs. We also provide a broad suite of subsea tooling, both industry standard and custom designed for unique subsea applications. Industry standard tooling includes hot stabs, cable cutters, torque tools and indicators. Our recent acquisition of Specialist complemented and enhanced our range of subsea tooling, and has provided us with a greater capacity to respond to customer needs. Our customers frequently come to us with unique subsea challenges and we attempt to quickly develop custom tools to solve these specialized problems. Examples of our specialized tooling include: a riser repair system, a manipulator for nuclear decommissioning and control systems for subsea well intervention. In addition to tooling associated with ROVs, we also manufacture hydraulic power units, valve packs, and control systems.

Among our newest subsea products is an innovative seafloor coring tool named ROVDrill™. Lowered to the seafloor and powered by a work class ROV, it is capable of retrieving geologic core samples using conventional diamond drilling techniques in water depths that exceed

 

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3,000 meters. With a relatively small footprint, the ROVDrill™ can be flown into any region of the world on short notice and be deployed on any of a wide range of vessels, without the need for large specialized vessels or drill ships of limited availability that command a high day rate. We are in the process of commercializing the third generation of this tool, after recently performing work in the South Pacific to support a customer in delineating the extent of a subsea mineral deposit.

We also develop simulation software under the VMAX™ brand that allows customers to simulate complex deepwater operations before deploying expensive equipment spreads. This product is both a stand-alone product and can also be a value-added component of our largest ROVs. Our latest version of this product is an extensive upgrade that allows oil and gas operators, service companies and engineering firms to have full control of subsea field scenario development while providing cutting edge graphical advancements and customized user interface. As the complexity and difficulty of deepwater projects increase, we believe that the demand for this and other cost-saving and safety-enhancing tools will increase.

In addition to vehicle-related subsea products, our Offshore Joint Services (“OJS”) brand is a leading provider of applied protective coatings on rigid subsea pipeline field joints, spools, and structures. The OJS brand has a 25 year history and is a recognized worldwide leader in this sector. Our field joint coatings address the corrosion protection, thermal insulation and concrete weight coating infill requirements. We offer proprietary and patented applied products that we believe provide significant speed, quality, reliability, safety, and environmental benefits to our customers. We believe that the chemistry of these fast curing applied products, along with the specialized machinery and crew used to apply the product, are vital ingredients in providing a safe and reliable product that will withstand the pipe-laying process and decades of use on the seafloor.

We mobilize for offshore pipeline construction operations globally out of facilities in Houston, Texas and Batam, Indonesia. Our primary customers in this product line are offshore construction companies that own or lease the pipe laying vessel. From time to time, we are directly hired by operators, oil and gas exploration and production companies and welding subcontractors. These services are performed at our customers’ sites, either onboard an offshore pipe lay vessel or at an onshore fabrication yard.

Technical services and subsea rental lines

We also maintain an extensive fleet of subsea rental items and provide our customers with complementary subsea technical services. Among the technical services we offer is the provisioning of ROV pilots and other offshore personnel on a contract basis for those customers who do not employ their own on a full time basis. Branded UKPS, this business line operates out of a main office in Great Yarmouth, United Kingdom, and serves subsea construction and offshore service companies globally.

Our VisualSoft™ product line provides another related technical product that reinforces our strength in subsea vehicles and products. We sell or rent VisualWorks and VisualDVR Digital Video Systems that provide a complete solution for digital video capture, playback, processing and reporting of pipeline, structural or other inspection survey data. These products are often used in conjunction with the operation of inspection class ROVs or diving personnel when conducting survey work. VisualWorks systems are also in operation supporting clients involved in

 

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detailed inspection surveys of flooded tunnels and mines, underwater archaeological sites and seabed environments. This equipment is complementary to our inspection class vehicles and augments our capabilities and offering to our customers.

Operating for more than fourteen years, Geoscience Earth and Marine Science (“GEMS”) is our geophysical and geotechnical engineering group that provides consulting services to the oil and gas, and marine industries. We typically provide an interpretation service based on the analysis of third party subsea data provided by clients. In recent years, the business has broadened into managing every phase of project development, including scope of work, liaising with data acquirers, interpretation and analysis. The majority of the work performed by GEMS is in the Gulf of Mexico, although it also carries out work internationally, particularly in West Africa. Our primary customer base consists of oil and gas operator producers. These services are focused on the earliest stages of life of field development and provide us with unique insights into future subsea construction and development work, which we believe provides us with a competitive advantage.

We also have an extensive rental fleet of critical subsea equipment and products. Our DPS Offshore branded rental fleet provides electronic marine equipment for survey, ROV and dynamic positioning applications. Importantly, our customers often rely on our expertise in the provisioning of this equipment and ask us to design a customized rental equipment package for their intended operation or application. We often sell equipment from this fleet as well. In keeping with our efforts to provide top quality customer service, we offer fleet management services to our customers, including equipment repair and calibration, as well as the provision of specialist personnel to assist with equipment integration and installation. To compete with other rental companies we endeavor to provide better quality customer service, equipment breadth, flexibility and speed of response. As with a number of our subsea business lines, the principal customers are subsea construction contractors, survey companies and offshore vessel companies. The main rental fleet locations are in Aberdeen, Scotland; Great Yarmouth, United Kingdom; Houston, Texas; and Singapore. The business line also has long standing agent relationships in Norway and the Middle East.

 

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Key subsea product lines

 

Capital equipment		• Work class remote operating vehicles • Observation class remote operating vehicles • Remote operating seafloor coring tools (ROVDrill™) • Specialty vehicles • Rescue submarines • Tether management systems
Operating items, components, and / or consumable products		• ROV thrusters, valve packs, hot stabs • Seafloor coring tools and accessories • Standardized and specialized ROV tooling • Subsea pipeline infill joint coatings and related applied products
Technical & aftermarket services and rental items		• Simulation software for complex subsea operations • ROV simulator rental items • Geotechnical and geosciences consultancy services • ROV pilot provisioning services • Offshore/subsea dynamic positioning rental equipment

Downhole Products

In late 2010, we undertook a strategic initiative to build a platform that would provide us exposure to the growing market of downhole products associated with the increasing complexity of well construction and completion. We targeted niche downhole products that were consumed during the well construction, completion and production enhancement processes, as well as those that were associated with the growth in intelligent well construction. Our objective in 2011 and 2012 is to build a downhole products platform with the critical expertise and proprietary products to position the Company as a long-term, market leading downhole products provider. Since July 2011, we have made two acquisitions to begin building our downhole products business and we have focused on two areas: (i) casing and cementing products and (ii) downhole protection solutions.

Casing and Cementing Products

Through our recently acquired Davis-Lynch™ downhole well construction and completion tools product line, we are a market leading designer and manufacturer of proprietary, mission critical products used in the construction of oil and gas wells. We design and manufacture a full range of centralizers, float equipment, stage cementing tools, inflatable packers, flotation collars, cementing plugs, fill and circulation tools for running casing, casing hangars and surge reduction equipment. Our products are used in the construction of onshore and offshore wells, and the 64 year old “Davis-Lynch™” brand is a well-known and trusted name in the industry. Our objective is to use our global sales and distribution infrastructure to grow this product line, while also continuing to look for opportunities to expand the depth of the product line through product development efforts and targeted acquisition opportunities. The key drivers of this product line

 

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are the growth in the complexity of onshore and offshore completion market globally and the increasing number of stages being employed in the North American unconventional shale plays.

Downhole Protection Solutions

We offer a full range of associated downhole protection solutions through our 25 year old Cannon Services™ brand. The clamp and protection system is a critical component of complex well completion and is used to shield the downhole control lines and gauges during installation and to provide protection during production enhancement operations. We design and manufacture a full range of downhole protection solutions for ESP cabling, encapsulated control lines, sub-surface safety valves (“SSSV”) and permanent downhole gauges, including gauges used in intelligent wells and the steam-assisted gravity drainage (“SAGD”) wells of the Canadian heavy oil developments. We provide both standard and highly customized protection systems, and we supply the full range of alloys for various downhole environments. While we provide standardized protection systems, we have a core strength in working directly with reservoir engineers and our service company customers to design unique protection solutions to complex well design challenges.

The key driver of our downhole products business is the construction and completion of new wells. In particular, we believe that the growing complexity of onshore and offshore well construction and the increasing use of artificial lift to increase production from oil and gas wells have created a long-term growth market. We believe our focus on niche downhole products provides exposure to attractive investment trends in the downhole oil and gas market while insulating us from the intense competitive environment often associated with providing the associated installation or completion services. Our primary customers in this business line are producers and service companies providing completion, ESP and other intervention services to the producers.

 

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A representative sampling of our key downhole products is listed below.

Key downhole product lines

 

		Products
Well construction and completion tools		• Centralizers • Float equipment • Stage cementing tools • Inflatable packers • Flotation collars • Cementing plugs • Fill and circulate tools for running casing • Casing hangars • Surge reduction equipment
Downhole protection systems		• Standard and Customized protection systems for: • ESP cabling • Permanent downhole gauges • Encapsulated control lines and flatpacks • Customized guards for safety valves • Specialized stream-assisted gravity drainage (SAGD) gauge protection systems • Specialized installation tools

Drilling products

We provide both drilling consumables and capital equipment, including powered and manual tubular handling equipment, specialized torque equipment, customized offline crane systems, drilling data acquisition management systems, pumps, valves, manifolds, drilling fluid end-components, pressure control equipment for both coiled tubing and wireline well intervention operations and a broad line of items consumed in the drilling process. We have a core focus on products that enhance our customers’ handling of tubulars on the drilling rig. Our drilling capital equipment offering is concentrated on targeted, high value added products and equipment where we have identified a clear market opportunity.

The primary drivers impacting our drilling products business are global drilling and workover activity, the level of capital investment in drilling rigs, and the severity of the conditions under which the rigs and well service equipment operate. Although a portion of our rig-related sales is directed at new rigs, a larger portion is associated with equipment replacement and rig upgrades as drilling contractors modify their existing rigs to improve efficiency and to operate in increasingly challenging drilling conditions associated with the development of unconventional resource plays or service intensive offshore drilling. We also believe that the increasing use of well stimulation in mature fields will contribute to demand for increased well service activity, which in turn should drive demand for our well intervention products.

 

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Tubular handling

Our core strength and focus in drilling products is in powered and manual tubular handling equipment used on drilling rigs. Our Wrangler™ branded systems reduce direct human involvement in the handling of pipe during drilling operations, improving both the safety and efficiency of operations. For example, we believe our proprietary catwalk product improves rig safety by mechanizing the lifting and lowering of tubulars to and from the drill floor while reducing direct exposure of rig personnel to this potentially dangerous task. Furthermore, our catwalks improve efficiency by eliminating or reducing the need for traditional drill pipe and casing “pick-up and lay-down” equipment with associated personnel. We recently developed a make-up and break-out tool called the Wrangler Roughneck™, which we believe is a vital piece of equipment on the drilling rig. It was designed to address a growing need for a spinning and torque tool with a more durable and economical design to adequately handle premium drill pipe connections, which are associated with higher torque requirements. As another example, our proprietary powered mousehole tool increases rig efficiency by spinning up joints of drill pipe or bottom hole assemblies offline, while the rig continues to drill, saving significant amounts of time. As our industry drills deeper wells with longer laterals, the weight of the drill string increases, which drives demand for tools capable of holding the string without damaging it.

In 2011, we complemented our tubular handling offering through the acquisition of AMC, based in Aberdeen, Scotland. Through our AMC product brand, we design and manufacture specialized torque equipment for tubular connections, including high torque stroking (or “bucking”) units, fully rotational torque units, portable torque units for field deployment and related control systems, and we provide aftermarket service. As well construction becomes more complex, we expect the increasing amount of downhole tools and equipment required to drive the need for more specialized and capable torque machines. We intend to support the growth of this complementary product offering through our existing global distribution and sales network.

We also design and manufacture a range of value-added offline activity cranes, multi-purpose cranes and personnel transfer solutions. Many of these cranes are fit-for-purpose, multi-axis cranes that provide access to hard-to-reach places and eliminate the need for manual interface. To provide added utility to our customers on these key pieces of equipment, we manufacture specialty cranes, as well as several of our tubular handling capital equipment products to fit specified rig configurations.

Our tradition of product innovation also extends to manual tubular handling equipment. We have designed and developed products in conjunction with our customers to address specific problems encountered when drilling in deepwater and other challenging environments. Our lightweight 1,000 ton elevators and 1,000 ton slips allow a drilling rig to safely support up to two million pounds of drill pipe without damaging it. Originally designed to solve a specific customer’s challenge of handling landing strings in deepwater, these products now serve broader applications in deeper wells both onshore and offshore. As a further example of customer responsiveness, we integrated a specially designed skidding system into our catwalk product line. This transforms the catwalk into a self-propelled device that is more efficient for pad drilling, and allows it to easily move with the rig to the next well location. Through the drilling products business, we intend to continue to leverage existing product lines to create integrated systems that completely automate the pipe handling functions. We expect to continue to work with our customers to design and develop products to upgrade their drilling rigs for safer and more efficient operation.

 

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Drilling flow control and intervention

Our pressure control products used for well intervention operations are sold directly to oilfield service companies and also to equipment rental companies. These products include both coiled tubing and wireline blowout preventers and their accessories. We also conduct aftermarket refurbishment and recertification service on our pressure control equipment. We expect the repair and replacement of these components to become more frequent as service contractors conduct operations in increasingly challenging environments associated with increased well depths, greater wellbore deviations and longer laterals, which are often accompanied by higher pressures and temperatures. In particular, as coiled tubing and other intervention operations address evolving industry needs, we intend to support this growing area with reliable and innovative products. For example, in response to recent changes in the coiled tubing market, we recently completed the design of a 4-1/16 inch 15,000 psi coiled tubing blowout preventer, which is now in production with a growing backlog. We are also in the final engineering stages of a 7 inch 10,000 psi blowout preventer for this growing market. We expect these products to allow us to serve this evolving market.

We recently added to our flow control offering through the acquisition of UK-based P-Quip, which designs and manufactures a range of patented liner retention and mud pump rod piston systems. These systems are sold directly to mud pump manufacturers and drilling contractors, and are focused on improving the efficiency, serviceability and safety of mud pump operations on the rig. They are complementary to our existing SPD mud pump product line, and we believe they have a strong brand in the marketplace. We plan to grow this product line using our existing global sales and distribution network, especially in North America where this UK-based product line has only recently begun to achieve penetration.

We also manufacture data acquisition and management products that include integrated drill floor instrumentation and monitoring systems. These systems manage and provide real-time monitoring and logging of drilling data to drilling contractors and oil and natural gas producers. They measure, collect, store and display drilling data on a real-time basis, substantially increasing drilling efficiency and improving the well construction process. The drilling data can be monitored by local rig supervisors as well as transmitted to remote customer locations for monitoring the drilling process.

Examples of our consumable drilling products include inserts and dies, as well as manual elevators, tongs and slips. As rigs drill these products are consumed and need to be replaced periodically, resulting in a recurring revenue opportunity for our Company. We are also among the largest providers of oilfield bearings to the North American market, where we provide original equipment manufacturers and repair businesses the bearings they need to serve the drilling and well stimulation markets.

In addition to designing and manufacturing capital products and providing consumable products, we also repair and service drilling equipment for both land and offshore rigs. Many of our service employees work in the field addressing problems at the rig site, which we believe further enhances our relationships with customers. Our experienced service employees, in combination with our specialized repair facilities, enable us to survey rigs in the field, design comprehensive upgrade packages and refurbish existing rig equipment.

Our ability to source low cost raw materials and components, such as steel castings and forgings is critical to our ability to manufacture our drilling products competitively. In order to purchase

 

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raw materials and components in a cost effective manner we have developed a broad international sourcing capability and we maintain quality assurance and testing programs to analyze and test these raw materials and components. In addition, we believe we have established a reputation among our customers for high-quality products, reliable after-sale support and product innovation.

Key drilling product lines

 

Capital equipment		• Tubular handling equipment such as powered mousehole tools, powered elevators • Wrangler Roughnecks™ • Wrangler Catwalks™ • Specialized torque machines and bucking units • Customized crane systems • Drill floor electronic instrumentation and data monitoring systems • Choke and kill manifold mud systems and related components • Coiled tubing and wireline blowout preventers and related products
Operating items, components, and / or consumable products		• Drilling and production valves, chokes and flowline connections • Manual tubular handling equipment such as slips, inserts, dies and manual tongs • Centrifugal pumps and fluid end-components for mud pumps • Patented mud pump liner retention and mud pump rod piston systems • Specialty oilfield bearings
Technical & aftermarket services and rental items		• Drilling equipment field service, repair, refurbishment and upgrade • Workover BOP aftermarket service and recertification • Torque machine aftermarket services and spare parts

Production and Infrastructure Segment

We design and manufacture products and provide related equipment and services to the well stimulation, completion, production and infrastructure markets. The top five customers in our Production and Infrastructure Segment together accounted for approximately 35.9% of that segment’s revenue during the year ended December 31, 2010, with no single customer representing as much as 10% of our consolidated revenue during this same period. We offer these products and related services through three primary business lines.

 

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Flow equipment

In late 2010, we undertook a strategic initiative to build a platform that would provide us exposure to the rapidly growing completion products sector of the oil and gas industry. We targeted the products that were consumed during the stimulation and flowback processes to take advantage of the recurring revenue inherent in the flow equipment market. The complete set of equipment used by a well stimulation, or pressure pumping, company is referred to as a “frac spread” and is often measured by the amount of pressure pumping horsepower the frac spread produces. While the capital equipment associated with provided new, incremental horsepower to the industry has been increasing as well completion practices are evolving, we chose to focus on the consumable components of the frac spread that experience high rates of wear and replacement. We believe this strategy enables us to capture a greater share of the total spend over the useful life of the typical frac spread.

Our objective in 2011 and 2012 is to build a top three player in the North American flow equipment market that provides all of the critical components typically found in the flow equipment train from the frac pressure pump to the manifold at the wellhead, with the full range of sizes suitable for both the stimulation and flow back markets. We also believe that it is vital to the long-term sustainability of this product line that we invest in and expand the associated recertification and refurbishment offering across the major unconventional basins in North America.

Since February 2011, we have made three acquisitions to begin building our flow equipment product line. The management teams of these companies are experts in this sector and share our common vision for the type of business we intend to create. Prior to our acquisition, these companies had a track record of collaboration to satisfy customer needs. The platform provided by these acquisitions offers us critical expertise in the design, engineering, and manufacture of the full range and sizes of swivel joints, triplex and quintuplex fluid-end assemblies, manifolds and manifold trailers, as well as the full suite of pressure control plug, choke, and relief valves. As recertification and refurbishment operations are critical to ensuring the reliable and safe operation of a pressure pumping company’s fleet, we operate a fleet of sophisticated mobile recertification and refurbishment tractor trailers, which can deploy to the customer’s yard or to the well site. We currently serve several of the key unconventional basins, and we are in the process of using the full Production and Infrastructure Segment footprint to expand this business line’s coverage area.

The key driver of this platform is the completion of new wells. In particular, we believe that the growing use of fracturing to develop the oil and gas reserves in shale or tight sands basins across North America has created a long-term growth market. We also believe that the growing service intensity associated with this trend will support sustained growth in the sale of consumable products associated with the stimulation and flowback markets. Our primary customers in this business line are pressure pumping and flowback service companies, although we also generate sales to original equipment manufacturers of pressure pumping units when they assemble new frac spreads. While we benefit from the ongoing new build cycle of pressure pumping equipment, our business model is focused on developing deep relationships with the service companies by providing top quality products and reliable recertification and refurbishment services.

 

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A representative sampling of our key products and related services is listed below. We manufacture a full range of sizes and materials including those needed for sour service to deal with high H₂S concentrations.

Key flow equipment product lines

 

Consumable flow equipment		• Swivel joints, including large diameter (up to 6 inch) • Pup joints • Swages • Hammer unions • Crossovers
Consumable pressure control equipment		• Triplex and quintuplex fluid end assemblies, for 600 and 2250 horsepower pumps • LT and TE Plug valves (up 5 inch) • Chokes • Relief valves • Bull plugs
Capital equipment (equipped with associated consumable products)		• Pressure pumping manifold trailers • Flowback manifolds skids • Flow equipment trucks
Aftermarket services		• Refurbishment and recertification • Mobile recertification • Replacement parts and internals for flow equipment • Online flow line management

Surface process and onshore pipeline equipment

Our surface production equipment platform provides engineered process systems and field services from the wellhead to inside the refinery fence. We serve the upstream, midstream and downstream segments in oil and gas production equipment and services. Once a well has been drilled, completed and brought on stream, we provide the well operator-producer with the process equipment necessary to make the oil or gas ready for transmission. We design, develop and fabricate tanks, a broad range of separators, packaged production systems and American Society of Mechanical Engineers (“ASME”) coded and non-coded pressure vessels, skidded vessels with gas measurement, modular process plants, headers and manifolds, process equipment and flow control and separators to help clean and process oil or gas as it travels from the wellhead and along the transmission line to the refinery. Our customers are principally oil and gas operator producers, and we are positioning our manufacturing and staging locations strategically across North America to best serve the key emerging shale and unconventional resource plays.

A key to our competiveness is manufacturing tanks and pressure vessels in close proximity to their location of use to reduce freight costs, as well as helping our customers manage and anticipate their production equipment needs as their drilling programs progress. We also provide specialized trucks and crews that install the production equipment on the well site, which allows us to capture more value for the product we provide and affords our customers a more streamlined process for bringing a well on production. We continually seek to improve our

 

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designs to better serve our customers’ evolving requirements. For example, we have developed and installed low profile skid mounted process systems that our customer requested for processing natural gas near urban areas. In working with another customer, we developed a modular production processing system that left the plant “installation ready”, and we subsequently provided the installation service for that customer as well. This system reduced the installation time from days to hours and allowed our customer to initiate production from the new wells sooner and with greater reliability. Importantly, we have specialized equipment and service crews that allow us to stage, deliver and install the equipment described above, further streamlining the total well development process that has become so important in the “manufacturing” of shale resource basins.

We also provide industrial construction and manufacturing services for clients in the refining and chemicals industries from our Pasadena, Texas facility, which is strategically located to service this market. We have the engineering expertise and track record in this facility to design and manufacture highly specialized skid mounted systems for a broad array of customers, such as offshore production companies and government related aeronautical customers. This facility also has the flexibility to support incremental production of code pressure vessels destined for use in nearby emerging shale basins, such as the Eagle Ford in South Texas. In early 2010, we acquired the EDGE™ desalination and dehydration product line and a non-exclusive license to manufacture and sell dual frequency technology for use in desalination applications. This product line acquisition also gave us access to an installed base of over 500 systems in oil refineries worldwide. We believe this product line will generate solid, steady results in the future.

We maintain a fleet of specialized onshore pipeline bending, line-up, and construction equipment that we rent to pipeline construction contractors under the brand C&L. Our bending machines, mandrels and bending sets are used to bend pipe to conform to the contours of the land. We also rent internal line up clamps that align and hold together two sections of pipe so they can be welded to each other. Finally, we provide rental equipment to facilitate pipe handling. The C&L brand has been a recognized name in the North American market for over 15 years, and retains a strong reputation for the condition and maintenance of its equipment. Equipment condition directly impacts reliability in the field, which in turn affects construction company productivity. Much of the equipment we offer is niche, pipeline diameter specific equipment, and contractors generally prefer to rent size-specific equipment rather than own it since the diameter of pipelines they build varies from job to job. Demand for these products is largely driven by the increasing need for greenfield gathering systems in new shale resource basins as well as the construction of transmission lines that bring the resource from new regions of supply in emerging shale basins to existing markets.

 

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A representative sampling of the key products and related services in our surface production and processing equipment are listed below.

Key surface production, process, pipeline equipment products

 

Upstream		• Steel and fiberglass tanks • Separators: • High / Low Pressure • Vertical / Horizontal • Two / Three Phase • Sand separators • Vapor recovery units • Horizontal and vertical heater treaters • Free water knockouts		• Scrubbers • Gas conditioning and treating products • Gas production units • Water heating units • Fluid storage and measurement units • Well test units • Dehydration skids • Gas measurement skids • Bubble towers
Midstream		• Skid mounted compressor headers and manifolds • Glycol towers • TEG dehydration units • Control valve skids • Slug catchers • Process piping spools • Pig launchers and receivers		• Pipeline bending and construction equipment • Pigging separators • Gas measurement skids • Regeneration units • Filter separators • Scrubbers • Fuel gas skid units
Downstream/ Measurement & Monitoring		• EDGE™ Desalination and Dehydration • LACT units • Calibrated meter provers • Sales gas skids		• Condensate meter skids • Custody transfer skids • Prover tanks • Spare parts and other specialty equipment

Valve solutions

We design, manufacture and provide a wide range of industrial valves that principally serve the upstream, midstream and downstream markets of the oil and gas value chain. To a lesser extent, our valves serve general industrial, power and process industry customers as well as the mining industry. We provide a comprehensive suite of ball, gate, globe, check and butterfly valves across a wide range of sizes and application. We believe the worldwide market for industrial valves like ours is approximately $12 billion, with 55% of the market being in the United States. By percentage of our 2010 full year revenue, our valve solutions business is made up of the following types: 45% ball valves, 30% butterfly valves and 25% multi-turn valves.

We market our valves to our customers and end users through our four recognized brands: PBV, DSI, Quadrant and ABZ. Much of our production is sold through distribution channels, with marketing efforts targeting end users for pull through of our products. Our global sales force and representatives cover 30 countries, with significant affiliated distribution in Canada and South Africa. Our Canadian affiliate provides significant exposure to the growing heavy oil spend cycle while our South African affiliate serves chemical, petrochemical and refining customers. We

 

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have recently established a presence in both Australia and Brazil to enhance our exposure to those growing markets. After rigorous testing, our valve products in this segment have been included on the Approved Manufacturers List (“AML”) of many end users. A key component of our future growth will lay in our ability to increase our presence on more AMLs in key markets outside of North America. To accomplish this, we intend to continue to market our valves to end users and aggressively expand our international presence. During 2010, 43% of our valve solutions business line revenue was derived from outside of the United States.

Our manufacturing and supply chain systems enable us to design and produce high-quality, engineered valves, as well as provide standardized products, while maintaining competitive pricing and minimizing capital requirements. We manufacture and warehouse our highly engineered PBV ball valves inside of our 300,000 square foot valve manufacturing and warehouse facility in Stafford, Texas and utilize our international manufacturing partners to produce components and completed products for a number of our other valve brands. We have developed stringent quality control procedures over many years in close collaboration with our manufacturing partners, and have invested significant resources to bring our partners’ level of reliability and quality up to the very best standards in the industry.

Valve product lines

Our valve solutions products fit broadly into the quarter-turn and multi-turn valve categories. With the exception of our mud valves, which are part of our drilling products line, and the valves we market through our flow equipment business, the quarter-turn category includes valves that open and close with 90 degrees of rotation. These valves are typically more compact, lightweight and high performance than multi-turn valves and are generally designed for specific applications. Quarter-turn products consist of butterfly valves and ball mounted valves of both floating and trunnion designs. When in the open position, ball valves provide a seamless media path, which is an important feature for applications that require pigging of the piping system. Multi-turn products, consisting of gate and globe valves, are considered the workhorse of the industry. Their robust design allows them to work under a very broad range of operating conditions. We also manufacture a variety of check valves, which prevent backflow of media. Every type of valve has applications in all segments of the energy value chain and in industrial processes. Many permutations of valve design have evolved to match the large variety of temperature, pressure, media, flow conditions and customer preferences in the energy and general industrial settings.

We manufacture our valves to conform to the standards of the American Petroleum Institute (“API”), American National Standards Institute (“ANSI”), American Bureau of Shipping (“ABS”), and International Organization for Standardization (“ISO”) and other relevant standards governing the design and manufacture of industrial valves. Though our valve solutions segment, we participate in the API’s standard-setting process. In addition to published standards, we have deep knowledge of specific design standards and manufacturing procedures demanded by large global energy players.

 

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A representative sampling of the key products and associated brands in our valve solutions product lines are listed below.

Key valve solutions products

 

Upstream		• Flanged floating ball valves (Quadrant) • Threaded and socket welded ball valves (Quadrant) • Butterfly valves (Quadrant) • Metal seated ball valves (PBV) • Trunnion mounted ball valves (PBV)
Midstream		• Trunnion mounted ball valves (PBV) • Flanged floating ball valve (PBV) • Full opening check valves (PBV) • Threaded and stockweld valves (PBV)
Downstream		• Cast steel gate, globe, and check valves (DSI), available in  1/2” to 48” • Forged steel gate, globe, and check valves (DSI) • Pressure seal valves (DSI) • Cast iron valves (DSI) • Threaded and socket weld ball valves (PBV/Quadrant) • Flanged floating ball valves (PBV/Quadrant) • Multi-port ball valve (Quadrant) • Triple offset butterfly valves (ABZ)
Mining, other		• Resilient seated butterfly valves • High performance butterfly valves (ABZ), available in 2” to 60” • Pneumatic and electric actuated butterfly valves

Business history

SCF Partners is a private equity firm that has specialized in investments in the oilfield services sector since it was founded in 1989. In May 2005, SCF formed FOT in connection with its acquisition of Access Oil Tools, a pipe-handling tool manufacturer and supplier. FOT was founded largely to create a capital equipment provider focused on the drilling sector. Over time, FOT added other businesses to provide a balanced mix of capital and consumable goods to the drilling industry. From 2005 through 2008, FOT experienced rapid growth both organically and through thirteen acquisitions.

In June 2005, SCF became the controlling stockholder of Global Flow, a manufacturer of industrial valves. Global Flow presented an opportunity for global expansion due to its international supply chain and channels to market, and offered a valve platform around which to develop a larger valve focused business. From 2005 to 2008, Global Flow acquired three complementary valve businesses to create a company with exposure to the upstream, midstream, and downstream markets.

In February 2007, Triton was formed following the acquisition of Perry Slingsby Systems by SCF. Perry Slingsby Systems was identified as a platform company around which to create a subsea focused business that specializes in providing products and services to the international offshore

 

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oil and gas industry. Triton targeted the global growth in deepwater and offshore resource developments. Triton grew rapidly through acquisitions, acquiring eight companies by the end of 2008.

In August 2007, Allied was formed by SCF through the acquisition and merger of four companies focused on the growing process and infrastructure requirements associated with unconventional gas and liquids developments in North America.

Finally, Subsea, a provider of subsea pipeline infield joint coatings and other applied products, was formed by SCF through the acquisition of OJS in January 2007. Subsea subsequently acquired a specialty pipeline construction rental equipment business focused on the onshore market to create a broader pipeline infrastructure equipment business.

During the industry-wide downcycle in 2009, FOT, Global Flow, Triton, Allied and Subsea focused on working capital management, margin preservation and customer targeting, and generally positioned themselves for competitive growth in 2010. Beginning in 2009, and in collaboration with SCF Partners, several of the companies initiated strategic discussions concerning the formation of a broadly based oilfield products company that would be capitalized to take advantage of growth opportunities as the industry recovered. After a thorough review involving the management and independent board members of each of the five companies, FOT, Global Flow, Triton, Allied and Subsea were combined on August 2, 2010 in the Combination. In the Combination, FOT became the parent company and was renamed Forum Energy Technologies, Inc. The primary objectives of the Combination were to provide the shareholders and management of the constituent companies a broader platform for growth and access to new equity and debt capital, resulting in an enhanced ability to take advantage of growth opportunities.

During the strategic discussions leading up to the Combination process, key members of management identified the following objectives and benefits of consummating the Combination:

 

•

Increase access to growth capital.    Many of the Combination companies projected that there would be significant growth opportunities available during a recovery from the 2009 economic downturn, both in terms of organic and acquisition growth. However, many of these growth opportunities required financial commitments that would strain the individual company balance sheets. On an aggregate basis, and with a new credit facility and equity commitment from SCF Partners, the combined Company could have the capability to make those investments. Among the opportunities discussed at the time were: (1) building greenfield manufacturing and aftermarket service facilities in emerging basins, such as in the Marcellus and Macae, Brazil; (2) substantially increasing the size of our subsea equipment rental fleet; (3) creating alternative financing models to help customers accelerate their purchase of key capital equipment; and (4) creating a dedicated new product engineering and development capability.

 

•

Enhance ability to serve our customers and improve cross selling of products.    Several of the Combination companies perceived that their relatively small scale inhibited their ability to make a qualitative step change in their relationship with certain large, key customers. A larger platform with better financing would instill greater confidence in customers and better position the business to pursue larger capital equipment orders, multi-year fleet renewal programs, consumable product inventory management and other long-term strategic supplier arrangements. In addition, access to a more expansive geographic platform would provide

 

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several of the Combination companies with a greater capacity to provide aftermarket service. Finally, the management teams believed that we would have more opportunities to reach certain targeted customers and the ability to leverage those interactions to drive incremental revenue opportunities. For example, management believed that Allied’s customer relationships with producers would provide introductory opportunities for Global Flow’s valve business, which generally is pulled through distribution companies to the producer.

 

•

Leverage the strengths of each company across the combined Company.    Each of the Combination companies had particular strengths, many of which would benefit one or more of the others. For example, the controls technology expertise imbedded within Triton’s ROV development group could provide FOT’s tubular handling capital equipment development effort with access to highly skilled engineers who had solutions to controls technology challenges. A second example involved Global Flow’s robust supply chain system, which involved outsourced manufacturing and critical vendor relationships in Asia. The combined management believed that access to this supply chain and the knowledge that produced it would accelerate similar efforts across the other companies.

 

•

Enhance financial stability.    Each of the Combination companies was subject to different industry drivers, many of which have historically experienced different cycles. The management teams believed that a combined company participating in each of these varying cycles would provide an enhanced measure of stability to the business and to the long-term planning process by decreasing the volatility of its financial results.

 

•

Internally source products.    Some of the Combination companies used products of other Combination companies in their manufacturing process. For example, Allied’s surface production equipment business used a large quantity of valves, such as those produced by Global Flow, in the production of skidded process systems. The management teams believed there would be an opportunity to generate incremental business by internally sourcing some of these products.

Having concluded the Combination, we believe that the investment thesis and the associated operational benefits to us have been proven. As integration has proceeded, we have discovered benefits and opportunities incremental to those described above. We believe that the operational and financial benefits realized through the Combination have: (1) enhanced our growth potential; (2) offered ongoing synergistic opportunities; (3) provided the opportunity to develop broader and more diversified product lines; (4) enabled us to compete with larger companies; (5) provided an opportunity to leverage discrete internal initiatives across a broader platform; and (6) established a good foundation for long-term growth. Several of these opportunities are under development and we believe that there will be strong benefits to the business as we continue to grow.

 

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Backlog

We had the following backlog as of the dates indicated, consisting of written orders or commitments believed to be firm contracts for our products:

 

		Actual
		As of December 31, 2010				As of June 30, 2011
(in millions)
Production and Infrastructure Segment		$	52.7			$	140.9
Drilling and Subsea Segment			97.5				155.1
Total		$	150.2			$	296.0

Consistent with our strategy of preserving a balanced mix of capital goods, consumable products, repair parts, and rental services, a majority of our business does not require lengthy lead times, and we therefore believe that the size of our backlog is mostly representative of the activity level of our capital equipment related businesses. Substantially all of the orders and commitments included in our backlog as of August 25, 2011 were scheduled to be delivered within six months.

Our consumable and repair products are predominantly off-the-shelf items requiring short lead-times, and our related refurbishment or other services are also not contracted with much lead time. Our consumable products, spare parts and aftermarket or other services comprised 52% of the pro forma revenue we generated in fiscal 2010. The majority of these products and related services have lead-times shorter than six months.

We can give no assurance that our backlog will remain at current levels. Sales of our products are affected by prices for oil and natural gas, which may fluctuate significantly. Additional future declines in oil and natural gas prices and production or additional regulatory provisions could reduce new customer orders, possibly causing a decline in our future backlog. Substantially all of our projects currently included in our backlog are subject to change and/or termination at the option of the customer. In the case of a change or termination, the customer is required to pay us for work performed and other costs necessarily incurred as a result of the change or termination. In the past, terminations and cancellations have not been material to our overall operating results.

Seasonality

A substantial portion of our business is not significantly impacted by changing seasons. A small portion of the revenue we generate from selected Canadian operations may benefit from higher first quarter activity levels, as operators take advantage of the winter freeze to gain access to remote drilling and production areas. In the past, some of our revenue in Canada has declined during the second quarter due to warming weather conditions that resulted in thawing, softer ground, difficulty accessing drill sites and road bans that curtailed drilling activity. However, in 2010, this business generated substantially less than 50% of our total fiscal 2010 Canadian revenue. We also experience some exposure to seasonality through the portion of our subsea rental business that serves the North Sea. It is customary for activity related to this rental equipment to slow down between the months of November and February. However, revenue exposed to this type of seasonality comprised less than 5% of our overall revenue in fiscal 2010.

 

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Competition

The markets in which we operate are highly competitive. We compete with a number of companies, some of which have financial and other resources greater than us. The principal competitive factors in our markets are the quality, price and availability of products and services and a company’s responsiveness to customer needs and reputation for safety. We believe several factors give us a strong competitive position. In particular, we believe our products and services in each segment are at least comparable in price, quality, performance and dependability. We seek to differentiate ourselves from our competitors by providing a rapid response to the needs of our customers, a high level of customer service, and innovative product development initiatives. While we have no single competitor across all of our product lines, the companies we compete with across the greatest number of our product lines include Cameron International Corporation and FMC Technologies.

Drilling and Subsea Segment

Subsea products.    We have no one direct competitor across all of our product and service lines. We hold established market leading positions in several of our core businesses on a global basis, and we compete with a small number of competitors. The most significant competitor we have across our subsea business is Schilling Robotics, a subsidiary of FMC Technologies Inc. Our principal competitors in some of our subsea business lines are as follows:

 

•

Vehicles and products—Schilling Robotics (45% owned by FMC Technologies Inc.); Soil Machine Dynamics; and Saab Seaeye (a wholly owned subsidiary of Saab Underwater Systems AB); and

 

•

Subsea rental equipment—Ashtead Technology Rental; Seatronics Ltd. (a subsidiary of Acteon Group Ltd) and Fugro N.V.

Downhole products.    We have no one direct competitor across all of our downhole product lines. However, our principal competitors can be separated into these categories:

 

•

Casing and cementing tools—Weatherford International, Ltd.; Halliburton Company (however, Halliburton focuses on production for internal use); Frank’s Casing Crews & Rentals, Inc.; Varel International Energy Services Inc.; Ray Oil Tool; and

 

•

Downhole protection solutions—Lasalle Engineering Limited (a subsidiary of Schlumberger Ltd., which focuses on production for Schlumberger’s internal use in services capacity); Tube-Tec (a subsidiary of Polymer Holdings Ltd.), providing cast protectors principally to the North Sea market.

Drilling products.    Our drilling, intervention and flow control products business lines compete in a highly consolidated market. Principal competitors include: National Oilwell Varco, Inc., Maritime Hydraulics, Canrig (a division of Nabors Industries), Blohm + Voss GmbH, LeTourneau (a division of Joy Global), Pason Systems, Inc., Cameron International Corporation, Southwest Oilfield Products, Double Life Corporation, Inc., and Oteco, Inc.

Production and Infrastructure Segment

Flow equipment.    We have two large competitors in this business line, and a number of smaller competitors. The largest competitors are FMC Technologies and Weir SPM.

 

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Surface production and process products.    The most direct competitor we across this business line is Natco Group Inc. (a division of Cameron International Corporation). Our principal competitors by product type are as follows:

 

•

Vessels and Separators—Exterran; Valerus Compression Services; Energy WeldFab; Natco Group Inc.; Sivalls; Challenger Tank and Manufacturing;

 

•

Tanks—Palmer Tanks; Permian Tank and Manufacturing; Challenger Tank and Manufacturing (owned by Dover Corp.); Smith Pipe of Abilene; and

 

•

Desalter product line—Cameron International Corporation.

Valve products.    Our valve products business line competes with a number of competitors in each of its market segments. Our largest competitors have similar or greater scope of product offering. Among these larger competitors are Cameron International, Velan, Inc., Balon Corporation, and CIRCOR International, Inc.

Properties

The following tables describe the material facilities owned or leased by us as of August 31, 2011:

Drilling and Subsea facilities:

 

Location		Leased or owned		Principal/Most Significant Use
Liberty, TX		Leased		Drilling Aftermarket
Victoria, TX		Leased		Drilling Aftermarket
Tyler, TX		Leased		Drilling Equipment Distribution
Broussard, LA		Leased		Drilling Equipment Distribution
Spring, TX		Owned		Drilling Equipment Distribution
Dubai, UAE		Leased		Drilling Equipment Distribution
Nisku, Canada		Owned		Drilling Equipment Distribution
Aberdeenshire, UK		Leased		Drilling Equipment Distribution
Broussard, LA		Owned		Drilling Equipment Manufacturing
San Antonio, TX		Owned		Drilling Equipment Manufacturing
Singapore		Leased		Drilling Equipment Manufacturing
Monterrey, Mexico		Leased		Drilling Equipment Manufacturing
Tyne & Wear, UK		Leased		Drilling Equipment Manufacturing
Leduc, Canada		Leased		Drilling Equipment Manufacturing
Aberdeen, UK		Leased		Drilling Equipment Manufacturing
Caithness, UK		Leased		Drilling Equipment Manufacturing
Kilbirnie, UK		Leased		Drilling Equipment Manufacturing
Houston, TX		Leased		Drilling Headquarters, Engineering
Katy, TX		Leased		Offshore Pipeline Construction
Batam, Indonesia		Leased		Offshore Pipeline Construction
Houston, TX		Leased		ROV Engineering, Sales, Software
Kirkbymoorside, UK		Leased		ROV Manufacturing
Aberdeenshire, UK		Leased		ROV Manufacturing
Aberdeenshire, UK		Leased		ROV Sales and Services
Norfolk, UK		Leased		ROV Sales and Services

 

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Location		Leased or owned		Principal/Most Significant Use
Houston, TX		Leased		ROV Sales and Services
Singapore		Leased		ROV Sales and Services
Aberdeenshire, UK		Leased		ROV Software & Technology
Jupiter, FL		Leased		ROV Software & Technology
Houston, TX		Leased		Seafloor Geoservices
Aberdeenshire, UK		Leased		Subsea Management
Stafford, TX		Owned		Downhole Products Manufacturing
Pearland, TX		Owned		Downhole Products Manufacturing

Production and Infrastructure facilities:

 

Location		Leased or Owned		Principal/ Most Significant Use
Alice, TX		Leased		Flow Equipment Manufacturing
Davis, OK		Owned		Flow Equipment Manufacturing
Odessa, TX		Leased		Flow Equipment Recertification / Distribution
Decatur, TX		Leased		Flow Equipment Recertification / Distribution
Longview, TX		Leased		Flow Equipment Recertification / Distribution
Clearfield, PA		Owned		Production Equipment Manufacturing
Pasadena, TX		Leased		Production Equipment Manufacturing
Chickasha, OK		Owned		Production Equipment Manufacturing
Guthrie, OK		Leased		Production Equipment Manufacturing
Elmore City, OK		Leased		Production Equipment Manufacturing
Gainesville, TX		Leased		Production Equipment Manufacturing
Smithton, PA		Leased		Production Equipment Manufacturing
Cotulla, TX		Leased		Production Equipment Service Center
Greenwood, LA		Leased		Production Equipment Service Center
Stafford, TX		Leased		Valve Distribution
Edmonton, Canada		Leased		Valve Distribution
Vereeniging, South Africa		Leased		Valve Distribution
Madison, KS		Leased		Valve Manufacturing
Stafford, TX		Leased		Valve Manufacturing
Broussard, LA		Leased		Valve Manufacturing
Conroe, TX		Leased		Pipeline Construction Equipment

New product development and intellectual property

We have dedicated resources toward the development of new technology and equipment to enhance the safety and efficiency of drilling, completion, well servicing and production processes. Our sales and earnings are influenced by our ability to successfully introduce new or improved products to the market. We currently hold multiple U.S. and international patents and have a number of pending patent applications.

 

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Although in the aggregate our patents and licenses are important to us, we do not regard any single patent or license as critical or essential to our business as a whole. In general, in the conduct of our operations, we depend on our technological capabilities and application of our know-how to distinguish ourselves from our competitors, rather than our right to exclude others through patents or exclusive licenses. We also consider the quality and timely delivery of our products, the service we provide to our customers, and the technical knowledge and skill of our personnel to be more important than our registered intellectual property in our ability to compete. While we stress the importance of our research and development programs, the technical challenges and market uncertainties associated with the development and successful introduction of new products are such that we cannot assure you that we will realize any particular amount of future revenue from the products resulting from our research and development programs.

Suppliers and raw materials

We acquire component parts, products and raw materials from suppliers, including foundries, forge shops, and original equipment manufacturers. The prices we pay for our raw materials may be affected by, among other things, energy, steel and other commodity prices, tariffs and duties on imported materials and foreign currency exchange rates. Certain of our component parts, products or raw materials, such as bearings, are only available from a limited number of suppliers. Please see “Risk factors—Risks related to our business—We are subject to the risk of supplier concentration.”

We have experienced increased costs in recent years due to rising steel prices. There is also strong demand for forgings, castings and outsourced coating services necessary for us to make our products. We cannot assure you that we will be able to continue to purchase these raw materials on a timely basis or at acceptable prices.

We generally try to purchase our raw materials from multiple suppliers so we are not dependent on any one supplier, but this is not always possible.

Inventories and working capital

An important consideration for many of our customers in selecting a vendor is timely availability of the product. Often customers will pay a premium for earlier or immediate availability because of the cost of delays in critical operations. We aim to stock our consumable products in regional warehouses around the world so we can have these products available for our customers when needed. This availability is especially critical for our bearing and valve products, causing us to carry substantial inventories for these products. For critical capital items in which demand is expected to be strong, we often build certain items before we have a firm order. Our having such goods available on short notice can be of great value to our customers.

We typically offer our customers payment terms of net 30 days. For sales into certain countries we might require payment upfront or credit support through a letter of credit. For longer term projects we typically require stage payments as important milestones are reached. On average we collect our receivables in about sixty days from shipment resulting in a substantial investment in accounts receivable. Likewise, standard terms with our vendors are net 30 days. For critical items sourced from significant vendors we have settled accounts more quickly, sometimes in exchange for early payment discounts.

 

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Employees

As of August 31, 2011, we had approximately 2,900 employees. Of our total employees, approximately 2,100 were in the United States, 500 were in the United Kingdom, 130 were in Canada and 170 were located in other locations. We are not a party to any collective bargaining agreements, other than in our Monterrey, Mexico facility, and we consider our relations with our employees to be satisfactory.

Operating risk and insurance

We currently carry a variety of insurance for our operations. We are partially self-insured for certain claims in amounts we believe to be customary and reasonable. Although we believe we currently maintain insurance coverage adequate for the risks involved, there is a risk our insurance may not be sufficient to cover any particular loss or that our insurance may not cover all losses.

Environmental, health and safety regulation

Our operations are subject to numerous stringent and complex laws and regulations governing the discharge of materials into the environment, health and safety aspects of our operations, or otherwise relating to human health and environmental protection. Failure to comply with these laws or regulations or to obtain or comply with permits may result in the assessment of administrative, civil and criminal penalties, imposition of remedial or corrective action requirements, and the imposition of injunctions to prohibit certain activities or force future compliance.

The trend in environmental regulation has been to impose increasingly stringent restrictions and limitations on activities that may impact the environment, and thus, any changes in environmental laws and regulations or in enforcement policies that result in more stringent and costly waste handling, storage, transport, disposal, or remediation requirements could have a material adverse effect on our operations and financial position. Moreover, accidental releases or spills of regulated substances may occur in the course of our operations, and we cannot assure you that we will not incur significant costs and liabilities as a result of such releases or spills, including any third party claims for damage to property, natural resources or persons. While we believe that we are in substantial compliance with existing environmental laws and regulations and that continued compliance with current requirements will not have a material adverse effect on our financial condition or results of operations, there can be no assurance that incidents will not occur or that we will be able to comply with increasingly stringent requirements.

The following is a summary of the more significant existing environmental, health and safety laws and regulations to which our business operations are subject and for which compliance may have a material adverse impact on our capital expenditures, results of operations or financial position.

Hazardous substances and waste

The Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes, regulate the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous wastes. Under the auspices of the EPA, the individual states administer some or all

 

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of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. We are required to manage the transportation, storage and disposal of hazardous and non-hazardous wastes in compliance with RCRA.

The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), also known as the Superfund law, imposes joint and several liability, without regard to fault or legality of conduct, on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. These persons include the owner or operator of the site where the release occurred, and anyone who disposed or arranged for the disposal of a hazardous substance released at the site. We currently own, lease, or operate numerous properties that have been used for manufacturing and other operations for many years. We also contract with waste removal services and landfills. These properties and the substances disposed or released on them may be subject to CERCLA, RCRA and analogous state laws. Under such laws, we could be required to remove previously disposed substances and wastes, remediate contaminated property, or perform remedial operations to prevent future contamination. In addition, it is not uncommon for neighboring landowners and other third-parties to file claims for personal injury and property damage allegedly caused by hazardous substances released into the environment.

Water discharges

The Federal Water Pollution Control Act (the “Clean Water Act”) and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the United States. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or an analogous state agency. A responsible party includes the owner or operator of a facility from which a discharge occurs. The Clean Water Act and analogous state laws provide for administrative, civil and criminal penalties for unauthorized discharges and, together with the Oil Pollution Act of 1990, impose rigorous requirements for spill prevention and response planning, as well as substantial potential liability for the costs of removal, remediation, and damages in connection with any unauthorized discharges.

Air emissions

The federal Clean Air Act and comparable state laws regulate emissions of various air pollutants through air emissions permitting programs and the imposition of other emission control requirements. In addition, the EPA has developed, and continues to develop, stringent regulations governing emissions of toxic air pollutants at specified sources. Non-compliance with air permits or other requirements of the federal Clean Air Act and associated state laws and regulations can result in the imposition of administrative, civil and criminal penalties, as well as the issuance of orders or injunctions limiting or prohibiting non-compliant operations.

Climate change

In December 2009, the EPA determined that emissions of carbon dioxide, methane and other “greenhouse gases” present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth’s atmosphere and other climatic changes. Based on these findings, the EPA has begun adopting and implementing regulations to restrict emissions of greenhouse gases under existing provisions of the federal Clean Air Act. The EPA recently adopted two sets of rules regulating greenhouse

 

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gas emissions under the Clean Air Act, one of which requires a reduction in emissions of greenhouse gases from motor vehicles and the other of which regulates emissions of greenhouse gases from certain large stationary sources, effective January 2, 2011. The EPA’s rules relating to emissions of greenhouse gases from large stationary sources of emissions are currently subject to a number of legal challenges, but the federal courts have thus far declined to issue any injunctions to prevent the EPA from implementing, or requiring state environmental agencies to implement, the rules. The EPA has also adopted rules requiring the reporting of greenhouse gas emissions from specified large greenhouse gas emission sources in the United States, including petroleum refineries, on an annual basis, beginning in 2011 for emissions occurring after January 1, 2010, as well as onshore oil and natural gas production facilities, on an annual basis, beginning in 2012 for emissions occurring in 2011.

In addition, the United States Congress has from time to time considered adopting legislation to reduce emissions of greenhouse gases and almost one-half of the states have already taken legal measures to reduce emissions of greenhouse gases primarily through the planned development of greenhouse gas emission inventories and/or regional greenhouse gas cap and trade programs. Most of these cap and trade programs work by requiring major sources of emissions, such as electric power plants, or major producers of fuels, such as refineries and gas processing plants, to acquire and surrender emission allowances. The number of allowances available for purchase is reduced each year in an effort to achieve the overall greenhouse gas emission reduction goal.

The adoption of legislation or regulatory programs to reduce emissions of greenhouse gases could require us to incur increased operating costs, such as costs to purchase and operate emissions control systems, to acquire emissions allowances or comply with new regulatory or reporting requirements. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, the oil and natural gas produced by our customers. Consequently, legislation and regulatory programs to reduce emissions of greenhouse gases could have an adverse effect on our business, financial condition and results of operations. Finally, it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events. If any such effects were to occur, they could have an adverse effect on our business, financial condition, results of operations and cash flow.

Employee health and safety

We are subject to a number of federal and state laws and regulations, including the federal Occupational Safety and Health Act (“OSHA”) and comparable state statutes, establishing requirements to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of the federal Superfund Amendment and Reauthorization Act and comparable state statutes require that information be maintained concerning hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and the public. Substantial fines and penalties can be imposed and orders or injunctions limiting or prohibiting certain operations may be issued in connection with any failure to comply with laws and regulations relating to worker health and safety.

We also operate in non-U.S. jurisdictions, which may impose similar liabilities against us.

 

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Legal proceedings

From time to time, we have various claims, lawsuits and administrative proceedings that are pending or threatened, all arising in the ordinary course of business, with respect to commercial, product liability and employee matters.

Asbestos litigation

One of our subsidiaries has been named as one of many defendants in a number of product liability claims for alleged exposure to asbestos. These lawsuits are typically filed on behalf of plaintiffs who allege exposure to some asbestos, against numerous defendants, often 40 or more, who may have manufactured or distributed products containing asbestos. The injuries alleged by plaintiffs in these cases range from mesothelioma to other cancers to asbestosis. The earliest claims against our subsidiary were filed in New Jersey in 1998, and our subsidiary currently has active cases in Missouri, New Jersey, New York and Illinois. The product line with asbestos exposure was acquired by our subsidiary in 1986. Our subsidiary has been successful in obtaining dismissals in most lawsuits where the exposure is alleged to have occurred prior to our acquisition of the product line. The law in some states requires purchasers of product lines to assume responsibility for incidents occurring prior to the acquisition date under so called “successor liability” laws, and the law in other states is ambiguous in this regard. Most claimants alleging illnesses due to asbestos sue on the basis of exposure prior to 1986, as by that date the hazards of asbestos exposure were well known and asbestos had begun to fall into disuse in industrial settings. To date, asbestos claims have not had a material adverse effect on our business, financial condition, results of operations, or cash flow, as our annual out-of-pocket costs over the last five years has been less than $200,000. There are typically approximately forty to eighty cases filed against our subsidiary each year, and a similar number of cases are dismissed, settled or otherwise disposed of each year. We currently have approximately 135 lawsuits pending against this subsidiary. Our subsidiary has over $17 million in face amount of per occurrence and over $23 million of aggregate primary insurance coverage. In addition, our subsidiary has over $950 million in face amount of excess coverage applicable to the claims. There can be no guarantee that all of this can be collected due to policy conditions and insurer insolvencies in the past or in the future. In February 2011, we entered into an agreement with seven of our primary insurers under which they have agreed to pay 80% of the costs of handling or settling each claim against the affected subsidiary. After an initial period, and under certain circumstances, our subsidiary and the subscribing underwriters may withdraw from this agreement.

Portland Harbor Superfund litigation

In May 2009, one of our subsidiaries (which is presently a dormant company with nominal assets except for rights under insurance policies) was named along with many defendants in a suit filed by the Port of Portland, Oregon seeking reimbursement of costs related to a five-year study of contaminated sediments at the port. In March 2010, the subsidiary also received a notice letter from the EPA indicating that it had been identified as a potentially responsible party with respect to environmental contamination in the “study area” for the Portland Harbor Superfund Site. Under a 1997 indemnity agreement, our subsidiary is indemnified by a third party with respect to losses relating to environmental contamination. As required under the indemnity agreement, our subsidiary provided notice of these claims, and the indemnitor has assumed responsibility and is providing a defense of the claims. Although we believe that it is unlikely that our subsidiary contributed to the contamination at the Portland Harbor Superfund Site, the potential liability of our subsidiary and the ability of the indemnitor to fulfill its indemnity obligations cannot be quantified at this time.

 

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Management

Executive officers and directors

Set forth below are the names, ages and positions of our executive officers and directors as of August 31, 2011. All directors are elected for a term of one year or serve until their successors are elected and qualified or upon earlier of death, disability, resignation or removal. All executive officers hold office until their successors are elected and qualified or upon earlier of death, disability, resignation or removal. There are no family relationships among any of our directors or executive officers. The address of each director and executive officer is: 920 Memorial City Way, Suite 800, Houston, Texas 77024.

 

Name		Age		Position
C. Christopher Gaut		55		President, Chief Executive Officer and Chairman of the Board
Charles E. Jones		52		Executive Vice President; President—Drilling and Subsea
Wendell R. Brooks		61		Executive Vice President; President—Production and Infrastructure
James W. Harris		52		Senior Vice President and Chief Financial Officer
James L. McCulloch		58		Senior Vice President, General Counsel and Secretary
W. Patrick Connelly		35		Vice President—Strategic Development
Michael D. Danford		48		Vice President—Human Resources
Evelyn Angelle		44		Director
David C. Baldwin		48		Director
John A. Carrig		59		Director
Michael McShane		57		Director
Franklin Myers		58		Director
John Schmitz		51		Director
Andrew L. Waite		50		Director

C. Christopher Gaut.    Mr. Gaut has served as our President, Chief Executive Officer and Chairman of the board of directors since August 2010 and as one of our directors since December 2006. He served as a consultant to LESA, the ultimate general partner of SCF, from November 2009 to August 2010. Mr. Gaut served at Halliburton Company, a leading diversified oilfield service company, as President of the Drilling and Evaluation Division and prior to that as Chief Financial Officer, from March 2003 through April 2009. From April 2009 through November 2009, Mr. Gaut was a private investor. Prior to joining Halliburton Company in 2003, Mr. Gaut was the Co-Chief Operating Officer of Ensco International, a provider of offshore contract drilling services. He also served as Ensco’s Chief Financial Officer from 1988 until 2003. Mr. Gaut is currently a member of the Board of Directors of Ensco plc. Mr. Gaut holds an A.B. in Engineering Sciences from Dartmouth College and an M.B.A. from The Wharton School at the University of Pennsylvania.

Charles E. Jones.    Mr. Jones has served as an Executive Vice President and the President of our Drilling and Subsea Segment since the Combination in August 2010. He served as FOT’s President

 

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and Chief Executive Officer from October 2007 to the Combination. Prior to joining FOT, from January 2003 until October 2007, Mr. Jones was the Executive Vice President and Chief Operating Officer of Hydril Company, a supplier of drilling equipment to the oil and gas industry. Mr. Jones served as Vice President of Hydril Company’s Pressure Control segment from November 2001 until January 2003. Prior to serving in that position, he served as the Managing Director, Pressure Control for Hydril beginning in March 1998. From March 1996 until March 1998, Mr. Jones served as a Director of the subsea business for Cooper Cameron Corporation, a provider of flow equipment products, systems and services to oil, gas and process industries. From April 1995 until March 1996, Mr. Jones served as an Engineering Manager for Subsea Offshore (formerly Dresser Industries), a provider of ROV and remote intervention systems. Mr. Jones holds a B.S. in Mechanical Engineering from the University of Houston and, in 2002, he completed the Harvard Business School Advanced Management Program.

Wendell R. Brooks.    Mr. Brooks has served as an Executive Vice President and the President of our Production and Infrastructure Segment since August 2010. He served as Chief Executive Officer and President of Allied Production Services, Inc. from October 2007 until August 2010. Prior to that, from 1996 to October 2007, he was the Group Director for the well support business of John Wood Group Plc, a public Scottish company traded on the London Stock Exchange. Mr. Brooks also served on the Board of Directors of Wood Group during that time. Mr. Brooks has also been President of Del Norte Inc. and was employed by Geosource, Inc. from 1975 to 1984 where he was involved in business development and served as President of two divisions. Mr. Brooks has a B.B.A. from the University of Texas at Arlington and an M.B.A. from the Harvard Business School.

James W. Harris.    Mr. Harris has served as our Senior Vice President and Chief Financial Officer since the Combination in August 2010. From December 2005 until the Combination, Mr. Harris served as FOT’s Executive Vice President and Chief Financial Officer. Mr. Harris was Vice President, Controller of VeriCenter, Inc., a provider of information technology services, and General Manager of its AppSite Hosting service line from January 2004 through November 2005. Prior to joining VeriCenter, from August 1999 through December 2001, Mr. Harris worked for Enron Energy Services, Inc., as a Vice President and thereafter served as a consultant through December 2003. Mr. Harris began his career at PriceWaterhouse from January 1985 until February 1994, with his final position being a Senior Tax Manager, and at Baker Hughes Incorporated from February 1994 until May 1999 in various positions, including Vice President, Tax and Controller. Mr. Harris received his B.S. and his Masters of Accounting from Brigham Young University and his M.B.A. from Rice University. Mr. Harris is a certified public accountant.

James L. McCulloch.    Mr. McCulloch has served as our Senior Vice President, General Counsel and Secretary since October 2010. Mr. McCulloch was a private investor from January 2008 until joining the Company, and since February 2008 has also served on the Board of Directors of Sunland Inc., a privately held pipeline construction and services company. In 1983 Mr. McCulloch joined Global Marine Inc., a leading international offshore drilling contractor, as Assistant General Counsel and served in a variety of capacities within the legal department until being named Senior Vice President and General Counsel in 1995. In 2001 Global Marine merged with Santa Fe International Corporation, an international land and offshore drilling contractor, to form GlobalSantaFe Corporation, the second largest offshore drilling company in the world, where Mr. McCulloch continued to serve as Senior Vice President and General Counsel until the company’s merger with Transocean Inc. in December 2007. Prior to joining Global Marine, Mr. McCulloch worked for a privately held shipping company based in Tampa, Florida and as an

 

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associate with the Phelps Dunbar law firm in New Orleans, Louisiana. Mr. McCulloch received his B.A. from Tulane University and his J.D. from Tulane University School of Law.

W. Patrick Connelly.    Mr. Connelly provides services pursuant to a Secondment Agreement between us and LESA. Please see, “Certain relationships and related party transactions—Transactions with our significant stockholder prior to the Combination.” Mr. Connelly has served as our Vice President of Strategic Development since August 2010. In this capacity, Mr. Connelly is responsible for the development and execution of a range of strategic initiatives, including mergers and acquisitions, new product line concept development, strategic marketing initiatives, long-term capital formation, and other similar efforts. Before joining our Company, Mr. Connelly worked at SCF Partners, where he played an instrumental role in the merger and recapitalization of the five SCF Partners’ portfolio companies that formed Forum Energy Technologies, Inc. Mr. Connelly received his B.S. in Mathematics and Systems Engineering from the U.S. Military Academy at West Point, an M.B.A. from Harvard Business School and a Masters of Public Administration from the Harvard Kennedy School of Government. Prior to joining SCF Partners, he served as an active duty infantry officer in the United States Army for over six years, and participated in operational deployments throughout the Balkans, North Africa, and Iraq.

Michael D. Danford.    Mr. Danford has served our Vice President—Human Resources since August 2010. He served as Vice President Human Resources for FOT from November 2007 until August 2010. Prior to joining our Company, from August 2007 through November 2007, he worked at Trico Marine Services Inc. as Vice President—Human Resources. From 1997 through July 2007, Mr. Danford served as Director of Human Resources and Vice President Human Resources for Hydril Company. From 1991 to 1997, Mr. Danford served in various human resources roles for Baker Hughes Incorporated. Prior to joining Baker Hughes Incorporated, Mr. Danford served as a recruiter and as an employee relations representative in the human resources department for Compaq Computer from 1990 to 1991. Mr. Danford holds a B.S. degree in Computer Science from the University of Louisiana at Monroe (formerly Northeast Louisiana University).

Evelyn M. Angelle.    Ms. Angelle was appointed as a director of the Company in February 2011. Since January 2011, Ms. Angelle has served as Senior Vice President and Chief Accounting Officer for Halliburton. From January 2008 until January 2011, Ms. Angelle was Vice President, Corporate Controller and Principal Accounting Officer for Halliburton, responsible for financial reporting, planning, budgeting, financial analysis and accounting services. From December 2007 until January 2008, Ms. Angelle was Vice President of Operations Finance for Halliburton, leading Finance employees located around the world. From April 2005 until November 2007, she has also served as Vice President of Investor Relations for Halliburton, for which she oversaw Halliburton communications and relationships with investors and analysts. Prior to that, she was responsible for internal and external reporting of consolidated financial statements, technical accounting research and consultation, and income tax accounting. Before joining Halliburton, Ms. Angelle worked for 15 years in the audit department of Ernst & Young LLP, where she specialized in serving large, multinational public companies and provided technical accounting and consultation to clients and other professionals. She is a certified public accountant in Texas and a certified management accountant. She currently serves on the executive committee of Junior Achievement of Southeast Texas and on the board of directors for Junior Achievement USA. As a result of her professional experience, Ms. Angelle possesses particular knowledge in accounting, internal controls and public company disclosure compliance. In addition, she brings added judgment about investor relations and the financial management of a large organization.

 

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David C. Baldwin.    Mr. Baldwin was appointed as a director of the Company in May 2005. Mr. Baldwin is currently a Managing Director of LESA, the ultimate general partner of SCF and a private equity firm, and has held various positions since joining LESA in 1991. Prior to joining LESA, Mr. Baldwin was a drilling and production engineer with Union Pacific Resources, an independent natural gas and oil exploration and production company. Mr. Baldwin serves as a director of Rockwater Energy Solutions, Inc., a private energy services company and served as a director of Complete Production Services, Inc., a provider of specialized oil and gas completion and production services, from September 2002 through September 2007. Mr. Baldwin’s extensive experience in identifying strategic growth trends in the energy industry and evaluating potential transactions makes him well qualified to serve on our board. Further, his service as Managing Director of the general partner of our largest stockholder provides a valuable perspective into its insights and interests.

John A. Carrig.    Mr. Carrig was appointed as a director of the Company in July 2011. He retired from ConocoPhillips on March 1, 2011, having most recently served as President and Chief Operating Officer since 2008, where he was responsible for global Exploration and Production, Refining and Marketing, Commercial, Project Development and Procurement and the Health, Safety and Environment functions. Mr. Carrig served as Executive Vice President, Finance, and Chief Financial Officer from 2002 to 2008. Prior to the merger with Conoco Inc. in 2002, Mr. Carrig was with Phillips Petroleum Company, where he was named Senior Vice President and Chief Financial Officer in 2001. In 2000, he joined Phillips’ management committee as Senior Vice President and Treasurer. From 1996 to 2000, he was Vice President and Treasurer. Mr. Carrig served as Treasurer in 1995, and Assistant Treasurer in 1994. He joined Phillips in 1978 as a tax attorney. He has been a private investor and engaged in charitable endeavors since his retirement from ConocoPhillips. The board selected Mr. Carrig due to the length and breadth of his experience in the oil and gas industry, the perspective he brings as a result of his long service as an executive of a major public company with global reach and his strategic, financial and management acumen. In addition, Mr. Carrig brings valuable insight as a result of his long history as a customer for oilfield equipment and services.

Michael McShane.    Mr. McShane was appointed as a director of the Company in September 2010. Mr. McShane also currently serves as an Operating Partner to Advent International, an international private equity fund. Mr. McShane is a director of Spectra Energy Corp., a provider of natural gas infrastructure, since April 2008, Complete Production Services, Inc., a provider of specialized oil and gas completion and production services, Oasis Petroleum Inc., an exploration and production company, and Globalogix, a privately held company that provides comprehensive services to upstream oil and gas producers and operators, since June 2007. Previously, Mr. McShane served as a director and President and Chief Executive Officer of Grant Prideco, Inc., a manufacturer and supplier of oilfield drill pipe and other drill stem products, from June 2002 until April 2008, having also served as Chairman of the Board from May 2003 through April 2008. Prior to joining Grant Prideco, Mr. McShane was Senior Vice President—Finance and Chief Financial Officer and director of BJ Services Company, a provider of pressure pumping, cementing, stimulation and coiled tubing services for oil and gas operators, from 1990 to June 2002 and Vice President—Finance from 1987 to 1990 while BJ Services Company was a division of Baker Hughes Incorporated. Mr. McShane joined BJ Services Company in 1987 from Reed Tool Company, where he was employed for seven years in various financial management positions. The board selected Mr. McShane because of his expansive knowledge of the oil and gas industry, as well as relationships with chief executives and other senior management at oil and natural gas companies and oilfield service companies throughout the world. He brings to the board his experiences as a senior leader and chief financial

 

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officer within the oilfield service industry, as well as his leadership as chairman and chief executive officer of a leading North American drill bit technology and drill pipe manufacturer. Mr. McShane also provides the board with a producer perspective that is valuable in strategic discussions.

Franklin Myers.    Mr. Myers was appointed as a director of the Company in September 2010. Mr. Myers served as Senior Advisor to Cameron International Corporation, a publicly traded provider of flow equipment products, from April 2008 through March 2009, prior to which, from 2003 through March 2008, he served as the Senior Vice President and Chief Financial Officer. From 1995 to 2003, he served at various times as Senior Vice President and President of a division within Cooper Cameron Corporation as well as General Counsel and Secretary. Prior to joining Cooper Cameron Corporation in 1995, Mr. Myers served as Senior Vice President and General Counsel of Baker Hughes Incorporated, and as attorney and partner at the law firm of Fulbright & Jaworski. Mr. Myers serves on the Board of Directors of ION Geophysical Corporation, a technology-focused seismic solutions company, Comfort Systems USA, Inc., a national heating, ventilation and cooling company, Frontier Oil Corporation, a regional refining and marketing company, and Seahawk Drilling, Inc., a drilling services provider in the Gulf of Mexico. Mr. Myers also serves as an operating advisor for Paine Partners, a private equity fund. Mr. Myers’ extensive experience as both a financial and legal executive makes him uniquely qualified as a valuable member of our board. Mr. Myers has been responsible for numerous successful finance and acquisition transactions throughout his career, and his expertise gained through those experiences has proven to be a significant resource for our board. In addition, Mr. Myers’ service on Boards of Directors of other NYSE-listed companies enables Mr. Myers to observe and advise on favorable governance practices pursued by other public companies.

John Schmitz.    Mr. Schmitz was appointed as a director of the Company in September 2010. Mr. Schmitz currently serves as the Chairman and Chief Executive Officer of Select Energy Services, LLC, an oil and gas service company, a position he has held since January 2007. In addition, Mr. Schmitz has served as the President of HEP Oil Company from March 1992 to the present. Prior to his current involvement at Select Energy Services, LLC and HEP Oil Company, Mr. Schmitz served as the North Texas Division Manager for Complete Production Services, a provider of specialized services and products focused on helping oil and gas companies develop hydrocarbon reserves, reduce costs and enhance production. Mr. Schmitz has keen insight into emerging trends in North American shale plays and the types of equipment needed to service producers’ requirements. He also has knowledge of other manufacturers’ capabilities and their reputations for quality and deliverability, providing an interesting perspective on our evaluation of potential acquisitions.

Andrew L. Waite.    Mr. Waite was appointed as a director in August 2010. Mr. Waite is a Managing Director of LESA, the ultimate general partner of SCF, and has been an officer of that company since October 1995. He was previously Vice President of Simmons & Company International, where he served from August 1993 to September 1995. From 1984 to 1991, Mr. Waite held a number of engineering and project management positions with the Royal Dutch/Shell Group, an integrated energy company. Mr. Waite served on the Board of Directors of Complete Production Services, Inc., a provider of specialized oil and gas completion and production services, from 2005 to 2009, Hornbeck Offshore Services, Inc., a provider of marine services to exploration and production oilfield service, offshore construction and military customers, from 2000 to 2006 and Oil States International, Inc., a manufacturer of deepwater production products and subsea pipeline, from 1995 to 2006. Mr. Waite’s extensive experience in identifying strategic growth trends in the energy industry and evaluating potential transactions

 

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makes him well qualified to serve on our board. Further, his service as Managing Director of the general partner of our largest stockholder provides a valuable perspective into its insights and interests.

Board of directors

The number of members of our board of directors is determined from time to time by resolution of the board of directors. Our board of directors currently consists of eight members, including our Chief Executive Officer, who serves as the Chairman of the board of directors, and two members designated by SCF, Mr. Baldwin and Mr. Waite.

Our board of directors reviewed the independence of our directors using the independence standards of the NYSE and, based on this review, determined that Ms. Angelle and Messrs. Carrig, McShane, Myers and Schmitz are independent within the meaning of the NYSE listing standards currently in effect.

Because SCF will own a majority of our outstanding common stock following the completion of this offering, we will be a “controlled company” as that term is set forth in Section 303A of the NYSE Listed Company Manual. Under the NYSE rules, a “controlled company” may elect not to comply with certain NYSE corporate governance requirements, including: (1) the requirement that a majority of our board of directors consist of independent directors, (2) the requirement that our nominating and governance committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities, and (3) the requirement that our compensation committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities. While these requirements will not apply to us as long as we remain a “controlled company,” we expect that our board of directors will continue to consist of a majority of independent directors and that, shortly after the completion of this offering, our Nominating, Governance and Compensation Committee will consist entirely of independent directors. We also expect that it will have a written charter addressing such committee’s purpose and responsibilities.

In evaluating director candidates, we will assess whether a candidate possesses the integrity, judgment, knowledge, experience, skills and expertise that are likely to enhance the board’s ability to manage and direct the affairs and business of the Company, including, when applicable, to enhance the ability of committees of the board to fulfill their duties and the quality of the board’s deliberations and decisions. In evaluating directors, we consider diversity in its broadest sense, including persons diverse in perspectives, personal and professional experiences, geography, gender, race and ethnicity. This process has resulted in a board that is comprised of highly qualified directors that reflect diversity as we define it.

Committees of the board of directors

Our board of directors has established an audit committee and a nominating, governance and compensation committee, and may have such other committees as the board of directors shall determine from time to time. Each of the standing committees of the board of directors currently has the composition and responsibilities described below.

Audit committee

Our board established an audit committee in February 2011 that is currently comprised of three members, Ms. Angelle, Mr. Myers and Mr. Schmitz. Ms. Angelle serves as our committee

 

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chairwoman. SEC rules require that a public company disclose whether or not its audit committee has an “audit committee financial expert” as a member. An “audit committee financial expert” is defined as a person who, based on his or her experience, possesses the attributes outlined in such rules. Our board of directors determined that Ms. Angelle satisfies the definition of “audit committee financial expert.”

Our Audit Committee performs substantially similar functions to the audit committee of a public company. For instance, the Audit Committee oversees, reviews, acts on and reports on various auditing and accounting matters to our board of directors, including: the selection of our independent accountants, the scope of our annual audits, fees to be paid to the independent accountants, the performance of our independent accountants and our accounting practices. In addition, the Audit Committee oversees our compliance programs relating to legal and regulatory requirements. Prior to the completion of this offering, we expect to adopt an audit committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NYSE or market standards.

Nominating, governance and compensation committee

Our board of directors established a Nominating, Governance and Compensation Committee in February 2011. It is comprised of four members, Messrs. Baldwin, Carrig, McShane and Waite. Mr. Baldwin serves as our committee chairman. Our Nominating, Governance and Compensation Committee performs substantially similar functions to the compensation committee and nominating and governance committee of a public company.

Shortly after the completion of this offering, we anticipate that the Nominating, Governance and Compensation Committee will consist entirely of “independent” directors under the applicable rules of the NYSE and the SEC. The Nominating, Governance and Compensation Committee will establish salaries, incentives and other forms of compensation for officers and other employees, and it will administer our incentive compensation and benefit plans. The Nominating, Governance and Compensation Committee will also identify, evaluate and recommend qualified nominees to serve on our board of directors, develop and oversee our internal corporate governance processes and maintain a management succession plan. We expect to adopt a charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NYSE or market standards.

Compensation committee interlocks and insider participation

None of our officers or employees will be members of the Nominating, Governance and Compensation Committee. None of our executive officers serve on the board of directors or compensation committee of a company that has an executive officer that serves on our board or Nominating, Governance and Compensation Committee. No member of our board is an executive officer of a company in which one of our executive officers serves as a member of the board of directors or compensation committee of that company.

Executive sessions of our board of directors

Our independent directors are provided the opportunity to meet in executive session at each regularly scheduled meeting of our board. The director presiding over such meetings rotates among the directors eligible to participate in such executive sessions.

 

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Risk oversight

The board is actively involved in oversight of risks that could affect us. This oversight function is conducted primarily through committees of our board, but the full board retains responsibility for general oversight of risks. The Audit Committee is charged with oversight of our system of internal controls and risks relating to financial reporting, legal, regulatory and accounting compliance. Our board will continue to satisfy its oversight responsibility through full reports from the Audit Committee chair regarding the committee’s considerations and actions, as well as through regular reports directly from officers responsible for oversight of particular risks within our Company. In addition, we have internal audit systems in place to review adherence to policies and procedures, which are supported by a separate internal audit department.

Code of ethics for chief executive officer, chief financial officer, controller and certain other officers

Prior to the closing of this offering, our board will adopt a Code of Ethics for our Chief Executive Officer, our Chief Financial Officer and all other financial and accounting officers. Following the adoption of our Code of Ethics, any change to, or waiver from, the Code of Ethics will be will be promptly disclosed as required by applicable U.S. federal securities laws and the corporate governance rules of the NYSE.

Code of conduct

In February 2011, our board adopted a Code of Conduct, which sets forth the standards of behavior expected of each of our employees, officers, directors and agents. The Code of Conduct describe the responsibility of our employees, officers, directors and agents to:

 

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Protect our assets and customer assets;

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Foster a safe and healthy work environment;

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Deal fairly with customers and other third parties;

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Conduct international business properly;

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Report misconduct; and

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Protect employees from retaliation.

Employees, officers and directors are required to certify annually that they have read, understand and will comply with this Code of Conduct.

Corporate governance guidelines

Prior to the closing of this offering, our board of directors will adopt corporate governance guidelines in accordance with the corporate governance rules of the NYSE.

 

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Executive compensation and other information

Compensation discussion and analysis

This compensation discussion and analysis, or CD&A, provides information about our compensation objectives and policies for the executives who served as our principal executive officer (including Mr. Jones, who served in that capacity for FOT prior to the Combination), our principal financial officer and our other three most highly-compensated executive officers during fiscal year 2010, and is intended to place in perspective the information contained in the executive compensation tables that follow this discussion. This CD&A provides a general description of our compensation program and specific information about its various components.

Throughout this discussion, the following individuals are referred to as the “Named Executive Officers” or “NEOs” and are included in the Summary Compensation Table:

 

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C. Christopher Gaut—President, Chief Executive Officer and Chairman of the Board

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James W. Harris—Senior Vice President and Chief Financial Officer

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Charles E. Jones—Executive Vice President; President, Drilling and Subsea

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Wendell R. Brooks—Executive Vice President; President, Production and Infrastructure

•

James L. McCulloch—Senior Vice President, General Counsel and Secretary

•

Steven W. Twellman—President and Chief Executive Officer, Global Flow Technologies, Inc.

In each case the NEO is an officer of Forum Energy Technologies, Inc., except for Mr. Twellman.

Although this CD&A focuses on the information in the following tables and related footnotes, as well as the supplemental narratives relating to the last completed fiscal year, we also describe compensation actions taken before or after the last completed fiscal year to the extent such discussion enhances the understanding of our executive compensation disclosure. Contemporaneous with this offering, we will make adjustments to our compensatory practices to be utilized in 2011 and later years that we believe will be more appropriate for a company with public stockholders. This CD&A discusses the compensatory practices in place during 2010 and highlights changes we will implement upon the consummation of this offering.

Historical note: the Combination

With the exception of Messrs. Gaut and McCulloch, each of our NEOs was, prior to the Combination, an executive of a company that participated in the Combination. Messrs. Jones and Harris were, respectively, President, and Senior Vice President and Chief Financial Officer, of FOT; Mr. Brooks was President of Allied; and Mr. Twellman was President of Global Flow. Mr. Gaut was a director of FOT. Each of those executives was granted an employment agreement with us as of August 2, 2010. Mr. McCulloch was granted an employment agreement with us as of October 25, 2010, the date of his employment. Each NEO who was an executive of a company that participated in the Combination maintained his prior base compensation notwithstanding any change in title or duties. The base compensation for Messrs. Gaut and McCulloch was determined by our board of directors in a manner consistent with the compensation philosophy described in this prospectus.

Accomplishments of our executive team in 2010

Our executive team spent months of effort, under Mr. Gaut’s leadership, planning and executing the Combination that culminated in August 2010. Considerable effort was also spent in negotiating and arranging the recapitalization of the combined Company, including a $450 million credit

 

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agreement to finance the growth of the new organization. The executive team then created an overarching strategy for the organization, with a view of creating a leading global oilfield equipment company. The team also planned and executed the integration of the pre-Combination companies throughout the balance of the year, while at the same time maintaining focus on delivering quality products and services to their customers in a timely and cost effective manner.

Executives’ personal net worth at risk

Following the Combination, each NEO was given the opportunity to invest a portion of his personal net worth in shares of our common stock, in contrast to the practice at most companies of simply granting equity awards as compensation. As a group, our NEOs invested over $6.8 million of their personal assets in shares of our common stock, providing a direct stake in our future prospects. We believe that these personal investments align the interest of our NEOs with those of our stockholders in a meaningful way, and provide a true risk/reward balance.

Elements of our executive compensation program

Our compensation and benefits programs have historically consisted of the following components, which are described in greater detail below:

 

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Base salary;

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Annual cash bonus awards;

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Long-term equity-based incentives; and

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401(k) and health benefits.

Key components of our compensation philosophy

Our overall compensation philosophy is to provide competitive pay to our executives that rewards strong corporate performance. Our philosophy with respect to cash compensation is that target total cash should be at or near the market median. Base salaries will typically be set slightly below the market median while our annual incentive award targets are designed to be slightly above the market median. The result of this design is the opportunity for our executives to earn cash compensation at or near the market median in a year where our performance has met our target goals. We believe that this philosophy provides a strong link for our executives to short term corporate goals and we expect to continue to design our cash compensation elements post-offering in a similar fashion.

While we have not established strict guidelines for our grants of equity awards following the consummation of this offering, it is and will be our philosophy that long-term compensation should account for a significant portion of total direct compensation. For this reason we expect to make annual grants of equity-based awards to the executives, while placing long-term restrictions on the awards. Our objective is to be a high growth, high performing oilfield services company and we want to link a significant portion of our executives’ compensation to the long-term interests of our stockholders. To implement this strong link to our executives’ total compensation potential, we anticipate that the capital accumulation opportunities resulting from our long-term grants will be at or above the market median and will represent a significant portion of total compensation to each NEO.

 

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Overall, our compensation program will be designed to pay our executives near the market median in a target performance year and reward them with higher than median total compensation in years of superior performance relative to our internal performance metrics and our direct competitors. This compensation philosophy will allow us to attract and retain executives who will be committed to our strategic corporate plan.

Role of the compensation committee in setting compensation

Our board of directors established a Nominating, Governance and Compensation Committee in February 2011, which performs substantially similar functions to the compensation committee and nominating and corporate governance committee of a public company. The Nominating, Governance and Compensation Committee is responsible for designing, implementing, and administering our executive compensation programs and, in doing so, the Nominating, Governance and Compensation Committee is guided by the compensation philosophy stated above. References to “the Committee” within this CD&A refer to the Nominating, Governance and Compensation Committee.

On an annual basis the Committee will review and approve total compensation and the process will include:

 

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Selecting and engaging an external, independent consultant;

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Reviewing and selecting companies to be included in our peer group;

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Reviewing market data on all major elements of executive compensation; and

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Reviewing performance results against operating plans and incentive plan targets.

A complete listing of our Committee’s responsibilities will be included in the committee charter available for view on our corporate website.

Role of management in setting compensation

Our Chief Executive Officer (“CEO”) will be involved in recommending the compensation of our executive officers, excluding his own compensation which will be discussed and determined in executive sessions of the Committee. Each year the CEO will make recommendations to the Committee regarding such components as salary adjustments, target annual incentive opportunities, and the value of long-term incentive awards. In making his recommendations, the CEO will consider such components as experience level, individual performance, overall contribution to company performance, and market data for similar positions. The Committee will take the CEO’s recommendations under advisement, but the Committee will make all final decisions regarding executive officer compensation.

Our CEO will attend Committee meetings as necessary. He will excuse himself from any meeting when the Committee deems it advisable to meet in executive session or when the Committee meets to discuss and make determinations which directly impact the CEO’s compensation. The Committee may also consult other employees, including the remaining NEOs, when making compensation decisions, but the Committee will be under no obligation to involve the NEOs in its decision making process.

Role of the compensation consultant in setting compensation

The Committee has engaged the services of Pearl Meyer & Partners (“PM&P”) as its independent executive compensation consultant. PM&P’s current role is to advise the Committee on matters

 

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relating to executive compensation to help guide, develop, and implement our executive compensation programs. PM&P does not report directly to management and any requests management may have of PM&P throughout the course of its engagement will be approved by the Committee before any work is undertaken. PM&P may perform work for the Company outside of the scope of its engagement by the Committee, such as compensation surveys, but the Committee will review and approve all such assignments in order to ensure that the independence of its compensation consultant is not compromised.

Comparator compensation peer group

We have developed a comparator peer group which is composed of specific peer companies within the energy industry. Our peer group was developed with the assistance of PM&P and used to analyze our NEO compensation in May and August 2011. This peer group will be used to determine direct market levels of the main elements of executive compensation (base salary, annual incentives, long-term incentives, as well as total direct compensation). The peer group will also be used to gauge industry practices regarding the structure and mechanics of annual and long-term incentive plans, employment agreements, severance and change in control policies, and employee benefits. We did not use a peer group analysis in 2010 but intend to utilize and maintain a peer group going forward. The composition of the peer group will be reviewed by the Committee on an annual basis to ensure that we have and maintain an appropriate group of comparator companies.

Criteria for selecting peer companies for compensation benchmarking is based on a number of factors. The peer companies selected should reflect an optimum mix of the following criteria listed below in their relative order of importance:

Competitive market:

 

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Competing Talent—companies with executive talent similar to that valued by us;

•

Direct Competitors—in same or similar industry sector for products or services; and

•

Competing Industry—companies in the same general industry sector having similar talent pools.

Size and demographics:

 

•

Firms with competitive posture that are generally similar in revenue or market cap size;

•

Firms as described above which are significantly larger or smaller but whose data can be statistically normalized in the analysis;

•

Firms with a competitive posture and comparable area of operations;

•

Firms in the same or similar competitive posture that experience similar market cycles; and

•

Firms that serve the same sector of the industry.

Investor perspective:

Firms that analysts would track similarly or look at as similar investment opportunities.

 

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The initial comparator peer group approved by the Committee in 2011 includes the following 16 companies (table includes company name and ticker symbol):

 

BAS		Basic Energy Services, Inc.		LUFK		Lufkin Industries, Inc.
CAM		Cameron International Corporation		NR		Newpark Resources, Inc.
CPX		Complete Production Services, Inc.		OII		Oceaneering International, Inc.
DRC		Dresser-Rand Group Inc.		OIS		Oil States International, Inc.
DRQ		Dril-Quip, Inc.		RBN		Robbins & Myers, Inc.
EXH		Exterran Holdings, Inc.		TISI		Team, Inc.
FTI		FMC Technologies, Inc.		TESO		Tesco Corporation
KEG		Key Energy Services, Inc.		TTI		TETRA Technologies, Inc.

A different peer group may be utilized in the future to track performance. The performance peer group will be a more selective group of our direct competitors and may be utilized for tracking performance tied to long-term incentive awards.

Role of market data

PM&P uses compensation data gathered from the peer group as well as supplemental data from published market surveys to benchmark our executive compensation. The supplemental survey data will allow the Committee to consider compensation levels through the broader energy industry compared to the oilfield services focused data of the peer group. Survey data also provides market norms for executive positions which may not be reported as named executive officers in the peer group data. The Committee will periodically commission PM&P to conduct a market-based compensation study. The first such study was completed in May 2011. Additional details on the findings of the PM&P 2011 study are included below under “—Findings of recent compensation study.”

Elements of compensation for our named executive officers

Base salary.    Base salary is the fixed annual compensation we pay to each Named Executive Officer for performing specific job responsibilities, experience and requisite skills. It represents the minimum income a Named Executive Officer may receive in any year. Base salaries are determined for each Named Executive Officer based on the executive’s position and responsibility. We review the base salaries for each Named Executive Officer annually as well as at the time of any promotion or significant change in job responsibilities, and in connection with each review we consider individual and company performance over the course of that year. The employment agreements we maintain with the Named Executive Officers (described in greater detail below) provide that base salaries will generally not be reduced during the annual review unless the decrease is in connection with a similar reduction applicable to all of our executive officers, and if so, the decrease could be a reduction of up to 10% of the executive’s base salary.

 

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The table below sets out the annual base salaries of our NEOs in 2010 and 2011. In August 2011 the Committee reviewed the executive compensation report provided by PM&P and found our base salaries, except for those of Mr. Harris and Mr. McCulloch, to be within the middle range of the market. Effective August 29, 2011 the salaries of both Mr. Harris and Mr. McCulloch were increased by $25,000 per year, bringing them into the middle range of the market. Base salaries will be reviewed on an annual basis and we will consider adjustments again in the first quarter of 2012.

 

		2010 Annual base salary				2011 Annual base salary				Percentage increase
C. Christopher Gaut		$	625,000			$	625,000				0%
James W. Harris		$	300,000			$	325,000				8.3%
Charles E. Jones		$	475,000			$	475,000				0%
Wendell R. Brooks		$	375,000			$	375,000				0%
Steven W. Twellman		$	355,000			$	355,000				0%
James L. McCulloch		$	285,000			$	310,000				8.8%

Bonuses and annual incentive awards.    Our annual incentive awards for 2011 will be formulaic and performance based. Our payouts will be expressed as a percentage of an executive’s base salary as laid out in the table below. Each year the Committee will review bonus targets as well as target and actual total cash compensation paid to the named executive officers of our peer group to gauge the competitive level of our targets and ultimate payouts. Below we have highlighted our annual incentive plans effective in 2010 and 2011.

2010

The employment agreement we maintain with Mr. Gaut states that he was entitled to receive a cash bonus for 2010 at the discretion of our board of directors. The employment agreement we maintain with each of our other Named Executive Officers, except for Mr. McCulloch, provides that, for 2010, such Named Executive Officer would participate in the annual cash incentive bonus program in which he was participating as of the effective date of such employment agreement. Mr. McCulloch’s employment agreement did not provide for participation in the 2010 program due to his date of initial employment occurring late in the year.

 

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Our board of directors considered several factors in granting a cash bonus to Mr. Gaut for the 2010 year. The board of directors took into account Mr. Gaut’s central role in the long and complicated effort to combine the pre-Combination companies, his leadership in negotiating and arranging the recapitalization for the Combination and the financing for our future growth, his efforts in crafting a strategy to guide the new enterprise, and the successful conclusion of the first phases of integrating the pre-Combination companies and their management teams into one company. With respect to our other Named Executive Officers eligible for bonuses, each was a participant in the legacy annual incentive plan in place at his respective employer prior to the Combination. The payouts from these legacy plans were based on specific performance criteria which included at least one or a combination of the following: EBITDA, cash flow, and safety, but the cash bonus payments that were ultimately granted to these NEOs for 2010 were determined in the discretion of our board of directors. Each eligible NEO received a near target bonus in 2010.

 

Legacy Company		Measure		Weighting
FOT		EBITDA		70%
		Cash Flow		30%
Allied		EBITDA		60%
		Cash Flow		25%
		Safety		15%
Global Flow		EBITDA		60%
		Inventory		40%
Triton		EBITDA		100%
Subsea		EBITDA		70%
		Cash Flow		10%
		Individual Performance		20%

2011

Our 2011 Management Incentive Plan (the “MIP”), which was approved and adopted by our board of directors in February 2011, is designed to incentivize and reward key executives who have a significant impact on our achievement of overall corporate performance goals. The Committee approved NEO participants and their target bonus levels for the MIP and will continue to do so or future plans.

The following table sets out the current NEO target and maximum bonus levels for 2011 expressed as a percentage of annual base salary:

 

Executive		Target bonus (% of base)				Maximum bonus (% of base)
C. Christopher Gaut			125%			250%
James W. Harris			80%			160%
Charles E. Jones			100%			200%
Wendell R. Brooks			100%			200%
Steven W. Twellman			80%			160%
James L. McCulloch			80%			160%

 

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MIP payout curve

The MIP has a built in threshold such that zero bonus is paid if we achieve anything less than 75% of the established performance goals for the year. When actual performance is 125% or greater than the target performance level, referred to as “Over-Achievement,” the participant is eligible to receive an amount of up to two times (2X) the target award.

MIP performance metrics

Under the MIP, performance is measured in terms of operating income and earnings per share. For our Named Executive Officers, operating income accounts for two-thirds (66.67%) of an award while earnings per share accounts for the other one-third (33.33%). MIP performance targets are developed by management and recommended to the Committee which will make the final determination of performance targets. Our 2011 performance targets were originally set in accordance with our 2011 operating plan, but were later adjusted for the 2011 Acquisition, and will be subject to final adjustment when the assessment of consideration allocation is finalized. The targets will be similarly adjusted for any additional acquisitions completed during the calendar year. As mentioned in our compensation philosophy above, we have set our bonus payout targets at a level that is slightly above the market median. Our cash compensation policy provides that we pay slightly below median base salaries and utilize bonus targets slightly above median to allow our executives the opportunity to earn median or above total cash compensation, but only when our corporate performance is at target levels or above. We believe that our program motivates our NEOs to support our high growth objectives.

Long-term equity based incentives and adjustment of certain pre-combination equity awards

The pre-Combination companies historically granted equity awards to our NEOs (other than Messrs. Gaut and McCulloch, who were not employed by any such company prior to the Combination), and we expect to do so in the future through our Forum Energy Technologies, Inc. 2010 Stock Incentive Plan (the “2010 Plan”). We believe that long-term equity awards are the strongest link between executive pay and stockholder interests.

Prior to the Combination, Allied maintained the Allied Production Services, Inc. 2007 Long Term Incentive Plan, Global Flow maintained the Global Flow Technologies, Inc. 2005 Stock Incentive

 

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Plan, and Subsea maintained the Subsea Services International, Inc. 2007 Stock Incentive Plan (each, a “Pre-Combination Equity Plan”). Certain of our Named Executive Officers held equity-based awards under a Pre-Combination Equity Plan that were based on the underlying securities of their previous employing entities, whose common stock was exchanged for our common stock in connection with the Combination. In connection with the Combination, each stock option and restricted stock award outstanding under a Pre-Combination Equity Plan (including each stock option and restricted stock award held by certain of our Named Executive Officers) was converted into an award with respect to our common stock based on the exchange ratio utilized in the Combination for purposes of our acquisition of the corporate sponsor of such plan. Restricted stock awards outstanding under a Pre-Combination Equity Plan were converted into restricted shares of our common stock by multiplying the number of restricted shares still subject to the original award by the applicable exchange ratio. At the time of the Combination, both vested and unvested stock options outstanding under a Pre-Combination Equity Plan were converted into an option to acquire the number of shares of our common stock that resulted from multiplying the applicable exchange ratio by the number of shares still subject to the original award. The exercise price under each stock option was adjusted by dividing the exercise price of the original underlying stock option award by the same exchange ratio applicable to the adjustment utilized for determining the number of converted shares. The exchange ratios for our common stock used in connection with the Combination were as follows: (1) for Allied, 0.4623; (2) for Global Flow, 0.9886; and (3) for Subsea, 0.3168. The material terms of the restricted stock and stock option awards granted under a Pre-Combination Equity Plan that were converted in connection with the Combination, such as vesting or expiration schedules, remained unchanged following the Combination. In addition, at the effective time of the Combination, we assumed each Pre-Combination Equity Plan, with the result that all obligations under each such plan became our obligations.

On a going forward basis, we plan for long-term equity grants to be a significant portion of our NEO total compensation. We have most recently granted options to our NEOs in conjunction with the Combination, and in Mr. McCulloch’s case at the time of his initial employment with us, and we expect to continue to grant options in the future. Options are inherently performance based and we believe provide a strong link between our executives’ and stockholders’ long-term interests. We may grant restricted stock to balance the compensation risk associated with options and to provide value in equity which is tied to retention by placing a vesting requirement on the restricted stock grants. Another reason we may grant restricted stock is to conserve our share pool. Fewer full value shares are required to deliver a targeted equity value than would be required if the grant were made in options alone. We may also consider adding performance based awards to the mix of equity granted to our NEOs and may adopt a program for doing so in the future. We have not yet formally established a mix of equity vehicles (i.e., the percentages of each year’s grant made up of options, restricted stock and possibly performance based shares) but plan to do so in the future to provide a balanced approach which considers the motivation of our executives, the interests of our stockholders, as well as the practices common within our peer group.

We anticipate that our future grants of long-term incentives will occur annually. Future grant levels will be determined by the Committee. The Committee will consider input from management and will seek the guidance of its compensation consultant in an effort to make competitive grants to each NEO.

 

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For more information about our 2010 Plan, please see “—2010 Stock incentive plan” below.

Employee benefits

Our 401(k) Plan is designed to allow all employees, including the participating NEOs, to contribute on a pre-tax basis. Contributions to the 401(k) Plan are not taxable to employees until withdrawn from the 401(k) Plan. Each participant may elect to contribute up to 75% of his pre-tax compensation to the 401(k) Plan as pre-tax contributions (but limited by the statutory maximum of $16,500 for each of 2010 and 2011). Additionally, participants age 50 years and older may make a “catch-up contribution” to the 401(k) Plan each year up to an amount set by statute ($5,500 for each of 2010 and 2011). We currently match 100% of participant contributions up to 3% of compensation, and we match 50% of any additional contributions up to 5% of compensation, for a total potential matching contribution of 4% of compensation. Because of the statutory limits on amounts contributed to qualified plans, our NEOs generally do not receive the full potential matching contribution under the 401(k) Plan.

We also provide medical, dental and vision coverage to all our employees, as well as basic life and disability coverage.

Employment agreements

We believe that it is important to formally document the employment relationship that we have agreed to maintain with our Named Executive Officers in the form of employment agreements. We entered into employment agreements with each of the Named Executive Officers, except for Mr. McCulloch, effective August 2, 2010. We also entered into an employment agreement with Mr. McCulloch, effective October 25, 2010. These employment agreements are designed to provide an individual with an understanding of how the employment relationship may be extended or terminated, the compensation and benefits that we provide during the term of employment and the obligations each party has in the event of termination of the officer’s employment.

We believe that severance protections, particularly in the context of a change in control transaction, play a critical role in attracting and retaining key executive officers. Providing this type of protection is common in the oilfield services industry. In addition, these benefits serve our interests by promoting a continuity of management in the context of an actual or threatened change in control transaction.

The material terms of these agreements are set forth below under “Summary compensation table” and “Grants of plan-based awards for 2010.” The severance provisions within the employment agreements are set forth in detail in “Potential payments upon termination and change in control” below.

Change in control arrangements

The individual equity award agreements that govern the stock option and restricted stock awards under the 2010 Plan currently contain certain change in control protections for the NEOs, described in greater detail in the “Potential payments upon termination and change in control” section below. We provide such protections because we believe that the occurrence, or potential occurrence, of a change in control transaction will create uncertainty regarding the continued employment of our executive officers. By having certain change in control related benefits in place, we alleviate the uncertainty and put our executives in a position to make decisions in the best interest of our stockholders.

 

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Perquisites

We do not provide for any perquisites or any other personal benefits for our executive officers that are not available to other employees. Messrs. Brooks and Twellman received a car allowance for a portion of 2010, but this benefit was terminated in August 2010. We do not provide a car allowance to any Named Executive Officer.

Findings of recent compensation study

During 2011 PM&P conducted an independent review of all our executives’ compensation and presented the findings of the review to the Committee. Our peer group plus PM&P’s database were used to assess all three elements of pay: base, annual bonus and long-term compensation.

 

•

Regarding base pay, with the exception of base salaries in force from their pre-Combination company roles for two of the NEOs, the average base pay levels for the NEOs, including the CEO, was slightly above the 25th percentile of the market (actually 29th percentile for the NEOs – and 34th percentile for entire officer group other than Messrs. Jones and Twellman).

 

•

Bonus opportunity levels provided by our annual bonus plan were slightly above market median levels. This finding supports our philosophy that variable, at-risk pay presents our executives with the opportunity to earn market median or higher total cash in superior performance years. We have implemented formal performance measures for funding and payout of the MIP.

 

•

Long-term incentive awards were also analyzed by PM&P and were assessed as middle of the market relative to annual grants made by our peer group. The initial equity awards were at or below median when compared to a new company and management team.

Executive compensation mix

The charts below set out our current pay mix for our CEO and other NEOs collectively based on current base salary, target bonus, and the grant date value of 2010 equity grants.

2010 compensation decisions

Base salary

With the exception of Messrs. Gaut and McCulloch, each of the NEOs was employed prior to the Combination by a company that participated in the Combination. Each of those NEOs had his previous salary continue at the same level following the Combination, although in some cases the

 

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individual no longer held the same position in the combined company that he previously held in the pre-Combination company. In the case of Messrs. Gaut and McCulloch, their salaries were determined by our board of directors consistent with the compensation philosophy set forth herein.

Annual bonus payments for fiscal year 2010

As previously described, each of the NEOs, with the exception of Mr. McCulloch who was hired near the end of 2010, received a bonus for 2010. Mr. Gaut’s employment agreement stated that he was eligible to receive a discretionary cash bonus. Our board of directors exercised its discretion to award Mr. Gaut his bonus based upon the overall success we had following the Combination as well as exceeding our 2010 EBITDA targets. The remaining NEOs participated in the legacy plans of their respective employers prior to the Combination. Such bonuses were paid taking into account performance goals related to EBITDA, cash flow, safety and/or other factors, and were paid at the discretion of our board of directors.

2010 equity grants

Certain of our Named Executive Officers held equity-based awards that were granted under equity plans in effect prior to the Combination and, after the Combination, such awards continued to be outstanding and remained subject to the terms of the applicable plan and award agreement. Mr. Gaut’s employment agreement, which was entered into when he was hired as our CEO in August 2010, provided him with a new stock option grant under the 2010 Plan covering 61,557 shares of our common stock at an exercise price of $284.29 per share. This was awarded to him in connection with the closing of the Combination and was conditioned upon Mr. Gaut investing $3.5 million of his personal net worth in the Company. Our other NEOs also received grants in 2010 which (along with Mr. Gaut’s award described above) are summarized in the table below and detailed in the Grants of Plan Based Awards Table.

 

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The option and restricted stock grants shown below in 2010 were a combination of inducement and pre-offering grants intended to cover 2010 and 2011 and to recruit and retain individuals with the ability to drive our potential. These grants were also intended to quickly build and align our NEOs’ ownership stakes with that of our stockholders. To date, no additional grants have been made to our NEOs. We anticipate that additional grants will be made to our NEOs following completion of the offering.

 

		Share quantity				Option exercise price				Grant date
C. Christopher Gaut
Options			61,557			$	284.29				8/2/2010
James W. Harris
Options			6,000			$	284.29				8/2/2010
Options			569			$	284.29				11/29/2010
Restricted Stock			431								11/29/2010
Charles E. Jones
Options			9,500			$	284.29				8/2/2010
Restricted Stock			2,638								11/1/2010
Wendell R. Brooks
Options			7,000			$	284.29				8/2/2010
Steven W. Twellman
Options			2,000			$	284.29				8/2/2010
James L. McCulloch
Options			6,000			$	284.29				10/25/2010
Restricted Stock			1,760								10/25/2010

2010 Stock incentive plan

Objective

In connection with the Combination, we adopted an amendment and restatement of the Forum Oilfield Technologies, Inc. 2005 Stock Incentive Plan, as amended (prior to such amendment and restatement, the “Prior Plan”), which changed, among other things, the name of the plan to the Forum Energy Technologies, Inc. 2010 Stock Incentive Plan. The 2010 Plan provides us with the flexibility to make grants of options, restricted stock awards, performance awards, phantom stock awards, stock appreciation rights and bonus stock awards to our employees, consultants and directors serving on our board of directors.

Eligibility

Employees, consultants and members of our board of directors are eligible for awards under the 2010 Plan. The Committee will select the participants from time to time for the grants of awards.

Administration

The 2010 Plan will be administered by the Committee. The Committee will have the authority to select participants and to determine the terms and conditions of awards. The Committee will

 

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have the power to construe the 2010 Plan, adopt rules and regulations for administering the 2010 Plan and to make all other determinations necessary or advisable for administering the 2010 Plan. Any decisions of the Committee will be conclusive. The Committee will have the ability to delegate certain of its authority as provided under the 2010 Plan. Subject to the consent of the employee, consultant or director who has been granted an award, the Committee will be authorized to amend outstanding award agreements from time to time in any manner not inconsistent with the terms of the 2010 Plan.

Shares available for awards

Pursuant to the 2010 Plan, the aggregate maximum number of shares of our common stock that may be issued under the 2010 Plan, and the aggregate maximum number of shares of our common stock that may be issued under the 2010 Plan through incentive stock options, will not exceed 400,000 shares (inclusive of the shares subject to outstanding awards granted under and the shares that remained available under the Prior Plan). To the extent that an award terminates or is forfeited, any shares of our common stock subject to such award will again be available for the grant of an award under the 2010 Plan. In addition, shares surrendered in payment of the exercise price or purchase price of an award, and shares withheld for payment of applicable employment taxes and/or withholding obligations associated with an award will again be available for the grant of an award under the 2010 Plan. Any shares of our common stock delivered pursuant to an award may consist, in whole or in part, of authorized and unissued shares or (where permitted by applicable law) previously issued shares of our common stock that have been reacquired. Further, the following limitations apply with respect to awards granted under the Plan:

 

•

the maximum number of shares of our common stock that may be subject to awards denominated in shares of our common stock granted to any one individual during the term of the 2010 Plan may not exceed 50% of the aggregate maximum number of shares of our common stock that may be issued under the 2010 Plan; and

 

•

the maximum amount of compensation that may be paid under all performance awards denominated in cash (including the fair market value of any shares of our common stock paid in satisfaction of such performance awards) granted to any one individual during any calendar year may not exceed $20,000,000 and any payment due with respect to a performance award must be paid no later than 10 years after the date of the grant of the award.

The 2010 Plan provides that if we effect a subdivision or consolidation, or a payment of a stock dividend without receipt of consideration, on the shares of our common stock, the number of shares subject to the award, and the purchase price thereunder (if applicable) are proportionately adjusted. If we recapitalize, reclassify or otherwise change our capital structure, outstanding awards will be adjusted so that the award will thereafter cover the number and class of shares to which the holder would have been entitled if he had been the holder of record of the shares covered by such award immediately prior to the recapitalization, reclassification or other change in our capital structure. Further, the aggregate number of shares available under the 2010 Plan and the individual award limitations described above may also be appropriately adjusted by the Committee.

 

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Awards

At the discretion of the Committee, awards under the 2010 Plan may be made in the forms described below. Each award will be evidenced by an award agreement setting out the specific terms and conditions applicable to the award.

Options.    The 2010 Plan provides for two types of options: incentive stock options and non-statutory stock options. Incentive stock options may only be awarded to individuals who are employed by us or one of our subsidiaries at the time of grant. The Committee will determine the purchase price per share of our common stock subject to an option; however, the purchase price will not be less than the fair market value of a share of our common stock on the date of the grant of such option. The purchase price will be paid in the manner prescribed by the Committee. The Committee will also determine the term of each option (up to a maximum term of 10 years), the time at which an option may be exercised and the method by which payment of the purchase price may be made. Option awards may include the right to surrender the optioned shares in exchange for a payment in the amount of the fair market value of the shares for which the option is surrendered over the exercise price for such shares (a “stock appreciation right”). The term of each stock appreciation right may not exceed 10 years from the date of grant.

Restricted Stock Awards.    Pursuant to a restricted stock award, shares of our common stock will be issued or delivered to the participant, subject to certain restrictions on the disposition thereof and certain obligations to forfeit the shares to us as may be determined in the discretion of the Committee. The restrictions on disposition and the forfeiture restrictions for a restricted stock award may lapse upon the satisfaction of one or more of the performance criteria set forth in the 2010 Plan and determined by the Committee (which are listed below under “—Performance awards”), the holder’s continued employment or service to us over a specified period of time, the occurrence of any event or the satisfaction of any other condition specified by the Committee, or any combination of the foregoing factors.

The participant may not sell, transfer, pledge, exchange, hypothecate, or otherwise dispose of the shares until the expiration of the restriction period. However, upon the issuance of shares of our common stock pursuant to a restricted stock award, except as otherwise determined by the Committee, the holder will have all the rights of a holder of our common stock with respect to the shares, including the right to vote the shares and to receive all dividends and other distributions paid with respect to the shares.

Performance awards.    For performance awards granted under the 2010 Plan, the Committee will establish the maximum number of shares of common stock subject to, or the maximum value of, each performance award and the performance period over which the performance applicable to the award will be measured. The performance measures to which a performance award are subject will be determined by the Committee and will be based on one or more of the following performance measures: (a) the price of a share of our common stock, (b) our earnings per share, (c) our market share, (d) the market share of one of our business units designated by the Committee, (e) our sales, (f) the sales of one of our business units designated by the Committee, (g) our or any business unit’s operating income or operating income margin, as designated by the Committee, (h) our or any business unit’s net income or net income margin (before or after taxes), as designated by the Committee, (i) our or any business unit’s cash flow or return on investment, as designated by the Committee, (j) our or any business unit’s earnings or earnings margin before or after interest, taxes, depreciation, and/or amortization, as designated by the Committee, (k) the economic value added, (l) our return on capital, assets or stockholders’ equity, (m) our total stockholders’ return or (n) any combination of the foregoing.

 

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Payment of a performance award may be made in cash, shares of our common stock or a combination thereof, as determined by the Committee.

Phantom stock.    The Committee will be authorized to grant phantom stock awards under the 2010 Plan. These are awards of rights to receive (including restricted stock units which give a participant the right to receive) shares of our common stock (or the fair market value thereof), or rights to receive amounts equal to share appreciation over a specific period of time. These awards vest over a period of time to be established by the Committee, without satisfaction of any performance criteria or objectives. The Committee may, in its discretion, require payment or other conditions of the recipient of a phantom stock award. A phantom stock award may include a stock appreciation right that is granted independently of a stock option. Payment of a phantom stock award may be made in cash, shares of our common stock, or a combination thereof.

Bonus stock awards.    The Committee will also be authorized to grant bonus stock awards under the 2010 Plan. Bonus stock awards are unrestricted shares of our common stock that are subject to such terms and conditions as the Committee may determine and they need not be subject to performance criteria or objectives or to forfeiture.

Corporate change

The 2010 Plan provides that, upon a Corporate Change (as defined below), the Committee may accelerate the vesting and exercise date of options and stock appreciation rights, cancel options and stock appreciation rights and cause us to make payments in respect thereof in cash or adjust the outstanding options and stock appreciation rights as appropriate to reflect the Corporate Change. Upon the occurrence of a Corporate Change, the Committee may fully vest any restricted stock awards then outstanding and, upon such vesting, all restrictions applicable to the restricted stock will terminate. The 2010 Plan provides that a Corporate Change occurs if:

 

•

we are dissolved and liquidated;

 

•

we are not the surviving entity in any merger, consolidation or reorganization (or survive only as a subsidiary of an entity);

 

•

we sell, lease or exchange or agree to sell, lease or exchange all or substantially all of our assets;

 

•

any person, entity or group acquires or gains ownership or control of more than 50% of the outstanding shares of our voting stock; or

 

•

after a contested election of directors, the persons who were directors before such election cease to constitute a majority of our board of directors.

Transferability of awards

Generally, awards granted under the 2010 Plan may not be transferred other than (i) by will or the laws of descent and distribution, (ii) pursuant to a qualified domestic relations order as defined by the Code or Title I of the Employee Retirement Income Security Act of 1974, as amended or (iii) with the consent of the Committee. Each incentive stock option is not transferable other than by will or the laws of descent and distribution and is exercisable during the holder’s lifetime only by the holder or the holder’s guardian or legal representative.

 

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Amendment and termination of 2010 Plan

Our board of directors, in its discretion, may terminate the 2010 Plan at any time with respect to any shares of our common stock for which awards have not been granted. Our board of directors also has the right to alter or amend the 2010 Plan or any part thereof from time to time; provided that no change in the 2010 Plan may be made that would materially impair the rights of a participant without the consent of the participant. In addition, our board of directors may not, without approval of our stockholders, amend the 2010 Plan to increase the aggregate maximum number of shares our common stock that may be issued under the 2010 Plan, increase the aggregate maximum number of shares of our common stock that may be issued under the 2010 Plan through incentive stock options, change the class of individuals eligible to receive awards under the 2010 Plan or amend or delete the restrictions on the repricing of options.

Other policies and practices

Clawbacks

Payments made under our incentive plans, as well as any other payments and benefits which an NEO receives pursuant to a company plan or other arrangement, shall be subject to a clawback to the extent necessary to comply with the requirements of the Dodd-Frank Wall Street Reform and Consumer Protection Act or any other SEC guidelines. Our clawback policies will be reviewed annually.

Risk assessment

Our board of directors has reviewed our compensation policies as generally applicable to our employees and believes that our policies do not encourage excessive and unnecessary risk-taking, and that the level of risk that they do encourage is not reasonably likely to have a material adverse effect on us. In the future our Committee will perform this assessment and if a likelihood of a material risk exists, it will enlist additional resources for a full assessment.

Our compensation philosophy and culture support the use of base salary, certain performance-based compensation, and benefit plans that are generally uniform in design and operation throughout our organization and with all levels of employees. These compensation policies and practices are centrally designed and administered, and are substantially identical between our business segments. In addition, the following specific factors, in particular, reduce the likelihood of excessive risk-taking:

 

•

Our overall compensation levels are competitive with the market;

 

•

Our compensation mix is balanced among (i) fixed components like salary and benefits and (ii) annual incentives that reward our overall financial performance, business unit financial performance, operational measures and individual performance;

 

•

We intend to always have a strategic long-term plan;

 

•

Our annual corporate goals will be established with specific consideration given to behavioral risk;

 

•

We will implement appropriate performance measures each year, whether absolute or relative;

 

•

We have established maximum payouts to cap any performance incentives in place; and

 

•

We have clawback provisions built into the MIP.

 

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In summary, although a portion of the compensation provided to Named Executive Officers is based on our performance or individual successes of the employee, we believe our compensation programs do not encourage excessive and unnecessary risk-taking by executive officers (or other employees) because these programs are designed to encourage employees to remain focused on both our short- and long-term operational and financial goals. We set performance goals that we believe are reasonable in light of our past performance and market conditions.

Accounting and tax considerations

Under Section 162(m) of the Internal Revenue Code of 1986, as amended (the “Code”), a limitation was placed on tax deductions of any publicly-held corporation for individual compensation to certain executives of such corporation exceeding $1,000,000 in any taxable year, unless the compensation is performance-based. An exception applies to this deductibility limitation for a limited period of time in the case of companies that become publicly-traded.

When Section 162(m) of the Code applies to us, we reserve the right to use our judgment to authorize compensation payments that do not comply with the exemptions in Section 162(m) of the Code when we believe that such payments are appropriate and in the best interest of the stockholders, after taking into consideration changing business conditions or the executive’s individual performance and/or changes in specific job duties and responsibilities.

If an executive is entitled to nonqualified deferred compensation benefits that are subject to Section 409A of the Code, and such compensation does not comply with Section 409A of the Code, then the benefits are taxable in the first year they are not subject to a substantial risk of forfeiture and are subject to certain additional adverse tax consequences. We intend to design such arrangements to comply with (or be exempt from) Section 409A of the Code to the extent that the design is also appropriate for our business goals with respect to that arrangement.

All equity awards to our employees, including executive officers, and to our directors will be granted and reflected in our consolidated financial statements, based upon the applicable accounting guidance, at fair market value on the grant date in accordance with FASB Accounting Standards Codification, Topic 718, “Compensation—Stock compensation.”

 

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Summary compensation table

The following table shows information concerning the annual compensation for services provided to us by our Named Executive Officers during the 2010 fiscal year.

Summary compensation table for the year ended December 31, 2010

 

Name and Principal Position		Year				Salary(1)				Bonus(2)				Stock awards(3)				Option awards(3)				All other compensation(4)				Total
C. Christopher Gaut			2010			$	252,404			$	625,000			$	—			$	6,462,254			$	320,182			$	7,659,840
President, Chief Executive Officer and Chairman of the Board
James W. Harris			2010			$	276,178			$	234,203			$	122,529			$	689,614			$	71,559			$	1,394,083
Sr. Vice President and Chief Financial Officer
Charles E. Jones(5)			2010			$	475,000			$	671,345			$	749,957			$	997,310			$	10,917			$	2,904,529
Exec. Vice President; President—Drilling and Subsea
Wendell R. Brooks			2010			$	344,100			$	397,708			$	—			$	734,860			$	14,700			$	1,491,368
Exec. Vice President; President—Production & Infrastructure
Steven W. Twellman			2010			$	331,667			$	148,054			$	—			$	209,960			$	14,074			$	703,755
President and Chief Executive Officer, Global Flow Technologies, Inc.
James L. McCulloch			2010			$	49,327			$	—			$	500,350			$	618,180			$	—			$	1,167,857
Sr. Vice President, General Counsel and Secretary

 

(1)

Amounts in this column reflect base salary earned during the 2010 year.

 

(2)

Amounts in this column reflect discretionary bonus amounts paid in 2011 for services provided in 2010.

 

(3)

The amounts in the “Stock Awards” and “Option Awards” columns represent the grant-date fair value in 2010 as determined in accordance with the FASB Accounting Standards Topic 718. All equity awards were granted based on the fair market value of a share of our common stock being $284.29. See footnote 2 under “Grants of plan-based awards for 2010” for further information on Black-Scholes input details. For additional information, please read Note 11 to our audited consolidated financial statements included elsewhere in this prospectus.

 

(4)

The amounts in the “All Other Compensation” column represent values from benefits and perquisites and related compensation to the NEOs. Mr. Gaut’s $320,182 is comprised of 401(k) Company matching contributions of $8,432, cash fees paid for services rendered as a member of our board of directors prior to the commencement of Mr. Gaut’s employment as our CEO totaling $21,750, and $290,000 paid by LESA for consulting services provided in 2010 prior to the commencement of Mr. Gaut’s employment as our CEO. Mr. Harris’ $71,559 is comprised of 401(k) Company matching contributions of $9,822 and cash resulting from the option exchange totaling $61,737 (option exchange discussed in greater detail under “Long Term Equity Based Incentives and Adjustment of Certain Pre-Combination Equity Awards” above). Mr. Jones’ $10,917 is comprised of 401(k) Company matching contributions. Mr. Brooks’ $14,700 is comprised of 401(k) Company matching contributions of $9,800 and a company car allowance totaling $4,900. Mr. Twellman’s $14,074 is comprised of 401(k) Company matching contributions of $7,074 and a company car allowance totaling $7,000.

 

(5)

Mr. Jones was the President (and principal executive officer) of FOT prior to the Combination. He now serves as our Executive Vice President and President, Drilling and Subsea.

 

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Grants of plan-based awards for 2010

The following table is intended to provide a detailed disclosure of Plan-Based Awards. Plan-Based Awards include all equity awards made during the last completed fiscal year. The data in this table shows awards by grant date and does not show aggregate awards. Award descriptions in this table set out the relevant awards made during the 2010 fiscal year to each of the Named Executive Officers.

 

Name		Grant date				All other stock awards: number of shares of stock				All other option awards: number of securities underlying options				Exercise or base price of option awards ($/sh)				Grant date fair value of stock and option awards (1)(2)
C. Christopher Gaut			8/2/2010								61,557			$	284.29			$	6,462,254
James W. Harris			8/2/2010								6,000			$	284.29			$	629,880
			11/29/2010								569			$	284.29			$	59,734
			11/29/2010				431											$	122,529
Charles E. Jones			8/2/2010								9,500			$	284.29			$	997,310
			11/1/2010				2,638											$	749,957
Wendell R. Brooks			8/2/2010								7,000			$	284,29			$	734,860
Steven W. Twellman			8/2/2010								2,000			$	284.29			$	209,960
James L. McCulloch			10/25/2010								6,000			$	284.29			$	618,180
			10/25/2010				1,760											$	500,350

 

(1)

The amounts in the “Grant Date Fair Value of Stock and Option Awards” column represent the grant-date fair value in 2010 as determined in accordance with the FASB Accounting Standards Topic 718. All equity awards were granted based on the fair market value of a share of our common stock being $284.29. For additional information, please read Note 11 to our audited consolidated financial statements included elsewhere in this prospectus.

 

(2)

Black-Scholes Input Details:

 

Input		Input Values
Exercise Price		$	284.29
Expected Term			6.25 years
Volatility			33.73%
Dividend Yield			0.0%
Risk Free Interest Rate			2%
Black-Scholes Value		$	104.98

Employment agreements

In connection with the Combination, we entered into employment agreements with Messrs. Gaut, Harris, Jones, Brooks, and Twellman. We also entered into an employment agreement with Mr. McCulloch dated October 25, 2010.

The employment agreements we entered into with Messrs. Gaut, Harris, Jones, Brooks, Twellman, and McCulloch are each dated effective as of August 2, 2010, except as noted above with respect to Mr. McCulloch, and they contain substantially similar provisions with the exception of the

 

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determination of the amount of the severance benefit described below under “Quantification of payments.” The initial term of each employment agreement will terminate on the second anniversary of its effective date, provided that commencing on such second anniversary, the term will be automatically extended for successive one-year periods unless either party gives 60-days prior written notice of its intention to not renew the term of employment. The employment term can also be terminated at any time upon prior written notice by us or the executive. The annual base salary stated in each of the agreements is as follows: Mr. Gaut, $625,000; Mr. Harris, $300,000; Mr. Jones, $475,000; Mr. Brooks, $375,000; Mr. Twellman, $355,000; and Mr. McCulloch, $285,000. Each executive will be eligible to participate in, and may be awarded an annual bonus under, our annual cash incentive bonus program if certain performance targets are met for the performance period, which is expected to be each calendar year. Mr. Gaut’s employment agreement also contains an additional provision that provided him with a one-time stock option grant in connection with the consummation of the Combination covering 61,557 shares of our common stock, which will vest in four equal installments on each year anniversary of the grant date. Under each of the employment agreements, if the executive’s employment is terminated prior to the expiration of the term by the executive for good reason, by notice of non-renewal by us, or by our action for any reason other than the executive’s death or disability or for cause, subject to the executive’s execution and nonrevocation of a release within the period specified in the employment agreement, the executive will be entitled to receive certain severance payments and benefits from us. Please see the “Potential payments upon termination and change in control” section below for a more detailed description of the terms and payments provided under each of the employment agreements.

Outstanding equity awards at 2010 fiscal year end

The Named Executive Officers (other than Mr. McCulloch) held equity-based awards prior to the Combination. The pre-Combination equity awards that were issued to the Named Executive Officers by Allied, Global Flow and Subsea were adjusted and converted into awards that are now based on our common stock. Awards that were granted by FOT prior to the Combination were not adjusted in connection with the Combination. The awards disclosed below reflect awards that were granted to the Named Executive Officers at their previous employing entities as well as awards that we granted to the Named Executive Officers under the 2010 Plan (including under the terms of such plan as it existed prior to its amendment and restatement as described above under “2010 Stock incentive plan”). Expiration dates are also shown for each individual award. Additionally, no performance-based equity grants have been made to the Named Executive Officers.

For a detailed explanation of the exchange ratios utilized for the conversion of equity-based awards in connection with the Combination, please see “Elements of compensation for our named executive officers—Long-term equity based incentives and adjustment of certain pre-combination equity awards.”

 

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Outstanding equity awards as of December 31, 2010

 

Name		Number of securities underlying unexercised options exercisable				Number of securities underlying unexercised option unexercisable				Option exercise price				Option expiration date				Number of shares of stock that have not vested				Market value of shares of stock that have not vested ($)(1)
C. Christopher Gaut			500				—			$	200.00				12/06/11
			—				61,557	(2)		$	284.29				08/01/20
			—				—												99	(3)			33,660
			—				—												234	(4)			79,560
James W. Harris			450				—			$	200.00				12/06/11
			175				175	(5)		$	320.00				01/31/12
			213				638	(6)		$	225.00				06/30/14
			—				6,000	(2)		$	284.29				08/01/20
			—				569	(7)		$	284.29				11/29/20
																			431	(8)			146,540
Charles E. Jones			4,500				1,500	(9)		$	300.00				09/29/12
			575				1,725	(6)		$	225.00				06/30/14
			—				9,500	(2)		$	284.29				08/01/20
			—				—												1,250	(10)			425,000
			—				—												2,638	(11)			896,920
Wendell R. Brooks			2,600				867	(9)		$	216.31				09/30/17
			2,600				867	(12)		$	216.31				10/21/17
			231				231	(13)		$	216.31				11/20/18
			87				260	(14)		$	216.31				12/16/19
			—				7,000	(2)		$	284.29				08/01/20
Steven W. Twellman			2,718				—			$	101.16				12/21/12
			1,977				—			$	101.16				04/21/13
			741				—			$	161.85				04/30/14
			—				2,000	(2)		$	284.29				08/01/20
James L. McCulloch			—				6,000	(15)		$	284.29				10/25/20
																			1,760	(16)			598,400

 

(1)

Amounts in this column were calculated by assuming a market value of our common stock of $340.00 per share.

 

(2)

Options vest annually in equal installments over a four-year period on each of August 2, 2011, 2012, 2013 and 2014.

 

(3)

Restricted stock vests annually in equal installments over a two-year period on each of July 28, 2011 and 2012.

 

(4)

Restricted stock vests annually in equal installments over a three-year period on each of September 15, 2011, 2012 and 2013.

 

(5)

Options vest annually in equal installments over a two-year period on each of February 1, 2011 and 2012.

 

(6)

Options vest annually in equal installments over a three-year period on each of July 1, 2011, 2012 and 2013.

 

(7)

Options vest annually in equal installments over a four-year period on each of November 29, 2011, 2012, 2013 and 2014.

 

(8)

Restricted stock vests annually in equal installments over a four-year period on each of November 29, 2011, 2012, 2013 and 2014.

 

(9)

Options vest 100% on October 1, 2011.

 

(10)

Restricted stock vests 100% on October 1, 2012.

 

(11)

Restricted stock vests annually in equal installments over a four-year period on each of November 1, 2011, 2012, 2013 and 2014.

 

(12)

Options vest 100% on October 22, 2011.

 

(13)

Options vest annually in equal installments over a three-year period on each of November 21, 2011, 2012 and 2013.

 

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(14)

Options vest annually in equal installments over a three-year period on each of December 17, 2011, 2012 and 2013.

 

(15)

Options vest annually in equal installments over a four-year period on each of October 25, 2011, 2012, 2013 and 2014.

 

(16)

Restricted stock vests annually in equal installments over a four-year period on each of October 25, 2011, 2012, 2013 and 2014.

Options exercised and stock vested in the 2010 fiscal year

None of the NEOs exercised a stock option award during 2010. Values shown in the table below were calculated by multiplying the number of shares of restricted stock that vested by the market value of our common stock on the date of vesting.

Stock vested for the year ended December 31, 2010

 

		Stock Awards
		Number of shares acquired on vesting				Value realized on vesting
C. Christopher Gaut			78			$	22,175
James W. Harris			—			$	—
Charles E. Jones			1,250			$	355,363
Wendell R. Brooks			—			$	—
Steven W. Twellman			—			$	—
James L. McCulloch			—			$	—

Pension benefits

We maintain a 401(k) Plan for our employees, including our Named Executive Officers, but at this time our Named Executive Officers do not participate in a pension plan.

Non-qualified deferred compensation

We do not provide our Named Executive Officers with a deferred compensation plan at this time.

Potential payments upon termination and change in control

The employment agreements we maintain with our Named Executive Officers will provide the executives with severance benefits upon certain terminations of employment, and the individual award agreements that govern our stock option and restricted stock awards under the 2010 Plan contain accelerated vesting provisions that will apply upon our Change in Control (as defined below).

The employment agreements for each of our Named Executive Officers contain similar termination provisions. Under the employment agreements, if the executive’s employment is terminated prior to the expiration of the term by the executive for good reason (as defined below), by notice of non-renewal by us, or by our action for any reason other than his death or disability (as defined below) or for cause (as defined below), subject to the executive’s execution and nonrevocation of a release within the period specified in the employment agreement, the executive will be entitled to receive the following benefits: (1) a lump sum payment of an amount equal to the applicable “severance multiple” times the sum of his annual base salary at the time of the termination plus a specified percentage of his annual base salary (provided that Mr. Twellman’s payment will be made over a 24-month period rather than in a lump sum), (2) a

 

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lump sum payment of an amount equal to his unpaid bonus for the prior calendar year, if any, payable at the same time such bonus is paid to active executives, (3) a lump sum payment of an amount equal to his bonus for the calendar year in which his termination occurs, if any, as determined in good faith by our board of directors in accordance with the performance criteria established pursuant to the employment agreement, prorated through and including the date of termination, payable at the same time as such bonus is paid to active executives and (4) if he elects COBRA continuation coverage for himself and his eligible dependents, monthly reimbursement of the differential between the COBRA premium and the active executive contribution amount for such coverage under our group health plans for up to eighteen months.

The employment agreements provide that the “severance multiple” in clause (1) above is two for each of our Named Executive Officers unless the executive’s termination of employment occurs on or within two years after the occurrence of a Change in Control, in which case the “severance multiple” is three. The employment agreements for our Named Executive Officers (other than Mr. Jones) provide that in the event any payments to the executives constitute excess parachute payments within the meaning of Section 280G of the Code, payments under the employment agreement will be reduced to an amount that would no longer create an excess parachute payment or be paid in full, whichever produces the better net after-tax position for the executive. Consistent with Mr. Jones’s prior employment agreement with FOT, his employment agreement provides that any payments or benefits to which he may be entitled (whether under the employment agreement or otherwise) which would be subject to a parachute payment excise tax under Section 4999 of the Code will be grossed up so that he will receive an additional payment from us sufficient to cover such excise tax and all excise taxes imposed on such additional payment. If a Named Executive Officer’s employment is terminated for any reason other than those described above, the executive will continue to receive his compensation and benefits to be provided by us until the date of termination, and the compensation and benefits will terminate contemporaneously with the termination of his employment. Under the terms of the employment agreements, subject to certain exceptions, the executives may not compete in the market in which we and our respective affiliates engage during his employment and for two years following the termination of his employment.

The employment agreements define the term “Good Reason” as any of the following events: (1) a material decrease in annual base salary (other than as part of a decrease of up to 10% for all of our executive officers), (2) in the case of Mr. Gaut, the executive’s demotion from his current position with the Company, and in the case of Messrs. Harris, Jones, Brooks, Twellman, and McCulloch a material diminution in the executive’s authority, duties or responsibilities (other than certain changes in management structure primarily affecting reporting responsibility); or (3) an involuntary relocation of the geographic location of the executive’s principal place of employment by more than 75 miles. “Disability” is generally defined as an executive’s inability to perform the executive’s duties or fulfill his obligations under the employment agreement by reason of any physical or mental impairment for a continuous period of not less than three months. The employment agreements state that a termination for “Cause” will occur when an executive has (a) engaged in gross negligence or willful misconduct in the performance of his duties with respect to us, (b) materially breached any material provision of his employment agreement or any written corporate policy, (c) willfully engaged in conduct that is materially injurious to us, or (d) been convicted of, pleaded no contest to, or received adjudicated probation or deferred adjudication in connection with a felony involving fraud, dishonesty or moral turpitude.

 

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In terms of the severance benefits payable to our Named Executive Officers under the circumstances described above that are based on the “severance multiple,” the following table sets out the formula for determining the amount of such benefits for the Named Executive Officers’ under the agreements.

 

Executive		Current base salary (“B”)				Annual bonus target (“T”) as a percent of base				Severance amount for termination not within 2 years after a change in control				Severance amount for termination within 2 years after a change in control
C. Christopher Gaut		$	625,000				125%				2 times (B+T)				3 times (B+T)
Charles E. Jones		$	475,000				100%				2 times (B+T)				3 times (B+T)
Wendell R. Brooks		$	375,000				100%				2 times (B+T)				3 times (B+T)
James W. Harris		$	325,000				80%				2 times (B+T)				3 times (B+T)
Steven W. Twellman		$	355,000				80%				2 times (B+T)				3 times (B+T)
James L. McCulloch		$	310,000				80%				2 times (B+T)				3 times (B+T)

“Change in Control” is generally defined in the employment agreements to occur upon (1) the acquisition by an individual, entity or group (within the meaning of the Exchange Act) of the beneficial ownership of fifty percent or more of either (a) our then outstanding shares of common stock, or (b) the combined voting power of our then outstanding voting securities entitled to vote in our election of directors; (2) the date the individuals who, immediately following the time when our stock becomes publicly traded, constitute our board of directors (and certain approved individuals who become directors after such time) cease to constitute a majority of the board of directors; or (3) the consummation of a corporate transaction (merger, reorganization, consolidation, or a sale of all or substantially all of our assets) unless, following that transaction, all or substantially all of the individuals and entities that were the beneficial owners of our outstanding common stock and outstanding voting securities prior to the transaction still beneficially own more than fifty percent of those shares of common stock or voting power of the resulting entity following the transaction, and at least a majority of the members of the board of directors of the ultimate parent entity resulting from the transaction were members of our board of directors at the time of the execution of the agreement that led to the transaction. The employment agreements include a modified definition of the term “Change in Control” that applies before our stock becomes publicly traded.

The restricted stock and stock option award agreements under our 2010 Plan have accelerated vesting provisions in the event of our Change in Control (the 2010 Plan and award agreements contain substantially the same definition of a Change in Control as provided within the Named Executive Officer’s employment agreement). If a Change in Control occurs during the period of time that the award is still outstanding, any unvested portion of the award will immediately vest so long as the executive has been continuously employed with us from the date of grant until the Change in Control event.

Quantification of payments

The table below discloses the amount of compensation and/or benefits due to the Named Executive Officers in the event of their termination of employment and/or in the event we undergo a Change in Control. The amounts disclosed assume such termination and/or the occurrence of such Change in Control was effective December 31, 2010, and using the price of

 

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our common stock on that date of $340.00. The column titled “Termination without cause, for good reason, or due to non-extension by company not within a two year period following a change in control” utilizes the 2 times (B+T) formula above, while the column titled “Termination without cause, for good reason, or due to non-extension by company within a two year period following a change in control” utilizes the 3 times (B+T) formula. COBRA premiums reflected below are based upon the monthly premiums in effect for each of the Named Executive Officers on December 31, 2010 for a period of eighteen months. Mr. Jones’ Change in Control payment reflects our estimation of the payment that would be necessary to gross him up for the excise taxes he could be required to pay following a Change in Control. The amounts below constitute estimates of the amounts that would be paid out to the Named Executive Officers upon their respective terminations and/or upon a Change in Control under such arrangements, but final amounts can only be determined with certainty upon the actual event. The actual amounts to be paid out are dependent on various factors, which may or may not exist at the time a Named Executive Officer is actually terminated and/or a Change in Control actually occurs. Therefore, such amounts and disclosures should be considered “forward-looking statements.”

 

Named Executive Officer		Termination due to death or disability				Termination without cause, for good reason, or due to non-extension by company not within a two year period following a change in control				Termination without cause, for good reason, or due to non-extension by company within a two year period following a change in control				Change in control without termination
C. Christopher Gaut
Salary			NA			$	1,250,000			$	1,875,000			$	—
Bonus Amounts			NA			$	1,562,500			$	2,343,750			$	—
COBRA Premiums			NA			$	18,576			$	18,576			$	—
Change in Control Payments			NA				NA				NA			$	—
Accelerated Equity Vesting			NA			$	3,542,560			$	3,542,560			$	3,542,560
Total		$	—			$	6,373,636			$	7,779,886			$	3,542,560
James W. Harris
Salary			NA			$	650,000			$	975,000			$	—
Bonus Amounts			NA			$	520,000			$	780,000			$	—
COBRA Premiums			NA			$	22,608			$	22,608			$	—
Change in Control Payments			NA				NA				NA			$	—
Accelerated Equity Vesting			NA			$	589,254			$	589,254			$	589,254
Total		$	—			$	1,781,862			$	2,366,862			$	589,254
Charles E. Jones
Salary			NA			$	950,000			$	1,425,000			$	—
Bonus Amounts			NA			$	950,000			$	1,425,000			$	—
COBRA Premiums			NA			$	6,030			$	6,030			$	—
Change in Control Payments			NA				NA			$	1,131,921			$	—
Accelerated Equity Vesting			NA			$	2,109,540			$	2,109,540			$	2,109,540
Total		$	—			$	4,015,570			$	6,097,491			$	2,109,540

 

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Named Executive Officer		Termination due to death or disability				Termination without cause, for good reason, or due to non-extension by company not within a two year period following a change in control				Termination without cause, for good reason, or due to non-extension by company within a two year period following a change in control				Change in control without termination
Wendell R. Brooks
Salary			NA			$	750,000			$	1,125,000			$	—
Bonus Amounts			NA			$	750,000			$	1,125,000			$	—
COBRA Premiums			NA			$	17,172			$	17,172			$	—
Change in Control Payments			NA				NA				NA			$	—
Accelerated Equity Vesting			NA			$	665,057			$	665,057			$	665,057
Total		$	—			$	2,182,229			$	2,932,229			$	665,057
Steven W. Twellman
Salary			NA			$	710,000			$	1,065,000			$	—
Bonus Amounts			NA			$	568,000			$	852,000			$	—
COBRA Premiums			NA			$	17,172			$	17,172			$	—
Change in Control Payments			NA				NA				NA			$	—
Accelerated Equity Vesting			NA			$	111,420			$	111,420			$	111,420
Total		$	—			$	1,406,592			$	2,045,592			$	111,420
James L. McCulloch
Salary			NA			$	620,000			$	930,000			$	—
Bonus Amounts			NA			$	496,000			$	744,000			$	—
COBRA Premiums			NA			$	22,194			$	22,194			$	—
Change in Control Payments			NA				NA				NA			$	—
Accelerated Equity Vesting			NA			$	932,660			$	932,660			$	932,660
Total		$	—			$	2,070,854			$	2,628,854			$	932,660
Total			NA			$	17,830,743			$	23,850,914			$	7,950,491

Director compensation

Directors fees

All non-employee directors, with the exception of Mr. Baldwin and Mr. Waite, have received an annual retainer of $50,000. The Chairman of the Audit Committee has received an additional annual retainer of $15,000, and the other members of that committee have received an additional annual retainer of $5,000. We have not paid board of directors meeting fees or committee meeting fees to our directors.

Both Mr. Baldwin and Mr. Waite are Managing Directors of LESA, the ultimate general partner of SCF. It is LESA’s policy that its directors and others associated with it do not receive retainers for board service until the company on whose board they serve becomes publicly traded.

In August 2011 PMP benchmarked our director compensation using compensation data gathered from the same peer group used to analyze compensation for our executive officers, as well as

 

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supplemental data from published market surveys, in order to determine whether, and to what extent, it would be appropriate to increase director compensation following an initial public offering. Directors serving on public company boards are exposed to enhanced liability and assume duties and responsibilities over and above those required of private company directors.

As a result of the benchmarking survey, and with the assistance of PMP, it was determined that upon the completion of an initial public offering all non-employee directors, including Mr. Baldwin and Mr. Waite, will receive an annual retainer of $60,000. The Chairman of the Audit Committee will receive an additional annual retainer of $15,000, and the other members of that committee will receive additional annual retainers of $7,500. The Chairman of any other committee will receive an additional annual retainer of $10,000 and members of other committees will receive an additional annual retainer of $5,000.

Director equity-based compensation

We anticipate that each non-employee director will receive equity-based compensation. In 2010 we granted stock options to our non-employee directors, with the exception of Mr. Baldwin and Mr. Waite, in accordance with a formula determined by the Board of Directors. In 2011 we granted initial stock options to Ms. Angelle and Mr. Carrig upon their joining of the Board of Directors, and granted annual stock options in accordance with our formula to the non-employee members of the board (in Ms. Angelle’s case on a prorated basis in view of her appointment to the Board in February 2011), except for Mr. Baldwin, Mr. Waite and Mr. Carrig, the latter of whom had only recently been appointed to the Board of Directors. It has been determined to grant restricted shares or restricted share units to non-employee directors, including Mr. Baldwin and Mr. Waite, on an annual basis after our initial public offering.

Director Compensation for the year ended December 31, 2010

 

Name(1)		Fees earned or paid in cash(2)				Option awards(3)				Total
Michael McShane		$	25,000			$	36,738			$	61,738
Franklin Myers		$	25,000			$	36,738			$	61,738
John Schmitz		$	25,000			$	36,738			$	61,738

 

(1)

Messrs. Baldwin and Waite did not receive any compensation for their services as directors during 2010. The compensation Mr. Gaut received as a non-employee director of FOT prior to the Combination is disclosed above in the Summary Compensation Table.

 

(2)

The fees paid in cash in 2010 reflect two quarterly payments of our $50,000 annual retainer.

 

(3)

The amounts in the “Option Awards” column represent the grant-date fair value in 2010 as determined in accordance with the FASB Accounting Standards Topic 718. All option awards were granted based on the fair market value of a share of our common stock being $284.29. See footnote 2 under “Grants of plan-based awards for 2010” for further information on Black-Scholes input details. For additional information, please read Note 11 to our audited consolidated financial statements included elsewhere in this prospectus. As of December 31, 2010, the number of shares of our common stock subject to outstanding stock option awards held by each of the directors is as follows: Mr. McShane, 602; Mr. Myers, 352; and Mr. Schmitz, 352.

 

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Certain relationships and related party transactions

The descriptions set forth below are qualified in their entirety by reference to the applicable agreements.

The Combination

The Combination closed on August 2, 2010. Immediately prior to the Combination, SCF owned the following amounts of each of the five companies involved in the Combination (before giving effect to the application of the exchange ratios used with respect to the Combination to convert the shares of each company into shares of our common stock):

 

Company		No. of shares				Percentage ownership
FOT			465,226				64.4%
Global Flow			163,000				87.9%
Allied			130,000				46.2%
Triton			621,767				79.1%
Subsea			170,000				89.9%

Immediately following the completion of the transactions contemplated by the Combination and the related transactions, SCF would have been deemed to have beneficially owned a total of 1,518,792 shares of our common stock (calculated pursuant to Rule 13d-3 under the Securities Exchange Act of 1934). This beneficial ownership would have consisted of (1) 991,162 shares of common stock issued to SCF in connection with the Combination, (2) 175,876 shares of common stock issued to SCF in connection with its original subscription of approximately $50.0 million immediately following the Combination, (3) warrants to purchase 87,938 shares of our common stock issued to SCF in connection with its original $50.0 million subscription at the closing of the Combination, (4) 175,877 shares of common stock issuable to SCF had it exercised its subscription right for the remaining $50.0 million of committed capital in full immediately following the closing of the Combination, and (5) warrants to purchase 87,939 shares of our common stock issuable to SCF had it exercised its subscription right for the remaining $50.0 million of committed capital in full immediately following the closing of the Combination. For a discussion of the Combination, please see “Business—Business history,” and for a discussion of the subscription rights of, and related issuance of warrants to, SCF, please see “—Subscription and warrant agreements.”

Pursuant to the Combination Agreement that effected the Combination (the “Combination Agreement”), certificates representing 26,395 shares of our common stock in the aggregate that would otherwise have been issued to certain of our shareholders at the time of the Combination (the “Escrow Stockholders”) are currently held in escrow pending determination of our subsidiary’s future asbestos liability exposure as described in “Business—Legal proceedings—Asbestos litigation.” At any time prior to the Escrow Termination Date (as defined in the Combination Agreement and described below), we may elect to disburse all or any portion of the shares of our common stock held in escrow to the Escrow Stockholders. In addition, we may deliver at any time prior to the date that is 120 days prior to August 2, 2014, an irrevocable written notice, indicating our intent to engage a valuation firm to prepare a final valuation report, in which case the process of disbursing and/or retaining the shares of common stock held in escrow, as provided for in the Combination Agreement, will begin.

 

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On the Escrow Termination Date, we will disburse to each Escrow Stockholder such pro rata portion of the shares of common stock held in escrow on the Escrow Termination Date, minus an amount of escrow shares having an aggregate fair market value as of the time the escrow termination materials are delivered equal to such Escrow Stockholder’s pro rata portion of the Indemnification Amount (as defined in the Combination Agreement, and which generally relates to any increase in the overall anticipated future discounted costs our subsidiary expects to incur in defending the asbestos litigation following the Escrow Termination Date relative to the overall anticipated future discounted costs our subsidiary expected to incur in connection with such defense at the time of the Combination) (if any). Under the terms of the Combination Agreement, each Escrow Stockholder has the ability to elect to fund its pro rata portion of any Indemnification Amount in cash or using the shares of our common stock held in escrow. Thereafter, (i) the Escrow Stockholders will possess such disbursed shares of our common stock (if any), and will have no further obligation to us with respect thereto, and (ii) we will retain all of the remaining shares (if any), and will have no further obligation to any Escrow Stockholder with respect thereto. The Escrow Stockholders will owe no obligation to us for any Indemnification Amount in excess of the value of the shares of common stock held in escrow.

The Combination Agreement defines the Escrow Termination Date as the earlier of (i) the date the Indemnification Amount (as defined in the Combination Agreement) is determined to be zero in accordance with the terms of the Combination Agreement, (ii) the date of consummation of a transaction that results in a change of control or (iii) August 2, 2014 or, if a Dispute Notice (as defined in the Combination Agreement) is delivered, in lieu of such date, the date that the arbitrating accountant delivers its final written decisions regarding such dispute.

Transactions with our significant stockholder prior to the combination

FOT was a party to that certain Financial Advisory Agreement dated May 31, 2005 with LESA, as amended from time to time, pursuant to which we paid $62,500 per quarter for on-going advisory and consulting services in connection with our operations. In August 2010, this agreement was terminated by the parties and is no longer in effect.

We are a party to that certain Secondment Agreement dated August 2, 2010 with LESA and Mr. Connelly. Pursuant to the Secondment Agreement, LESA assigned Mr. Connelly to us for a period of two years to perform, among other things, strategic development services in return for a monthly cash payment by us to LESA in the amount of $25,000.

Allied was a party to that certain Financial Advisory Agreement dated August 20, 2007 with LESA, pursuant to which Allied paid LESA $31,250 per quarter for on-going advisory and consulting services in connection with Allied’s operations. In August 2010, this agreement was terminated by the parties and is no longer in effect.

Global Flow was a party to that certain Financial Advisory Agreement dated June 30, 2005 with LESA, pursuant to which Global Flow paid $62,500 per quarter for on-going advisory and consulting services in connection with Global Flow’s operations. This agreement has been terminated by the parties and is no longer in effect.

Triton was a party to that certain Financial Advisory Agreement dated February 2, 2007 between PSSI Holdings, Inc., a Delaware corporation, TGH (UK) Limited, incorporated in England, and LESA, pursuant to which Triton paid $62,500 per quarter for on-going advisory and consulting services in connection with Triton’s operations. This agreement has been terminated by the parties and is no longer in effect.

 

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Subsea was a party to that certain Financial Advisory Agreement dated January 8, 2007 with LESA, pursuant to which Subsea paid $37,500 per quarter for on-going advisory and consulting services in connection with Subsea’s operations. This agreement has been terminated by the parties and is no longer in effect.

Transactions with our directors, officers and key operations managers

Allied was a party to that certain Financial Advisory Agreement dated as of August 20, 2007 with B-29 Investments, LP, as amended from time to time, pursuant to which Allied paid B-29 Investments, LP $31,250 per quarter for on-going advisory and consulting services in connection with Allied’s operations. On December 31, 2009, B-29 Investments, LP assigned to Sunray Capital, all of its rights, interests, duties and obligations in, under and to the Financial Advisory Agreement. John Schmitz, one of our directors, and Steven Schmitz, John Schmitz’s brother, are principals of Sunray Capital. This agreement has been terminated by the parties and is no longer in effect.

Allied was a party to that certain Stock Option Agreement, dated August 20, 2007 with B-29 Investments, LP, as amended from time to time, pursuant to which Allied granted to B-29 Investments, LP the right and option to purchase, in one or more transactions, all or any part of an aggregate 30,000 shares of Allied Common Stock at a purchase price of $200 per share at any time prior to August 20, 2017. John Schmitz, one of our directors, and Steven Schmitz, John Schmitz’s brother serve as officers, directors and employees of B-29 Investments, LP. This agreement has been terminated by the parties and is no longer in effect.

Allied leases a manufacturing facility in Cooke County, Texas from B-29 Properties, LLC, an affiliate of B-29 Investments, LP, for approximately $50,560 in base rent per month in the aggregate.

Allied leases an undeveloped property in Cooke County, Texas from B-29 Properties, LLC, an affiliate of B-29 Investments, LP, for approximately $1,235 in base rent per month in the aggregate.

Allied leases a manufacturing facility in Logan County, Oklahoma from B-29 Properties, LLC, for approximately $12,500 per month.

Allied leases a manufacturing facility in Clearfield, Pennsylvania to Select Energy Services, LLC, for approximately $13,000 per month. Select Energy Services, LLC is an affiliate of B-29 Investments, LP.

 

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Subscription and warrant agreements

In connection with the Combination and pursuant to a Subscription Agreement dated August 20, 2010, we offered each of our stockholders who were accredited investors or non-U.S. persons (as such term is defined for purposes of the Securities Act of 1933) the opportunity to purchase shares of our common stock worth $115 million in the aggregate, up to their pro-rata ownership of the Company. In connection with this subscription offer, we issued to those stockholders who purchased shares of our common stock a warrant to purchase additional shares of our common stock on the basis of one warrant share for every two shares purchased in the subscription offer. The warrants were exercisable upon their issuance and will remain exercisable until the date that is the 30 month anniversary following the consummation of this offering. The initial exercise price of the warrants was $284.29 per share, and the exercise price increases by 0.5% of the then-current exercise price on the last day of each month following their original issuance. The following table identified each related person who participated in the subscription offer:

 

Related person		No. of shares purchased				Purchase price				No. of warrant shares
Michael McShane			47			$	13,361				23
Franklin Myers			171			$	48,613				85
Jonathan Fairbanks(1)			1,708			$	485,567				854
E. Gregory Hottle(2)			1,230			$	349,676				615
James W. Harris			1,158			$	329,207				579
Wendell R. Brooks			821			$	233,402				410
Michael Danford			100			$	28,429				50

 

(1)

Mr. Fairbanks was a director of FOT prior to the completion of the Combination.

 

(2)

Mr. Hottle was an executive officer of FOT prior to the completion of the Combination.

In connection with the Combination and pursuant to that certain Subscription Agreement dated July 16, 2010, each of SCF-VII, L.P., Sunray Capital and Messrs. Gaut and Connelly subscribed to purchase 175,876, 17,587, 12,311 and 1,055 shares of our common stock in exchange for a cash payment of $49,999,788.04, $4,999,808.23, $3,499,894.19 and $299,925.95, respectively.

In connection with the purchase of these shares of our common stock pursuant to the Subscription Agreement, each of SCF-VII, L.P., Sunray Capital and Messrs. Gaut and Connelly received a warrant to purchase 87,938, 8,794, 6,156 and 528 shares of our common stock, respectively. Each of these warrants entitle the holder to purchase shares of our common stock at a purchase price per share of $284.29, subject to a monthly increase of the then-current exercise price by 0.5%, and expire on the 30 month anniversary of the completion of this offering. For more information about these warrants, please see “Description of capital stock—Warrants.”

Pursuant to the terms of the Subscription Agreement among Forum Energy Technologies, Inc., SCF-VII, L.P., Sunray Capital and Messrs. Gaut and Connelly, SCF-VII, L.P. purchased an additional 168,236 shares of our common stock in June 2011 in exchange for a cash payment of $50.0 million. In connection with the purchase of these shares, SCF-VII, L.P. also received a warrant to purchase 84,118 shares of our common stock pursuant to the Subscription Agreement.

Pursuant to a Subscription Agreement dated October 25, 2010 between Forum Energy Technologies, Inc. and Mr. James L. McCulloch, Mr. McCulloch subscribed to purchase 7,035 shares of our common stock in exchange for a cash payment of $1,999,980.

Pursuant to a Subscription Agreement dated November 18, 2010 between Forum Energy Technologies, Inc. and Mr. Charles E. Jones, Mr. Jones subscribed to purchase 2,638 shares of our common stock in exchange for a cash payment of $749,957.

 

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Pursuant to a Subscription Agreement dated August 2, 2011 between Forum Energy Technologies, Inc. and Mr. John A. Carrig, Mr. Carrig subscribed to purchase 884 shares of our common stock in exchange for a cash payment of $499,460.

Pursuant to a Subscription Agreement dated August 3, 2011 between Forum Energy Technologies, Inc. and Ms. Evelyn Angelle, Ms. Angelle subscribed to purchase 176 shares of our common stock in exchange for a cash payment of $99,440.

Stock repurchases

In connection with the Combination, we offered to purchase shares of our common stock from our stockholders immediately after giving effect to the Combination at the price per share used for purposes of the Combination. Our offer was subject to a pro rata cutback among the shareholders who elected to participate in the repurchase offer and was subject to an aggregate cap of $25.0 million. In connection with this share repurchase offer, Mr. James R. Burke and Mr. Joe S. Ramey, who were a director and an executive officer of FOT prior to the Combination, elected to participate in the offer by selling 10,000 shares in exchange for $2,842,900 and 2,750 shares in exchange for $781,797, respectively.

Registration rights agreement

Demand registration rights

Under our Amended and Restated Forum Stockholders Agreement (the “Amended Forum Stockholders Agreement”), from and after 180 days following an initial public offering, SCF has the right to demand on five occasions that we register all or any portion of SCF’s Registrable Securities (as such term is defined in the Amended Forum Stockholders Agreement) so long as the Registrable Securities proposed to be sold on an individual registration statement have an aggregate gross offering price of at least $20.0 million (or at least $10.0 million if we are then eligible to register such sale on a Form S-3 registration statement (or any comparable or successor form) (a “Demand Registration”). Holders of SCF’s Registrable Securities may not require us to effect more than one Demand Registration in any six-month period. After such time that we become eligible to use Form S-3 (or comparable form) for the registration under the Securities Act of any of our securities, any demand request by SCF with a reasonably anticipated aggregate offering price of $100.0 million may be for a “shelf” registration statement pursuant to Rule 415 under the Securities Act; provided that any such “shelf” registration statement Demand Request will count as two Demand Requests.

We may delay the filing of a demand registration statement until a date not later than 60 days after the required filing date if (A) we are engaged in confidential negotiations or other confidential business activities which would require disclosure in the registration statement and our board of directors determines in good faith that such disclosure would be materially detrimental to us or (B) we have experienced some other material non-public event or is in possession of material non-public information concerning us. We may also delay the filing if, prior to receiving a demand request, we are already proceeding with another offering or pursuant to a demand by another requesting holder. If we delay the filing of a demand registration statement for any of the foregoing reasons, then we must deliver a certificate signed by our Chief Executive Officer stating we are delaying the filing and the basis for the delay.

 

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Piggyback registration rights

If we propose to file a registration statement under the Securities Act relating to an offering of our common stock for our Company or for the account of any holder of our common stock (other than a registration statement filed relating to securities offered in connection with benefit plans or acquisitions or any registration statement filed in connection with an exchange offer or offering solely to our stockholders), we will provide written notice to holders of Registrable Securities no less than 15 days, provided that, in the case of an initial public offering, we are not obligated to provide written notice of any proposed filing of a registration statement to the Holders of the Registrable Securities until no less than 15 days before the anticipated filing date of a registration statement (or a pre-effective amendment thereof) that first identifies SCF as a selling stockholder in such registration statement. If SCF elects not to register any Registrable Securities in our initial public offering, then no other holder of Registrable Securities is entitled to register any Registrable Securities in our initial public offering. Upon notice and written request of holders of Registrable Securities, we will use our commercially reasonable efforts to include in such registration, and any related underwriting, all of the Registrable Securities included in such requests. To the extent a stockholder is not a party to the Amended Forum Stockholders Agreement, such stockholder may not be entitled to the registration rights set forth therein.

If the managing underwriter of a proposed underwritten offering advises us that in its opinion the total amount of securities to be included in such offering is sufficiently large to materially and adversely affect the price or success of the offering, then the securities to be included in such offering will be allocated first to the requesting holders if the registration statement is pursuant to a demand request or, if not, then to us, and then pro rata among the holders of piggyback securities on the basis of the number of Registrable Securities then held by each such holder.

Holdback agreements

Each holder of Registrable Securities is subject to certain lock-up provisions that restrict transfer during the period beginning 14 days prior to, and continuing for a period not to exceed 180 days after, the date of a final prospectus for this offering, or 90 days for any subsequent underwritten public offering of our equity securities, except as part of such registration (subject to an extension of such lock-up period in certain circumstances).

Registration procedures and expenses

The Amended Forum Stockholders Agreement contains customary procedures relating to underwritten offerings and the filing of registration statements. We have agreed to pay all registration expenses incurred in connection with any registration, including all registration, qualification and filing fees, printing expenses, accounting fees, escrow fees, legal fees of the Company, reasonable fees of one counsel to the holders of Registrable Securities, blue sky fees and expenses and the expense of any special audits incident to or required by any such registration. All underwriting discounts and selling commissions and stock transfer taxes applicable to securities registered by holders and fees of counsel to any such holder (other than as described above) will be payable by holders of Registrable Securities.

Indemnification and contribution

The Amended Forum Stockholders Agreement also contains customary indemnification and contribution provisions by us for the benefit of holders participating in any registration. Each

 

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holder participating in any registration agrees to indemnify us in respect of information provided by such holder to us for use in connection with such registration; provided that such indemnification will be limited to the net proceeds actually received by such indemnifying holder from the sale of Registrable Securities.

Procedures for approval of related person transactions

A “Related Party Transaction” is a transaction, arrangement or relationship in which we or any of our subsidiaries was, is or will be a participant, the amount of which involved exceeds $120,000, and in which any related person had, has or will have a direct or indirect material interest. A “Related Person” means:

 

•

any person who is, or at any time during the applicable period was, one of our executive officers or one of our directors;

 

•

any person who is known by us to be the beneficial owner of more than 5.0% of our common stock;

 

•

any immediate family member of any of the foregoing persons, which means any child, stepchild, parent, stepparent, spouse, sibling, mother-in-law, father-in-law, son-in-law, daughter-in-law, brother-in-law or sister-in-law of a director, executive officer or a beneficial owner of more than 5.0% of our common stock, and any person (other than a tenant or employee) sharing the household of such director, executive officer or beneficial owner of more than 5.0% of our common stock; and

 

•

any firm, corporation or other entity in which any of the foregoing persons is a partner or principal or in a similar position or in which such person has a 10.0% or greater beneficial ownership interest.

Our board of directors intends to adopt a written related party transactions policy prior to the completion of this offering. Pursuant to this policy, the Audit Committee expects to review all material facts of all Related Party Transactions and either approve or disapprove entry into the Related Party Transaction, subject to certain limited exceptions. In determining whether to approve or disapprove entry into a Related Party Transaction, the Audit Committee expects to take into account, among other factors, the following: (1) whether the Related Party Transaction is on terms no less favorable than terms generally available to an unaffiliated third-party under the same or similar circumstances and (2) the extent of the Related Person’s interest in the transaction. Further, the policy would require that all Related Party Transactions required to be disclosed in our filings with the SEC be so disclosed in accordance with applicable laws, rules and regulations.

 

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Principal and selling stockholders

The following table sets forth information with respect to the beneficial ownership of our common stock as of August 31, 2011 by:

 

•

each of our Named Executive Officers;

 

•

each of our directors;

 

•

all of our directors and executive officers as a group;

 

•

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

 

•

each of the selling stockholders.

Except as otherwise indicated, the persons or entities listed below have sole voting and investment power with respect to all shares of our common stock beneficially owned by them, except to the extent this power may be shared with a spouse. All information with respect to beneficial ownership has been furnished by the respective directors, executive officers, 5% or more stockholders or the selling stockholders, as the case may be.

 

Name and address of beneficial owner		Shares beneficially owned prior to the offering										Shares beneficially owned after offering(2)
		Number				Percentage(1)				Shares being offered		Number		Percentage
Selling Stockholders:
5% or more Stockholders:
SCF-V, L.P.(3)			626,367				31.3%
SCF-VI, L.P.(3)			364,795				18.2%
SCF-VII, L.P.(3)			516,168				25.8%
Directors and Executive Officers:
C. Christopher Gaut			35,563				1.9%
Charles E. Jones			19,141				1.0%
Wendell R. Brooks			13,168				*
James W. Harris			8,945				*
James L. McCulloch			10,295				*
Steven W. Twellman			6,692				*
Evelyn Angelle			176				*
John A. Carrig			884				*
David C. Baldwin(4)			—				—
Michael McShane			579				*
Franklin Myers			957				*
John Schmitz			78,899				4.3%
Andrew L. Waite(5)			—				—
All directors and executive officers as a group (15 persons)(6)			179,253				9.5%

 

*less

than 1%.

 

(1)

Based upon an aggregate of 1,831,908 shares outstanding as of August 31, 2011. For each stockholder, in accordance with Rule 13d-3 promulgated under the Securities Exchange Act of 1934, this percentage is determined by assuming the named

 

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stockholder exercises all options, warrants and other instruments pursuant to which the stockholder has the right to acquire shares of our common stock within 60 days of August 31, 2011, but that no other person exercises any options, warrants or other purchase rights (except with respect to the calculation of the beneficial ownership of all directors and executive officers as a group, for which the percentage assumes that all directors and executive officers exercise any options, warrants or other purchase rights).

 

(2)

Assumes no exercise of the underwriters’ over-allotment option to purchase             additional shares of our common stock.

 

(3)

L.E. Simmons is the natural person who has voting and investment control over the securities owned by SCF. Mr. Simmons serves as the President and sole member of the board of directors of LESA, the ultimate general partner of SCF. Because SCF-V, L.P., SCF-VI, L.P. and SCF-VII, L.P. are controlled by LESA, each of these entities may be considered to be a group for purposes of Section 13(d)(3) under the Securities Exchange Act of 1934. As a group, SCF beneficially owns 1,507,330 shares of our common stock, or 75.4% of our common stock, in the aggregate. This beneficial ownership includes 626,367 shares of our common stock currently outstanding and held by SCF-V, L.P., 364,795 shares of our common stock currently outstanding and held by SCF-VI, L.P., 344,112 shares of our common stock currently outstanding and held by SCF-VII, L.P. and 172,056 shares of our common stock issuable upon the exercise of warrants (assuming such warrants are exercised by the payment of the applicable exercise price in cash and assuming the previously described purchase right was exercised on August 31, 2011) issued and issuable by us to SCF-VII, L.P., in each case as further described under “Certain relationships and related party transactions—Subscription and warrant agreements.”

 

(4)

Mr. Baldwin serves as a managing director of LESA, the ultimate general partner of SCF. As such, Mr. Baldwin may be deemed to have dispositive power over the shares of common stock owned by SCF. Mr. Baldwin disclaims beneficial ownership of such shares of common stock owned by SCF.

 

(5)

Mr. Waite serves as a managing director of LESA, the ultimate general partner of SCF. As such, Mr. Waite may be deemed to have dispositive power over the shares of common stock owned by SCF. Mr. Waite disclaims beneficial ownership of such shares of common stock owned by SCF.

 

(6)

The number of shares beneficially owned includes the following shares that are subject to stock options and warrants that were exercisable as of, or will become exercisable within 60 days of, August 31, 2011:

 

Holder		Option shares				Warrant shares
C. Christopher Gaut			15,389				6,155
Charles E. Jones			9,525				—
Wendell R. Brooks			9,002				410
James W. Harris			2,638				579
James L. McCulloch			1,500				—
W. Patrick Connelly			—				527
Michael D. Danford			1,200				50
Steven W. Twellman			5,436				—
Michael McShane			338				23
John Schmitz			88				8,793

 

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Description of capital stock

Upon completion of the stock split and this offering, the authorized capital stock of Forum Energy Technologies, Inc. will consist of             shares of common stock, par value $0.01 per share, of which             shares of common stock will be issued and outstanding, and             shares of preferred stock, par value $0.01 per share, of which no shares will be issued and outstanding.

We will adopt an amended and restated certificate of incorporation and amended and restated bylaws concurrently with the completion of this offering. The following summary of the capital stock and our amended and restated certificate of incorporation and our amended and restated bylaws does not purport to be complete and is qualified in its entirety by reference to the provisions of applicable law and to our amended and restated certificate of incorporation and amended and restated bylaws, which are filed as exhibits to the registration statement of which this prospectus is a part.

Common stock

Except as provided by law or in a preferred stock designation, holders of our common stock are entitled to one vote for each share held of record on all matters submitted to a vote of the stockholders. Because holders of our common stock have the exclusive right to vote for the election of directors and do not have cumulative voting rights, the holders of a majority of the shares of our common stock can elect all of the members of the board of directors standing for election, subject to the rights, powers and preferences of any outstanding series of preferred stock. Subject to the rights and preferences of any preferred stock that we may issue in the future, the holders of our common stock are entitled to receive:

 

•

dividends as may be declared by our board of directors; and

 

•

all of our assets available for distribution to holders of our common stock in liquidation, pro rata, based on the number of shares held.

There are no redemption or sinking fund provisions applicable to our common stock. All outstanding shares of our common stock are fully paid and non-assessable, and the shares of common stock to be issued upon completion of this offering will be fully paid and non-assessable.

Preferred stock

Subject to the provisions of our amended and restated certificate of incorporation and legal limitations, our board of directors will have the authority, without further vote or action by our stockholders:

 

•

to issue up to             shares of preferred stock in one or more series; and

 

•

to fix the rights, preferences, privileges and restrictions of our preferred stock, including provisions related to dividends, conversion, voting, redemption, liquidation and the number of shares constituting the series or the designation of that series, which may be superior to those of our common stock.

There will be no shares of preferred stock outstanding upon the closing of this offering, and we have no present plans to issue any preferred stock.

 

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The issuance of shares of preferred stock by our board of directors as described above may adversely affect the rights of the holders of our common stock. For example, preferred stock may rank prior to our common stock as to dividend rights, liquidation preference or both, may have full or limited voting rights and may be convertible into shares of our common stock. The issuance of shares of preferred stock may discourage third-party bids for our common stock or may otherwise adversely affect the market price of our common stock. In addition, preferred stock may enable our board of directors to make it more difficult or to discourage attempts to obtain control of us through a hostile tender offer, proxy contest, merger or otherwise, or to make changes in our management.

Warrants

Overview

In connection with the consummation of the Combination, we offered each of our stockholders who were accredited investors or non-U.S. persons (as such term is defined for purposes of the Securities Act of 1933) the opportunity to purchase shares of our common stock worth $115 million in the aggregate, up to their pro rata ownership of us. In connection with this subscription offer, we issued to those stockholders who purchased shares of our common stock a warrant to purchase additional shares of our common stock on the basis of one warrant share for every two shares purchased in the subscription offer. The warrants were exercisable upon their issuance and will remain exercisable until the date that is the 30 month anniversary following the consummation of this offering. The initial exercise price of the warrants was $284.29 per share, and the exercise price increases by 0.5% of the then-current exercise price on the last day of each month following their original issuance. The warrants do not confer upon the holder any voting or any other rights of our stockholders.

Exercise of the warrants

The warrants were issued pursuant to a Warrant Agreement by and between the holders of the warrants and us. The warrants may be exercised, in whole or in part, either for cash or on a cashless basis, subject to the limitations described below.

Cash exercise

Upon the completion of this offering, the holder of any warrant may no longer exercise such warrant by the payment of cash for the applicable exercise price of such warrant exercised. Notwithstanding the preceding sentence, unless otherwise determined by the holders of warrants representing not less than 80% of the shares of our common stock then subject to purchase pursuant to outstanding warrants, at any time after the completion of this offering, a holder of a warrant may exercise such warrant for cash if such exercise occurs during (1) the 60 days prior to the expiration time or (2) at any time after we have publicly announced or delivered notice that we have entered into a definitive agreement that would result in a reclassification or reorganization of our common stock or a merger or consolidation into another entity or that involves our common stock or a sale of all or substantially all of our assets and ending on the consummation or abandonment of such transaction. Any such exercise for cash, however, must be in compliance with applicable federal and state securities laws and in accordance with a valid exemption from registration in connection with the issuance of our common stock underlying such warrant, in each case as we determine.

 

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Conversion rights

In addition to the cash exercise method described above, following the completion of this offering, holders of warrants will have the right (but not the obligation) to require us to convert a warrant, in whole or in part, into shares of our common stock (the “Conversion Right”) pursuant to the Warrant Agreement. Upon exercise of the Conversion Right, we will deliver to the holder of the warrant (without payment by such holder of the exercise price) the number of shares of our common stock equal to (x) the aggregate fair market value of the shares of our common stock for which the Conversion Right is exercised less the aggregate exercise price applicable to such shares of our common stock (and any taxes allocated to the holder of such warrant in connection with such exercise) divided by (y) the fair market value of one share of our common stock immediately prior to the exercise of the Conversion Right. In addition, if less than 20% of the aggregate shares of our common stock originally subject to the Warrant Agreement remain subject to purchase upon exercise, we will have the right, by delivery of a written notice to the holders of the warrants that remain outstanding, to cause the exercise of all warrants pursuant to the Conversion Right. In addition, all warrants outstanding as of the expiration time will be deemed to have been exercised pursuant to the Conversion Right.

Adjustments

The exercise price of the warrants and the number of shares of our common stock issuable upon exercise of the warrants are subject to adjustment in certain circumstances, including in the event we (1) make a distribution payable in our common stock, subdivide our outstanding common stock into a larger number or combine our outstanding shares of common stock into a smaller number, (2) issue rights, options, warrants or equivalent rights to all or substantially all of the holders of our common stock (and not to the holders of warrants) entitling our stockholders to subscribe for or purchase shares of our common stock at a price less than fair market value or (3) distribute (A) shares of any class other than our common stock, (B) evidences of our indebtedness, (C) cash or other assets or (D) rights or warrants other than as described above.

Renouncement of business opportunities

SCF has investments in other oilfield service companies that may compete with us, and SCF and its affiliates, other than us, may invest in such other companies in the future. SCF, its other affiliates and its portfolio companies are referred to as the SCF group. Our amended and restated certificate of incorporation will provide that, until we have had no directors that are SCF Nominees for a continuous period of one year, we renounce any interest in any business opportunity in which any member of the SCF group participates or desires or seeks to participate in and that involves any aspect of the energy equipment or services business or industry, other than:

 

•

any business opportunity that is brought to the attention of an SCF Nominee solely in such person’s capacity as our director or officer and with respect to which no other member of the SCF group independently receives notice or otherwise identifies such opportunity; or

 

•

any business opportunity that is identified by the SCF group solely through the disclosure of information by or on behalf of us.

Thus, for example, members of the SCF group, which includes any SCF Nominees, may pursue opportunities in the oilfield services industry for their own account or present such opportunities

 

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to SCF’s other portfolio companies. Our amended and restated certificate of incorporation will provide that the SCF group, which includes any SCF Nominees, has no obligation to offer such opportunities to us, even if the failure to provide such opportunity would have a competitive impact on us. We are not prohibited from pursuing any business opportunity with respect to which we have renounced any interest.

Our certificate of incorporation further provides that any amendment to or adoption of any provision inconsistent with the certificate of incorporation’s provisions governing the renouncement of business opportunities must be approved by the holders of at least 80% of the voting power of the outstanding stock of the corporation entitled to vote thereon.

Amendment of the bylaws

Our board of directors may amend or repeal the bylaws and adopt new bylaws by the affirmative vote of a majority of the whole board of directors. The stockholders may amend or repeal the bylaws and adopt new bylaws by a majority vote at any annual meeting or special meeting for which notice of the proposed amendment, repeal or adoption was contained in the notice for such special meeting.

Limitation of liability and indemnification of officers and directors

Our directors will not be personally liable to us or our stockholders for monetary damages for breach of fiduciary duty as a director, except, if required by Delaware law, for liability:

 

•

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

 

•

for acts or omissions not in good faith or involving intentional misconduct or a knowing violation of law;

 

•

for unlawful payment of a dividend or unlawful stock purchases or redemptions; or

 

•

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

As a result, neither we nor our stockholders have the right, through stockholders’ derivative suits on our behalf, to recover monetary damages against a director for breach of fiduciary duty as a director, including breaches resulting from grossly negligent behavior, except in the situations described above. We intend to enter into indemnification agreements with each of our current and future directors and officers.

Registration rights

For a description of our Registration Rights Agreement, please read “Certain relationships and related party transactions—Registration rights agreement.”

Transfer agent and registrar

The transfer agent and registrar for the common stock is             .

 

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Listing; public market

There is no established market for our shares of common stock. We intend to apply to list on the NYSE under the ticker symbol “FET,” subject to completion of the offering and compliance with certain conditions. The development and maintenance of a public market for our common stock, having the desirable characteristics of depth, liquidity and orderliness, depends on the existence of willing buyers and sellers, the presence of which is not within our control or that of any market maker. The number of active buyers and sellers of shares of our common stock at any particular time may be limited, which may have an adverse effect on the price at which shares of our common stock can be sold.

 

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Shares eligible for future sale

Prior to this offering, there has been no public market for our common stock. Future sales of our common stock in the public market, or the availability of such shares for sale in the public market, could adversely affect market prices prevailing from time to time. As described below, only a limited number of shares will be available for sale shortly after this offering due to contractual and legal restrictions on resale. Nevertheless, sales of a substantial number of shares of our common stock in the public market after such restrictions lapse, or the perception that those sales may occur, could adversely affect the prevailing market price at such time and our ability to raise equity-related capital at a time and price we deem appropriate.

Sales of restricted shares

Upon the closing of this offering, we will have outstanding an aggregate of             shares of common stock. Of these shares, all of the             shares of common stock to be sold in this offering will be freely tradable without restriction or further registration under the Securities Act, unless the shares are held by any of our “affiliates” as such term is defined in Rule 144 of the Securities Act. All remaining shares of common stock held by existing stockholders will be deemed “restricted securities” as such term is defined under Rule 144. The restricted securities were issued and sold by us in private transactions and are eligible for public sale only if registered under the Securities Act or if they qualify for an exemption from registration under Rule 144 or Rule 701 under the Securities Act, which rules are summarized below.

As a result of the lock-up agreements described below and the provisions of Rule 144 and Rule 701 under the Securities Act, the shares of our common stock (excluding the shares to be sold in this offering) that will be available for sale in the public market are as follows:

 

•

shares will be eligible for sale on the date of this prospectus or prior to 180 days after the date of this prospectus;

 

•

shares will be eligible for sale upon the expiration of the lock-up agreements, beginning 180 days after the date of this prospectus (subject to extension) and when permitted under Rule 144 or Rule 701; and

 

•

shares will be eligible for sale, upon exercise of vested options, upon the expiration of the lock-up agreements, beginning 180 days after the date of this prospectus (subject to extension).

Lock-up agreements

We, all of our directors and officers, certain of our principal stockholders and the selling stockholders have agreed not to sell any common stock for a period of 180 days from the date of this prospectus, subject to certain exceptions and extensions. See “Underwriting (conflicts of interest)” for a description of these lock-up provisions.

Rule 144

In general, under Rule 144 as currently in effect, once we have been a reporting company subject to the reporting requirements of Section 13 or 15(d) of the Exchange Act for 90 days, a person (or persons whose shares are aggregated) who is not deemed to have been an affiliate of ours at any time during the three months preceding a sale, and who has beneficially owned restricted

 

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securities within the meaning of Rule 144 for a least six months (including any period of consecutive ownership of preceding non-affiliated holders) would be entitled to sell those shares, subject only to the availability of current public information about us. A non-affiliated person who has beneficially owned restricted securities within the meaning of Rule 144 for at least one year would be entitled to sell those shares without regard to the provisions of Rule 144.

Once we have been a reporting company subject to the reporting requirements of Section 13 or 15(d) of the Exchange Act for 90 days, a person (or persons whose shares are aggregated) who is deemed to be an affiliate of ours and who has beneficially owned restricted securities within the meaning of Rule 144 for at least six months would be entitled to sell within any three-month period a number of shares that does not exceed the greater of one percent of the then outstanding shares of our common stock or the average weekly trading volume of our common stock reported through the NYSE during the four calendar weeks preceding the filing of notice of the sale. Such sales are also subject to certain manner of sale provisions, notice requirements and the availability of current public information about us.

Rule 701

In general, under Rule 701, any of our employees, directors, officers, consultants or advisors who purchases shares from us in connection with a compensatory stock or option plan or other written agreement pursuant to Rule 701 before the effective date of the registration statement for this offering is entitled to sell such shares 90 days after the effective date of this offering in reliance on Rule 144, without having to comply with the holding period requirement of Rule 144 and, in the case of non-affiliates, without having to comply with the public information, volume limitation or notice filing provisions of Rule 144. The SEC has indicated that Rule 701 will apply to typical stock options granted by an issuer before it becomes subject to the reporting requirements of the Exchange Act, along with the shares acquired upon exercise of such options, including exercises after the date of this prospectus.

Stock issuable under employee plans

We intend to file a registration statement on Form S-8 under the Securities Act to register stock issuable under our 2010 Plan. This registration statement is expected to be filed following the effective date of the registration statement of which this prospectus is a part and will be effective upon filing. Accordingly, shares registered under such registration statement will be available for sale in the open market following the effective date, unless such shares are subject to vesting restrictions with us, Rule 144 restrictions applicable to our affiliates or the lock-up restrictions described above.

Registration rights

For a description of our Registration Rights Agreement, please read “Certain relationships and related party transactions—Registration rights agreement.”

 

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Material U.S. federal income and estate tax considerations

to non-U.S. holders

The following is a general discussion of the material U.S. federal income and estate tax considerations relating to the acquisition, ownership and disposition of our common stock by non-U.S. holders (as defined below). The following discussion is based on current provisions of the Code, the U.S. Treasury regulations promulgated thereunder, and administrative and judicial interpretations thereof, all as in effect on the date hereof, and all of which are subject to change or differing interpretations, possibly with retroactive effect. For the purpose of this discussion, a non-U.S. holder is any beneficial owner of our common stock that is not, for U.S. federal income tax purposes, any of the following:

 

•

an individual who is a citizen or resident of the United States (as determined for U.S. federal income tax purposes);

 

•

a corporation (or other entity treated as a corporation for U.S. federal income tax purposes) created or organized in or under the laws of the United States, any state thereof or the District of Columbia;

 

•

a partnership (or other entity treated as a partnership for U.S. federal income tax purposes);

 

•

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

 

•

a trust (x) if a U.S. court is able to exercise primary supervision over the administration of the trust and one or more U.S. persons (within the meaning of Section 7701(a)(30) of the Code) have authority to control all substantial decisions of the trust or (y) that has made a valid election to be treated as a U.S. person.

If a partnership (or an entity treated as a partnership for U.S. federal income tax purposes) holds our common stock, the tax treatment of a partner in the partnership will generally depend on the status of the partner and the activities of the partnership. Partnerships that hold our common stock, and partners in such partnerships, should consult their own tax advisors regarding the tax consequences of the acquisition, ownership and disposition of our common stock.

This discussion is limited to non-U.S. holders that will hold our common stock as a capital asset within the meaning of Section 1221 of the Code (generally, property held for investment). This discussion does not address all of the U.S. federal income and estate tax consequences that may be relevant to a non-U.S. holder in light of such holder’s particular circumstances, nor does it deal with special situations, such as:

 

•

tax consequences to non-U.S. holders that may be subject to special treatment under U.S. federal income tax laws, including, without limitation, U.S. expatriates, individuals who are not present in the United States for 183 days or more in a year, but who maintain status as non-resident aliens for U.S. federal income tax purposes; insurance companies, tax-exempt or governmental organizations, mutual funds, dealers or traders in securities or currency, banks or other financial institutions, investors whose functional currency is other than the U.S. dollar, “controlled foreign corporations,” “passive foreign investment companies,” common trust funds, certain trusts, and hybrid entities;

 

•

tax consequences to investors that hold our common stock as part of a hedge, straddle, synthetic security, conversion transaction or other integrated investment;

 

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•

any gift tax consequences;

 

•

any alternative minimum tax consequences; or

 

•

any aspects of state, local or non-U.S. taxation.

Prospective investors should consult their own tax advisors regarding the U.S. federal income and estate tax consequences to them in light of their own particular circumstances, as well as any tax consequences arising under the U.S. federal gift or alternative minimum tax laws and the laws of any state, local or non-U.S. taxing jurisdiction, the effect of any changes in applicable tax law and their entitlement to benefits under any applicable tax treaty.

Distributions on our common stock

We have not made any distributions on our common stock, and we do not plan to make any distributions in the foreseeable future. However, if we do make distributions of cash or other property on our common stock, those distributions will constitute dividends for U.S. tax purposes to the extent paid from our current or accumulated earnings and profits, as determined under U.S. federal income tax principles. To the extent those distributions exceed our current and accumulated earnings and profits, the distributions will constitute a return of capital and will first reduce a non-U.S. holder’s adjusted tax basis in our common stock, but not below zero, and then will be treated as gain from the sale of our common stock (see “—Gain on disposition of common stock).

Any dividends paid to a non-U.S. holder of our common stock generally will be subject to withholding of U.S. federal income tax at a rate of 30%, or such lower rate as may be specified by an applicable tax treaty, of the gross amount of the dividend. To receive the benefit of a reduced treaty rate, a non-U.S. holder must provide us with an Internal Revenue Service (“IRS”) Form W-8BEN (or successor form) or other appropriate version of IRS Form W-8 certifying qualification for the reduced rate. A non-U.S. holder of our common stock that is eligible for a reduced rate of U.S. federal withholding tax under an income tax treaty may obtain a refund from the IRS of any excess amounts withheld by timely filing an appropriate claim for refund with the IRS.

Dividends received by a non-U.S. holder that are effectively connected with a trade or business conducted by the non-U.S. holder in the United States (and, if an applicable tax treaty so provides, are attributable to a permanent establishment or fixed base maintained by the non-U.S. holder in the United States) generally will be exempt from the withholding tax described above and instead will be subject to U.S. federal income tax on a net income basis at the same graduated rates generally applicable to U.S. persons. To obtain this exemption from withholding tax, the non-U.S. holder must provide us with an IRS Form W-8ECI properly certifying eligibility for such exemption. In addition to the income tax described above, dividends received by a corporate non-U.S. holder that are effectively connected with a trade or business conducted by the corporate non-U.S. holder in the United States (and, if an applicable tax treaty so provides, are attributable to a permanent establishment or fixed base maintained by the corporate non-U.S. holder in the United States) may be subject to a branch profits tax at a rate of 30% or such lower rate as may be specified by an applicable tax treaty.

 

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Gain on disposition of common stock

A non-U.S. holder generally will not be subject to U.S. federal income tax on any gain realized upon the sale or other disposition of our common stock unless:

 

•

the gain is effectively connected with a trade or business conducted by the non-U.S. holder in the United States (and, if an applicable tax treaty so provides, is attributable to a permanent establishment or fixed base maintained by the non-U.S. holder in the United States), in which case the non-U.S. holder generally will be subject to U.S. federal income tax on any gain realized upon the sale or other disposition on a net income basis at the same graduated rates generally applicable to U.S. persons (furthermore, the branch profits tax described above also may apply to a corporate non-U.S. holder); or

 

•

we are or have been a “U.S. real property holding corporation” (“USRPHC”) for U.S. federal income tax purposes at any time within the shorter of the five-year period preceding the date of the sale or other disposition and the non-U.S. holder’s holding period.

Generally, a corporation is a USRPHC if the fair market value of its “United States real property interests” equals or exceeds 50% of the sum of the fair market value of its worldwide real property interests and its other assets used or held for use in a trade or business (all as determined for U.S. federal income tax purposes). For this purpose, real property interests include land, improvements and associated personal property. We believe that we are not presently, and have not been within the preceding five year period, a USRPHC for U.S. federal income tax purposes. If we are a USRPHC at any time during the applicable testing period described above, then, provided that our common stock is considered to be “regularly traded on an established securities market” (within the meaning of Section 897 of the Code and the applicable Treasury regulations) at any time during the calendar year in which the future sale or other disposition occurs, and the non-U.S. holder does not own (directly, indirectly or constructively) at any time during the five-year period ending on the date of the sale or other disposition more than 5% of our common stock, gains realized upon the sale or other disposition of our common stock generally will not be subject to U.S. federal income tax pursuant to the third bullet point above. If we are a USRPHC at any time during the applicable testing period described above and our common stock is not considered to be “regularly traded on an established securities market,” upon a future sale or other disposition of our common stock, a non-U.S. holder will be subject to U.S. federal income tax on a net income basis at the same graduated rates generally applicable to U.S. persons and will be subject to U.S. federal income tax withholding on the amount realized from such sale or other disposition at a 10% rate. Non-U.S. holders should consult their own tax advisors with respect to the application of the foregoing rules to their ownership and disposition of our common stock.

U.S. federal estate tax

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

 

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Information reporting and backup withholding

Generally, we must report annually to the IRS the amount of dividends paid to each non-U.S. holder, the name and address of the recipient, and the amount, if any, of tax withheld with respect to those dividends, regardless of whether withholding was required. In addition, except as described below, payments of the proceeds from the sale or other disposition of our common stock are potentially subject to information reporting to the IRS. Pursuant to tax treaties or other agreements, the IRS may make its reports available to tax authorities in the recipient’s country of residence.

Dividends and the proceeds from the sale or other disposition of our common stock are potentially subject to backup withholding (at the applicable rate, which is currently 28%). In general, backup withholding (and information reporting with respect to the proceeds of a sale or other disposition of our common stock) will not apply to payments to a non-U.S. holder if the holder has provided the required certification that it is a non-U.S. holder, such as providing an IRS Form W-8BEN or IRS Form W8-ECI (or appropriate substitute or successor form). Notwithstanding the foregoing, backup withholding (and information reporting) may apply if either we or a broker or other paying agent has actual knowledge, or reason to know, that the beneficial owner is a U.S. person.

Backup withholding is not an additional tax. Any amounts withheld under the backup withholding rules will be allowed as a refund or credit against a holder’s U.S. federal income tax liability, provided that the required information is furnished to the IRS in a timely manner.

Non-U.S. holders should consult their own tax advisors regarding the application of the information reporting and backup withholding rules to them.

Foreign account tax compliance act withholding

Enacted legislation generally will impose, effective for payments made after December 31, 2012, a withholding tax of 30% on dividends on, and the gross proceeds of a sale or other disposition of, our common stock paid to certain foreign entities unless various information and due diligence requirements are satisfied. Non-U.S. holders should consult their own tax advisers regarding the potential application and impact of these new requirements to them based on their particular circumstances.

 

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Underwriting (conflicts of interest)

We and the selling stockholders are offering the shares of common stock described in this prospectus through a number of underwriters. J.P. Morgan Securities LLC is acting as representative of the underwriters. We and the selling stockholders have entered into an underwriting agreement with the underwriters. Subject to the terms and conditions of the underwriting agreement, we and the selling stockholders have agreed to sell to the underwriters, and each underwriter has severally agreed to purchase, at the public offering price less the underwriting discount set forth on the cover page of this prospectus, the number of shares of common stock listed next to its name in the following table.

 

Name		Number of shares
J.P. Morgan Securities LLC
Total

The underwriters are committed to purchase all the shares of our common stock offered by us and the selling stockholders if they purchase any shares. The underwriting agreement also provides that if an underwriter defaults, the purchase commitments of non-defaulting underwriters may also be increased or the offering may be terminated.

The underwriters propose to offer the common stock directly to the public at the initial public offering price set forth on the cover page of this prospectus and to certain dealers at that price less a concession not in excess of $             per share. Any such dealers may resell shares to certain other brokers or dealers at a discount of up to $             per share from the initial public offering price. After the initial public offering of the shares, the offering price and other selling terms may be changed by the underwriters. Sales of shares made outside of the United States may be made by affiliates of the underwriters. The representatives have advised us that the underwriters do not intend to confirm discretionary sales in excess of 5% of the common stock offered in this offering.

The underwriters have an option to buy up to             additional shares of common stock from us and up to             additional shares of common stock from selling stockholders to cover sales of shares by the underwriters which exceed the number of shares specified in the table above. The underwriters have 30 days from the date of this prospectus to exercise this over-allotment option. If any shares are purchased with this over-allotment option, the underwriters will purchase shares in approximately the same proportion as shown in the table above. If any additional shares of common stock are purchased, the underwriters will offer the additional shares on the same terms as those on which the shares are being offered.

 

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The underwriting fee is equal to the public offering price per share of common stock, less the amount paid by the underwriters to us and the selling stockholders per share of common stock. The underwriting fee is $             per share. The following table shows the per share and total underwriting discounts and commissions that we and the selling stockholders are to pay to the underwriters, assuming both no exercise and full exercise of the underwriters’ option to purchase additional shares.

 

Per share

Total

Without over- allotment exercise

With full over- allotment exercise

Without over- allotment exercise

With full over- allotment exercise

Underwriting discounts and commissions paid by us

$

$

$

$

Expenses payable by us

$

$

$

$

Underwriting discounts and commissions paid by the selling stockholders

$

$

$

$

Expenses payable by the selling stockholders

$

$

$

$

We estimate that the total expenses of this offering to us, including registration, filing and listing fees, printing fees, and legal and accounting expenses, but excluding the underwriting discounts and commissions, will be approximately $            .

A prospectus in electronic format may be made available on the websites maintained by one or more underwriters, or selling group members, if any, participating in the offering. The underwriters 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 representatives to underwriters and selling group members that may make Internet distributions on the same basis as other allocations.

We have agreed that we will not (1) offer, pledge, announce the intention to sell, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right, or warrant to purchase, or otherwise transfer or dispose of, directly or indirectly, or file with the SEC a registration statement under the Securities Act (other than any registration statement on Form S-8) relating to, any shares of our common stock or securities convertible into or exchangeable or exercisable for any shares of our common stock, or publicly disclose the intention to make any offer, sale, pledge, disposition, or filing, or (2) enter into any swap or other arrangement that transfers all or a portion of the economic consequences associated with the ownership of any shares of common stock or any such other securities (regardless of whether any of these transactions are to be settled by the delivery of shares of common stock or such other securities, in cash or otherwise), in each case without the prior written consent of J.P. Morgan Securities LLC, for a period of 180 days after the date of this prospectus, other than the shares of our common stock to be sold hereunder, common stock contingently issuable under existing acquisition contracts, common stock issued in connection with future acquisitions (subject to a cap of 5% of the shares outstanding upon completion of this offering and provided that the recipients of any shares of common stock agree to be bound by the same restrictions on sales), any stock options, restricted stock awards, phantom stock awards, and other equity-based incentive awards to be issued to our directors, officers, employees or consultants in accordance with our stock incentive plan and in compliance with the requirements of the NYSE, and any

 

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shares of our common stock to be issued upon the exercise of options or other awards or the vesting or other equity-based incentive awards granted under our stock-based compensation plans.

Notwithstanding the foregoing, if (A) during the last 17 days of the 180-day restricted period, we issue an earnings release or material news or a material event relating to our Company occurs; or (B) prior to the expiration of the 180-day restricted period, we announce that we will release earnings results during the 16-day period beginning on the last day of the 180-day period, the restrictions described above shall continue to apply until the expiration of the 18-day period beginning on the issuance of the earnings release or the occurrence of the material news or material event.

Our directors and executive officers and certain of our principal stockholders and the selling stockholders have entered into lock-up agreements with the underwriters pursuant to which each of these persons or entities, with limited exceptions, for a period of 180 days after the date of this prospectus, may not, without the prior written consent of J.P. Morgan Securities LLC, (1) offer, pledge, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right or warrant to purchase, or otherwise transfer or dispose of, directly or indirectly, any shares of our common stock or any securities convertible into or exercisable or exchangeable for our common stock (including, without limitation, common stock or such other securities which may be deemed to be beneficially owned by such persons in accordance with the rules and regulations of the SEC and securities which may be issued upon exercise of a stock option or warrant), or publicly disclose the intention to make any offer, sale, pledge, or disposition, (2) enter into any swap or other agreement that transfers, in whole or in part, any of the economic consequences of ownership of the common stock or such other securities, whether any such transaction described in clause (1) or (2) above is to be settled by delivery of common stock or such other securities, in cash, or otherwise, or (3) make any demand for or exercise any right with respect to the registration of any shares of our common stock or any security convertible into or exercisable or exchangeable for our common stock. The lock-up agreements will not restrict the shares of common stock sold by the selling stockholders in this offering or the transfer of common stock as bona fide gifts, so long as the transferee agrees to be bound by the restrictions in the lock-up agreements. Notwithstanding the foregoing, if (A) during the last 17 days of the 180-day restricted period, we issue an earnings release or material news or a material event relating to our Company occurs; or (B) prior to the expiration of the 180-day restricted period, we announce that we will release earnings results during the 16-day period beginning on the last day of the 180-day period, the restrictions described above shall continue to apply until the expiration of the 18-day period beginning on the issuance of the earnings release or the occurrence of the material news or material event.

We and the selling stockholders have agreed to indemnify the underwriters against certain liabilities, including liabilities under the Securities Act.

We intend to apply to list our common stock on the NYSE under the symbol “FET.”

In connection with this offering, the underwriters may engage in stabilizing transactions, which involves making bids for, purchasing, and selling shares of common stock in the open market for the purpose of preventing or retarding a decline in the market price of the common stock while this offering is in progress. These stabilizing transactions may include making short sales of the common stock, which involves the sale by the underwriters of a greater number of shares of common stock than they are required to purchase in this offering, and purchasing shares of

 

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common stock on the open market to cover positions created by short sales. Short sales may be “covered” shorts, which are short positions in an amount not greater than the underwriters’ over-allotment option referred to above, or may be “naked” shorts, which are short positions in excess of that amount. The underwriters may close out any covered short position either by exercising their over-allotment option, in whole or in part, or by purchasing shares in the open market. In making this determination, the underwriters will consider, among other things, the price of shares available for purchase in the open market compared to the price at which the underwriters may purchase shares through the over-allotment option. A naked short position is more likely to be created if the underwriters are concerned that there may be downward pressure on the price of the common stock in the open market that could adversely affect investors who purchase in this offering. To the extent that the underwriters create a naked short position, they will purchase shares in the open market to cover the position.

The underwriters have advised us that, pursuant to Regulation M of the Securities Act, they may also engage in other activities that stabilize, maintain, or otherwise affect the price of the common stock, including the imposition of penalty bids. This means that if the representatives of the underwriters purchase common stock in the open market in stabilizing transactions or to cover short sales, the representative can require the underwriters that sold those shares as part of this offering to repay the underwriting discount received by them.

These activities may have the effect of raising or maintaining the market price of the common stock or preventing or retarding a decline in the market price of the common stock, and, as a result, the price of the common stock may be higher than the price that otherwise might exist in the open market. If the underwriters commence these activities, they may discontinue them at any time. The underwriters may carry out these transactions on the NYSE, in the over-the-counter market, or otherwise.

Prior to this offering, there has been no public market for our common stock. The initial public offering price will be determined by negotiations between us and the representatives of the underwriters. In determining the initial public offering price, we and the representatives of the underwriters expect to consider a number of factors including:

 

•

the information set forth in this prospectus and otherwise available to the representative;

 

•

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

 

•

an assessment of our management;

 

•

our prospects for future earnings;

 

•

the general condition of the securities markets at the time of this offering;

 

•

the recent market prices of, and demand for, publicly traded common stock of generally comparable companies; and

 

•

other factors deemed relevant by the underwriters and us.

Neither we nor the underwriters can assure investors that an active trading market will develop for our common stock, or that the shares will trade in the public market at or above the initial public offering price.

 

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European economic area

In relation to each Member State of the European Economic Area which has implemented the Prospectus Directive (each, a “Relevant Member State”), each underwriter has represented and agreed that with effect from and including the date on which the Prospectus Directive is implemented in that Relevant Member State (the “Relevant Implementation Date”) it has not made and will not make an offer of shares to the public in that Relevant Member State prior to the publication of a prospectus in relation to the shares which has been approved by the competent authority in that Relevant Member State or, where appropriate, approved in another Relevant Member State and notified to the competent authority in that Relevant Member State, all in accordance with the Prospectus Directive and the 2010 PD Amending Directive to the extent implemented, except that it may, with effect from and including the Relevant Implementation Date, make an offer of shares to the public in that Relevant Member State at any time:

 

(1)

to any legal entity which is a qualified investor as defined in the Prospectus Directive or the 2010 PD Amending Directive if the relevant provision has been implemented;

 

(2)

to fewer than (i) 100 natural or legal persons per Relevant Member State (other than qualified investors as defined in the Prospectus Directive or the 2010 PD Amending Directive if the relevant provision has been implemented) or (ii) if the Relevant Member State has implemented the relevant provision of the 2010 PD Amending Directive, 150 natural or legal persons per Relevant Member State (other than qualified investors as defined in the Prospectus Directive or the 2010 PD Amending Directive if the relevant provision has been implemented), subject to obtaining the prior consent of the relevant Dealer or Dealers nominated by the Issuer for any such offer; or

 

(3)

in any circumstances falling within Article 3(2) of the Prospectus Directive or Article 3(2) of the 2010 PD Amending Directive to the extent implemented.

For the purposes of this provision, the expression an “offer of shares to the public,” in relation to any shares in any Relevant Member State, means the communication in any form and by any means of sufficient information on the terms of the offer and the shares to be offered so as to enable an investor to decide to purchase or subscribe the shares, as the same may be varied in that Member State by any measure implementing the Prospectus Directive in that Member State and the expression Prospectus Directive means Directive 2003/71/EC and includes any relevant implementing measure in each Relevant Member State and the expression 2010 PD Amending Directive means Directive 2010/73/EC.

Each underwriter has represented and agreed that:

 

(1)

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

 

(2)

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

 

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Notice to prospective investors in Switzerland

This document does not constitute an issue prospectus within the meaning of Art. 652a of the Swiss Code of Obligations. The shares of common stock may not be sold directly or indirectly in or into Switzerland except in a manner which will not result in a public offering within the meaning of the Swiss Code of Obligations. Our common stock will not be listed on the SWX Swiss Exchange and, therefore, the documents relating to our common stock, including, but not limited to, this document, do not claim to comply with the disclosure standards of the listing rules of SWX Swiss Exchange and corresponding prospectus schemes annexed to the listing rules of the SWX Swiss Exchange. This document as well as any other material relating to our common stock is personal and confidential and does not constitute an offer to any other person. This document may only be used in Switzerland by those investors to whom it has been handed out in connection with the offering described herein and may neither directly nor indirectly be distributed or made available to other persons without our express consent. It may not be used in connection with any other offer and shall in particular not be copied and/or distributed to the public in (or from) Switzerland. Neither this document nor any other offering materials relating to the shares of common stock may be distributed, published, or otherwise made available in Switzerland except in a manner which will not constitute a public offer of the shares of common stock in Switzerland.

Notice to prospective investors in Hong Kong

The shares may not be offered or sold by means of any document other than (1) in circumstances which do not constitute an offer to the public within the meaning of the Companies Ordinance (Cap.32, Laws of Hong Kong), or (2) to “professional investors” within the meaning of the Securities and Futures Ordinance (Cap.571, Laws of Hong Kong) and any rules made thereunder or (3) in other circumstances which do not result in the document being a “prospectus” within the meaning of the Companies Ordinance (Cap.32, Laws of Hong Kong), and no advertisement, invitation or document relating to the shares may be issued or may be in the possession of any person for the purpose of issue (in each case whether in Hong Kong or elsewhere), which is directed at, or the contents of which are likely to be accessed or read by, the public in Hong Kong (except if permitted to do so under the laws of Hong Kong) other than with respect to shares which are or are intended to be disposed of only to persons outside Hong Kong or only to “professional investors” within the meaning of the Securities and Futures Ordinance (Cap. 571, Laws of Hong Kong) and any rules made thereunder.

Notice to prospective investors in Singapore

This prospectus has not been registered as a prospectus with the Monetary Authority of Singapore. Accordingly, this prospectus and any other document or material in connection with the offer or sale, or invitation for subscription or purchase, of the shares may not be circulated or distributed, nor may the shares be offered or sold, or be made the subject of an invitation for subscription or purchase, whether directly or indirectly, to persons in Singapore other than (1) to an institutional investor under Section 274 of the Securities and Futures Act, Chapter 289 of Singapore (the “SFA”), (2) to a relevant person, or any person pursuant to Section 275(1A), and in accordance with the conditions, specified in Section 275 of the SFA or (3) otherwise pursuant to, and in accordance with the conditions of, any other applicable provision of the SFA.

Where the shares are subscribed or purchased under Section 275 by a relevant person which is: (1) a corporation (which is not an accredited investor) the sole business of which is to hold

 

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investments and the entire share capital of which is owned by one or more individuals, each of whom is an accredited investor; or (2) a trust (where the trustee is not an accredited investor) whose sole purpose is to hold investments and each beneficiary is an accredited investor, shares, debentures and units of shares and debentures of that corporation or the beneficiaries’ rights and interest in that trust shall not be transferable for 6 months after that corporation or that trust has acquired the shares under Section 275 except: (1) to an institutional investor under Section 274 of the SFA or to a relevant person, or any person pursuant to Section 275(1A), and in accordance with the conditions, specified in Section 275 of the SFA; (2) where no consideration is given for the transfer; or (3) by operation of law.

Notice to prospective investors in Japan

The securities have not been and will not be registered under the Financial Instruments and Exchange Law of Japan (the “Financial Instruments and Exchange Law”) and each underwriter has agreed that it will not offer or sell any securities, directly or indirectly, in Japan or to, or for the benefit of, any resident of Japan (which term as used herein means any person resident in Japan, including any corporation or other entity organized under the laws of Japan), or to others for re-offering or resale, directly or indirectly, in Japan or to a resident of Japan, except pursuant to an exemption from the registration requirements of, and otherwise in compliance with, the Financial Instruments and Exchange Law and any other applicable laws, regulations and ministerial guidelines of Japan.

Notice to prospective investors in the United Arab Emirates

This prospectus relates to an Exempt Offer with the Offered Securities Rules of the Dubai Financial Services Authority (“DFSA”). This prospectus is intended for distribution only to persons of a type specified in the Offered Securities Rules of the DFSA. It must not be delivered to, or relied on by, any other person. The DFSA has no responsibility for reviewing or verifying any documents in connection with Exempt Offers. The DFSA has not approved this prospectus nor taken steps to verify the information set forth herein and has no responsibility for this prospectus. The securities to which this prospectus relates may be illiquid and/or subject to restrictions on their resale. Prospective purchasers of the securities offered should conduct their own due diligence on the securities. If you do not understand the contents of this prospectus you should consult an authorized financial advisor.

Relationships with underwriters and their affiliates

The underwriters and their respective affiliates are full service financial institutions engaged in various activities, which may include securities trading, commercial and investment banking, financial advisory, investment management, investment research, principal investment, hedging, financing and brokerage activities. Certain of the underwriters and their affiliates have provided in the past to us and our affiliates and may provide from time to time in the future certain commercial banking, financial advisory, investment banking, and other services in the ordinary course of their business, for which they have received and may continue to receive customary fees and commissions. Affiliates of the underwriters are lenders under our credit agreement. See “—Conflicts of interest.”

In the ordinary course of their various business activities, the underwriters and their respective affiliates may make or hold a broad array of investments and actively trade debt and equity

 

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securities (or related derivative securities) and financial instruments (including bank loans) for their own account and for the accounts of their customers, and such investment and securities activities may involve our securities and/or instruments. The underwriters and their respective affiliates may also make investment recommendations and/or publish or express independent research views in respect of such securities or instruments. In addition, from time to time, certain of the underwriters and their affiliates may at any time hold, on behalf of themselves or their customers, or recommend to clients that they acquire, long or short positions in our equity or debt securities or loans.

Conflicts of interest

An affiliate of J.P. Morgan Securities LLC, an underwriter in this offering, is a lender under our credit agreement and may receive more than 5% of the net proceeds of this offering in connection with the repayment of amounts under our credit agreement. Accordingly, this offering is being made in compliance with the requirements of Rule 5121 of the Financial Industry Regulatory Authority, Inc. In accordance with this rule,              has assumed the responsibilities of acting as a “qualified independent underwriter.” In its role as a qualified independent underwriter,              has participated in due diligence and the preparation of the registration statement of which this prospectus is a part.              will not receive any additional fees for serving as a qualified independent underwriter in connection with this offering. J.P. Morgan Securities LLC will not confirm sales of the shares to any account over which they exercise discretionary authority without the prior written approval of the customer. We have agreed to indemnify              against certain liabilities incurred in connection with acting as a “qualified independent underwriter,” including liabilities under the Securities Act.

 

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Legal matters

The validity of our common stock offered by this prospectus will be passed upon for Forum Energy Technologies, Inc., by Vinson & Elkins L.L.P., Houston, Texas. Certain legal matters in connection with this offering will be passed upon for the underwriters by Baker Botts L.L.P., Houston, Texas. Baker Botts L.L.P. represents us from time to time in matters unrelated to this offering.

Experts

The audited financial statements of Forum Energy Technologies, Inc. included in this prospectus, except as they relate to 2008 and 2009 financial statements of Allied Production Services, Inc. (“Allied”), Subsea Services International, Inc. (“Subsea”) and Triton Group Holdings LLC (“Triton”), have been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm. Such financial statements, except as they relate to Allied, Subsea and Triton, have been so included in reliance on the report (which contains an explanatory paragraph relating to the Company’s combination as described in Note 1 to the financial statements) of such independent registered public accounting firm given on the authority of such firm as experts in auditing and accounting.

The audited 2008 financial statements of Allied and the audited 2008 and 2009 financial statements of Subsea and Triton, not separately presented in this prospectus, have been audited by Deloitte & Touche LLP, Pannell Kerr Forster of Texas, P.C., and Deloitte LLP, respectively, each an independent registered public accounting firm, whose reports thereon appear herein. The audited financial statements of Forum Energy Technologies, Inc., to the extent they relate to Allied, Subsea or Triton, have been so included in reliance on the reports of such independent registered public accounting firms given on the authority of said firms as experts in auditing and accounting.

The consolidated financial statements of Allied Production Services, Inc. and Subsidiaries at December 31, 2009, and for the year then ended, not presented separately herein in this Prospectus and Registration Statement have been audited by Ernst & Young LLP, independent registered public accounting firm, as set forth in their report thereon appearing elsewhere herein. The audited financial statements of Forum Energy Technologies, Inc. and Subsidiaries are included in reliance upon such report given on the authority of such firm as experts in accounting and auditing.

The financial statements of Davis-Lynch, Inc. as of December 31, 2009 and 2010 and for each of the three years in the period ended December 31, 2010 included in this prospectus have been so included in reliance on the report of UHY LLP, an independent registered public accounting firm, given on the authority of said firm as experts in auditing and accounting.

The financial statements of Wood Flowline LLC as of December 31, 2010 and for the year then ended included in this prospectus have been so included in reliance on the report of PricewaterhouseCoopers LLP, an independent registered public accounting firm, given on the authority of said firm as experts in auditing and accounting.

The financial statements of AMC Global Group Limited as of April 30, 2011 and for the year then ended included in this prospectus have been so included in reliance on the report of

 

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PricewaterhouseCoopers LLP (which contains an explanatory paragraph relating to differences in accounting principles as described in Note 2), an independent registered public accounting firm, given on the authority of said firm as experts in auditing and accounting.

The financial statements of P-Quip Limited as of May 31, 2011 and for the year then ended included in this prospectus have been so included in reliance on the report of PricewaterhouseCoopers LLP (which contains an explanatory paragraph relating to differences in accounting principles as described in Note 2), an independent registered public accounting firm, given on the authority of said firm as experts in auditing and accounting.

The financial statements of Cannon Services, Ltd as of December 31, 2010 and for the year then ended included in this prospectus have been so included in reliance on the report of PricewaterhouseCoopers LLP, an independent registered public accounting firm, given on the authority of said firm as experts in auditing and accounting.

Where you can find more information

We have filed with the SEC a registration statement on Form S-1 (including the exhibits, schedules and amendments thereto) under the Securities Act, with respect to the shares of our common stock offered hereby. This prospectus does not contain all of the information set forth in the registration statement and the exhibits and schedules thereto. For further information with respect to us and the common stock offered hereby, we refer you to the registration statement and the exhibits and schedules filed therewith. Statements contained in this prospectus as to the contents of any contract, agreement or any other document are summaries of the material terms of this contract, agreement or other document. With respect to each of these contracts, agreements or other documents filed as an exhibit to the registration statement, reference is made to the exhibits for a more complete description of the matter involved. A copy of the registration statement, and the exhibits and schedules thereto, may be inspected without charge at the public reference facilities maintained by the SEC at 100 F Street NE, Washington, D.C. 20549. Copies of these materials may be obtained, upon payment of a duplicating fee, from the Public Reference Section of the SEC at 100 F Street NE, Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the operation of the public reference facility. The SEC maintains a website that contains reports, proxy and information statements and other information regarding registrants that file electronically with the SEC. The address of the SEC’s website is http://www.sec.gov.

After we have completed this offering, we will file annual, quarterly and current reports, proxy statements and other information with the SEC. We maintain a website at http://www.f-e-t.com and we expect to make our periodic reports and other information filed with or furnished to the SEC available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC. Information on our website or any other website is not incorporated by reference into this prospectus and does not constitute a part of this prospectus. We will provide electronic or paper copies of our filings free of charge upon request.

 

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Forum Energy Technologies, Inc. and subsidiaries

Index to consolidated financial statements

December 31, 2008, 2009 and 2010

 

		Page(s)
Forum Energy Technologies, Inc. Consolidated Financial Statements
Audited Financial Statements
Report of independent registered public accounting firm			F-3
Report of independent registered public accounting firm to the Board of Directors of Triton Group Holdings LLC			F-4
Report of independent registered public accounting firm to the Board of Directors and Shareholders of Allied Production Services, Inc.			F-5
Report of independent registered public accounting firm to the Board of Directors and Management of Allied Production Services, Inc.			F-6
Report of independent registered public accounting firm to the Board of Directors and Shareholders of Subsea Services International, Inc.			F-7
Consolidated Balance Sheets at December 31, 2009 and 2010			F-8
Consolidated Statements of Income For the Years Ended December 31, 2008, 2009 and 2010			F-9
Consolidated Statements of Changes in Stockholders’ Equity For the Years Ended December  31, 2008, 2009 and 2010			F-10
Consolidated Statements of Cash Flows For the Years Ended December 31, 2008, 2009 and 2010			F-13
Notes to Consolidated Financial Statements			F-15
Interim Financial Statements
Consolidated Balance Sheets at December 31, 2010 and June 30, 2011 (Unaudited)			F-62
Consolidated Statements of Income for the Six Months Ended June 30, 2010 and 2011 (Unaudited)			F-63
Consolidated Statement of Changes in Stockholders’ Equity For the Six Months Ended June  30, 2011 (Unaudited)			F-64
Consolidated Statements of Cash Flows For the Six Months Ended June 30, 2010 and 2011 (Unaudited)			F-65
Notes to Consolidated Interim Financial Statements (Unaudited)			F-66
Davis-Lynch, Inc. Financial Statements
Audited Financial Statements for the Year Ended December 31, 2010
Report of Independent Registered Public Accounting Firm			F-78
Balance Sheets			F-79
Statements of Operations			F-80
Statements of Changes in Stockholder’s Equity			F-81
Statements of Cash Flows			F-82
Notes to Financial Statements			F-83
Interim Financial Statements for the Six Months Ended June 30, 2010 and 2011
Balance Sheets			F-92
Statements of Operations			F-93

 

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		Page(s)
Statements of Changes in Stockholder’s Equity			F-94
Statements of Cash Flows			F-95
Notes to Financial Statements			F-96
Wood Flowline Products, LLC Financial Statements
Audited Financial Statements for the Year Ended December 31, 2010
Report of Independent Registered Public Accounting Firm			F-105
Balance Sheet			F-106
Statement of Operations			F-107
Consolidated Statement of Members’ Equity			F-108
Statement of Cash Flows			F-109
Notes to Financial Statements			F-110
AMC Global Group Limited Financial Statements
Audited Financial Statements for the Year Ended April 30, 2011
Report of Independent Registered Public Accounting Firm to the member of AMC Global Group Limited			F-117
Consolidated profit and loss account for the year ended 30 April 2011			F-118
Consolidated and Company balance sheets as at 30 April 2011			F-119
Consolidated cash flow statement for the year ended 30 April 2011			F-120
Notes to the consolidated financial statements for the year ended 30 April 2011			F-121
P-Quip Limited Financial Statements
Audited Financial Statements for the Year Ended May 31, 2011
Report of Independent Registered Public Accounting Firm to the member of P-Quip Limited			F-134
Profit and loss account for the year ended 31 May 2011			F-135
Balance sheet as at 31 May 2011			F-136
Cash flow statement for the year ended 31 May 2011			F-137
Notes to the financial statements for the year ended 31 May 2011			F-138
Cannon Services, Ltd. Financial Statements
Audited Financial Statements for the Year Ended December 31, 2010
Report of Independent Registered Public Accounting Firm			F-150
Balance Sheet			F-151
Statement of Income			F-152
Statement of Changes in Partners’ Capital			F-153
Statement of Cash Flows			F-154
Notes to Financial Statements			F-155
Interim Financial Statements for the Six Months Ended June 30, 2010 and June 30, 2011
Balance Sheets			F-160
Statements of Income			F-161
Statements of Cash Flows			F-162
Notes to Financial Statements			F-163

 

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Report of independent registered public accounting firm

To the Stockholders of

Forum Energy Technologies, Inc.

In our opinion, based on our audits and the reports of other auditors, the accompanying consolidated balance sheets and the related consolidated statements of income, of stockholders’ equity and of cash flows present fairly, in all material respects, the financial position of Forum Energy Technologies, Inc. (formerly Forum Oilfield Technologies, Inc.) and its subsidiaries (“the Company”) at December 31, 2009 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2010 in conformity with accounting principles generally accepted in the United States of America. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits. We did not audit the 2008 and 2009 financial statements of Allied Production Services, Inc. (“Allied”), Subsea Services International, Inc. (“SSI”) and Triton Group Holdings LLC (“Triton”), all wholly-owned subsidiaries of the Company, whose statements reflect total assets of $382,438,000 as of December 31, 2009, and total revenues of $380,496,000 and $287,279,000 for the years ended December 31, 2008 and 2009, respectively. Those statements were audited by other auditors whose reports thereon have been furnished to us, and our opinion expressed herein, insofar as it relates to the amounts included for Allied, SSI and Triton, is based solely on the reports of the other auditors. We conducted our audits of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits and the reports of other auditors provide a reasonable basis for our opinion.

As discussed in Note 1 to the consolidated financial statements, on August 2, 2010 the Company completed the combination of the Company with Allied, SSI, Triton and Global Flow Technologies, Inc. Prior to the combination, all of the companies were under the common control of three private equity funds with the same sponsor.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

August 31, 2011

 

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Index to Financial Statements

Report of independent registered public accounting firm

To the Board of Directors of

Triton Group Holdings LLC

We have audited the consolidated balance sheet of Triton Group Holdings LLC (the “Company”) as of December 31, 2009, and the related consolidated statements of income, comprehensive income, members’ equity, and cash flows for the two years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such financial statements present fairly, in all material respects, the consolidated financial position of Triton Group Holdings LLC at as of December 31, 2009, and the results of its operations and its cash flows for the two years then ended in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE LLP

Aberdeen, United Kingdom

July 14, 2010

 

F-4

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Table of Contents

Index to Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Shareholders of Allied Production Services, Inc.

We have audited the consolidated balance sheet of Allied Production Services, Inc. and Subsidiaries as of December 31, 2009, and the related consolidated statements of operations, shareholders’ equity, and cash flows for the year then ended (not presented separately herein). These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. We were not engaged to perform an audit of the Company’s internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Allied Production Services, Inc. and Subsidiaries at December 31, 2009, and the consolidated results of their operations and their cash flows for the year then ended, in conformity with U.S. generally accepted accounting principles.

/s/ Ernst & Young LLP

Houston, Texas

August 26, 2011

 

F-5

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Table of Contents

Index to Financial Statements

Report of independent registered public accounting firm

To the Board of Directors and Management of

Allied Production Services, Inc.

We have audited the consolidated statements of operations and cash flows of Allied Production Services, Inc. and subsidiaries (the “Company”), for the year ended December 31, 2008. The statements of operations and cash flows are the responsibility of the Company’s management. Our responsibility is to express an opinion on the statements of operations and cash flows based on our audit.

We conducted our audit in accordance with auditing standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the statements of operations and cash flows are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the statements of operations and cash flows, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall statements of operations and cash flows presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, such consolidated statements of operations and cash flows present fairly, in all material respects, the results of operations and cash flows of the Company for the year ended December 31, 2008, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Dallas, Texas

May 29, 2009

 

F-6

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Table of Contents

Index to Financial Statements

Report of independent registered public accounting firm

Board of Directors and Shareholders of

Subsea Services International, Inc.

We have audited the accompanying consolidated balance sheets of Subsea Services International, Inc. (the “Company”) as of December 31, 2008 and 2009 and the related consolidated statements of income, changes in stockholders’ equity, and cash flows for the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purposes of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Subsea Services International, Inc. as of December 31, 2008 and 2009, and the consolidated results of its operations and its cash flows for the years then ended in conformity with United States generally accepted accounting principles

/s/ Pannell Kerr Forster of Texas, P.C.

Houston, Texas

March 30, 2010

 

F-7

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Consolidated balance sheets

at December 31, 2009 and 2010

 

		2009				2010
		(in thousands of dollars, except share information)
Assets
Current assets
Cash and cash equivalents		$	26,894			$	20,348
Accounts receivable—trade, net			106,377				117,656
Inventories, net			168,628				173,777
Prepaid expenses and other current assets			21,232				18,051
Costs and estimated profits in excess of billings			7,060				3,660
Deferred income taxes, net			9,768				8,615
Current assets of discontinued operations			230				—
Total current assets			340,189				342,107
Property and equipment, net of accumulated depreciation			96,747				90,632
Deferred financing costs, net			7,249				6,458
Intangibles, net			91,615				80,159
Goodwill			300,576				294,381
Other long-term assets			3,850				4,595
Total assets		$	840,226			$	818,332
Liabilities and Equity
Current liabilities
Current portion of long-term debt and capital lease obligations		$	34,940			$	3,209
Accounts payable—trade			50,484				61,981
Accrued liabilities and other current liabilities			43,246				44,542
Deferred revenue			6,729				7,130
Billings in excess of costs and profits recognized			12,659				7,889
Derivative instruments			445				2,194
Liabilities from discontinued operations			773				—
Total current liabilities			149,276				126,945
Long-term debt, net of current portion			236,937				204,715
Deferred income taxes, net			24,928				20,368
Derivative instruments			5,562				2,162
Other long-term liabilities			3,093				1,065
Mandatorily redeemable preferred stock			18,062				—
Total liabilities			437,858				355,255
Commitments and contingencies
Equity
Preferred stock			62				—
Series A and B units			2,064				—
Common stock, $0.01 par value, 8,000,000 shares authorized, 1,555,514 and 1,317,290 shares issued and outstanding, respectively			13				16
Additional paid-in capital			281,144				342,217
Warrants			—				7,825
Retained earnings			126,865				150,803
Treasury stock			(661	)			(25,823	)
Accumulated other comprehensive loss			(7,560	)			(12,515	)
Total stockholders’ equity			401,927				462,523
Noncontrolling interest in subsidiary			441				554
Total equity			402,368				463,077
Total liabilities and equity		$	840,226			$	818,332

The accompanying notes are an integral part of these consolidated financial statements.

 

F-8

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Consolidated statements of income

For the years ended December 31, 2008, 2009 and 2010

 

		2008				2009				2010
		(in thousands of dollars, except share information)
Net sales		$	972,551			$	677,378			$	747,335
Cost of sales			691,824				491,463				533,078
Gross profit			280,727				185,915				214,257
Operating expenses
Selling, general and administrative expenses			146,943				128,562				141,441
Impairment of goodwill and other intangible assets			44,015				7,009				—
(Gain) loss on sale of assets			(619	)			137				(461	)
Total operating expenses			190,339				135,708				140,980
Income from operations			90,388				50,207				73,277
Other expense (income)
Expenses related to the combination			—				—				6,968
Deferred loan costs written off			—				—				6,082
Interest expense			24,704				19,451				18,189
Other, net			(2,065	)			(1,088	)			(2,308	)
Total other expense (income)			22,639				18,363				28,931
Income from continuing operations before income taxes			67,749				31,844				44,346
Provision for income tax expense			32,938				11,011				20,297
Income from continuing operations			34,811				20,833				24,049
Loss from discontinued operations, net of taxes			(396	)			(1,342	)			—
Net income			34,415				19,491				24,049
Less: Income attributable to noncontrolling interest			(39	)			(155	)			(111	)
Net income attributable to common stockholders		$	34,376			$	19,336			$	23,938
Weighted average shares outstanding
Basic			1,232				1,304				1,454
Diluted			1,261				1,322				1,468
Earnings per share
Basic		$	27.90			$	14.83			$	16.46
Diluted			27.26				14.63				16.31

The accompanying notes are an integral part of these consolidated financial statements.

 

F-9

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Consolidated statements of changes in stockholders’ equity

For the years ended December 31, 2008, 2009 and 2010

 

		Preferred shares								Triton series A and B								Common stock								Additional paid-in capital				Treasury stock				Warrants				Retained earnings				Accumulated other comprehensive income/(loss)				Total common stockholders’ equity				Non controlling interest				Total equity
		Shares				Amount				Units				Amount				Shares				Amount
		(in thousands of dollars, except share information)
Balance at January 1, 2008			62,000			$	31				20,425			$	223				1,205,655			$	12			$	227,572			$	—			$	—			$	73,418			$	4,662			$	305,918			$	133			$	306,051
Share based compensation expense			—				—				—				—				—				—				2,177				—				—				—				—				2,177				—				2,177
Issuance of equity			—				—				—				—				34,160				—				19,743				—				—				—				—				19,743				—				19,743
Issuance of restricted stock			—				—				—				—				2,142				—				—				—				—				—				—				—				—				—
Repurchase of stock			—				—				—				—				—				—				—				(410	)			—				—				—				(410	)			—				(410	)
Excess tax benefit from share based compensation			—				—				—				—				—				—				424				—				—				—				—				424				—				424
Issuance of stock for acquisitions			—				—				—				—				15,625				—				5,547				—				—				—				—				5,547				—				5,547
Issuance of preferred stock			6,820				31				—				—				—				—				6,820				—				—				—				—				6,851				—				6,851
Issuance of Series A and B units			—				—				22,637				768				—				—				—				—				—				—				—				768				—				768
Exercise of warrants			—				—				—				—				57,857				1				16,242																				16,243				—				16,243
Comprehensive income:
Net income			—				—				—				—				—				—				—				—				—				34,376				—				34,376				39				34,415
Loss on foreign currency translation, net of tax of $0			—				—				—				—				—				—				—				—				—				—				(12,278	)			(12,278	)			(135	)			(12,413	)
Loss on derivative instruments, net of tax of $1,292			—				—				—				—				—				—				—				—				—				—				(2,401	)			(2,401	)			—				(2,401	)
Comprehensive income / (loss)																																															19,697				(96	)			19,601
Balance at December 31, 2008			68,820				62				43,062				991				1,315,439				13				278,525				(410	)			—				107,794				(10,017	)			376,958				37				376,995

 

F-10

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Consolidated statements of changes in stockholders’ equity

For the years ended December 31, 2008, 2009 and 2010 (continued)

 

		Preferred shares								Triton series A and B								Common stock								Additional paid-in capital				Treasury stock				Warrants				Retained earnings				Accumulated other comprehensive income/(loss)				Total common stockholders’ equity				Non controlling interest				Total equity
		Shares				Amount				Units				Amount				Shares				Amount
		(in thousands of dollars, except share information)
Share based compensation expense			235				—				—				1,184				—				—				1,832				—				—				—				—				3,016				—				3,016
Exercise of stock options			—				—				—				—				607				—				76				—				—				—				—				76				—				76
Issuance of common stock			—				—				—				—				3,643				—				255				—				—				—				—				255				—				255
Issuance of restricted stock			—				—				—				—				1,248				—				—				—				—				—				—				—				—				—
Repurchase of stock			—				—				—				—				(291	)			—				(97	)			(251	)			—				—				—				(348	)			—				(348	)
Excess tax benefit from share based compensation			—				—				—				—				—				—				(47	)			—				—				—				—				(47	)			—				(47	)
Issuance of stock for acquisitions			—				—				—				—				—				—				600				—				—				—				—				600				—				600
Surrendered restricted stock			—				—				—				—				(3,356	)			—				—				—				—				—				—				—				—				—
Forfeiture of Series A and B			—				—				(3,095	)			(111	)			—				—				—				—				—				—				—				(111	)			—				(111	)
Adoption of uncertain tax positions			—				—				—				—				—				—				—				—				—				(265	)			—				(265	)							(265	)
Comprehensive income
Net income			—				—				—				—				—				—				—				—				—				19,336				—				19,336				155				19,491
Gain on foreign currency translation, net of tax of $0			—				—				—				—				—				—				—				—				—				—				1,409				1,409				249				1,658
Gain on derivative instruments, net of tax of $564			—				—				—				—				—				—				—				—				—				—				1,048				1,048				—				1,048
Comprehensive income																																															21,793				404				22,197
Balance at December 31, 2009			69,055				62				39,967				2,064				1,317,290				13				281,144				(661	)			—				126,865				(7,560	)			401,927				441				402,368

 

F-11

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Consolidated statements of changes in stockholders’ equity

For the years ended December 31, 2008, 2009 and 2010 (continued)

 

		Preferred shares								Triton series A and B								Common stock								Additional paid-in capital				Treasury stock				Warrants				Retained earnings				Accumulated other comprehensive income/(loss)				Total common stockholders’ equity				Non controlling interest				Total equity
		Shares				Amount				Units				Amount				Shares				Amount
		(in thousands of dollars, except share information)
Share based compensation expense			—				—				—				403				—				—				4,733				—				—				—				—				5,136				—				5,136
Exercise of stock options			—				—				—				—				500				—				50				—				—				—				—				50				—				50
Issuance of common stock			—				—				—				—				9,673				—				2,750				—				—				—				—				2,750				—				2,750
Issuance of restricted stock			—				—				—				—				5,129				—				—				—				—				—				—				—				—				—
Repurchase of stock			—				—				—				—				(3,107	)			—				(838	)			(166	)			—				—				—				(1,004	)			—				(1,004	)
Excess tax benefit from share based compensation			—				—				—				—				—				—				38				—				—				—				—				38				—				38
Items related to the combination:
Issuance of common stock			—				—				—				—				218,536				2				62,126				—				—				—				—				62,128				—				62,128
Issuance of warrants			—				—				—				—				—				—				(7,825	)			—				7,825				—				—				—				—				—
Purchase of stock related to the tender offer at the time of the combination			—				—				—				—				—				—				—				(24,996	)			—				—				—				(24,996	)			—				(24,996	)
Purchase of stock related to the conversion of shares			(69,055	)			(62	)			(39,967	)			(2,467	)			7,133				1				39				—				—				—				—				(2,489	)			—				(2,489	)
Comprehensive income
Net income			—				—				—				—				—				—				—				—				—				23,938				—				23,938				111				24,049
Loss on foreign currency translation, net of tax of $0			—				—				—				—				—				—				—				—				—				—				(6,315	)			(6,315	)			2				(6,313	)
Gain on derivative instruments, net of tax of $732			—				—				—				—				—				—				—				—				—				—				1,360				1,360				—				1,360
Comprehensive income																																															18,983				113				19,096
Balance at December 31, 2010			—			$	—				—			$	—				1,555,154			$	16			$	342,217			$	(25,823	)		$	7,825			$	150,803			$	(12,515	)		$	462,523			$	554			$	463,077

The accompanying notes are an integral part of these consolidated financial statements.

 

F-12

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Consolidated statements of cash flows

For the years ended December 31, 2008, 2009 and 2010

 

		2008				2009				2010
		(in thousands of dollars, except share information)
Cash flows from operating activities
Net income		$	34,415			$	19,491			$	24,049
Adjustments to reconcile net income to net cash provided by operating activities
Deferred loan costs written off			—				—				6,082
Noncash interest expense from mandatorily redeemable preferred stock			972				1,464				—
Impairment of goodwill and other intangible assets			44,015				7,009				—
Unrealized loss (gain) on interest rate swap			809				1,001				441
Share-based compensation expense			2,947				3,016				5,136
Depreciation expense			21,330				24,221				21,889
Amortization of deferred loan costs			1,532				1,401				1,784
Amortization of intangible assets			13,584				14,217				11,327
Provision for doubtful accounts			1,236				2,865				955
Loss (gain) on disposal of fixed assets			(1,515	)			67				(182	)
Deferred income taxes			(893	)			(8,123	)			(1,178	)
Changes in operating assets and liabilities
Accounts receivable—trade			12,213				38,443				(13,132	)
Income taxes receivable			352				(810	)			2,575
Inventories			(37,589	)			60,428				(5,745	)
Prepaid expenses and other current assets			(9,355	)			1,338				(297	)
Cost and estimated profit in excess of billings			(3,839	)			1,420				2,550
Accounts payable, deferred revenue and other accrued liabilities			35,982				(61,846	)			14,167
Billings in excess of costs and estimated profits earned			(3,733	)			2,149				(4,440	)
Net cash provided by operating activities			112,463				107,751				65,981
Cash flows from investing activities
Capital expenditures for property and equipment			(39,642	)			(15,078	)			(19,624	)
Proceeds from sale of property and equipment			12,887				6,089				670
Capitalized costs related to patents			(143	)			(200	)			(262	)
Acquisition of businesses, net of cash acquired			(134,039	)			(1,725	)			—
Net cash used in investing activities			(160,937	)			(10,914	)			(19,216	)

The accompanying notes are an integral part of these consolidated financial statements.

 

F-13

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries Consolidated statements of cash flows

Years ended December 31, 2008, 2009 and 2010 (continued)

 

		2008				2009				2010
		(in thousands of dollars, except share information)
Cash flows from financing activities
Payment of capital lease obligations			(208	)			(182	)			(627	)
Borrowings on long-term debt			132,064				8,214				323,916
Repayment of long-term debt			(95,750	)			(102,342	)			(407,360	)
Deferred financing costs			(2,526	)			—				(6,671	)
Purchased stock due to the combination			—				—				(3,327	)
Treasury stock			—				(251	)			(25,162	)
Excess tax expense (benefits) from stock based compensation			(424	)			(47	)			38
Proceeds from stock issuance			25,715				76				64,928
Net cash (used in) provided by financing activities			58,871				(94,532	)			(54,265	)
Effect of exchange rate changes on cash			(23,143	)			4,648				954
Net increase (decrease) in cash and cash equivalents			(12,746	)			6,953				(6,546	)
Cash and cash equivalents
Beginning of year			32,687				19,941				26,894
End of year		$	19,941			$	26,894			$	20,348
Supplemental cash flow disclosures
Interest paid		$	23,289			$	17,817			$	14,219
Income taxes paid			31,926				24,586				25,009
Noncash investing and financing activities
Acquisition of equipment via capital lease		$	969			$	1,424			$	—
Insurance policy financed through notes payable			3,736				2,672				3,809
Common stock issued for acquisitions			23,147				600				—

The accompanying notes are an integral part of these consolidated financial statements.

 

F-14

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010

1. Nature of operations and combination

Forum Energy Technologies, Inc. (“FET” or the “Company”), a Delaware corporation, is a global provider of manufactured technologies and applied products to the energy industry. The manufactured products include, among other products, pipe handling tools, pressure control equipment, remotely operated vehicles and a wide range of related subsea products, surface production equipment and industrial valves. The Company is owned by three private equity funds with the same sponsor, certain current and former employees of the Company and former owners of acquired companies.

On August 2, 2010, the Company completed the combination (“Combination”) of Forum Oilfield Technologies, Inc. (“FOT”), Triton Group Holdings LLC (“Triton”), Subsea Services International, Inc. (“SSI”), Global Flow Technologies, Inc. (“GFT”) and Allied Production Services, Inc. (“Allied”) pursuant to which the shareholders of the companies other than FOT exchanged all of their common stock for common stock of FOT. In conjunction with the Combination, FOT changed its name to Forum Energy Technologies, Inc.

The shareholders of each company received the following number of FET shares for each share of the respective companies:

 

Allied			.4623 shares
Global Flow			.9886 shares
Subsea			.3168 shares
Triton			.3562 shares

Prior to the Combination, the private equity funds controlled a majority of the voting interests in FOT, Triton, SSI, and GFT. The same owner was also in a controlling position with respect to Allied by virtue of its ownership of 46.2% of Allied’s issued and outstanding voting stock and its contractual right to fill three of the five directors’ seats comprising the full Allied Board. The mergers of the entities into the combined Company are accounted for using reorganization accounting (i.e., “as if” pooling of interest) for entities under common control. Under this method of accounting, the historical financial statements of each entity are included in the combined financial statements from the date on which the majority owner obtained control of the company. These consolidated financial statements include the results of FOT, Triton, SSI, GFT and Allied and all of their subsidiaries.

2. Summary of significant accounting policies

Basis of presentation

The accompanying consolidated financial statements include the accounts of FET and its majority-owned subsidiaries and are prepared in accordance with accounting principles generally accepted in the United States of America (“United States GAAP”).

 

F-15

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Principles of consolidation

The consolidated financial statements include the accounts of the Company and its wholly and majority owned subsidiaries after elimination of intercompany balances and transactions. Noncontrolling interest principally represents ownership by others of the equity in our consolidated majority owned South Africa subsidiary.

Reclassifications

Certain reclassifications have been made in prior period financial statements to conform with current period presentation. Reclassifications have no impact on the Company’s financial position, results of operations, or cash flows.

Use of estimates

The preparation of financial statements in conformity with United States GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.

In the preparation of these consolidated financial statements, estimates and assumptions have been made by management including costs to complete contracts, an assessment of percentage of completion of projects, the selection of useful lives of tangible and intangible assets, fair value of reporting units used for goodwill impairment testing, expected future cash flows from long lived assets to support impairment tests, provisions necessary for trade receivables and income tax contingencies. Actual results could differ from these estimates.

The financial reporting of contracts depends on estimates, which are assessed continually during the term of those contracts. Recognized revenues and income are subject to revisions as the contract progresses to completion and changes in estimates are reflected in the period in which the facts that give rise to the revisions become known. Additional information that enhances and refines the estimating process that is obtained after the balance sheet date, but before issuance of the financial statements is reflected in the financial statements.

Cash and cash equivalents

Cash and cash equivalents consist of cash on deposit and high quality, short term money market instruments with an original maturity of three months or less. Cash equivalents are stated at cost plus accrued interest, which approximates fair value.

Accounts receivable-trade

Trade accounts receivables are carried at their estimated collectible amounts. Trade credit is generally extended on a short-term basis; thus receivables do not bear interest, although a finance charge may be applied to amounts past due. The Company maintains an allowance for

 

F-16

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

doubtful accounts for estimated losses that may result from the inability of its customers to make required payments. Such allowances are based upon several factors including but not limited to, credit approval practices, industry and customer historical experience as well as the current and projected financial condition of the specific customer. Accounts receivable outstanding longer than contractual terms are considered past due. The Company writes off accounts receivable to the allowance for doubtful accounts when they become uncollectible. Any payments subsequently received on receivables previously written off are credited to the allowance for doubtful accounts.

The change in amounts of the allowance for doubtful accounts during the three year period ending December 31, 2010 is as follows (in thousands):

 

Period ended		Item		Balance at beginning of period				Charged to expenses				Deductions or other				Balance at end of period
December 31, 2008		Allowance for doubtful accounts		$	2,557			$	1,235			$	(500	)		$	3,292
December 31, 2009		Allowance for doubtful accounts			3,292				2,865				(2,306	)			3,851
December 31, 2010		Allowance for doubtful accounts			3,851				956				(682	)			4,125

Inventories

Inventory consisting of finished goods and materials and supplies held for resale is carried at the lower of cost or market. For certain subsidiaries, cost, which includes the cost of raw materials and labor for finished goods, is determined on a first-in first-out basis. For other subsidiaries, this cost is determined on an average cost basis. Market means current replacement cost except that (1) market should not exceed net realizable value and (2) market should not be less than net realizable value reduced by an allowance for a normal profit margin. The Company continuously evaluates inventories, based on an analysis of inventory levels, historical sales experience and future sales forecasts, to determine obsolete, slow-moving and excess inventory. Adjustments to reduce such inventory to its estimated recoverable value have been recorded by management.

Property and equipment

Property and equipment are stated at cost less accumulated depreciation. Equipment held under capital leases are stated at the present value of minimum lease payments. Expenditures for property and equipment and for items which substantially increase the useful lives of existing assets are capitalized at cost and depreciated over their estimated useful life utilizing the straight-line method. Routine expenditures for repairs and maintenance are expensed as incurred. Depreciation is computed using the straight-line method based on the estimated useful lives of assets, generally 3 to 19 years. Plant and equipment held under capital leases are amortized straight-line over the shorter of the lease term or estimated useful life of the asset.

 

F-17

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Gains or losses resulting from the disposition of assets are recognized in income, and the related asset cost and accumulated depreciation are removed from the accounts. Assets acquired in connection with business combinations are recorded at fair value.

Rental equipment consists of equipment leased to customers under operating leases. Rental equipment is recorded at cost and depreciated using the straight-line method over the estimated useful lives of three to ten years.

Effective January 1, 2010, we implemented a change in accounting estimate to adjust the useful life of marine electronic survey equipment. This change resulted in an approximately $3.2 million reduction in the depreciation expense in the year ended December 31, 2010, an increase to net income of $2.1 million (or $1.43 per diluted share). We extended the useful lives of these long-lived assets based on our review of their historical service lives, technological improvements in the assets and proven longer useful mechanical and technical lives.

The Company reviews long-lived assets for potential impairment whenever events or changes in circumstances indicate that the carrying amount of a long-lived asset may not be recoverable. In performing the review for impairment, future cash flows expected to result from the use of the asset and its eventual disposal are estimated. If the undiscounted future cash flows are less than the carrying amount of the assets, the asset is impaired. The amount of the impairment is measured as the difference between the carrying value and the estimated fair value of the asset. The fair value is determined either through the use of an external valuation, or by means of an analysis of discounted future cash flows based on expected utilization. The impairment loss recognized represents the excess of the assets carrying value as compared to its estimated fair value. For the years ended December 31, 2008, 2009 and 2010, no impairments were recorded.

To the extent that asset retirement obligations are incurred, the Company records the fair value of an asset retirement obligation as a liability in the period in which the associated legal obligation is incurred. The fair values of these obligations are recorded as liabilities on a discounted basis. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for any change in their present value. Asset retirement obligations at December 31, 2009 or 2010 are not significant.

Goodwill and intangible assets

For goodwill and intangible assets with indefinite lives, an assessment for impairment is performed annually or whenever an event indicating impairment may have occurred. The Company completes its annual impairment test for goodwill and other indefinite-lived intangibles using an assessment date of December 31. Goodwill is reviewed for impairment by comparing the carrying value of each reporting unit’s net assets (including allocated goodwill) to the fair value of the reporting unit. We have four reporting units. We determine the fair value of our reporting units using a discounted cash flow approach. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. Such estimates and assumptions include revenue growth rates, operating margins, weighted average costs of capital and future market conditions, among others. We believe that the estimates and

 

F-18

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

assumptions used in our impairment assessments are reasonable. If the reporting unit’s carrying value is greater than its fair value, a second step is performed whereby the implied fair value of goodwill is estimated by allocating the fair value of the reporting unit in a hypothetical purchase price allocation analysis consistent with that described in ASC 805, Business Combinations. The Company recognizes a goodwill impairment charge for the amount by which the carrying value of goodwill exceeds its fair value. The impairment test is a fair value test which includes assumptions such as growth and discount rates. Any impairment losses are reflected in operating income. In December 2008, an impairment loss of $39.8 million was recorded and in 2009 an impairment loss of $5.5 million was recorded. In December 2010, no impairment loss was recorded.

Intangible assets with definite lives comprised of customer and distributor relationships, non-compete agreements, and patents are amortized on a straight-line basis over the life of the intangible asset, generally 3 to 17 years. These assets are tested for impairment whenever events or changes in circumstances indicate that their carrying amount may not be recoverable. In 2008 and 2009, the Company recorded impairment charges of $4.2 million and $1.5 million, respectively, which are classified within impairment of goodwill and other intangible assets on the consolidated statement of income. No impairment to intangible assets was recorded at December 31, 2010.

In the third quarter of 2010, we implemented a change in accounting estimate to adjust the useful lives of certain of our customer relationship and distributor relationship intangible assets. This change resulted in an approximate $2.2 million reduction in the amortization expense in the year ended December 31, 2010, an increase to net income of $1.4 million (or $1.00 per diluted share). We extended the useful lives of these intangible assets based on positive changes in customer attrition rates and due to several factors pursuant to the Combination which would further strengthen these relationships.

Recognition of provisions for contingencies

In the ordinary course of business, the Company is subject to various claims, suits and complaints. The Company, in consultation with internal and external advisors, will provide for a contingent loss in the consolidated financial statements if it is probable that a liability has been incurred at the date of the consolidated financial statements and the amount can be reasonably estimated. If it is determined that the reasonable estimate of the loss is a range and that there is no best estimate within the range, provision will be made for the lower amount of the range. Legal costs are expensed as incurred.

An assessment is made of the areas where potential claims may arise under the contract warranty clauses. Where a specific risk is identified and the potential for a claim is assessed as probable and can be reasonably estimated, an appropriate warranty provision is recorded. Warranty provisions are eliminated at the end of the warranty period except where warranty claims are still outstanding. The liability for product warranty is included in other accrued liabilities on the consolidated balance sheet.

 

F-19

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Changes in the Company’s warranty liability were as follows (in thousands):

 

Period ended		Item				Balance at beginning of period				Charged to expense				Deductions or other				Balance at end of period
December 31, 2008			Warranty accrual			$	6,277			$	5,067			$	(3,924	)		$	7,420
December 31, 2009			Warranty accrual				7,420				3,210				(5,149	)			5,481
December 31, 2010			Warranty accrual				5,481				2,281				(1,054	)			6,708

Revenue recognition and deferred revenue

Revenue is recognized when all of the following criteria have been met: (a) persuasive evidence of an arrangement exists, (b) delivery of the equipment has occurred or services have been rendered, (c) the price of the product or service is fixed and determinable and (d) collectability is reasonably assured. Revenue from product sales, including shipping costs, is recognized as title passes to the customer, which generally occurs when items are shipped from the Company’s facilities. Revenue from services is recognized when the service is completed to the customer’s specifications.

Customers are sometimes billed in advance of services performed or products manufactured, and the Company recognizes the associated liability as deferred revenue. On a contract by contract basis, cost and profit in excess of billings represents the cumulative revenue recognized less the cumulative billings to the customer. Billings in excess of costs and profits represents the cumulative billings to the customer less the cumulative revenue recognized.

Revenue generated from long-term contracts typically longer than six months in duration are recognized on the percentage-of-completion method of accounting. The Company recognizes revenue and cost of goods sold each period based upon the advancement of the work-in-progress unless the stage of completion is insufficient to enable a reasonably certain forecast of profit to be established. In such cases, no profit is recognized during the period. The percentage-of-completion is calculated based on the ratio of costs incurred to-date to total estimated costs, taking into account the level of completion. The percentage-of-completion method requires management to calculate reasonably dependable estimates of progress toward completion of contract revenues and contract costs. Whenever revisions of estimated contract costs and contract values indicate that the contract costs will exceed estimated revenues, thus creating a loss, a provision for the total estimated loss is recorded in that period.

Primarily related to our remotely operated vehicles product lines, which may take longer to manufacture, accounting estimates during the course of multi-year projects may change. The effect of such a change, which can be upward as well as downward, is accounted for in the period of change and the cumulative income recognized to date is adjusted to reflect the latest estimates. These revisions to estimates are accounted for on a prospective basis.

Revenue from the rental of equipment or providing of services is recognized over the period when the asset is rented or services are rendered and collectability is reasonably assured. Rates for asset rental and service provision are priced on a per day, per man hour, or similar basis.

 

F-20

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Concentration of credit risk

Financial instruments which potentially subject the Company to credit risk include trade accounts receivable. Trade accounts receivable consist of uncollateralized receivables from domestic and internationally based customers. For the years ended December 31, 2008, 2009 and 2010, no one customer accounted for 10% or more of the total revenue or 10% or more of the total account receivable balance at the end of the respective period.

Share-based compensation

The Company accounts for awards of share-based compensation under the proper accounting guidance. This guidance and the related interpretations require companies to measure all employee share-based compensation awards at fair value on the date they are granted to employees and recognize compensation cost in their financial statements over the requisite service period. The Company has stock-based compensation plans for its employees, directors, and consultants of the Company and its subsidiaries. Compensation expense is recorded for restricted stock over the applicable vesting period based on the fair value of the stock on the date of grant. Options are issued with an exercise price equal to the fair value of the stock on the date of grant. Compensation expense is recorded for the fair value of the stock options, and is recognized over the period of the underlying security’s vesting schedule. Consideration paid on the exercise of stock options is credited to share capital and additional paid-in capital.

Fair value of the share-based compensation was measured by use of the Black-Scholes model for most of the outstanding options and a Binomial model for certain legacy share-based compensation instruments issued by Triton. The following sections address the assumptions used related to the Black-Scholes pricing model.

Expected life

The expected term of stock options represents the period the stock options are expected to remain outstanding and is based on the simplified method which is the weighted average vesting term plus the original contractual term divided by two.

Expected volatility

Expected volatility measures the amount that a stock price has fluctuated or is expected to fluctuate during a period. Since the Company’s stock is not publicly traded, the Company determines volatility based on an analysis of comparable companies.

Dividend yield

The Company has never declared or paid any cash dividends and does not plan to pay cash dividends in the foreseeable future. Therefore, a zero expected dividend yield was used in the valuation model.

 

F-21

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Risk-free interest rate

The risk-free interest rate is based on United States Treasury zero-coupon issues with remaining terms similar to the expected term on the options.

Forfeitures

The applicable accounting guidance also requires the Company to estimate forfeitures at the time of grant, and revise those estimates in subsequent periods if actual forfeitures differ from those estimates. The Company uses historical data to estimate pre-vesting option forfeitures and record stock-based compensation expense only for those awards that are expected to vest. If the Company’s actual forfeiture rate is materially different from its estimate, the stock-based compensation expense could be different from what the Company has recorded in the current period.

Fair value of common stock

The value of the Company’s stock at the time of each option grant used to establish the strike price, and the value applied in each acquisition transaction, was estimated by management, and approved by the Company’s Board of Directors, in accordance with an internal valuation model. These valuation models are based upon an average of cash flow and book value multiples of comparable companies. The comparable companies selected reflect the market’s view on key sector, geographic, and product type exposure that are similar to those that impact the Company’s business. The value is further subject to judgmental factors such as prevailing market conditions, changes in oilfield service indices and the overall outlook for the Company and its products in general.

Income taxes

The Company follows the liability method of accounting for income taxes. Under this method, deferred income tax assets and liabilities are determined based upon temporary differences between the carrying amounts and tax bases of the Company’s assets and liabilities at the balance sheet date, and are measured using enacted tax rates and laws that will be in effect when the differences are expected to reverse. The effect on deferred tax assets and liabilities of a change in the tax rates is recognized in income in the period in which the change occurs. The Company records a valuation reserve in each reporting period when management believes that it is more likely than not that any deferred tax asset created will not be realized.

The accounting guidance for income taxes requires that the Company recognize the financial statement benefit of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. If a tax position meets the “more likely than not” recognition criteria, the accounting guidance requires the tax position be measured at the largest amount of benefit greater than 50% likely of being realized upon ultimate settlement.

 

F-22

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Earnings per share

Basic earnings per share for all periods presented equals net income divided by the weighted average number of the shares of the Company’s common stock outstanding during the period. Diluted earnings per share is computed by dividing net income by the weighted average number of shares of the Company’s common stock outstanding during the period as adjusted for the dilutive effect of the Company’s stock options, restricted share plans and warrants.

The exercise price of each option is based on the fair value of the Company’s stock at the date of grant. The diluted earnings per share calculation excludes 14 thousand stock options for the year ended December 31, 2008, 26 thousand stock options for the year ended December 31, 2009 and excludes 440 thousand stock options and warrants for the year ended December 31, 2010, because increasing fair values during the year resulted in these options’ exercise prices being greater than the average market price over the entire year in the respective periods.

The following is a reconciliation of the number of shares used for the basic and diluted earnings per share computations:

 

		December 31,
		2008				2009				2010
		(shares in thousands)
Basic weighted average shares outstanding			1,232				1,304				1,454
Dilutive effect of stock option and restricted share plan			29				18				14
Diluted weighted average shares outstanding			1,261				1,322				1,468

Non-United States local currency translation

The Company operates globally and its primary functional currency is the United States dollar ($). The majority of the Company’s non-United States subsidiaries have designated the local currency as their functional currency. Financial statements of these foreign operations are translated into United States dollars using the current rate method whereby assets and liabilities are translated at the balance sheet rate and income and expenses are translated into United States dollars at the average exchange rates in effect during the period. The resultant translation adjustments are reported as a component of accumulated other comprehensive income within stockholders’ equity.

Hedging and use of derivative instruments

The Company utilizes interest rate swap and collar agreements to hedge the exposure to variable cash flows on a portion of its floating rate debt (i.e., cash flow hedges). The instruments are not used for trading or speculative purposes. The Company records these interest rate derivative instruments on the balance sheet as either derivative assets or derivative liabilities as applicable.

 

F-23

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Certain derivative instruments qualify for hedge accounting as they reduce the interest rate risk of the underlying hedged item and were formally designated as cash flow hedges at inception. These derivative instruments result in financial impacts that are inversely correlated to those of the items being hedged. Since the terms of the hedged item and the instruments substantially coincide, the hedge is expected to offset changes in expected cash flows due to fluctuations in the variable rate and, therefore, the Company currently does not expect any ineffectiveness. Changes in the fair value of the instruments designated as cash flow hedges are deferred in accumulated other comprehensive income, net of tax, to the extent the contracts are effective as hedges, until settlement of the underlying hedged transaction. If the necessary correlation ceases to exist or if physical delivery of the hedged item becomes improbable, the Company would discontinue hedge accounting and apply mark-to-market accounting with any changes in the fair values of the derivative instruments then recognized in earnings. Amounts paid or received from interest rate derivative instruments are charged or credited to interest expense and matched with the cash flows and interest expense of the debt being hedged, resulting in an adjustment to the effective interest rate.

The Company adjusts the balance of these derivative instruments to fair value on a recurring basis. The Company’s fair value measurements are based on projected future interest rates as provided by the counterparties to the interest rate swap agreements and the fixed rates that the Company is obligated to pay under these agreements. The Company determines the value of derivative financial instruments using composite quotes obtained from market pricing services or, in certain cases, active-market quotes obtained from financial institutions. The established fair value hierarchy divides fair value measurement into three broad levels: Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date; Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the assets or liability, either directly or indirectly; and Level 3 inputs are unobservable inputs for the asset or liability which reflect the best judgment of the Company. The Company’s measurements fall in Level 3.

Certain derivative instruments do not qualify for hedge accounting. These derivatives are also recorded at fair value, with the changes in fair value being recorded into earnings.

Fair value of financial instruments

The carrying amounts for financial instruments classified as current assets and current liabilities approximate fair value, due to the short maturity of such instruments. The book values of other financial instruments, such as the Company’s long-term debt, approximates fair value because interest rates charged are similar to other financial instruments with similar terms and maturities.

Noncontrolling interest

Effective January 1, 2009, the Company adopted newly issued accounting guidance that changed the accounting for, and reporting of, minority interest (now referred to as noncontrolling interest). Noncontrolling interests are now classified as equity in the consolidated balance sheet.

 

F-24

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

The new guidance also changed the way the consolidated statement of earnings is presented by requiring net earnings to include the net earnings for both controlling and noncontrolling interests, with disclosure of both amounts on the consolidated statement of earnings.

Fair value measurements

The Company has adopted the authoritative guidance for fair value measurements as they relate to nonfinancial assets and liabilities that are measured at fair value on a nonrecurring basis. The guidance defines fair value, establishes a framework for measuring fair value when an entity is required to use a fair value measure for recognition or disclosure purposes and expands the disclosures about fair value measures. The adoption did not have a material impact on the Company’s financial statements. The Company previously adopted the guidance as it relates to financial assets and liabilities that are measured at fair value and for nonfinancial assets and liabilities that are measured at fair value on a recurring basis.

Recent accounting pronouncements

In January 2010, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2010-06 “Improving Disclosures about Fair Value Measurements” (“ASU No. 2010-06”) as an update to Accounting Standards Codification Topic 820, “Fair Value Measurements and Disclosures” (“ASC Topic 820”). ASU No. 2010-06 requires additional disclosures about transfers between Levels 1 and 2 of the fair value hierarchy and disclosures about purchases, sales, issuances and settlements in the roll forward of activity in Level 3 fair value measurements. ASU No. 2010-06 is effective for interim and annual reporting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances, and settlements in the rollforward of activity in Level 3 fair value measurements. Those disclosures are effective for fiscal years beginning after December 15, 2010, and for interim periods within those fiscal years. The Company adopted the required provisions of ASU No. 2010-06. There was no significant impact to the Company’s Consolidated Financial Statements.

In June 2011, the FASB issued an update to ASC 220, Presentation of Comprehensive Income. This ASU provides that an entity that reports items of other comprehensive income has the option to present comprehensive income in either 1) a single statement that presents the components of net income and total net income, the components of other comprehensive income and total other comprehensive income, and a total for comprehensive income; or 2) a two-statement approach which presents the components of net income and total net income in a first statement, immediately followed by a financial statement that presents the components of other comprehensive income, a total for other comprehensive income, and a total for comprehensive income. The option in current GAAP that permits the presentation of other comprehensive income in the statement of changes in equity was eliminated. The guidance will be applied retrospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is permitted. The adoption of this guidance will not have a material impact on the Company’s financial statements.

 

F-25

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

In December 2010, the FASB issued FASB ASU 2010-28, which affects entities evaluating goodwill for impairment under FASB ASC 350-20. ASU 2010-28, among other things, requires entities with a zero or negative carrying value to assess, considering qualitative factors, whether it is more likely than not that goodwill impairment exists. If an entity concludes that it is more likely than not that goodwill impairment exists, the entity must perform step 2 of the goodwill impairment test. ASU 2010-28 is effective for impairment tests performed during an entity’s fiscal year beginning after December 15, 2010, with early adoption not permitted. We do not believe the adoption of this ASU will have a material impact on the Company’s financial position or results of operations.

3. Inventories

The significant components of inventory are as follows:

 

		December 31,
		2009				2010
		(in thousands)
Raw materials and parts		$	64,105			$	63,234
Work in process			11,807				19,534
Finished goods			101,651				101,115
			177,563				183,883
Inventory reserve			(8,935	)			(10,106	)
Inventories, net		$	168,628			$	173,777

The change in the amounts of the inventory reserve during the three year period ending December 31, 2010 is as follows (in thousands):

 

Period ended		Item		Balance at beginning of period				Charged to expenses				Deductions or other				Balance at end of period
December 31, 2008		Reserve for inventory obsolescence		$	6,162			$	3,518			$	(1,958	)		$	7,722
December 31, 2009		Reserve for inventory obsolescence			7,722				4,821				(3,608	)			8,935
December 31, 2010		Reserve for inventory obsolescence			8,935				1,244				(73	)			10,106

 

F-26

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

4. Property and equipment

Property and equipment consists of the following as of December 31:

 

		Estimated useful lives		2009				2010
		(in years)		(in thousands)
Land				$	1,206			$	2,026
Buildings and leasehold improvements		7-20			20,104				23,848
Computer equipment		3-5			8,233				9,433
Machinery and equipment		5-10			70,371				66,640
Furniture and fixtures		3-10			1,432				2,215
Vehicles		3-5			5,585				6,304
Construction in progress					2,037				853
					108,968				111,319
Less: Accumulated depreciation					(42,918	)			(55,746	)
Property and equipment, net					66,050				55,573
Rental equipment					45,805				57,962
Less: Accumulated depreciation					(15,108	)			(22,903	)
Rental equipment, net					30,697				35,059
Total property and equipment, net				$	96,747			$	90,632

5. Goodwill and intangible assets

Goodwill

The changes in the amount of goodwill from January 1, 2009 to December 31, 2010, are as follows:

 

		2009				2010
		(in thousands)
Goodwill Balance at January 1, net		$	299,246			$	300,576
Goodwill impairment			(5,545	)			—
Purchase price adjustments			(4,439	)			—
Impact of non-United States local currency translation			11,314				(6,195	)
Goodwill Balance at December 31, net		$	300,576			$	294,381

The Company performs its annual impairment tests of goodwill as of December 31. For the year ended December 31, 2009, the Company recognized a goodwill impairment loss of $5.5 million relating to certain Triton subsidiaries primarily due to the change in market conditions and declining operating results. There was no impairment of goodwill during the year ended December 31, 2010. The fair values were determined using the net present value of the expected future cash flows. Accumulated impairment losses on goodwill were $40.0 million as of December 31, 2009 and 2010, respectively.

 

F-27

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Intangible assets

At December 31, 2009 and 2010, intangible assets consist of the following, respectively:

 

		December 31, 2009
		Gross carrying amount				Accumulated amortization				Net amortizable intangibles				Amortization period (in years)
		(In thousands)
Customer relationships		$	71,698			$	(20,396	)		$	51,302				4-15
Patents and technology			5,389				(1,015	)			4,374				5-17
Non-compete agreements			4,074				(2,688	)			1,386				3-6
Trade names			15,174				(2,736	)			12,438				10-15
Contracts			260				(260	)			—				<1
Distributor relationships			22,160				(5,566	)			16,594				8-15
Trademark			5,521				—				5,521				Indefinite
		$	124,276			$	(32,661	)		$	91,615

 

		December 31, 2010
		Gross carrying amount				Accumulated amortization				Net amortizable intangibles				Amortization period (in years)
		(In thousands)
Customer relationships		$	70,837			$	(26,907	)		$	43,930				4-15
Patents and technology			5,764				(1,626	)			4,138				5-17
Non-compete agreements			4,047				(3,598	)			449				3-6
Trade names			15,312				(3,865	)			11,447				10-15
Contracts			260				(260	)			—				<1
Distributor relationships			22,160				(7,486	)			14,674				8-15
Trademark			5,521				—				5,521				Indefinite
		$	123,901			$	(43,742	)		$	80,159

Amortization expense was $13.6 million, $14.2 million and $11.3 million for the years ended December 31, 2008, 2009 and 2010, respectively. The total weighted average amortization period is 13 years and the estimated amortization expense for the next five years is as follows (in thousands):

 

Year ending December 31,
2011		$	8,470
2012			8,223
2013			7,927
2014			7,250
2015			6,979

 

F-28

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

In 2009, the Company concluded that the fair value of its trademarks was less than the carrying values and the assets were impaired. Accordingly, the Company recorded impairment charges of $1.5 million in the year ended December 31, 2009. Accumulated impairment losses on the trademark were $1.7 million as of December 31, 2009 and 2010.

6. Debt and mandatorily redeemable preferred stock

Notes payable and lines of credit as of December 31, 2009 and 2010 consist of the following:

 

						2009				2010
						(in thousands)
$450 million senior secured revolving credit facility			(f	)		$	—			$	204,000
FOT debt
US revolving line of credit and Canadian dollar revolving line of credit, interest at LIBOR plus applicable margin			(a	)			99,629				—
GFT debt
Revolving credit loan payable, interest at LIBOR rate plus 1.75%			(b	)			16,100				—
Revolving credit loan payable, interest at US prime rate			(b	)			232				—
Term note payable, interest at LIBOR rate plus 3.0%			(b	)			2,453				—
Triton
Facility A, interest of LIBOR plus the applicable margin			(c	)			40,729				—
Facility B, interest at LIBOR plus the applicable margin			(c	)			44,251				—
Facility C, interest at LIBOR plus the applicable margin			(c	)			44,251				—
Revolving credit facility, interest at LIBOR plus the applicable margin			(c	)			1,500				—
SSI
Notes payable to a financial institution, interest of rates based upon the bank’s prime rate			(d	)			12,750				—
Allied
Credit agreement, interest at various rates based on leverage ratios			(e	)			5,800				—
Other debt			(g	)			4,182				3,924
Total debt							271,877				207,924
Less: current maturities							(34,940	)			(3,209	)
Long-term debt						$	236,937			$	204,715

Debt as of December 31, 2009

(a) FOT had a $240 million US revolving line of credit and C$13.2 million (Canadian dollar) revolving line of credit, with the principal due in November 2011. Amounts outstanding at December 31, 2009 were $88.5 million and $11.1 million under the US and Canadian lines, respectively. Interest was payable every 30, 60 or 90 days based on interest rate elections. Amounts outstanding are collateralized by substantially all of Forum’s assets. Weighted average

 

F-29

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

interest rate (without the effect of hedging) at December 31, 2009 on all outstanding principal was 2.1%. FOT was in compliance with the covenants related to this facility at December 31, 2009. This line of credit was replaced by the Company’s senior secured credit facility in August 2010.

(b) GFT had a revolving line of credit of up to $35 million and a term loan in the amount of $19 million. Under the provisions of the term loan, amounts borrowed are subject to interest at the LIBOR rate plus 3%. Amounts outstanding at December 31, 2009 were $2.5 million at an interest rate of 3.28%. Under the revolving line of credit, GFT had borrowings of $0.2 million at the base rate of 3.25% and $16.1 million at the Eurodollar rate of 2.00%. The facility was secured by substantially all the assets of GFT. In conjunction with the Combination, this debt was paid through the funds obtained from the Company’s senior secured credit facility.

(c) Triton, in December 2009, through its UK and US subsidiaries, had a credit agreement and provided for up to $58.4 million and £54.6 million in term loans and credit facility borrowings, comprised of revolving facility commitments of up to $15.0 million and Facility A, Facility B and Facility C commitments of $16.8 million and £16.2 million, $13.3 million and £19.2 million, and $13.3 million and £19.2 million, respectively, at the effective date of the agreement. This credit agreement required quarterly payments of principal and interest with a maturity date for the revolving facility of December 31, 2013 and Facility A of between December 31, 2012 and December 31, 2013. The Facility B and Facility C commitments were repayable in full on their respective maturity dates of December 31, 2014 and December 31, 2015. Interest rates for the revolving and term loans under this credit agreement are based on interest rates tied to a margin calculation, LIBOR and a mandatory cost rate, if applicable, ranging from 2.5% to 5.5%. This debt was secured by debentures, bonds floating charges and pledges over certain of the Company’s subsidiary entities. In conjunction with the Combination, this debt was paid through the funds obtained from the Company’s senior secured credit facility.

(d) SSI had various notes payable to a financial institution. Each had annual interest at the greater of the bank’s Prime Rate in effect plus 1.25% or 5.75% (6.25% at December 31, 2009) and matured at various dates. The notes payable were secured by all assets of SSI. In conjunction with the Combination, this debt was paid through the funds obtained from the Company’s senior secured credit facility.

(e) Allied had a credit agreement, which gave Allied the ability to borrow up to $15.0 million under a revolver arrangement for working capital needs. The borrowing base was $16.1 million at December 31, 2009, and is calculated based upon 80% of receivables, 50% of finished goods inventory and 75% of the fixed asset values, all of which are subject to certain exclusions. Allied had $5.8 million outstanding under the credit agreement as of December 31, 2009. In conjunction with the Combination, this debt was paid through the funds obtained from the Company’s senior secured credit facility.

 

F-30

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Debt as of December 31, 2010

(f) In conjunction with the Combination, FET entered into a senior secured credit facility with several financial institutions. The credit facility provides for a $450.0 million revolving credit facility, including up to $75.0 million of letters of credit and up to $25.0 million in swingline loans, and matures in August 2014. In addition, the Company has the ability to increase the commitments under this facility by up to $150 million.

Amounts outstanding at December 31, 2010 were $204 million. Interest is payable every 30, 60 or 90 days based on interest rate elections. Amounts outstanding are collateralized by substantially all of FET’s assets. Weighted average interest rates (without the effect of hedging) at December 31, 2010 was 3.0%. The credit facility allows management to elect how interest will be computed which may be determined by reference to the London interbank offered rate, or LIBOR, plus an applicable margin between 2.0% and 3.75% per annum or a base rate plus an applicable margin between 0.5% and 2.25% per annum (with the applicable margin depending upon FET’s ratio of total funded debt to EBITDA).

This credit facility contains covenants which require FET to maintain certain financial ratios. These covenants are as follows:

 

•

Total funded debt to EBITDA (as defined in the credit facility) of not more than 3.75 to 1.0 for periods ending through June 30, 2011, 3.50 to 1.0 for periods ending from July 1, 2011 through June 30, 2012, 3.25 to 1.0 for periods ending from July 1, 2012 through June 30, 2013 and 3.00 to 1.0 for periods ending thereafter;

 

•

EBITDA to interest expense ratio (as defined in the credit facility) of not less than 3.0 to 1.0; and

 

•

Total balance sheet debt to total capitalization (as defined in the credit facility) of not more than 0.65 to 1.0.

Availability under the credit facility, considering the covenants discussed above, was approximately $210 million at December 31, 2010. The Company is in compliance with the aforementioned financial covenants at December 31, 2010.

Subsequent to December 31, 2010, we amended our credit facility to increase the commitment and we had significant increases in our debt amount related to acquisitions. See footnote 16, Subsequent Events.

Other debt

(g) Other debt consists primarily of upfront annual insurance premiums that have been financed and capital lease obligations.

 

F-31

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Debt issue costs

In conjunction with entering into the new senior secured facility, the Company incurred approximately $6.7 million in loan costs that have been capitalized and are amortized to interest expense over the term of the facility. As a result, approximately $1.8 million was amortized to interest expense for the year ended December 31, 2010. Due to the payment of the debt and replacement of the facilities held by certain combining entities, the related debt issue costs of $6.1 million that had been previously capitalized were fully written off in August 2010.

Future payments

Future principal payments under long-term debt, by year, are as follows (in thousands):

 

Year ending December 31,
2011		$	3,209
2012			715
2013			—
2014			204,000
Thereafter			—
		$	207,924

Allied and GFT redeemable preferred shares

Allied had issued shares of preferred stock to an investment advisor in lieu of payment of management fees. These shares were redeemable at $100 per share and paid an 8% dividend. As of December 31, 2009, there were 624 shares of its preferred stock outstanding. In conjunction with the Combination, these shares and the accrued dividends were redeemed for cash.

As part of GFT acquisitions prior to 2009, GFT had authorized and issued mandatorily redeemable preferred stock. Below is a description of each of Series of redeemable preferred shares. In conjunction with the Combination, these shares and the accrued annual dividends were redeemed for cash for the following amounts:

 

Series B		$	6.5 million
Series C			3.5 million
Series D			8.3 million
		$	18.3 million

Mandatorily redeemable Series B

As of December 31, 2009, 100,000 Series B preferred shares of GFT (“Series B”) were authorized and outstanding with a par value of $.001 per share. The Series B preferred stock (“Series B”) ranked senior to Series C and Series D preferred shares. The holders of Series B shares were

 

F-32

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

entitled to receive dividends at the rate of 6% per annum. Dividends were cumulative and payable on each anniversary of the date of issuance commencing with the fifth anniversary of that date. Each share of Series B preferred stock shall convert into one share of Series C preferred stock. For those Series B shares not converted to Series C shares in 2010, mandatory redemption began in 2011. The holders of Series B preferred shares, except as otherwise expressly provided by applicable law in the certificate of incorporation, were not entitled to vote. Due to the terms of the Series B preferred stock, the Company had recorded the value of the outstanding shares plus accreted interest as a liability.

Mandatorily redeemable Series C

As of December 31, 2009, 47,000 Series C preferred shares of GFT (“Series C”) were authorized with a par value of $.001. No shares were outstanding at December 31, 2009 but were outstanding at the time of the Combination and redemption due to the mandatory conversion of Series B preferred shares to Series C preferred shares. The Series C preferred shares (“Series C”) ranked senior to Series D preferred shares. The holder of Series C shares were entitled to receive dividends at the rate of 7% per annum. Dividends were cumulative and payable on each anniversary of the issue date commencing with the sixth anniversary of the issue date. The redemption value was equal to the issue price of the shares plus all unpaid, accreted interest. The Company had the right at any time to redeem Series C shares. The holders of Series C preferred shares, except as otherwise expressly provided by applicable law in the certificate of incorporation, were not entitled to vote.

Mandatorily redeemable Series D

As of December 31, 2009, 62,000 Series D preferred shares of GFT (“Series D”) were authorized and outstanding with a par value of $.001 per share. The holders of Series D preferred shares (“Series D”) were entitled to receive dividends at the rate of 6% per annum. In the event that all outstanding shares of Series D were not redeemed on the mandatory redemption date, the remaining outstanding shares of Series D were to continue to accrue dividends at the annual rate of 8% from the mandatory redemption date to the date on which there were no longer any shares of Series D outstanding. Dividends were cumulative and payable at the mandatory redemption date. The redemption value was equal to the issue price of the shares plus all unpaid, accreted interest. The Company had the right at any time to redeem Series D shares. The holders of Series D preferred shares, except as otherwise expressly provided by applicable law in the certificate of incorporation, were not entitled to vote. Due to the terms of the Series D preferred stock, the Company recorded the value of the outstanding shares plus accreted interest as a liability and accrued dividends are included in earnings as interest expense.

 

F-33

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

7. Income taxes

The components of the Company’s income before tax for the years ended December 31, 2008, 2009 and 2010 are as follows:

 

		2008				2009				2010
		(in thousands)
United States		$	42,391			$	18,026			$	24,162
Non United States			25,358				13,818				20,184
Income from continuing operations before taxes		$	67,749			$	31,844			$	44,346

The Company’s provision (benefit) for income taxes from continuing operations for the years ended December 31, 2008, 2009 and 2010 are as follows:

 

		2008				2009				2010
		(in thousands)
Current
United States Federal and state		$	24,341			$	4,334			$	13,869
Non-United States			13,429				8,111				7,606
Total Current			37,770				12,445				21,475
Deferred
United States Federal and state			(496	)			(2,241	)			132
Non-United States			(4,336	)			807				(1,310	)
Total Deferred			(4,832	)			(1,434	)			(1,178	)
Provision for income tax expense		$	32,938			$	11,011			$	20,297

 

F-34

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

The reconciliation between the actual provision for income taxes from continuing operations and that computed by applying the United States statutory rate to income from continuing operations before income tax and noncontrolling interests are outlined below. In 2008 and 2009, the United States statutory rate for purposes of this reconciliation is less than the corporate statutory rate of 35% as certain of the companies party to the Combination were subject to tax at 34% for United States purposes, which differs from the 35% that the Company is subject to in 2010.

 

		2008								2009								2010
		(In thousands)
Income tax expense at the statutory rate			$23,374				34.5	%			$11,048				34.7	%			$15,521				35.0%
Change resulting from
Impairment of goodwill and other intangible assets			11,497				17.0	%			—				—				—				—
State taxes, net of federal tax benefit			1,131				1.7	%			423				1.3	%			1,172				2.6%
Non-United States operations			(1,090	)			(1.6	)%			(2,003	)			(6.3	)%			(1,273	)			(2.9)%
Nondeductible expenses			1,636				2.4	%			797				2.5	%			3,936				8.9%
Domestic incentives			(779	)			(1.1	)%			(446	)			(1.4	)%			(1,107	)			(2.5)%
Prior year federal, non-U.S. and state tax			(3,698	)			(5.5	)%			2,048				6.4	%			1,431				3.2%
Other			867				1.2	%			(856	)			(2.7	)%			617				1.4%
			$32,938				48.6	%			$11,011				34.5	%			$20,297				45.7%

 

F-35

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

The primary components of deferred taxes include:

 

		2009				2010
		(in thousands)
Deferred Tax Assets
Reserves and accruals		$	3,249			$	4,788
Inventory			4,868				5,091
Stock awards			787				2,668
Interest rate swaps			1,670				1,442
Non-United States tax credit carryforwards			2,831				3,541
NOL and other tax credit carryforwards			2,223				1,579
Other			1,648				19
Total deferred tax assets			17,276				19,128
Deferred Tax Liabilities
Property and equipment			(3,529	)			(4,235	)
Goodwill and intangible assets			(25,593	)			(23,487	)
Unremitted non-United States earnings			(650	)			(740	)
Prepaid expenses and other			(1,171	)			(2,419	)
Total deferred tax liabilities			(30,943	)			(30,881	)
Net deferred tax liabilities		$	(13,667	)		$	(11,753	)

At December 31, 2010, the Company had $3.7 million of United States net operating loss carryforwards that expire in 2027. The company also had $1.0 million of non-United States foreign net operating loss carryforwards with indefinite expiration dates. All of the United States net operating losses relate to companies acquired by the Company. Use of these losses are subject to limitations under Section 382 of the Internal Revenue Code. The Company anticipates being able to fully utilize the losses prior to their expiration.

At December 31, 2010, the Company had $3.5 million of foreign tax credit carryforwards that are expected to be utilized in the carryforward period.

Goodwill from certain acquisitions is tax deductible due to the acquisition structure as an asset purchase or due to tax elections made by the Company and the respective sellers at the time of acquisition.

The Company is required to evaluate whether it is more likely than not that deferred tax assets will be realized. The Company believes that it is more likely than not that deferred tax assets at December 31, 2009 and 2010 will be utilized to offset future taxable income and the reversal of taxable temporary differences. Consequently, no valuation allowance has been recorded in the financial statements.

The Company is required to evaluate the need to provide United States income taxes on the undistributed earnings of non-United States subsidiaries. Taxes are provided as necessary with

 

F-36

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

respect to non-United States earnings that are not permanently reinvested. For all other non-United States subsidiaries, no United States taxes are provided because such earnings are intended to be reinvested indefinitely to finance non-United States activities.

The Company is the parent of a group of domestic companies which are included in the United States consolidated federal tax income short-period tax return. As a result of the Combination in August 2010, the Company will file pre-acquisition tax returns for all of the parties to the Combination except FOT. The Company will file a 2010 consolidated tax return which will include the full year earnings of FOT and the post-combination earnings of the other companies. The Company also files income tax returns in various states and non-United States jurisdictions. With few exceptions, the Company is no longer subject to income tax examination by tax authorities in these jurisdictions prior to 2007.

The Company accounts for uncertain tax positions in accordance with guidance in FASB ASC 740 which prescribes the minimum recognition threshold a tax position taken or expected to be taken in a tax return is required to meet before being recognized in the financial statements. A reconciliation of the beginning and ending amount of uncertain tax positions is as follows:

 

		(In thousands)
Balance at January 1, 2010		$	542
Additional based on tax positions related to prior years			1,553
Reduction based on tax positions related to prior years			—
Balance at December 31, 2010		$	2,095

The total amount of uncertain tax positions that, if recognized, would affect the Company’s effective tax rate was approximately $1.7 million as of December 31, 2010. The difference between this amount and the amount reflected in the tabular reconciliation above relates primarily to deferred United States federal and non-United States income tax benefits on uncertain tax positions related to United States federal and non-United States income taxes. The Company does not anticipate any significant changes to the unrecognized tax benefits within the next twelve months.

The Company recognizes interest and penalties related to uncertain tax positions within the provision for income taxes in the consolidated statement of income. As of December 31, 2009 and 2010, we had accrued approximately $0.1 million and $0.1 million, respectively, in interest and penalties. During the year ended December 31, 2009, we recognized $0.1 million in net interest and penalties charges related to uncertain tax positions. During the year ended December 31, 2010, we recognized no change in the interest and penalties related to uncertain tax positions.

As of December 31, 2010, the uncertain tax positions and accrued interest and penalties were not expected to be settled within one year and therefore are classified with other long-term liabilities. Increases as a result of positions taken during 2010 or in prior years were $1.6 million of which approximately $0.1 million were offset by tax benefits recognized in the current year

 

F-37

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

and therefore did not have an impact on the effective tax rate in 2010. The remaining $1.5 million increase relates primarily to uncertain tax positions that were not previously accrued and, consequently had an unfavorable impact on the effective tax rate in 2010.

8. Derivatives

As of December 31, 2010, the Company had interest rate swap agreements to convert variable interest payments related to $49 million of floating rate debt to fixed interest payments. These swaps expire in March and November 2011 and have a weighted average fixed rate of 5.1% plus the applicable margin. As of December 31, 2010, the Company also had an interest rate collar arrangement to reduce the variability in interest payments related to $20 million in floating rate debt. This interest rate collar instrument expires in November 2011 and has a floor interest rate of 4.36%, plus the applicable margin, and a cap interest rate of 5.36%, plus the applicable margin. The Company’s balance sheet at December 31, 2009 and 2010 included a derivative liability of approximately $4.3 million and $2.2 million, respectively.

These instruments, which the Company has designated as cash flow hedging instruments, meet the specific hedge criteria provided by the derivatives and hedging accounting guidance and any changes in their fair values are recognized in accumulated other comprehensive income or loss. Since the terms of the hedged item and the instruments substantially coincide, the hedge is expected to offset changes in expected cash flows due to fluctuations in the variable rate and, therefore, the Company currently does not expect any ineffectiveness.

The counterparties to the Company’s interest rate swap agreements are major international financial institutions with good credit ratings so nonperformance is not expected from them.

Certain derivative instruments were not designated for hedge accounting at inception. These derivatives are also recorded at fair value, which is measured using the market approach valuation technique. GFT and Triton had entered these interest rate swap agreements to hedge the interest rate risk exposure associated with a their respective debt. At December 31, 2009, the fair value of the swap agreements was recorded as a current and long-term liability of $0.4 million and $1.3 million, respectively. At December 31, 2010, the fair value of the swap agreements was recorded as a long-term liability of $2.2 million. Related to these swaps, the Company recorded $1.0 million of interest expense and $0.4 million as interest income in the year ended December 31, 2009 and 2010, respectively.

 

F-38

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Our financial assets and liabilities are measured at fair value on a recurring basis. There were no outstanding financial assets as of December 31, 2009 and 2010. The following fair value hierarchy table presents information about the Company’s financial liabilities measured at fair value on a recurring basis as of December 31, 2009 and 2010:

 

		Quoted prices in active markets for identical assets (Level 1)				Significant other observable inputs (Level 2)				Significant unobservable inputs (Level 3)				Balance as of December 31, 2009
		(in thousands)
Liabilities
Interest rate derivatives		$	—			$	—			$	6,007			$	6,007
Total Liabilities		$	—			$	—			$	6,007			$	6,007

 

		Quoted prices in active markets for identical assets (Level 1)				Significant other observable inputs (Level 2)				Significant unobservable inputs (Level 3)				Balance as of December 31, 2010
		(in thousands)
Liabilities
Interest rate derivatives		$	—			$	—			$	4,356			$	4,356
Total Liabilities		$	—			$	—			$	4,356			$	4,356

The following table sets forth a reconciliation of changes for the years ended December 31, 2008, 2009 and 2010 in the fair value of financial liabilities classified as Level 3 in the fair value hierarchy.

 

		December 31,
		2008				2009				2010
		(in thousands)
Balance at beginning of period		$	(2,254	)		$	(6,618	)		$	(6,007	)
Total Gains or (Losses) (Realized or Unrealized):
Included in Earnings			(809	)			(1,001	)			(441	)
Included in Other Comprehensive Income			(3,555	)			1,612				2,092
Purchases, Issuances and Settlements			—				—				—
Transfers In and/or Out of Level 3			—				—				—
Balance at end of period		$	(6,618	)		$	(6,007	)		$	(4,356	)

 

F-39

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

9. Commitments and contingencies

Litigation

In the ordinary course of business, the Company is, and in the future, could be involved in various pending or threatened legal actions, some of which may or may not be covered by insurance. Management has reviewed pending judicial and legal proceedings, reasonably anticipated costs and expenses in connection with such proceedings, and availability and limits of insurance coverage, and has established reserves that are believed to be appropriate in light of those outcomes that are believed to be probable and can be estimated. The reserve accrued at December 31, 2010 is insignificant. In the opinion of management, the amount of ultimate liability, if any, with respect to these actions will not have a material adverse effect on the Company’s financial statements.

Portland Harbor Superfund litigation

In May 2009, one of our subsidiaries (which is presently a dormant company with nominal assets except for rights under insurance policies) was named along with many defendants in a suit filed by the Port of Portland, Oregon seeking reimbursement of costs related to a five-year study of contaminated sediments at the port. In March 2010, the subsidiary also received a notice letter from the EPA indicating that it had been identified as a potentially responsible party with respect to environmental contamination in the “study area” for the Portland Harbor Superfund Site. Under a 1997 indemnity agreement, our subsidiary is indemnified by a third party with respect to losses relating to environmental contamination. As required under the indemnity agreement, our subsidiary provided notice of these claims, and the indemnitor has assumed responsibility and is providing a defense of the claims. Although we believe that it is unlikely that our subsidiary contributed to the contamination at the Portland Harbor Superfund Site, the potential liability of our subsidiary and the ability of the indemnitor to fulfill its indemnity obligations cannot be quantified at this time.

 

F-40

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Operating leases

The Company has operating leases for warehouse, office space, manufacturing facilities and equipment. The leases generally require the Company to pay certain expenses including taxes, insurance, maintenance, and utilities. The minimum future lease commitments under noncancelable leases in effect at December 31, 2010 are as follows for the respective years ended December 31:

 

		(In thousands)
2011		$	10,033
2012			6,758
2013			4,339
2014			2,327
2015			1,403
Thereafter			6,236
		$	31,096

Total rent expense was $7.5 million, $9.2 million and $11.6 million under operating leases for the years ended December 31, 2008, 2009 and 2010, respectively.

Letters of credit and guarantees

The Company executes letters of credit and guarantees in the normal course of business to secure the delivery of product from specific vendors and also to guarantee the Company fulfilling certain performance obligations relating to certain large contracts. At December 31, 2010, the Company had $9.4 million in letters of credit and guarantees.

10. Stockholders’ equity and employee benefit plans

Combination

On August 2, 2010, the Company completed the Combination pursuant to which the shareholders of the companies exchanged all of their common stock for common stock of FOT. In conjunction with the Combination, FOT changed its name to Forum Energy Technologies, Inc.

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

The shareholders received the following number of FET shares for each share of the respective companies.

 

Triton			.3562 shares
Subsea			.3168 shares
Global Flow			.9886 shares
Allied			.4623 shares

In conjunction with the Combination, other events occurred including;

 

•

the conversion of options to purchase shares of the legacy companies’ shares to options to purchase FET shares,

 

•

the conversion of certain restricted legacy shares to FET restricted shares,

 

•

conversion of certain legacy options and shares to cash

 

•

an offer by the majority shareholder to purchase shares from other shareholders, and

 

•

an offer for shareholders to purchase additional FET shares.

Conversion of options and restricted shares

FOT

While FOT changed its name to FET, option holders of FOT common stock retained their options unchanged. FOT restricted stock was also unchanged due to the Combination.

Allied, GFT and SSI options

The options related to Allied, GFT and Subsea were converted based on the conversion ratios described above. The respective exercise price changed in proportion so that the total expected proceeds from the now converted options to purchase FET shares would be the same as the expected proceeds from the legacy options.

Triton Series A and B units

Triton had issued Series A and B time-based management units which vested over time into common units. Depending on certain factors such as whether the person was an accredited investor or the person’s country of residency, the Series A units converted into:

 

•

options to purchase FET shares at a ratio of .25 options per each Series A unit, or

 

•

restricted or unrestricted FET shares based on the legacy vesting schedule at a ratio of .171 share per each Series A unit, and/or cash.

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Depending on certain factors, the Series B units converted into:

 

•

options to purchase FET shares at a ratio of .4809 options per each Series B unit, or

 

•

cash.

SSI and GFT convertible preferred stock

In 2008 and 2009, SSI granted to its major shareholder and to certain members of management 7,055 restricted convertible preferred stock awards. The preferred stock accrued an 18% cumulative and compounding dividend payable in common stock. Accrued but not declared dividends amounted to $2.0 million at December 31, 2009. In conjunction with the Combination, these shares and the accrued common stock dividends were converted to SSI common stock and, in turn, converted to FET shares at the applicable ratio.

As of December 31, 2009, in relation to GFT’s convertible preferred shares, 62,000 shares were outstanding with a par value of $.001 per share. The Series A preferred stock (“Series A”) ranked senior to all other GFT capital stock. In conjunction with the Combination, these shares were converted to FET shares at the applicable ratio.

Allied and GFT redeemable preferred shares

The redeemable preferred shares previously issued by Allied and GFT were redeemed for cash in conjunction with the Combination. See more discussion under the “Debt and redeemable preferred shares” footnote.

Offer to purchase shares

In conjunction with the Combination, the Company purchased 87,938 FET shares or approximately $25 million at a price of $284.29 each share. The amount is included in Treasury Stock in the Company’s Consolidated Balance Sheet.

Offer to sell shares

In conjunction with the Combination, the Company offered to sell FET shares to certain accredited investors at a price of $284.29 per share. In addition to this offer, purchasers obtained a warrant to purchase additional FET shares equal to one-half of the number of FET shares purchased. The warrants are discussed below. Detail of the purchased shares is as follows:

 

Purchaser		Shares purchased				Amount				Warrants granted
Majority shareholder			175,876			$	50.0 million				87,938
All others			42,660			$	12.1 million				21,321

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Capital from the majority shareholder

In addition to the above $50 million from the majority shareholder, the same shareholder is committed to purchasing an additional $50 million of common shares by August 2011. The commitment to purchase the shares is at a price per share of $284.29 plus a 5% annual increase or approximately $298.50 per share at August 2011. Similar to the initial purchase of shares, the shareholder will receive a warrant to purchase a share of common stock for every two shares purchased. Based on the August 2011 price, warrants of 83,752 would be issued.

Warrants

The warrants issued pursuant to the above offers to sell shares have an initial exercise price of $284.29 per FET share and are exercisable any time up to the expiration date. The exercise price increases 0.5% at the end of each month which equates to an annual increase of 6%. The warrants expire the earlier of five years from the initial issuance or 2.5 years after the consummation of an initial public offering of the Company stock or if other events occur such as a merger with another company.

The warrants outstanding as of December 31, 2010 were recorded to stockholders’ equity at their fair value. A fair value of $71.62 per warrant was determined using the Black-Scholes pricing model with the following assumptions:

 

•

Expected life of 5 years

•

Volatility of 36.2%

•

Dividend yield of 0%

•

Risk-free interest rate of 2.05%

Employee benefit plans

Each of the legacy entities maintained separate employee savings plans such as contributory profit sharing plans and/or 401(k) savings plan, which benefit eligible employees. Employees are allowed to make contributions to the respective plan in which they participate up to certain limits. The companies made employer contributions either at their discretion or as a matching percentage. The expense under these various plans were $3.5 million, $2.9 million and $3.3 million for the years ended December 31, 2008, 2009 and 2010, respectively.

11. Stock based compensation

FET share-based compensation plan

In August 2010, the Company created the 2010 Stock Incentive Plan (the “Plan”) to allow for employees, directors and consultants of the Company and its subsidiaries to maintain stock ownership in the Company through award of stock options, restricted stock or any combination thereof. When certain legacy Triton units were converted, the options granted in 2010 were from this Plan.

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Stock options

The exercise price of each option is based on the fair value of the Company’s stock at the date of grant. Options may be exercised over a ten-year period and generally vest annually in equal increments over four years. The Company’s policy for issuing stock upon a stock option exercise is to issue new shares. The following tables provide additional information related to the options:

 

2010 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			—			$	—							$	—
Granted			133,782				284
Exercised			—				—
Forfeited			—				—
Total outstanding			133,782				284				9.6			$	7,453
Options exercisable			—			$	—				—			$	—

The above intrinsic value at December 31, 2010, is the amount by which the fair value of the underlying share exceeds the exercise price of an option as of December 31, 2010.

The assumptions used in the Black-Scholes to estimate the fair value of the options granted in 2010 are as follows:

 

		2010
Weighted average fair value		$	105
Assumptions
Expected life (in years)			6.25
Volatility			34%
Dividend yield			0.0%
Risk free interest rate			1.54% - 2.0%

 

F-45

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

FOT share-based compensation plan

FOT’s 2005 Stock Incentive Plan (the “FOT Plan”) permitted employees, directors and consultants of FOT and its subsidiaries to maintain stock ownership in the Company through award of stock options, restricted stock or any combination thereof. For stock options, the exercise price of each option is based on the fair value of the Company’s stock at the date of grant and the options may be exercised over a five-year period and vest annually in equal increments over three or four years. The Company’s policy for issuing stock upon a stock option exercise is to issue new shares. The following tables provide additional information related to the options:

 

2008 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			34,079			$	215							$	—
Granted			4,610				320
Exercised			(706	)			132
Forfeited			(5,702	)			273
Total outstanding			32,281				221				3.1			$	2,222
Options exercisable			9,870				156				2.6			$	1,325

 

2009 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			32,281			$	221							$	—
Granted			11,380				225
Exercised			(607	)			125
Forfeited			(6,539	)			190
Total outstanding			36,515				230				2.9			$	—
Options exercisable			9,543				161				1.6			$	614

 

2010 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			36,515			$	221				2.9			$	—
Granted			—				—
Exercised			(500	)			100
Forfeited			(1,900	)			181
Total outstanding			34,115				234				2.9			$	—
Options exercisable			24,742				223				1.4			$	2,890

 

F-46

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

The intrinsic value of options exercised during 2008 was approximately $0.1 million. The above intrinsic value at December 31, 2008, is the amount by which the fair value of the underlying share exceeds the exercise price of an option as of December 31, 2008.

The intrinsic value of the options exercised during 2009 was approximately $0.1 million. The above intrinsic value at December 31, 2009, is the amount by which the fair value of the underlying share exceeds the exercise price of an option as of December 31, 2009.

The intrinsic value of the options exercised during 2010 was approximately $0.1 million. The above intrinsic value at December 31, 2010, is the amount by which the fair value of the underlying share exceeds the exercise price of an option as of December 31, 2010.

The assumptions used in the Black-Scholes to estimate the fair value of the options granted in 2008 and 2009 are as follows:

 

		2008				2009
Weighted average fair value		$	72.22			$	67.01
Assumptions
Expected life (in years)			3.8				3.8
Volatility			25.2%				38.9%
Dividend yield			0.0%				0.0%
Risk free interest rate			2.10%				0.32%

Allied share-based compensation plan

Stock option awards granted under the Allied plan generally vest over a four-year period, with one-fourth vesting in each successive year so that the option is fully exercisable after four years. Such awards generally have ten-year contractual terms.

The following provides additional information related to the options:

 

2008 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			24,905			$	216							$	1,835
Granted			1,225				216
Exercised			—				—
Forfeited			(832	)			216
Total outstanding			25,298				216				9.0			$	1,864
Options exercisable			16,317				216				9.0			$	1,202

 

F-47

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

2009 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			25,298			$	216				9.0			$	1,864
Granted			1,987				216
Exercised			(23	)			216
Forfeited			(184	)			216
Total outstanding			27,078				216				8.2			$	235
Options exercisable			18,624			$	216				8.0			$	162

 

2010 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			27,078			$	216				8.2			$	235
Granted			—				—
Exercised			—				—
Forfeited			(14,064	)			216
Total outstanding			13,014				216				7.2			$	1,610
Options exercisable			8,458			$	216				7.0			$	1,046

The assumptions used in the Black-Scholes to estimate the fair value of the options granted in 2008 and 2009 are as follows:

 

		2008				2009
Weighted average fair value		$	29.50			$	38.87
Assumptions
Expected life (in years)			6.25				6.25
Volatility			45%				50%
Dividend yield			0.0%				0.0%
Risk free interest rate			4.25%				2.79%

GFT share based compensation plan

GFT had its 2005 Stock Incentive Plan (“the GFT Plan”) which provided for the granting of nonqualified stock options, restricted stock awards, or any combination of the foregoing, as is best suited to the circumstances of the particular employee, consultant or director as provided herein. Option awards under the Plan vest 33% on the first anniversary of the grant date and 33% each year for the following two years and expire seven years from the grant date.

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

The following provides additional information related to the options:

 

2008 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			17,093			$	133				5.9			$	3,104
Granted			—
Exercised			—
Forfeited			—
Total outstanding			17,093				133				4.9			$	2,691
Options exercisable			8,217				120				4.9			$	1,391

 

2009 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			17,093			$	133				4.9			$	2,691
Granted			—
Exercised			—
Forfeited			(1,088	)			133
Total outstanding			16,005				133				3.9			$	1,467
Options exercisable			13,346				127				3.8			$	1,305

 

2010 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			16,005			$	133				3.9			$	1,467
Granted			—
Exercised			—
Forfeited			(1,212	)			129
Total outstanding			14,793				134				2.9			$	3,052
Options exercisable			14,793				134				2.9			$	3,052

 

F-49

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

SSI share-based compensation plan

Effective January 2007, the Company established the Subsea Services International, Inc. 2007 Stock Incentive Plan (“SSI Plan”). Awards granted under this plan generally vest over three years and have a six year contractual term. The following provides more information related to these options:

 

2008 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			1,467			$	316				6.2			$	—
Granted			—
Exercised			—
Forfeited			(525	)			316
Total outstanding			942				316				5.2			$	—
Options exercisable			314				316				4.4			$	—

 

2009 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(in thousands)
Beginning balance			942			$	316				5.2			$	—
Granted			587				316
Exercised			—
Forfeited
Total outstanding			1,529				316				4.2			$	—
Options exercisable			629				316				3.4			$	—

 

2010 Activity		Number of shares				Weighted average exercise price				Remaining weighted average contractual life in years				Intrinsic value
														(In thousands)
Beginning balance			1,529			$	316				4.2			$	—
Granted			316				316
Exercised			—
Forfeited			—				—
Total outstanding			1,845				316				3.2			$	45
Options exercisable			1,137				316				2.4			$	28

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Restricted stock for FET combined

Restricted stock vests over a three or four year period from the date of grant. Further information about the restricted stock follows:

 

		Restricted stock
2008 Activity
Nonvested at the beginning of the year			18,932
Granted			2,142
Vested			(8,686	)
Cancelled			(250	)
Nonvested at the end of the year			12,138
2009 Activity
Nonvested at the beginning of the year			12,138
Granted			1,248
Vested			(5,498	)
Cancelled			(600	)
Nonvested at the end of the year			7,288
2010 Activity
Nonvested at the beginning of the year			7,288
Granted			6,576
Vested			(4,133	)
Cancelled			(649	)
Nonvested at the end of the year			9,082

The weighted average grant date fair value of the restricted stock was $341, $225 and $282 per share during the years ended December 31, 2008, 2009 and 2010, respectively.

For all the plans, the total amount of compensation expense recorded was approximately $2.9 million, $3.3 million and $5.1 million for the years ended December 31, 2008, 2009 and 2010, respectively. As of December 31, 2010, the Company expects to record compensation expense of approximately $15.6 million over the remaining term of the restricted stock and options of approximately four years. Future stock option grants will result in additional compensation expense.

12. Related party transactions

FOT has related party transactions, including sales and leasing activity with certain former owners of acquired companies or certain stockholders. The dollar amounts related to these related party activities are not significant to the Company’s consolidated financial statements. For GFT, in conjunction with the acquisition of one of its subsidiaries, the Company entered into various operating lease agreements with the former principals for office and warehouse space. For the

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

years ended December 31, 2008, 2009 and 2010, the Company paid $0.3 million each year in lease payments to these affiliates. GFT also utilizes a certain agent, which is owned by a former owner. The amount paid to this agent for the years ended December 31, 2009 and 2010 was $0.2 million each year.

Allied leases two facilities from a stockholder in FET. Allied paid $0.7 million, $0.8 million and $0.9 million in lease payments for the years ended December 31, 2008, 2009 and 2010, respectively. Allied purchased inventory and services from a shareholder of $5.0 million, $3.1 million and $4.2 million from a shareholder for the years ended December 31, 2008, 2009 and 2010, respectively. The Company sold $0.1 million, $1.6 million and $0.1 million of equipment and services to a shareholder during the years ended December 31, 2008, 2009 and 2010, respectively.

13. Business segments

The Company’s operations are divided into the following segments: (1) Drilling and Subsea and (2) Production and Infrastructure and (3) Corporate. Our Drilling and Subsea segment designs, manufactures, and provides products and related services to the drilling and intervention sectors as well as to the subsea services and construction sectors. The company’s Production and Infrastructure segment designs, manufactures and provides surface process and pipeline equipment, specialty pipeline construction equipment, a broad range of valves, surface completion and flow equipment, and offer supporting aftermarket services.

The Company’s reportable segments are strategic units that offer distinct products and services. They are managed separately since each business segment requires different marketing strategies due to customer specifications. The Company evaluates the performance of its reportable segments based on operating income. This segmentation is representative of the manner in which our Chief Operating Decision Maker (“CODM”) and our Board of Directors views the business. We consider the CODM to be the Chief Executive Officer.

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Summary financial data by segment follows (in thousands):

 

		Year ended December 31, 2008
		Drilling and subsea				Production and infrastructure				Corporate				Consolidated				Gain/(Loss) on sale of assets not part of segment income				Total
Revenues		$	658,804			$	313,747			$	—			$	972,551			$	—			$	972,551
Depreciation and amortization			27,475				7,439				—				34,914				—				34,914
Operating income			67,041				22,728				—				89,769				619				90,388
Capital expenditures			32,066				7,576				—				39,642				—				39,642

 

		Year ended December 31, 2009
		Drilling and subsea				Production and infrastructure				Corporate				Consolidated				Gain/(Loss) on sale of assets not part of segment income				Total
Revenues		$	455,019			$	222,359			$	—			$	677,378			$	—			$	677,378
Depreciation and amortization			30,296				8,142				—				38,438				—				38,438
Operating income			38,226				12,118				—				50,344				(137	)			50,207
Capital expenditures			12,487				2,591				—				15,078				—				15,078
Total Assets			664,586				175,640				—				840,226				—				840,226
Goodwill			281,647				18,929				—				300,576				—				300,576
		Year ended December 31, 2010
		Drilling and subsea				Production and infrastructure				Corporate				Consolidated				Gain/(Loss) on sale of assets not part of segment income				Total
Revenues		$	474,306			$	273,029			$	—			$	747,335			$	—			$	747,335
Depreciation and amortization			25,777				7,439				—				33,216				—				33,216
Operating income			53,533				22,614				(3,331	)			72,816				461				73,277
Capital expenditures			13,188				6,436				—				19,624				—				19,624
Total assets			637,395				179,686				1,251				818,332				—				818,332
Goodwill			275,528				18,853				—				294,381				—				294,381

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

For internal management reporting, and therefore in the above segment information, Corporate includes expenses associated with the Company’s Corporate Office, as well as the Company’s interest income, interest expense and acquisition-related costs of the Company.

Revenues by shipping location and long-lived assets by country were as follows (in thousands):

 

		Year ended December 31,
		2008				2009				2010
Revenues:
United States		$	547,141			$	352,578			$	408,615
Canada			102,494				55,100				69,624
Latin America			18,697				28,300				26,228
Europe & Africa			173,673				131,600				119,204
Middle East			42,381				23,000				18,245
Asia-Pacific			88,165				86,800				105,419
Total revenues		$	972,551			$	677,378			$	747,335

 

		Year ended December 31,
		2009				2010
Long-lived assets:
United States		$	271,598			$	254,615
Canada			16,969				17,545
Latin America			1,584				1,551
Europe & Africa			198,277				191,487
Middle East			3,264				3,251
Asia-Pacific			8,345				7,776
Total long lived assets		$	500,037			$	476,225

14. Acquisitions

During the year ended December 31, 2008, the Company completed the acquisition of six companies. There were no significant acquisitions in 2009 or 2010. The Company allocated the total purchase consideration to the assets acquired and liabilities assumed based on their respective fair values as of the acquisition date. In making its purchase price allocations, the assets and liabilities acquired in these acquisitions are valued based upon estimated fair values of the tangible assets and appraisals of the intangible assets. The estimates used in valuing all intangible assets were based upon assumptions believed to be reasonable at the date of acquisition. The 2008 acquisitions are discussed below.

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Dynamic Positioning Services Ltd.

In March 2008, the Company acquired Dynamic Positioning Services Ltd (“DPS”). Based in Aberdeen, Scotland, DPS specializes in equipment rental, product sales, engineering sales, engineering solutions and personnel supply to leading oil and gas companies worldwide. The financial operating results of DPS are included in the Company’s consolidated financial statements beginning from March 14, 2008. The Company acquired DPS for total consideration of $84.9 million. Total consideration included $74.6 million in cash, contingent deferred loan notes of $3.4 million and common stock valued at $6.3 million. The Company incurred acquisition related fees and expenses of $0.6 million. Such consideration has been allocated to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. Such allocation resulted in goodwill of $45.3 million. The following table summarizes the fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Cash and cash equivalents		$	280
Accounts receivable			6,777
Inventory			350
Revenue equipment, property and equipment			20,823
Non-tax-deductible Goodwill			45,313
Intangible assets (primarily customer relationships)			17,655
Deferred tax asset			1,457
Other assets			6,923
Total assets acquired			99,578
Accounts payable			(3,022	)
Accrued liabilities			(721	)
Deferred tax liability			(4,943	)
Other liabilities			(1,783	)
Long-term debt			(4,160	)
Total liabilities assumed			(14,629	)
Total net assets acquired		$	84,949

Associated Dynamic, Ltd.

In July 2008, the Company purchased Associated Dynamics, Ltd. (“ADI”). ADI is a wholesaler of bearings used in the drilling industry primarily selling to distributors and original equipment manufacturers. This acquisition provides access to a global distribution network for the Company’s drilling consumables product line. The results of ADI’s operations are included in the consolidated financial statements of the Company beginning August 1, 2008. The purchase was for cash of $17.6 million, plus common stock of the Company valued at $5.5 million. Such consideration has been allocated to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. Such

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

allocation resulted in goodwill of $7.3 million. The following table summarizes the fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Current assets, net of cash acquired		$	12,952
Property and equipment			148
Other assets			323
Intangible assets (primarily customer relationships)			6,200
Non-tax-deductible goodwill			7,329
Current liabilities			(1,768	)
Deferred income tax (asset) liability, net			(1,991	)
Net assets acquired		$	23,193
Cash consideration, net of cash acquired		$	17,646
Issuance of stock			5,547
Total consideration		$	23,193

Equipment and Technical Services Inc.

In December 2008, the Company acquired Equipment and Technical Services Inc. (“ETS”). Based in Houston, ETS specializes in equipment rental, sales and technical support to the marine and offshore industries. The financial operating results of ETS are included in the Company’s consolidated financial statements beginning from December 23, 2008. The Company acquired ETS for total consideration of $27.4 million. Total consideration included $17.0 million in cash and common stock valued at $8.5 million. The Company incurred acquisition related fees and expenses of $1.9 million. Such consideration has been allocated to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. Such allocation resulted in goodwill of $14.6 million. The following table summarizes the fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Cash and cash equivalents		$	1,185
Accounts receivable			5,278
Inventory			101
Revenue equipment, property and equipment			7,230
Non-tax-deductible Goodwill			14,578
Intangible assets (primarily customer relationships)			2,770
Other assets			529
Total assets acquired			31,671
Accounts payable			(889	)
Accrued liabilities			(73	)
Deferred tax liability			(1,069	)
Other liabilities			(2,265	)
Total liabilities assumed			(4,296	)
Total net assets acquired		$	27,375

 

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Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Other acquisitions

In addition to the acquisitions previously mentioned, the Company had three other acquisitions during the year ended December 31, 2008. Total consideration was $31.0 million, which consisted of $25.3 million in cash, loan notes of $2.1 million and common stock valued at $2.8 million. The Company incurred acquisition related fees and expenses of $0.8 million. Such consideration was allocated to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the respective acquisition dates. The following table summarizes the fair values of the assets acquired and the liabilities assumed as of the acquisition dates (in thousands):

 

Cash and cash equivalents		$	3,208
Accounts receivable			4,654
Revenue equipment, property and equipment			6,143
Non-tax-deductible Goodwill			13,962
Intangible assets (primarily customer relationships)			8,599
Other assets			165
Total assets acquired			36,731
Accounts payable			(1,149	)
Accrued liabilities			(248	)
Deferred tax liability			(2,711	)
Other liabilities			(1,614	)
Total liabilities assumed			(5,722	)
Total net assets acquired		$	31,009

Pro forma information related to the acquisition (unaudited)

The following table provides pro forma information related to the acquisitions (in thousands, except per share data):

 

		Year ended December 31, 2008
Revenue		$	1,010,296
Net income			39,282
Basic earnings per share			30.76
Diluted earnings per share			30.08

The pro forma information for the year ended December 31, 2008 assumes the acquisitions listed above occurred at the beginning of the period.

The combined results of operations of the acquired businesses have been adjusted to reflect additional depreciation of fixed assets and amortization of intangible assets subject to amortization. Pro forma interest expense was calculated on notes payable and draws on the Company’s available line of credit at a rate of 7%, as if the businesses were acquired at the beginning of the period.

 

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Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Although the Company believes the accounting policies and procedures used to prepare the pro forma schedules are reasonable, these pro forma results do not purport to be indicative of the actual results which would have been achieved had the acquisition been consummated on January 1, 2008. The amounts shown are not intended to be a projection of future results.

15. Discontinued operations

Due to deteriorating economic conditions and the uncertainty surrounding the political climate, during 2009 GFT discontinued the valve operations of its Venezuelan subsidiary. For the year ended December 31, 2008 and 2009, the subsidiary incurred losses of $0.4 million and $1.3 million, respectively.

The assets and liabilities classified as discontinued operations as of December 31, 2009 were as follows (in thousands):

 

		2009
Assets
Accounts receivable		$	230
Total assets of discontinued operations		$	230
Liabilities
Accounts payable		$	10
Other liabilities			763
Total liabilities of discontinued operations		$	773

The results of discontinued operations were as follows (in thousands):

 

		2008				2009
Net sales		$	2,937			$	104
Operating loss from discontinued operations			(396	)			(1,342	)
(Provision) benefit from income taxes			—				—
Loss from discontinued operations		$	(396	)		$	(1,342	)

The Company has reclassified from continuing operations to discontinued operations, for periods presented, the results of operations and assets and liabilities for the subsidiary.

16. Subsequent events

The Company has evaluated subsequent events through the date these financial statements were issued.

Effective June 29, 2011, we amended our senior secured credit facility to, among other things, increase the commitment to $750 million. In conjunction with the acquisitions made subsequent to December 31, 2010, discussed below, the Company borrowed on its credit facility an amount of approximately $520 million.

 

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Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Subsequent to December 31, 2010, there were eight acquisitions, of which, the significant ones are discussed below.

In February 2011, the Company purchased Wood Flowline Products, LLC (“WFP”). WFP manufactures pressure control and flow equipment products that are principally used in the fracturing and well stimulation process. WFP also provides on-site recertification and refurbishment services of the associated flow equipment products. This acquisition provides the Company new exposure to the growing well completions sector, specifically focused on the development of North American unconventional shale and tight sands resources. The results of WFP’s operations have been included in the Company’s consolidated financial statements beginning February 1, 2011 and will be included in the Company’s Production and Infrastructure segment. The Company incurred acquisition related fees and expenses of $0.4 million. WFP recorded revenue and earnings of $22.1 million and $4.9 million, respectively, from the time of acquisition through June 30, 2011. The purchase price included: (1) cash of $32.7 million, (2) 35,000 shares of common stock of the Company valued at $340 per share based on an internal valuation and (3) two separate contingent consideration payments which may be payable in cash and/or shares of Company stock based upon WFP’s 2011 and 2012 calendar year earnings as defined in the purchase and sale agreement. The fair value of the contingent consideration was estimated to be $13.4 million based on an internal valuation of the earnings level that the acquired company is expected to achieve. The total consideration has been allocated on a preliminary basis to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. The fair value of the contingent consideration payment was remeasured as of June 30, 2011 at $16.2 million and is included in “Contingent consideration liability” in the consolidated balance sheet. The change in fair value of $2.8 million is included in “Contingent consideration” in the consolidated statements of operations.

The following table summarizes the preliminary fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Current assets, net of cash acquired		$	12,733
Property and equipment			3,239
Intangible assets (primarily customer relationships)			16,800
Non-tax-deductible goodwill			29,893
Current liabilities			(4,654	)
Net assets acquired		$	58,011

In April 2011, the Company purchased Phoinix Global LLC (“Phoinix”), a provider of high pressure flow control equipment and products utilized in the well stimulation and flow back processes of oil and gas well completion based in Alice, Texas. This acquisition adds to the Company’s completion products capabilities through a product offering that includes fluid-ends for frac pressure pumps, plug valves, relief valves, chokes, manifolds, manifold trailers and flow equipment transport trucks. The results of the Phoinix operations have been included in the Company’s consolidated financial statements beginning May 1, 2011 and will be included in the

 

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Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

Company’s Production and Infrastructure segment. The Company incurred acquisition related fees and expenses of $0.2 million. Phoinix recorded revenue and earnings of $10.6 million and $1.7 million, respectively, from the time of acquisition through June 30, 2011. The purchase price included: (1) cash of $23.6 million (subject to working capital adjustments), (2) 20,252 shares of common stock of the Company valued at $395 per share based on an internal valuation and (3) two separate contingent consideration payments which may be payable in cash based upon Phoinix’s 2011 and 2012 calendar year earnings as defined in the purchase and sale agreement. The fair value of the contingent consideration was estimated to be $16.3 million based on an internal valuation of the earnings level that the acquired company is expected to achieve. The total consideration has been allocated on a preliminary basis to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. The Company is still assessing the economic characteristics of certain customer relationships. The Company expects to substantially complete this assessment during the third quarter of 2011 and may adjust amounts recorded to reflect any revised evaluations. The fair value of the contingent consideration payment was remeasured as of June 30, 2011 at $19.3 million and is included in “Contingent consideration liability” in the consolidated balance sheet. The change in fair value of $3.0 million is included in “Contingent consideration” in the consolidated statements of operations.

The following table summarizes the preliminary fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Current assets, net of cash acquired		$	11,496
Property and equipment			1,350
Intangible assets (primarily customer relationships)			17,600
Non-tax-deductible goodwill			24,570
Current liabilities			(7,132	)
Net assets acquired		$	47,884

In July 2011, the Company acquired Cannon Services (“Cannon”), based in Stafford, Texas, and is a provider of standard and customized clamp and stamped metal protection systems used to shield the downhole control lines and gauges during their installation and provide protection during production enhancement operations. The purchase price included: (1) $48.7 million of cash (subject to working capital adjustments) and (2) 20,944 shares of common stock. The results of Cannon’s operations will be included in the Company’s consolidated financial statements beginning July 1, 2011.

In July 2011, the Company acquired AMC Global Group, Ltd. (“AMC”), based in Aberdeen, Scotland, and designs and manufactures specialized torque equipment for tubular connections, including high torque stroking units, fully rotational torque units and portable torque units for field deployment and related control systems, and provides aftermarket service. The purchase price included: (1) $42.5 million of cash (subject to working capital adjustments) and (2) 16,200 shares of common stock. The results of AMC’s operations will be included in the Company’s consolidated financial statements beginning July 1, 2011.

 

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Notes to consolidated financial statements

December 31, 2008, 2009 and 2010 (continued)

 

In July 2011, the Company acquired P-Quip, Ltd. (“P-Quip”), based in Kilbirnie, Scotland, a manufacturer of proprietary mud pump fluid end assemblies, mud pump rod systems, liner retention systems, valve cover retention systems and other drilling flow control products. The purchase price included $32.4 million of cash (subject to working capital adjustments). The results of P-Quip’s operations will be included in the Company’s consolidated financial statements beginning July 1, 2011.

On July 29, 2011, the Company acquired Davis-Lynch LLC (“Davis-Lynch”), a provider of proprietary, downhole cementing and casing products based in Pearland, Texas. The purchase price included $316.0 million of cash (subject to working capital adjustments). The results of Davis-Lynch’s operations will be included in the Company’s consolidated financial statements beginning August 1, 2011.

 

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Consolidated balance sheets

at December 31, 2010 and June 30, 2011

(Unaudited)

 

		December 31,				June 30,
(in thousands of dollars, except share information)		2010				2011
Assets
Current assets
Cash and cash equivalents		$	20,348			$	66,137
Accounts receivable—trade, net			117,656				159,395
Inventories, net			173,777				217,024
Prepaid expenses and other current assets			18,051				13,998
Costs and estimated profits in excess of billings			3,660				18,555
Deferred income taxes, net			8,615				6,481
Total current assets			342,107				481,590
Property and equipment, net of accumulated depreciation			90,632				104,496
Deferred financing costs, net			6,458				7,749
Intangibles, net			80,159				111,613
Goodwill			294,381				358,433
Other long-term assets			4,595				4,630
Total assets		$	818,332			$	1,068,511
Liabilities and Equity
Current liabilities
Current portion of long-term debt and capital lease obligations		$	3,209			$	1,940
Accounts payable—trade			61,981				81,044
Accrued liabilities and other current liabilities			44,542				56,275
Contingent consideration liability			—				35,500
Deferred revenue			7,130				11,187
Billings in excess of costs and profits recognized			7,889				9,802
Derivative instruments			2,194				940
Total current liabilities			126,945				196,688
Long-term debt, net of current portion			204,715				279,668
Deferred income taxes, net			20,368				16,626
Derivative instruments			2,162				2,160
Other long-term liabilities			1,065				998
Total liabilities			355,255				496,140
Commitments and contingencies
Equity
Common stock, $0.01 par value, 8,000,000 shares authorized, 1,555,514 and 1,784,536 shares issued and outstanding, respectively			16				18
Additional paid-in capital			342,217				397,411
Warrants			7,825				27,097
Retained earnings			150,803				176,906
Treasury stock			(25,823	)			(25,877	)
Accumulated other comprehensive loss			(12,515	)			(3,884	)
Total stockholders’ equity			462,523				571,671
Noncontrolling interest in subsidiary			554				700
Total equity			463,077				572,371
Total liabilities and equity		$	818,332			$	1,068,511

The accompanying notes are an integral part of these consolidated financial statements.

 

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Consolidated statements of income

for the six months ended June 30, 2010 and 2011

(Unaudited)

 

		Six months ended June 30,
(in thousands of dollars, except share information)		2010				2011
Net sales		$	349,290			$	460,506
Cost of sales			245,957				324,517
Gross profit			103,333				135,989
Operating expenses
Selling, general and administrative expenses			64,597				78,880
Contingent consideration			—				5,800
Transaction expenses			—				2,616
(Gain) loss on sale of assets			(123	)			(420	)
Total operating expenses			64,474				86,876
Income from operations			38,859				49,113
Other expense (income)
Interest expense			9,242				7,689
Other, net			(981	)			751
Total other expense (income)			8,261				8,440
Income before income taxes			30,598				40,673
Income tax expense			10,235				14,383
Net income			20,363				26,290
Less: Income attributable to noncontrolling interest			(73	)			(187	)
Net income attributable to common stockholders		$	20,290				26,103
Weighted average shares outstanding
Basic			1,309				1,591
Diluted			1,322				1,658
Earnings per share
Basic		$	15.50			$	16.41
Diluted			15.35				15.74

The accompanying notes are an integral part of these consolidated financial statements.

 

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Consolidated statement of changes in stockholders’

equity For the six months ended June 30, 2011

(Unaudited)

 

(in thousands of dollars, except share information)		Common Stock								Additional paid in capital				Treasury stock				Warrants				Retained earnings				Accumulated other comprehensive income / (loss)				Total common Stockholders’ equity				Non controlling Interest				Total Equity
		Shares				Amount
Balance at December 31, 2010			1,555,154			$	16			$	342,217			$	(25,823	)		$	7,825			$	150,803			$	(12,515	)		$	462,523			$	554			$	463,077
Stock issuance related to acquisitions			55,252				—				19,900				—				—				—				—				19,900				—				19,900
Stock issuance			168,236				2				49,998				—				—				—				—				50,000				—				50,000
Restricted stock issuance			755				—				—				—				—				—				—				—				—				—
Restricted stock purchase			4,075				—				1,610				—				—				—				—				1,610				—				1,610
Restricted stock withheld			(105	)			—				—				(54	)			—				—				—				(54	)			—				(54	)
Stock based compensation expense			—				—				2,664				—				—				—				—				2,664				—				2,664
Exercised stock options			1,084				—				163				—				—				—				—				163				—				163
Warrant issuance			—				—				(19,278	)			—				19,278				—				—				—				—				—
Exercise of warrants			85				—				31				—				(6	)			—				—				25				—				25
Excess tax benefits			—				—				106				—				—				—				—				107				—				107
Comprehensive income:
Net income			—				—				—				—				—				26,103				—				26,103				187				26,290
Change in currency translation adj			—				—				—				—				—				—				7,814				7,814				(41	)			7,773
Change related to derivative liabilities, net of tax			—				—				—				—				—				—				817				817				—				817
Comprehensive income			—				—				—				—				—				—				—				34,734				—				34,880
Balance at June 30, 2011			1,784,536			$	18			$	397,411			$	(25,877	)		$	27,097			$	176,906			$	(3,884	)		$	571,671			$	700			$	572,371

The accompanying notes are an integral part of these consolidated financial statements.

 

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Consolidated statements of cash flows

For the six months ended June 30, 2010 and 2011

(Unaudited)

 

		Six months ended June 30,
(in thousands of dollars, except share information)		2010				2011
Cash flows from operating activities
Net income		$	20,290			$	26,103
Adjustments to reconcile net income to net cash provided by operating activities
Change in contingent consideration			—				5,800
Share-based compensation expense			1,017				2,664
Depreciation expense			10,200				11,564
Amortization of deferred loan costs			259				960
Amortization of intangible assets			4,513				4,791
Loss (gain) on disposal of fixed assets			(113	)			(251	)
Deferred income taxes			468				(2,089	)
Changes in operating assets and liabilities
Accounts receivable—trade			(6,568	)			(26,589	)
Inventories			(5,730	)			(30,782	)
Prepaid expenses and other current assets			(231	)			2,830
Cost and estimated profit in excess of billings			927				(14,287	)
Accounts payable, deferred revenue and other accrued liabilities			7,039				19,353
Billings in excess of costs and estimated profits earned			(6,210	)			1,839
Net cash provided by operating activities			25,861				1,906
Cash flows from investing activities
Capital expenditures for property and equipment			(4,773	)			(20,482	)
Proceeds from sale of property and equipment			373				964
Capitalized costs related to patents			(645	)			(58	)
Acquisition of businesses, net of cash acquired			—				(65,249	)
Net cash used in investing activities			(5,045	)			(84,825	)
Cash flows from financing activities
Deferred financing costs			—				(2,252	)
Borrowings due to Acquisitions			—				65,249
Borrowings on long-term debt			5,774				11,256
Repayment of long-term debt			(27,087	)			—
Purchases of stock			(76	)			—
Proceeds from stock issuance			19				51,804
Net cash provided by (used in) financing activities			(21,370	)			126,057
Effect of exchange rate changes on cash			(691	)			2,651
Net increase (decrease) in cash and cash equivalents			(1,245	)			45,789
Cash and cash equivalents
Beginning of period			26,894				20,348
End of period		$	25,649			$	66,137
Supplemental cash flow disclosures
Interest paid		$	11,373			$	7,185
Income taxes paid			12,194				13,655
Noncash investing and financing activities
Acquisition via contingent consideration and stock		$	—			$	49,600

The accompanying notes are an integral part of these consolidated financial statements.

 

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Notes to consolidated interim financial statements

(Unaudited)

1. Organization and basis of presentation

The accompanying consolidated financial statements of the Company include the accounts of Forum Energy Technologies, Inc. and its subsidiaries Forum Oilfield Technologies, Inc. (“FOT”), Triton Group Holdings LLC (“Triton”), Subsea Services International, Inc. (“SSI”), Global Flow Technologies, Inc. (“GFT”), Allied Production Services, Inc. (“Allied”) and, effective February 1, 2011, Wood Flowline Products, LLC and, effective April 30, 2011, Phoinix Global LLC and, effective May 31, 2011, Specialist ROV Tooling Services, Ltd.

All significant intercompany transactions have been eliminated in consolidation. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for the fair presentation have been included.

These interim financial statements are unaudited and have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the audited consolidated financial statements for the years ended December 31, 2010 included elsewhere in this prospectus.

2. Recent accounting pronouncements

From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board which are adopted by the Company as of the specified effective date. Unless otherwise discussed, management believes that the impact of recently issued standards, which are not yet effective, will not have a material impact on the Company’s consolidated financial statements upon adoption.

In June 2011, the Financial Accounting Standards Board (“FASB”) issued an update to ASC 220, Presentation of Comprehensive Income. This Accounting Standards Update (“ASU”) provides that an entity that reports items of other comprehensive income has the option to present comprehensive income in either 1) a single statement that presents the components of net income and total net income, the components of other comprehensive income and total other comprehensive income, and a total for comprehensive income; or 2) a two-statement approach which presents the components of net income and total net income in a first statement, immediately followed by a financial statement that presents the components of other comprehensive income, a total for other comprehensive income, and a total for comprehensive income. The option in current GAAP that permits the presentation of other comprehensive income in the statement of changes in equity was eliminated. The guidance will be applied retrospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is permitted. The adoption of this guidance will not have a material impact on the Company’s financial statements.

In December 2010, the FASB issued FASB ASU 2010-28, which affects entities evaluating goodwill for impairment under FASB ASC 350-20. ASU 2010-28, among other things, requires entities with

 

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Notes to consolidated interim financial statements (continued)

(Unaudited)

 

a zero or negative carrying value to assess, considering qualitative factors, whether it is more likely than not that goodwill impairment exists. If an entity concludes that it is more likely than not that goodwill impairment exists, the entity must perform step 2 of the goodwill impairment test. ASU 2010-28 is effective for impairment tests performed during an entity’s fiscal year beginning after December 15, 2010, with early adoption not permitted. We do not believe the adoption of this ASU will have a material impact on the Company’s financial position or results of operations.

3. Acquisition

Wood Flowline Products, LLC

In February 2011, the Company purchased Wood Flowline Products, LLC (“WFP”). WFP manufactures pressure control and flow equipment products that are principally used in the fracturing and well stimulation process. WFP also provides on-site recertification and refurbishment services of the associated flow equipment products. This acquisition provides the Company new exposure to the growing well completions sector, specifically focused on the development of North American unconventional shale and tight sands resources. The results of WFP’s operations have been included in the Company’s consolidated financial statements beginning February 1, 2011 and will be included in the Company’s Production and Infrastructure segment. The Company incurred acquisition related fees and expenses of $0.4 million. WFP recorded revenue and earnings of $22.1 million and $4.9 million, respectively, from the time of acquisition through June 30, 2011. The purchase price included: (1) cash of $32.7 million, (2) 35,000 shares of common stock of the Company valued at $340 per share based on an internal valuation and (3) two separate contingent consideration payments which may be payable in cash and/or shares of Company stock based upon WFP’s 2011 and 2012 calendar year earnings as defined in the purchase and sale agreement. The fair value of the contingent consideration was estimated to be $13.4 million based on an internal valuation of the earnings level that the acquired company is expected to achieve. The total consideration has been allocated on a preliminary basis to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. The fair value of the contingent consideration payment was remeasured as of June 30, 2011 at $16.2 million and is included in “Contingent consideration liability” in the consolidated balance sheet. The change in fair value of $2.8 million is included in “Contingent consideration” in the consolidated statements of operations.

The following table summarizes the preliminary fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Current assets, net of cash acquired		$	12,733
Property and equipment			3,239
Intangible assets (primarily customer relationships)			16,800
Non-tax-deductible goodwill			29,893
Current liabilities			(4,654	)
Net assets acquired		$	58,011

 

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Notes to consolidated interim financial statements (continued)

(Unaudited)

 

Phoinix Global LLC

In April 2011, the Company purchased Phoinix Global LLC (“Phoinix”), a provider of high pressure flow control equipment and products utilized in the well stimulation and flow back processes of oil and gas well completion based in Alice, Texas. This acquisition adds to the Company’s completion products capabilities through a product offering that includes fluid-ends for frac pressure pumps, plug valves, relief valves, chokes, manifolds, manifold trailers and flow equipment transport trucks. The results of the Phoinix operations have been included in the Company’s consolidated financial statements beginning May 1, 2011 and will be included in the Company’s Production and Infrastructure segment. The Company incurred acquisition related fees and expenses of $0.2 million. Phoinix recorded revenue and earnings of $10.6 million and $1.7 million, respectively, from the time of acquisition through June 30, 2011. The purchase price included: (1) cash of $23.6 million (subject to working capital adjustments), (2) 20,252 shares of common stock of the Company valued at $395 per share based on an internal valuation and (3) two separate contingent consideration payments which may be payable in cash based upon Phoinix’s 2011 and 2012 calendar year earnings as defined in the purchase and sale agreement. The fair value of the contingent consideration was estimated to be $16.3 million based on an internal valuation of the earnings level that the acquired company is expected to achieve. The total consideration has been allocated on a preliminary basis to the assets acquired and liabilities assumed, including identifiable intangible assets, based on their respective fair values as of the acquisition date. The Company is still assessing the economic characteristics of certain customer relationships. The Company expects to substantially complete this assessment during the third quarter of 2011 and may adjust amounts recorded to reflect any revised evaluations. The fair value of the contingent consideration payment was remeasured as of June 30, 2011 at $19.3 million and is included in “Contingent consideration liability” in the consolidated balance sheet. The change in fair value of $3.0 million is included in “Contingent consideration” in the consolidated statements of operations.

The following table summarizes the preliminary fair values of the assets acquired and the liabilities assumed as of the acquisition date (in thousands):

 

Current assets, net of cash acquired		$	11,496
Property and equipment			1,350
Intangible assets (primarily customer relationships)			17,600
Non-tax-deductible goodwill			24,570
Current liabilities			(7,132	)
Net assets acquired		$	47,884

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

The following table provides pro forma information related to all acquisitions in the aggregate (in thousands, except per share data):

 

		Six months ended June 30, 2010				Six months ended June 30, 2011
Revenue		$	373,796			$	481,241
Net income			22,298				28,916
Basic earnings per share			16.35				17.57
Diluted earnings per share			16.19				16.88

The pro forma information for the six months ended June 30, 2010 and June 30, 2011 assumes the acquisitions listed above occurred as of January 1, 2010.

The combined results of operations of the acquired businesses have been adjusted to reflect additional depreciation of fixed assets and amortization of intangible assets subject to amortization. Pro forma interest expense was calculated on notes payable and draws on the Company’s available line of credit at a rate of 4.7%, as if the businesses were acquired at the beginning of the period.

Although the Company believes the accounting policies and procedures used to prepare the pro forma schedules are reasonable, these pro forma results do not purport to be indicative of the actual results which would have been achieved had the acquisition been consummated on January 1, 2010. The amounts shown are not intended to be a projection of future results.

4. Inventories

The significant components of inventory are as follows:

 

		December 31, 2010				June 30 2011
		(in thousands)
Raw materials and parts		$	63,234			$	99,080
Work in process			19,534				16,393
Finished goods			101,115				112,446
			183,883				227,919
Inventory reserve			(10,106	)			(10,895	)
Inventories, net		$	173,777			$	217,024

 

F-69

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

5. Goodwill and intangible assets

Goodwill

The changes in the amount of goodwill from January 1, 2011 to June 30, 2011, are as follows (in thousands):

 

Goodwill Balance at January 1, net		$	294,381
Acquisition			58,931
Impact of non-United States local currency translation			5,121
Goodwill Balance at June 30, net		$	358,433

Intangible assets

At December 31, 2010 and June 30, 2011, intangible assets consist of the following, respectively:

 

		December 31, 2010
		Gross carrying amount				Accumulated amortization				Net amortizable intangibles				Amortization period (in years)
		(in thousands)
Customer relationships		$	70,837			$	(26,907	)		$	43,930				4-15
Patents and technology			5,764				(1,626	)			4,138				5-17
Non-compete agreements			4,047				(3,598	)			449				3-6
Trade names			15,312				(3,865	)			11,447				10-15
Contracts			260				(260	)			—				<1
Distributor relationships			22,160				(7,486	)			14,674				8-15
Trademark			5,521				—				5,521				Indefinite
Intangible Assets Total		$	123,901			$	(43,742	)		$	80,159

 

		June 30, 2011
		Gross carrying amount				Accumulated amortization				Net amortizable intangibles				Amortization period (in years)
		(in thousands)
Customer relationships		$	106,182			$	(30,328	)		$	75,854				4-15
Patents and technology			5,822				(1,939	)			3,883				5-17
Non-compete agreements			4,960				(3,790	)			1,170				3-6
Trade names			15,312				(4,171	)			11,141				10-15
Contracts			260				(260	)			—				<1
Distributor relationships			22,160				(8,116	)			14,044				8-15
Trademark			5,521				—				5,521				Indefinite
Intangible Assets Total		$	160,217			$	(48,604	)		$	111,613

 

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

6. Debt

Notes payable and lines of credit consist of the following:

 

		December  31, 2010				June  30, 2011
		(in thousands)
Senior secured revolving credit facility		$	204,000			$	279,615
Other debt			3,924				1,993
Total debt			207,924				281,608
Less: current maturities			(3,209	)			(1,940	)
Long-term debt		$	204,715			$	279,668

In conjunction with the Combination, FET entered into a senior secured credit facility with several financial institutions. The credit facility provided for a $450.0 million revolving credit facility, including up to $75.0 million of letters of credit and up to $25.0 million in swingline loans, and matures in August 2014. Effective June 29, 2011, we amended our senior secured credit facility to, among other things, increase the commitment to $750 million.

Interest is payable every 30, 60 or 90 days based on interest rate elections. Amounts outstanding are collateralized by substantially all of FET’s assets. Weighted average interest rates (without the effect of hedging) at June 30, 2011 and December 31, 2010 were 4.5% and 3.0%, respectively. The credit facility allows management to elect how interest will be computed which may be determined by reference to the London interbank offered rate, or LIBOR, plus an applicable margin between 2.0% and 3.75% per annum or a base rate plus an applicable margin between 0.5% and 2.25% per annum (with the applicable margin depending upon FET’s ratio of total funded debt to EBITDA).

This credit facility contains covenants which require FET to maintain certain financial ratios. These covenants are as follows:

 

•

Total funded debt to EBITDA (as defined in the credit facility) of not more than 3.75 to 1.0 for periods ending through December 31, 2011; 3.50 to 1.0 for periods ending from January 1, 2012 through December 31, 2012; 3.25 to 1.0 for periods ending from January 1, 2013 through December 31, 2013 and 3.00 to 1.0 for periods ending thereafter;

 

•

EBITDA to interest expense ratio (as defined in the credit facility) of not less than 3.0 to 1.0; and

 

•

Total balance sheet debt to total capitalization (as defined in the credit facility) of not more than 0.65 to 1.0.

Availability under the credit facility, considering the covenants discussed above, was approximately $210 million and $292 million at December 31, 2010 and June 30, 2011, respectively. The Company was in compliance with the aforementioned financial covenants at December 31, 2010 and June 30, 2011.

 

F-71

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

Subsequent to June 30, 2011, we had significant increases in our debt amount related to acquisitions. See footnote 13, Subsequent Events.

Other debt

Other debt consists primarily of upfront annual insurance premiums that have been financed and capital lease obligations.

Debt issue costs

In conjunction with entering into the senior secured facility, the Company incurred approximately $8.9 million in loan costs that have been capitalized and are amortized to interest expense over the term of the facility.

7. Income taxes

The Company’s effective tax rates for the six months ended June 30, 2010 and 2011 were 33.4% and 35.4%, respectively. The tax provision for the first six months of 2011 is higher than the comparable period in 2010 primarily due to the fact that the applicable United States statutory rate for 2011 for the companies was 35%; however, in 2010, several of the companies in the Combination were taxed at the statutory rate of 34%.

8. Derivatives

The Company has an interest rate swap agreement to convert variable interest payments related to $34 million of floating rate debt to fixed interest payments. This swap expires in November 2011 and has a weighted average fixed rate of 4.9% plus the applicable margin. The Company also has an interest rate collar arrangement to reduce the variability in interest payments related to $20 million in floating rate debt. This interest rate collar instrument expires in November 2011 and has a floor interest rate of 4.36%, plus the applicable margin, and a cap interest rate of 5.36%, plus the applicable margin. The Company’s balance sheet at December 31, 2010 and June 30, 2011 included a current derivative liability of $2.2 million and $0.9 million, respectively.

These instruments, which the Company has designated as cash flow hedging instruments, meet the specific hedge criteria provided by the derivatives and hedging accounting guidance and any changes in their fair values are recognized in accumulated other comprehensive income or loss. Since the terms of the hedged item and the instruments substantially coincide, the hedge is expected to offset changes in expected cash flows due to fluctuations in the variable rate and, therefore, the Company currently does not expect any ineffectiveness.

The counterparties to the Company’s interest rate swap agreements are major international financial institutions with good credit ratings so nonperformance is not expected from them.

Certain derivative instruments were not designated for hedge accounting at inception. These derivatives are also recorded at fair value, which is measured using the market approach valuation technique. These interest rate swap agreements were entered into to hedge the

 

F-72

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

interest rate risk exposure. At December 31, 2010 and June 30, 2011, the fair value of the swap agreements was recorded as a long-term liability of $2.2 million and $2.2 million, respectively.

Our financial assets and liabilities are measured at fair value on a recurring basis. There were no outstanding financial assets as of December 31, 2010 and June 30, 2011. The following fair value hierarchy table presents information about the Company’s financial liabilities measured at fair value on a recurring basis as of December 31, 2010 and June 30, 2011:

 

		Quoted prices in active markets for identical assets (Level 1)				Significant other observable inputs (Level 2)				Significant unobservable inputs (Level 3)				Balance as of December 31, 2010
		(in thousands)
Liabilities
Interest rate derivatives		$	—			$	—			$	4,356			$	4,356
Total Liabilities		$	—			$	—			$	4,356			$	4,356
		Quoted prices in active markets for identical assets (Level 1)				Significant other observable inputs (Level 2)				Significant unobservable inputs (Level 3)				Balance as of June 30, 2011
		(in thousands)
Liabilities
Interest rate derivatives		$	—			$	—			$	3,100			$	3,100
Total Liabilities		$	—			$	—			$	3,100			$	3,100

The following table sets forth a reconciliation of changes for the three-month period ended June 30, 2011 in the fair value of financial liabilities classified as Level 3 in the fair value hierarchy.

 

		(in thousands)
Balance at beginning of period		$	(4,356	)
Total Gains or (Losses) (Realized or Unrealized):
Included in Earnings			2
Included in Other Comprehensive Income			1,254
Purchases, Issuances and Settlements			—
Transfers In and/or Out of Level 3			—
Balance at end of period		$	(3,100	)

 

F-73

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Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

9. Business segments

The Company’s operations are divided into three business segments, Drilling and Subsea (“D&S”), Production and Infrastructure (“P&I”) and Corporate. Summary financial data by segment follows (in thousands):

 

		Six months ended June 30, 2010
		D&S				P&I				Corp				Total segments				Gain/(loss) on sale of assets not part of segment income				Total
Revenue		$	221,949			$	127,341			$	—			$	349,290							$	349,290
Operating income			28,318				10,418								38,736				123				38,859
Total assets			666,493				171,950								838,443								838,443

 

		Six months ended June 30, 2011
		D&S				P&I				Corp				Total segments				Gain/(loss) on sale of assets not part of segment income				Contingent Consideration not part of segment income				Transaction expenses not part of segment income				Total
Revenue		$	267,965			$	192,541			$	—			$	460,506			$	—			$	—			$	—			$	460,506
Operating income			40,066				27,026				(9,983	)			57,109				420				(5,800	)			(2,616	)			49,113
Total assets			699,328				320,558				48,625				1,068,511				—				—				—				1,068,511

10. Earnings per share

The calculation of basic and diluted earnings per share for each presented was as follows (dollars and shares in thousands, except per share amounts):

 

		Six months ended June 30,
		2010				2011
Net Income attributable to common stockholders		$	20,290			$	26,103
Average shares outstanding (basic)			1,309				1,591
Common stock equivalents			13				67
Diluted shares			1,322				1,658
Basic earnings per share		$	15.50			$	16.41
Diluted earnings per share		$	15.35				15.74

 

F-74

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

11. Commitments and contingencies

In the ordinary course of business, the Company is, and in the future, could be involved in various pending or threatened legal actions, some of which may or may not be covered by insurance. Management has reviewed pending judicial and legal proceedings, reasonably anticipated costs and expenses in connection with such proceedings, and availability and limits of insurance coverage, and has established reserves that are believed to be appropriate in light of those outcomes that are believed to be probable and can be estimated. The reserve accrued at December 31, 2010 and June 30, 2011 is insignificant. In the opinion of management, the amount of ultimate liability, if any, with respect to these actions will not have a material adverse effect on the Company’s financial statements.

Portland Harbor Superfund litigation

In May 2009, one of our subsidiaries (which is presently a dormant company with nominal assets except for rights under insurance policies) was named along with many defendants in a suit filed by the Port of Portland, Oregon seeking reimbursement of costs related to a five-year study of contaminated sediments at the port. In March 2010, the subsidiary also received a notice letter from the EPA indicating that it had been identified as a potentially responsible party with respect to environmental contamination in the “study area” for the Portland Harbor Superfund Site. Under a 1997 indemnity agreement, our subsidiary is indemnified by a third party with respect to losses relating to environmental contamination. As required under the indemnity agreement, our subsidiary provided notice of these claims, and the indemnitor has assumed responsibility and is providing a defense of the claims. Although we believe that it is unlikely that our subsidiary contributed to the contamination at the Portland Harbor Superfund Site, the potential liability of our subsidiary and the ability of the indemnitor to fulfill its indemnity obligations cannot be quantified at this time.

12. Related party transactions

FOT has related party transactions, including sales and leasing activity with certain former owners of acquired companies or certain stockholders. The dollar amounts related to these related party activities are not significant to the Company’s consolidated financial statements. For GFT, in conjunction with the acquisition of one of its subsidiaries, the Company entered into various operating lease agreements with the former principals for office and warehouse space. For the six-month periods ended June 30, 2010 and 2011, the Company paid $0.1 million each period in lease payments to these affiliates. GFT also utilizes a certain agent, which is owned by a former owner. The amount paid to this agent for each of the three-month periods ended June 30, 2010 and 2011 was $0.1 million.

Allied leases two facilities from a stockholder of FET. Allied paid $0.4 million in lease payments for each of six-month periods ended June 30, 2010 and 2011. Allied purchased inventory and services from a shareholder totaling $2.0 million and $2.4 million during the six-month periods

 

F-75

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Table of Contents

Index to Financial Statements

Forum Energy Technologies, Inc. and subsidiaries

Notes to consolidated interim financial statements (continued)

(Unaudited)

 

ended June 30, 2010 and 2011, respectively. The Company sold less than $10,000 and $0.3 million of equipment and services to a stockholder during the six-month periods ended June 30, 2010 and 2011, respectively.

13. Subsequent events

Subsequent to June 30, 2011, there were five acquisitions, of which, the significant ones are discussed below.

In July 2011, the Company acquired Cannon Services (“Cannon”), based in Stafford, Texas, and is a provider of standard and customized clamp and stamped metal protection systems used to shield the downhole control lines and gauges during their installation and provide protection during production enhancement operations. The purchase price included: (1) $48.7 million of cash (subject to working capital adjustments) and (2) 20,944 shares of common stock. The results of Cannon’s operations will be included in the Company’s consolidated financial statements beginning July 1, 2011.

In July 2011, the Company acquired AMC Global Group, Ltd. (“AMC”), based in Aberdeen, Scotland, and designs and manufactures specialized torque equipment for tubular connections, including high torque stroking units, fully rotational torque units and portable torque units for field deployment and related control systems, and provides aftermarket service. The purchase price included: (1) $42.5 million of cash (subject to working capital adjustments) and (2) 16,200 shares of common stock. The results of AMC’s operations will be included in the Company’s consolidated financial statements beginning July 1, 2011.

In July 2011, the Company acquired P-Quip, Ltd. (“P-Quip”), based in Kilbirnie, Scotland, a manufacturer of proprietary mud pump fluid end assemblies, mud pump rod systems, liner retention systems, valve cover retention systems and other drilling flow control products. The purchase price included $32.4 million of cash (subject to working capital adjustments). The results of P-Quip’s operations will be included in the Company’s consolidated financial statements beginning July 1, 2011.

On July 29, 2011, the Company acquired Davis-Lynch LLC (“Davis-Lynch”), a provider of proprietary, downhole cementing and casing products based in Pearland, Texas. The purchase price included $316.0 million of cash (subject to working capital adjustments). The results of Davis-Lynch’s operations will be included in the Company’s consolidated financial statements beginning August 1, 2011.

In conjunction with the July acquisitions, the Company borrowed on its credit facility an amount of approximately $450 million.

 

F-76

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Financial statements for the year ended December 31, 2010

Index

 

		Page
Report of Independent Registered Public Accounting Firm			F-78
Balance Sheets			F-79
Statements of Operations			F-80
Statements of Changes in Stockholder’s Equity			F-81
Statements of Cash Flows			F-82
Notes to Financial Statements			F-83

 

F-77

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Table of Contents

Index to Financial Statements

Report of independent registered public accounting firm

To the Owner of

Davis-Lynch, Inc.:

We have audited the accompanying balance sheets of Davis-Lynch, Inc. (the “Company”) as of December 31, 2010 and 2009, and the related statements of operations, of changes in stockholder’s equity and of cash flows for each of the three years in the period ended December 31, 2010. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the 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 the significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Davis-Lynch, Inc. as of December 31, 2010 and 2009, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2010, in conformity with accounting principles generally accepted in the United States of America.

/s/ UHY LLP

Houston, Texas

August 26, 2011

 

F-78

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Balance sheets

 

		December 31,
		2010				2009
ASSETS
CURRENT ASSETS
Cash and cash equivalents		$	81,642,230			$	53,518,507
Accounts receivable—trade, net			19,865,005				11,029,726
Inventory, net			25,044,231				28,090,506
Prepaid expenses and other assets			288,959				293,853
TOTAL CURRENT ASSETS			126,840,425				92,932,592
PROPERTY AND EQUIPMENT, net			1,041,298				1,405,369
TOTAL ASSETS		$	127,881,723			$	94,337,961
LIABILITIES AND STOCKHOLDER’S EQUITY
CURRENT LIABILITIES
Accounts payable, trade		$	4,163,096			$	4,507,103
Accrued expenses and other liabilities			3,236,188				1,084,121
TOTAL CURRENT LIABILITIES			7,399,284				5,591,224
TOTAL LIABILITIES			7,399,284				5,591,224
COMMITMENTS AND CONTINGENCIES (NOTE E AND H)
STOCKHOLDER’S EQUITY
Common stock; $1 par value; 240,000 shares authorized, issued and outstanding			240,000				240,000
Retained earnings			120,242,439				88,506,737
TOTAL STOCKHOLDER’S EQUITY			120,482,439				88,746,737
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY		$	127,881,723			$	94,337,961

See accompanying notes to financial statements.

 

F-79

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Statements of operations

 

		Year ended December 31,
		2010				2009				2008
NET SALES		$	89,151,747			$	60,043,232			$	110,085,510
COST OF SALES			37,381,245				18,024,713				40,040,640
GROSS PROFIT			51,770,502				42,018,519				70,044,870
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES			13,943,185				12,637,033				17,103,185
OPERATING INCOME			37,827,317				29,381,486				52,941,685
OTHER INCOME (EXPENSE)
Interest income			329,852				278,337				1,034,670
Interest expense			—				(1,000,000	)			(1,000,000	)
Loss from unauthorized employee activities			—				(2,284,580	)			(4,114,016	)
Other, net			148,370				(6,212	)			87,039
TOTAL OTHER INCOME (EXPENSE)			478,222				(3,012,455	)			(3,992,307	)
NET INCOME BEFORE INCOME TAX EXPENSE			38,305,539				26,369,031				48,949,378
STATE INCOME TAX EXPENSE			1,569,837				157,412				410,051
NET INCOME		$	36,735,702			$	26,211,619			$	48,539,327

See accompanying notes to financial statements.

 

F-80

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Statements of changes in stockholder’s equity

For the years ended December 31, 2010, 2009 and 2008

 

		Common stock				Retained earnings				Total stockholder’s equity
Balance, January 1, 2008		$	240,000			$	55,087,867			$	55,327,867
Dividends			—				(31,332,076	)			(31,332,076	)
Net income			—				48,539,327				48,539,327
Balance, December 31, 2008			240,000				72,295,118				72,535,118
Dividends			—				(10,000,000	)			(10,000,000	)
Net income			—				26,211,619				26,211,619
Balance, December 31, 2009			240,000				88,506,737				88,746,737
Dividends			—				(5,000,000	)			(5,000,000	)
Net income			—				36,735,702				36,735,702
Balance, December 31, 2010		$	240,000			$	120,242,439			$	120,482,439

See accompanying notes to financial statements.

 

F-81

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Index to Financial Statements

Davis-Lynch, Inc.

Statements of cash flows

 

		Year ended December 31,
		2010				2009				2008
CASH FLOWS FROM OPERATING ACTIVITIES
Net income		$	36,735,702			$	26,211,619			$	48,539,327
Adjustment to reconcile net income to net cash provided by operating activities:
Depreciation and amortization			495,627				600,023				1,322,169
Provision for bad debts			—				88,515				408,610
Provision for inventory obsolescence			1,230,458				4,400,000				—
Gain on sale of property and equipment			(26,182	)			(9,609	)			(50,289	)
Changes in operating assets and liabilities:
Accounts receivable, trade			(8,835,279	)			11,654,639				(4,514,615	)
Inventories			1,815,817				(9,378,607	)			(11,437,721	)
Prepaid expenses and other assets			4,894				91,217				(4,892	)
Accounts payable, trade			(344,007	)			(5,705,293	)			(3,070,992	)
Accrued expenses and other liabilities			2,152,067				(702,751	)			263,488
Accrued interest			—				(1,000,000	)			1,000,000
NET CASH PROVIDED BY OPERATING ACTIVITIES			33,229,097				26,249,753				32,455,085
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from sale of property and equipment			49,000				16,145				66,967
Purchases of property and equipment			(154,374	)			(104,822	)			(811,728	)
NET CASH USED IN INVESTING ACTIVITIES			(105,374	)			(88,677	)			(744,761	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from notes payable, stockholder			—				10,000,000				10,000,000
Payment of notes payable, stockholder			—				(20,000,000	)			—
Payment of dividends			(5,000,000	)			(10,000,000	)			(31,332,076	)
NET CASH USED IN FINANCING ACTIVITIES			(5,000,000	)			(20,000,000	)			(21,332,076	)
NET INCREASE IN CASH AND CASH EQUIVALENTS			28,123,723				6,161,076				10,378,248
CASH AND CASH EQUIVALENTS, beginning of year			53,518,507				47,357,431				36,979,183
CASH AND CASH EQUIVALENTS, end of year		$	81,642,230			$	53,518,507			$	47,357,431
SUPPLEMENTAL DISCLOSURES:
Interest paid		$	—			$	2,000,000			$	—
State taxes paid		$	267,499			$	165,000			$	245,051
NON-CASH ACTIVITIES:
Write off of fully depreciated property and equipment		$	—			$	660,588			$	1,095,047

See accompanying notes to financial statements.

 

F-82

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements

Note A—Organization and nature of business

Davis-Lynch, Inc. (the “Company”) is a Subchapter S Corporation formed in 1947 that is privately and wholly owned by Carl A. Davis, President. The Company’s line of business includes designing, manufacturing, and marketing cementing equipment with operations solely in the United States. The Company operates in one segment. It sells its products primarily in the United States and through distributors in certain foreign geographic areas such as the Middle East, Africa, and South America. Originally a manufacturer of float equipment, the Company has expanded its product line to include a full line of centralizers and primary cementing aids, multi-purpose float collars, stage cementing tools, inner-string cementing tools, inflatable packers, flotation collars, cementing plugs, fill and circulate tools for running casing, casing hangers and drive pipe landing rings, as well as surge reduction equipment. The Company’s headquarters are located in Pearland, Texas. The financial statements of the Company have been prepared on the accrual basis of accounting in accordance with generally accepted accounting principles in the United States of America.

Note B—Summary of significant accounting policies

Cash and cash equivalents:    For purposes of the statements of cash flows, cash and cash equivalents consists of cash in banks, money market funds, and certificates of deposit with original maturities of three months or less.

The Company reclassified overdrafts of approximately $1.1 million and $3.3 million from cash and cash equivalents to accounts payable at December 31, 2009 and 2008, respectively. There were no cash overdrafts at December 31, 2010.

Allowance for doubtful accounts:    Earnings are charged with a provision for doubtful accounts based upon a current review of the collectability of accounts from customers. Accounts deemed uncollectible are applied against the allowance for doubtful accounts. Accounts receivable, trade was net of an allowance for doubtful accounts of $1,055,817 at December 31, 2010 and 2009, respectively. Bad debt expense totaled $0, $88,515 and $408,610 for the years ended December 31, 2010, 2009 and 2008, respectively.

 

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Inventory:    Inventories are stated at the lower of cost or market value using an average standard cost. Cost is determined using standard cost, which approximates average cost, and includes the application of related direct labor and overhead. The Company periodically evaluates the components comprising its inventories and reviews for items that have not been utilized over a certain period of time based on current products in production, physical condition, and future applicability to be utilized in production to determine its obsolescence reserve. Inventory obsolescence expense totaled $1,230,458, $4,400,000 and $0 for the years ended December 31, 2010, 2009 and 2008, respectively. Inventories consist of the following:

 

		December 31,
		2010				2009
Raw material		$	8,502,006			$	14,915,896
Work-in-process			9,317,852				2,951,182
Finished goods			12,854,831				14,623,428
			30,674,689				32,490,506
Less: obsolescence reserve			(5,630,458	)			(4,400,000	)
Inventory, net		$	25,044,231			$	28,090,506

Property and equipment:    Property and equipment are stated at cost. Depreciation is computed over the estimated useful lives of the related assets using the straight-line method. Maintenance and repairs are charged to expense as incurred and significant renewals and betterments are capitalized. The cost and related accumulated depreciation of assets retired or otherwise disposed of are eliminated from the accounts, and any resulting gains or losses are recognized in operations in the year of disposal.

Property and equipment, net and related accumulated depreciation consist of the following:

 

		Estimated useful life				December 31,
						2010				2009
Autos			3-20 years			$	440,544			$	452,121
Forklifts			3-10 years				321,033				321,033
Machinery and equipment			7-30 years				7,703,908				7,908,692
Leasehold improvements							2,314,447				2,314,447
							10,779,932				10,996,293
Less: accumulated depreciation and amortization							(9,738,634	)			(9,590,924	)
Property and equipment, net						$	1,041,298			$	1,405,369

For the years ended December 31, 2010, 2009 and 2008, depreciation expense related to property and equipment totaled $495,627, $600,023 and $1,322,169, respectively. For the years ended December 31, 2010, 2009 and 2008, $452,902, $536,560 and $1,199,252, respectively, of depreciation expense is included in “cost of sales” and $42,725, $63,463 and $122,917, respectively, is included in “selling, general and administrative expenses” in the accompanying statements of operations. Repairs and maintenance expense totaled $521,435, $209,339 and $885,571 for the years ended December 31, 2010, 2009 and 2008, respectively.

 

F-84

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Impairment of long-lived assets:    The Company reviews the recoverability of its long-lived assets, such as plant, property and equipment, when events or changes in circumstances occur that indicate the carrying value of the asset or asset group may not be recoverable and the expected future pre-tax cash flows (undiscounted) to be generated by those assets are less than the carrying value of the assets. In such case, the impairment loss would be equal to the amount by which the carrying value exceeds estimated fair market value of the related assets. Long-lived assets are reviewed for impairment at the individual asset or the asset group level for which the lowest level of independent cash flows can be identified. The Company determined that no impairment had occurred during the year ended December 31, 2010, 2009 or 2008.

Income taxes:    As the Company is a Subchapter S Corporation, there is no provision for federal income taxes reflected in the financial statements as the Company is not subject to federal income taxes. Earnings are included in the owner’s personal income tax return.

Effective January 1, 2009, the Company adopted guidance in Accounting Standards Codification (“ASC”) Topic 740 (ASC 740), Income Taxes, for the accounting for the uncertainty in income taxes. The guidance clarifies the accounting for income taxes by prescribing the minimum recognition threshold an income tax position is required to meet before being recognized in the financial statements and applies to all income tax positions. Each income tax position is assessed using a two step process. A determination is made as to whether it is more likely than not that the income tax position will be sustained, based upon technical merits, upon examination by the taxing authorities. If the income tax position is expected to meet the more likely than not criteria, the benefit recorded in the financial statements equals the largest amount that is greater than 50% likely to be realized upon its ultimate settlement.

The adoption of this guidance did not impact the Company’s financial position, results of operations, or cash flows as the income tax positions taken by the Company for any years open under the various statute of limitations is that the Company continues to be exempt from federal income taxes by virtue of its pass through status and that federal income tax is attributable to its owner. Management believes that this tax position meets the more likely than not threshold and accordingly, the tax benefit of this income tax position (no federal income tax expense or liability) has been recognized for the years ended on or before December 31, 2010.

The Company records income tax related interest and penalties as a component of the provision for income taxes. For the year ended December 31, 2010, the Company recorded approximately $177,000 of interest and $53,000 in penalties related to state income taxes. For the years ended December 31, 2009 and 2008, the Company did not record any income tax related interest or penalties. The Company believes there is no tax positions taken or expected to be taken that would significantly increase or decrease unrecognized tax benefits within twelve months of the reporting date.

During 2010, the Company underwent a tax audit by the State of Louisiana (the “State”). As a result of this audit, it was determined the Company owed additional taxes totaling $1,249,246, inclusive of interest and penalties, to the State. This amount was reflected in the December 31, 2010 financial statements and was subsequently paid in January 2011. No other state tax returns are currently under examination by state authorities. However, fiscal years 2007 and later remain subject to examination by the respective states in which the Company does business.

 

F-85

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

In May 2006, the State of Texas enacted a bill that replaced the existing state franchise tax with a margin tax. Effective January 1, 2007, the margin tax applies to legal entities conducting business in Texas, including previously non-taxable entities such as limited partnerships and limited liability partnerships. The margin tax is based on Texas sourced taxable margin. The tax is calculated by applying a tax rate to a base rate that considers both revenues and expenses and therefore has the characteristics of an income tax. As a result, the Company recorded $146,825, $134,389 and $154,705 in estimated state income taxes for the years ended December 31, 2010, 2009 and 2008, respectively, that is solely attributable to the Texas margin tax and is included in “state income tax expense” in the accompanying statements of operations. The Company also recorded $1,423,012, $23,023 and $255,346 in state income taxes for the years ended December 31, 2010, 2009 and 2008, respectively, attributable to various other states in which the Company conducts business.

Concentrations of credit risk:    Financial instruments that potentially subject the Company to credit risk are cash and cash equivalents and trade accounts receivable. The Company maintains cash balances in high credit quality financial institutions which at times may exceed federally insured limits. The Company monitors the financial condition of these institutions and has experienced no losses associated with these accounts. The Company extends credit to customers throughout the United States of America and certain foreign countries. The Company’s allowance for doubtful accounts is based upon a current review of collectability for each customer taking into consideration current market conditions and other factors.

The Company’s primary customers are in the energy industry. As such, the Company could be affected by events that affect this industry such as natural disasters, political unrest, terrorism, oil prices and domestic policies regarding energy related industries.

In October 2008, the Federal Deposit Insurance Corporation increased its insurance to $250,000 per depositor, and to an unlimited amount for non-interest bearing accounts. The coverage increase, which is temporary, extends through December 31, 2013.

Revenue recognition:    Revenue is recognized when products are shipped or services are performed.

Shipping and handling fees and costs:    Shipping and handling fees, if billed to customers, are included in net sales. Shipping and handling costs are classified as cost of sales.

Reclassifications:    Certain reclassifications of 2009 amounts were made to conform to the current period presentation. Such reclassifications had no impact on 2009 reported net income or stockholder’s equity.

Use of estimates:    The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, the Company evaluates its estimates and assumptions, including those related to its allowance for doubtful accounts, inventory obsolescence, impairment for property and equipment and contingencies. Actual results could differ from these estimates.

 

F-86

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Environmental remediation:    The Company accounts for environmental remediation in accordance with ASC Topic 410, Asset Retirement and Environmental Obligations. In accordance with this guidance, liabilities are recorded when environmental assessments indicate that remediation efforts are probable and the costs can be reasonably estimated. Estimates of the liability are based upon currently available facts, existing technology and presently enacted laws and regulations, taking into consideration the likely effects of inflation and other societal and economic factors, and include estimates of associated legal costs.

Fair value of financial instruments:    Financial instruments of the Company consist primarily of cash and cash equivalents, accounts receivable and accounts payable. The Company’s management considers the carrying values of cash and cash equivalents, accounts receivable and accounts payable to be representative of their respective fair values because of their short-term nature.

Recent accounting standards:    In June 2011, the Financial Accounting Standards Board (“FASB”) issued an update to ASC 220, Presentation of Comprehensive Income. This Accounting Standards Update (“ASU”) provides that an entity that reports items of other comprehensive income has the option to present comprehensive income in either 1) a single statement that presents the components of net income and total net income, the components of other comprehensive income and total other comprehensive income, and a total for comprehensive income; or 2) a two-statement approach which presents the components of net income and total net income in a first statement, immediately followed by a financial statement that presents the components of other comprehensive income, a total for other comprehensive income, and a total for comprehensive income. The option in current GAAP that permits the presentation of other comprehensive income in the statement of changes in equity was eliminated. The guidance will be applied retrospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is permitted. The adoption of this guidance will not have a material impact on the Company’s financial statements.

In May 2011, the FASB issued an update to ASC 820, Fair Value Measurements. This ASU clarifies the application of certain fair value measurement requirements and requires, among other things, expanded disclosures for Level 3 fair value measurements and the categorization by level for items for which fair value is required to be disclosed in accordance with ASC 825, Financial Instruments. The guidance will be applied prospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is not permitted. The adoption of this standard will not have an impact on the Company’s financial statements.

In October 2009, the FASB issued an update to ASC 605, Revenue Recognition. This ASU allows companies to allocate consideration for qualified separate deliverables using the estimated selling price for both delivered and undelivered items when vendor-specific objective evidence or third-party evidence is unavailable. It also requires additional disclosures on the nature of multiple element arrangements, the types of deliverables under the arrangements, the general timing of their delivery, and significant factors and estimates used to determine estimated selling prices. The Company adopted this new guidance on January 1, 2011. Accordingly, the Company applies this guidance to transactions initiated or materially modified on or after January 1, 2011. The Company’s adoption of this new guidance did not have an impact on its financial position, results of operations, cash flows or existing revenue recognition policies.

 

F-87

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

In December 2010, the FASB issued an update to ASC 805, Business Combinations. This ASU addressed the disclosure of comparative financial statements and expanded on the supplementary pro forma information for business combinations. The Company adopted this ASU prospectively for business combinations occurring on or after December 15, 2010.

Note C—Accrued expenses and other liabilities

Accrued expenses consisted of the following:

 

		December 31,
		2010				2009
Sales tax payable		$	131,164			$	119,881
Customer credits			74,270				195,729
Accrued commissions			2,098,912				297,297
Accrued royalties			527,842				306,259
Accrued state taxes			404,000				157,412
Payroll taxes payable			—				7,543
		$	3,236,188			$	1,084,121

Note D—Income taxes

The provision for income taxes consists of the following:

 

		December 31,
		2010				2009				2008
Texas margin tax		$	146,825			$	134,389			$	154,705
Louisiana income tax inclusive of interest and penalties			1,373,012				—				—
Other state income taxes			50,000				23,023				255,346
Total		$	1,569,837			$	157,412			$	410,051

Note E—Commitments and contingencies

In 2009, an embezzlement scheme totaling approximately $15 million was discovered by the Company, whereby former employees had submitted fraudulent invoices for payments for over a decade. The fraud came to light during a two-month examination of the Company’s accounting records. The Company hired a third-party independent consultant to investigate this matter and to conduct the examination. The consultant reported their findings to management of the Company, which has begun legal action against the defendants in Federal District Court. Approximately $2.3 million and $4.1 million of unauthorized invoices were recorded and paid in 2009 and 2008, respectively, related to this matter which is included as loss from unauthorized employee activities in the statement of operations. All other amounts pertaining to this matter related to years prior to 2008. In 2010, the Company was awarded summary judgment, no amounts have been received, and no receivable has been recorded by the Company at December 31, 2010, 2009 or 2008. The Company intends to vigorously pursue this matter.

 

F-88

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

In January 2010, a favorable settlement was reached in a patent infringement lawsuit whereby the Company was the plaintiff. Terms of the settlement were not disclosed, but the defendant will pay a 10% royalty on future sales of the products included in the lawsuit. The Company recognized royalty income of $608,062 related to this settlement for the year ended December 31, 2010.

The Company is involved in various disputes arising in the ordinary course of business. Management does not believe the outcome of these disputes will have a material adverse effect on the Company’s financial position, results of operations or cash flows.

The Company leases certain equipment and office and manufacturing space under non-cancelable operating leases which expired at various dates through 2010 and now are month to month in nature. Total rental expense for the years ended December 31, 2010, 2009 and 2008 was approximately $235,000, $189,000 and $254,000, respectively.

The Company has various standby letters of credit with a financial institution up to a total commitment limit of $3,000,000 of which approximately $2,503,000 was utilized at December 31, 2010. The letters of credit expire through November 2011, and support certain international operations.

Note F—Related party transactions

On January 1, 2008, the Company entered into a note payable with the owner of the Company for $10,000,000, bearing interest at 10% per annum. The Company repaid the outstanding note payable plus all accrued and unpaid interest on January 2, 2009. Concurrent with the repayment on January 2, 2009, the Company entered into a new note payable agreement with the owner of the Company for $10,000,000, bearing interest at 10% per annum. The Company repaid the outstanding note payable plus all accrued and unpaid interest on December 31, 2009. Interest expense incurred on the note payable was $1,000,000 for the year ended December 31, 2009. No interest expense was incurred for the year ended December 31, 2010 as no note payable with the owner was outstanding subsequent to December 31, 2009.

The Company leases land from a related party. Total rent expense for the years ended December 31, 2010, 2009 and 2008 was approximately $120,000 in each year, respectively. During 2010, 2009 and 2008, the Company purchased supplies and materials from a related party which totaled approximately $351,000, $150,000 and $258,000, respectively.

The Company utilizes a staffing company that is a related party. Total expense for the year ended December 31, 2010 to this company was approximately $2,748,000. There was no expense to this party for the years ended December 31, 2009 and 2008.

Note G—Significant customers

During the years ended December 31, 2010 and 2008, no customer had net sales of more than 10% of total net sales. During the year ended December 31, 2009, the Company had net sales from one customer totaling approximately 10% of total net sales, or $6,162,900. At December 31, 2009, accounts receivable from the customer was $594,724.

 

F-89

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Note H—Environmental remediation

In 2008, a toxic liquid substance was discovered in the water system at the Company’s manufacturing facility in Pearland, Texas. In 2008, a third party was contracted to perform an assessment and to perform remediation work. The total estimated cost for the remediation, which was completed and paid in 2009, totaling approximately $750,000 was recorded as an expense in 2008 in accordance with ASC Topic 410, Asset Retirement and Environmental Obligations. Quarterly water samples are now being taken in order to satisfy State regulatory authorities that the matter has been resolved.

Note I—Risk and uncertainties

The current downturn in the United States economy, the moratorium on drilling in the Gulf of Mexico, and any economic slowdown in future periods, could adversely affect the Company in ways that cannot be predicted. During times of economic slowdown, the Company’s customers may reduce their capital expenditures and defer or cancel pending orders. Such developments occur even among customers that are not experiencing financial difficulties. These deferrals or cancelling of capital expenditures could directly impact the demand for the Company’s products and services. Additionally, bankruptcies or financial difficulties among the Company’s customers could reduce its cash flows and adversely impact liquidity and profitability.

Note J—Subsequent events

The Company has evaluated all events subsequent from the balance sheet date of December 31, 2010 through August 26, 2011, and noted no subsequent events that would require recognition or disclosure in the financial statements, other than those items disclosed herein and below.

On June 23, 2011, the Company converted from a Subchapter S Corporation to a Limited Liability Company.

On June 25, 2011, Forum Energy Technologies, Inc. entered into an agreement to purchase the Company for cash, as outlined under the terms in the purchase and sale agreement, subject to certain working capital adjustments. The transaction closed on July 29, 2011.

 

F-90

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Financial statements for the six months ended June 30, 2011

Index

 

		Page
Balance Sheets			F-92
Statements of Operations			F-93
Statements of Changes in Stockholder’s Equity			F-94
Statements of Cash Flows			F-95
Notes to Financial Statements			F-96

 

F-91

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Table of Contents

Index to Financial Statements

Davis-Lynch, LLC

Balance sheets

 

		June 30, 2011				December 31, 2010
		(Unaudited)
ASSETS
CURRENT ASSETS
Cash and cash equivalents		$	71,903,646			$	81,642,230
Accounts receivable—trade, net			21,552,415				19,865,005
Inventory, net			31,594,469				25,044,231
Prepaid expenses and other assets			41,280				288,959
TOTAL CURRENT ASSETS			125,091,810				126,840,425
PROPERTY AND EQUIPMENT, net			887,979				1,041,298
TOTAL ASSETS		$	125,979,789			$	127,881,723
LIABILITIES AND STOCKHOLDER’S EQUITY
CURRENT LIABILITIES
Accounts payable, trade		$	2,067,177			$	4,163,096
Accrued expenses and other liabilities			4,472,862				3,236,188
TOTAL CURRENT LIABILITIES			6,540,039				7,399,284
TOTAL LIABILITIES			6,540,039				7,399,284
COMMITMENTS AND CONTINGENCIES (Note E)
STOCKHOLDER’S EQUITY
Common stock; $1 par value; 240,000 shares authorized, issued and outstanding			240,000				240,000
Retained earnings			119,199,750				120,242,439
TOTAL STOCKHOLDER’S EQUITY			119,439,750				120,482,439
TOTAL LIABILITIES AND STOCKHOLDER’S EQUITY		$	125,979,789			$	127,881,723

 

See accompanying notes to unaudited financial statements.

 

F-92

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Table of Contents

Index to Financial Statements

Davis-Lynch, LLC

Statements of operations

(Unaudited)

 

		Three months ended June 30,								Six months ended June 30,
		2011				2010				2011				2010
NET SALES		$	26,447,304			$	22,750,235			$	50,353,477			$	39,699,511
COST OF SALES			10,545,532				8,609,062				19,393,377				14,664,447
GROSS PROFIT			15,901,772				14,141,173				30,960,100				25,035,064
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES			3,437,077				4,751,250				6,186,204				6,445,339
OPERATING INCOME			12,464,695				9,389,923				24,773,896				18,589,725
OTHER INCOME
Interest income			96,217				74,659				189,102				135,856
Other income			—				—				—				2,000,000
Other, net			56,556				34,218				112,359				56,991
TOTAL OTHER INCOME			152,773				108,877				301,461				2,192,847
NET INCOME BEFORE INCOME TAX EXPENSE			12,617,468				9,498,800				25,075,357				20,782,572
INCOME TAX EXPENSE			(120,000	)			(45,568	)			(238,367	)			(65,568	)
NET INCOME		$	12,497,468			$	9,453,232			$	24,836,990			$	20,717,004

 

 

See accompanying notes to unaudited financial statements.

 

F-93

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Table of Contents

Index to Financial Statements

Davis-Lynch, LLC

Statements of changes in stockholder’s equity

Six months ended June 30, 2011

 

		Common stock				Retained earnings				Total stockholder’s equity
Balance, January 1, 2011		$	240,000			$	120,242,439			$	120,482,439
Dividend (unaudited)			—				(25,879,679	)			(25,879,679	)
Net income (unaudited)			—				24,836,990				24,836,990
Balance, June 30, 2011 (unaudited)		$	240,000			$	119,199,750			$	119,439,750

 

 

 

See accompanying notes to unaudited financial statements.

 

F-94

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Index to Financial Statements

Davis-Lynch, LLC

Statements of cash flows

(Unaudited)

 

		Six months ended June 30,
		2011				2010
CASH FLOWS FROM OPERATING ACTIVITIES
Net income		$	24,836,990			$	20,717,004
Adjustment to reconcile net income to net cash provided by operating activities:
Depreciation			169,656				210,267
Provision for inventory obsolescence			(158,909	)			2,659,790
Gain on sale of property and equipment			(18,322	)			—
Changes in operating assets and liabilities:
Accounts receivable, trade			(1,687,410	)			(6,079,655	)
Inventories			(6,391,329	)			(892,025	)
Prepaid expenses and other assets			247,679				255,460
Accounts payable, trade			(2,095,919	)			(1,806,651	)
Accrued expenses and other liabilities			1,236,674				875,786
NET CASH PROVIDED BY OPERATING ACTIVITIES			16,139,110				15,939,976
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from sale of property and equipment			20,675				—
Purchases of property and equipment			(18,690	)			(50,144	)
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES			1,985				(50,144	)
CASH FLOW FROM FINANCING ACTIVITIES
Payment of dividends			(25,879,679	)			—
NET CASH USED IN FINANCING ACTIVITIES			(25,879,679	)			—
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS			(9,738,584	)			15,889,832
CASH AND CASH EQUIVALENTS, beginning of period			81,642,230				53,518,507
CASH AND CASH EQUIVALENTS, end of period		$	71,903,646			$	69,408,339
SUPPLEMENTAL DISCLOSURES:
State taxes paid		$	1,679,445			$	157,412

See accompanying notes to unaudited financial statements.

 

F-95

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements

Note A—Organization and nature of business

Davis-Lynch, LLC (the “Company”) is a Subchapter S Corporation that converted to a limited liability company on June 23, 2011. The Company was formed in 1947 and is privately and wholly owned by Carl A. Davis, President. The Company’s line of business includes designing, manufacturing, and marketing cementing equipment with operations solely in the United States. The Company operates in one segment. It sells its products primarily in the United States and through distributors in certain foreign geographic areas such as the Middle East, Africa, and South America. Originally a manufacturer of float equipment, the Company has expanded its product line to include a full line of centralizers and primary cementing aids, multi-purpose float collars, stage cementing tools, inner-string cementing tools, inflatable packers, flotation collars, cementing plugs, fill and circulate tools for running casing, casing hangers and drive pipe landing rings, as well as surge reduction equipment. The Company’s headquarters are located in Pearland, Texas. The financial statements have been prepared in the accrual basis of accounting principles in the United States of America.

The unaudited financial statements contained herein include all adjustments which are, in the opinion of management, necessary to provide a fair presentation of the financial condition and results of operations for the periods presented. All such adjustments are of a normal recurring nature. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been condensed or omitted in these financial statements. These financial statements should be read in conjunction with the financial statements and notes included in the Company’s latest audited financial statements as of December 31, 2010 and each of the three years ended December 31, 2010. The results of operations as of June 30, 2011 and for the six-month periods ended June 30, 2011 and 2010 are not necessarily indicative of the results to be expected for the full years ending December 31, 2011 and 2010.

Note B—Summary of significant accounting policies

Cash and cash equivalents:    For purposes of the statements of cash flows, cash and cash equivalents consists of cash in banks, money market funds, and certificates of deposit with original maturities of three months or less.

Allowance for doubtful accounts:    Earnings are charged with a provision for doubtful accounts based upon a current review of the collectability of accounts from customers. Accounts deemed uncollectible are applied against the allowance for doubtful accounts. Accounts receivable, trade was net of an allowance for doubtful accounts of $1,055,817 at June 30, 2011 and December 31, 2010. Bad debt expense totaled $0 for the three months ended June 30, 2011 and 2010, and $0 for the six months ended June 30, 2011, and 2010.

Inventory:    Inventories are stated at the lower of cost or market value using an average standard cost. Cost is determined using standard cost, which approximates average cost, and includes the application of related direct labor and overhead. The Company periodically evaluates the components comprising its inventories and reviews for items that have not been utilized over a certain period of time based on current products in production, physical condition, and future applicability to be utilized in production to determine its obsolescence reserve.

 

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Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Inventories consist of the following:

 

		June 30, 2011				December 31, 2010
		(Unaudited)
Raw material		$	11,015,383			$	8,502,006
Work-in-process			11,574,594				9,317,852
Finished goods			14,476,041				12,854,831
			37,066,018				30,674,689
Less: obsolescence reserve			(5,471,549	)			(5,630,458	)
Inventory, net		$	31,594,469			$	25,044,231

Property and equipment:    Property and equipment are stated at cost. Depreciation is computed over the estimated useful lives of the related assets using the straight-line method. Maintenance and repairs are charged to expense as incurred and significant renewals and betterments are capitalized. The cost and related accumulated depreciation of assets retired or otherwise disposed of are eliminated from the accounts, and any resulting gains or losses are recognized in operations in the year of disposal.

Property and equipment, net and related accumulated depreciation consist of the following:

 

		Estimated useful life				June 30, 2011				December 31, 2010
		(Unaudited)
Autos			3-20 years			$	429,464			$	440,544
Forklifts			3-10 years				321,033				321,033
Machinery and equipment			7-30 years				7,642,423				7,703,908
Leasehold improvements							2,314,447				2,314,447
							10,707,367				10,779,932
Less: accumulated depreciation and amortization							(9,819,388	)			(9,738,634	)
Property and equipment, net						$	887,979			$	1,041,298

Depreciation expense related to property and equipment were $64,522 and $60,441 for the three months ended June 30, 2011 and 2010, respectively, and $169,656 and $210,268 for the six months ended June 30, 2011 and 2010, respectively. For the three months ended June 30, 2011, and 2010, $59,964 and $54,944, respectively, of depreciation expense is included in “cost of sales” and $4,558 and $5,497, respectively, is included in “selling, general, and administrative expenses” in the accompanying statements of operations. For the six months ended June 30, 2011, and 2010, $154,416 and $188,905, respectively, of depreciation expense is included in “cost of sales” and $15,240 and $21,363, respectively, is included in “selling, general and administrative expenses” in the accompanying statement of operations. Repairs and maintenance expense was $118,482 and $96,139 for the three months ended June 30, 2011 and 2010, respectively, and $253,486 and $135,725 for the six months ended June 30, 2011 and 2010, respectively.

 

F-97

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Impairment of long-lived assets:    The Company reviews the recoverability of its long-lived assets, such as plant, property and equipment, when events or changes in circumstances occur that indicate the carrying value of the asset or asset group may not be recoverable and the expected future pre-tax cash flows (undiscounted) to be generated by those assets are less than the carrying value of the assets. In such case, the impairment loss would be equal to the amount by which the carrying value exceeds estimated fair market value of the related assets. Long-lived assets are reviewed for impairment at the individual asset or the asset group level for which the lowest level of independent cash flows can be identified.

Income taxes:    On June 23, 2011, the Company converted from a Subchapter S Corporation to a Limited Liability Company. As a Limited Liability Company, there is no provision for federal income taxes reflected in the financial statements as the Company is not subject to federal income taxes. Earnings flow through to the owner’s personal income tax return.

Effective January 1, 2009, the Company adopted guidance in Accounting Standards Codification (“ASC”) Topic 740 (ASC 740), Income Taxes, for the accounting for the uncertainty in income taxes. The guidance clarifies the accounting for income taxes by prescribing the minimum recognition threshold an income tax position is required to meet before being recognized in the financial statements and applies to all income tax positions. Each income tax position is assessed using a two step process. A determination is made as to whether it is more likely than not that the income tax position will be sustained, based upon technical merits, upon examination by the taxing authorities. If the income tax position is expected to meet the more likely than not criteria, the benefit recorded in the financial statements equals the largest amount that is greater than 50% likely to be realized upon its ultimate settlement.

The adoption of this guidance did not impact the Company’s financial position, results of operations, or cash flows as the income tax positions taken by the Company for any years open under the various statute of limitations is that the Company continues to be exempt from federal income taxes by virtue of its pass through status and that federal income tax is attributable to its owner. Management believes that this tax position meets the more likely than not threshold and accordingly, the tax benefit of this income tax position (no federal income tax expense or liability) has been recognized for any period presented.

The Company records income tax related interest and penalties as a component of the provision for income taxes. For the three months and six months ended June 30, 2011 and 2010, the Company recorded approximately $0 of interest and $0 in penalties related to state income taxes, respectively. The Company believes there is no tax positions taken or expected to be taken that would significantly increase or decrease unrecognized tax benefits within twelve months of the reporting date.

During 2010, the Company underwent a tax audit by the State of Louisiana (the “State”). As a result of this audit, it was determined the Company owed additional taxes totaling $1,249,246, inclusive of interest and penalties, to the State. This amount was reflected in the December 31, 2010 financial statements and was subsequently paid in January 2011. No other state tax returns are currently under examination by state authorities. However, fiscal years 2007 and later remain subject to examination by the respective states in which the Company does business.

 

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

In May 2006, the State of Texas enacted a bill that replaced the existing state franchise tax with a margin tax. Effective January 1, 2007, the margin tax applies to legal entities conducting business in Texas, including previously non-taxable entities such as limited partnerships and limited liability partnerships. The margin tax is based on Texas sourced taxable margin. The tax is calculated by applying a tax rate to a base rate that considers both revenues and expenses and therefore has the characteristics of an income tax. As a result, the Company recorded $61,200 and $24,825 in estimated state income taxes for the three months ended June 30, 2011 and 2010, respectively, and $122,400 and $44,825 for the six months ended June 30, 2011 and 2010, respectively, that is solely attributable to the Texas margin tax and is included in “income tax expense” in the accompanying statements of operations. The Company also recorded $58,800 and $20,743 in state income taxes for the three months ended June 30, 2011 and 2010, respectively, and $115,967 and $20,743 for the six months ended June 30, 2011 and 2010, respectively, attributable to various other states in which the Company conducts business.

Concentrations of credit risk:    Financial instruments that potentially subject the Company to credit risk are cash and cash equivalents and trade accounts receivable. The Company maintains cash balances in high credit quality financial institutions which at times may exceed federally insured limits. The Company monitors the financial condition of these institutions and has experienced no losses associated with these accounts. The Company extends credit to customers throughout the United States of America and certain foreign countries. The Company’s allowance for doubtful accounts is based upon a current review of collectability for each customer taking into consideration current market conditions and other factors.

The Company’s primary customers are in the energy industry. As such, the Company could be affected by events that affect this industry such as natural disasters, political unrest, terrorism, oil prices and domestic policies regarding energy related industries.

In October 2008, the Federal Deposit Insurance Corporation increased its insurance to $250,000 per depositor, and to an unlimited amount for non-interest bearing accounts. The coverage increase, which is temporary, extends through December 31, 2013.

Revenue recognition:    Revenue is recognized when products are shipped or services are performed.

Shipping and handling fees and costs:    Shipping and handling fees, if billed to customers, are included in net sales. Shipping and handling costs are classified as cost of sales.

Use of estimates:    The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, the Company evaluates its estimates and assumptions, including those related to its allowance for doubtful accounts, inventory obsolescence, impairment for property and equipment and contingencies. Actual results could differ from these estimates.

 

F-99

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Table of Contents

Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Environmental remediation:    The Company accounts for environmental remediation in accordance with ASC Topic 410, Asset Retirement and Environmental Obligations. In accordance with this guidance, liabilities are recorded when environmental assessments indicate that remediation efforts are probable and the costs can be reasonably estimated. Estimates of the liability are based upon currently available facts, existing technology and presently enacted laws and regulations, taking into consideration the likely effects of inflation and other societal and economic factors, and include estimates of associated legal costs.

Fair value of financial instruments:    Financial instruments of the Company consist primarily of cash and cash equivalents, accounts receivable and accounts payable. The Company’s management considers the carrying values of cash and cash equivalents, accounts receivable and accounts payable to be representative of their respective fair values because of their short-term nature.

Recent accounting standards:    In June 2011, the Financial Accounting Standards Board (“FASB”) issued an update to ASC 220, Presentation of Comprehensive Income. This Accounting Standards Update (“ASU”) provides that an entity that reports items of other comprehensive income has the option to present comprehensive income in either 1) a single statement that presents the components of net income and total net income, the components of other comprehensive income and total other comprehensive income, and a total for comprehensive income; or 2) a two-statement approach which presents the components of net income and total net income in a first statement, immediately followed by a financial statement that presents the components of other comprehensive income, a total for other comprehensive income, and a total for comprehensive income. The option in current GAAP that permits the presentation of other comprehensive income in the statement of changes in equity was eliminated. The guidance will be applied retrospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is permitted. The adoption of this guidance will not have a material impact on the Company’s financial statements.

In May 2011, the FASB issued an update to ASC 820, Fair Value Measurements. This ASU clarifies the application of certain fair value measurement requirements and requires, among other things, expanded disclosures for Level 3 fair value measurements and the categorization by level for items for which fair value is required to be disclosed in accordance with ASC 825, Financial Instruments. The guidance will be applied prospectively and is effective for the Company for annual periods beginning on January 1, 2012. Early adoption is not permitted. The adoption of this standard will not have an impact on the Company’s financial statements.

In October 2009, the FASB issued an update to ASC 605, Revenue Recognition. This ASU allows companies to allocate consideration for qualified separate deliverables using the estimated selling price for both delivered and undelivered items when vendor-specific objective evidence or third-party evidence is unavailable. It also requires additional disclosures on the nature of multiple element arrangements, the types of deliverables under the arrangements, the general timing of their delivery, and significant factors and estimates used to determine estimated selling prices. The Company adopted this new guidance on January 1, 2011. Accordingly, the Company applies this guidance to transactions initiated or materially modified on or after January 1, 2011. The Company’s adoption of this new guidance did not have an impact on its financial position, results of operations, cash flows or existing revenue recognition policies.

 

F-100

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Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

In December 2010, the FASB issued an update to ASC 805, Business Combinations. This ASU addressed the disclosure of comparative financial statements and expanded on the supplementary pro forma information for business combinations. The Company adopted this ASU prospectively for business combinations occurring on or after December 15, 2010.

Note C—Accrued expenses and other liabilities

Accrued expenses consisted of the following:

 

		June 30, 2011				December 31, 2010
		(Unaudited)
Sales tax payable		$	165,774			$	131,164
Customer credits			74,270				74,270
Accrued commissions			2,063,768				2,098,912
Accrued bonuses			642,000				—
Accrued royalties			1,242,538				527,842
Accrued state taxes			159,512				404,000
Accrued professional services			125,000				—
		$	4,472,862			$	3,236,188

Note D—Income taxes

The provision for income taxes as of June 30, 2011 and 2010 consists of the following (unaudited):

 

		Three months ended June 30,								Six months ended June 30,
		2011				2010				2011				2010
Texas margin tax		$	61,200			$	24,825				122,400			$	44,825
Other state income taxes			58,800				20,743				115,967				20,743
Total		$	120,000			$	45,568			$	238,367			$	65,568

Note E—Commitments and contingencies

In 2009, an embezzlement scheme totaling approximately $15 million was discovered by the Company, whereby former employees had submitted fraudulent invoices for payments for over a decade. The fraud came to light during a two month examination of the Company’s accounting records. The Company hired a third party independent consultant to investigate this matter and to conduct the examination. The consultant has reported their findings to management of the Company, which has begun legal action against the defendants in Federal District Court. All amounts pertaining to this matter related to years prior to 2010. In 2010, the Company was awarded summary judgment, no amounts have been received, and no receivable has been recorded by the Company at June 30, 2011. The Company intends to vigorously pursue this matter.

 

F-101

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Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

In January 2010, a favorable settlement was reached in a patent infringement lawsuit whereby the Company was the plaintiff. Terms of the settlement were not disclosed, but the defendant will pay a 10% royalty on future sales of the products included in the lawsuit. The Company recognized royalty income of $88,936 and $396,793 related to this settlement in the six months ended June 30, 2011 and 2010, respectively.

The Company is involved in various disputes arising in the ordinary course of business. Management does not believe the outcome of these disputes will have a material adverse effect on the Company’s financial position, results of operations or cash flows.

The Company leases certain equipment and office and manufacturing space under non-cancelable operating leases which expire at various dates through 2010 and now are month to month in nature. Total rental expense for the three months ended June 30, 2011, and 2010, were both approximately $59,000, and approximately $118,000 for both the six months ended June 30, 2011 and 2010, respectively.

The Company has various standby letters of credit with a financial institution up to a total commitment limit of $3,000,000 of which approximately $2,645,675 was utilized at June 30, 2011. The letters of credit expire through November 2011, and support certain international operations.

Note F—Related party transactions

The Company leases land from a related party. Total rent expense was approximately $30,000 for both the three months ended June 30, 2011, and 2010, and approximately $60,000 for both the six months ended June 30, 2011 and 2010.

For the three months ended June 30, 2011 and 2010, the Company purchased supplies and materials from a related party which totaled approximately $79,000 and $63,000, respectively, and approximately $158,000 and $125,000 for the six months ended June 30, 2011 and 2010, respectively.

The Company utilizes a staffing company that is a related party. Total expense for the three months ended June 30, 2011 and 2010 was approximately $3,600,000 and $0, respectively, and approximately $6,896,000 and $0 for the six months ended June 30, 2011 and 2010, respectively.

Note G—Risk and uncertainties

The current downturn in the United States economy, and any economic slowdown in future periods, could adversely affect the Company in ways that cannot be predicted. During times of economic slowdown, the Company’s customers may reduce their capital expenditures and defer or cancel pending orders. Such developments occur even among customers that are not experiencing financial difficulties. These deferrals or cancelling of capital expenditures could directly impact the demand for the Company’s products and services. Additionally, bankruptcies or financial difficulties among the Company’s customers could reduce its cash flows and adversely impact liquidity and profitability.

 

F-102

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Index to Financial Statements

Davis-Lynch, Inc.

Notes to financial statements (continued)

 

Note H—Subsequent events

The Company has evaluated all events subsequent from the balance sheet date of June 30, 2011 through August 29, 2011, and noted no subsequent events that would require recognition or disclosure in the financial statements, other than those items disclosed herein and below.

On June 25, 2011, Forum Energy Technologies, Inc. entered into an agreement to purchase the Company for cash, as outlined under the terms in the purchase and sale agreement, subject to certain working capital adjustments. The transaction closed on July 29, 2011.

 

F-103

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Index to Financial Statements

Wood Flowline Products, LLC financial statements

Index

 

		Page(s)
Report of Independent Registered Public Accounting Firm			F-105
Balance Sheet			F-106
Statement of Operations			F-107
Consolidated Statement of Members’ Equity			F-108
Statement of Cash Flows			F-109
Notes to Financial Statements			F-110

 

F-104

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Index to Financial Statements

Report of independent registered public accounting firm

To the Members of

Wood Flowline Products, LLC

In our opinion, the accompanying balance sheet and the related statements of operations, of members’ equity and of cash flows, present fairly, in all material respects, the financial position of Wood Flowline Products, LLC at December 31, 2010 and the results of its operations and its cash flows for the year then ended in conformity with accounting principles generally accepted in the United States of America. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audit of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

June 24, 2011

 

F-105

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Index to Financial Statements

Wood Flowline Products, LLC

Balance sheet

December 31, 2010

 

		(thousands)
Assets
Current assets
Cash and cash equivalents		$	710
Accounts receivable, net			5,444
Inventories			4,792
Prepaid expenses and other current assets			373
Total current assets			11,319
Property, plant and equipment, net			2,265
Total assets		$	13,584
Liabilities and Members’ Equity
Current liabilities
Current portion of long-term debt—related party		$	629
Current portion of long-term debt			65
Accounts payable			2,359
Accrued expenses and other payables			496
Total current liabilities			3,549
Long-term debt, less current portion—related party			203
Long-term debt, less current portion			100
Commitments and contingencies (Note 7)
Members’ Equity			9,732
Total liabilities and members’ equity		$	13,584

The accompanying notes are an integral part of this financial statements.

 

F-106

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Index to Financial Statements

Wood Flowline Products, LLC

Statement of operations

Year ended December 31, 2010

 

		(thousands)
Revenue
Products		$	23,964
Services			4,560
Total revenue			28,524
Operating costs and expenses
Cost of revenue
Products			17,781
Services			958
Selling, general and administrative expenses			1,576
			20,315
Income from operations			8,209
Other income (expense)
Interest expense			(81	)
Other expense, net			(4	)
Total other expenses			(85	)
Net income		$	8,124

The accompanying notes are an integral part of this financial statements.

 

F-107

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Index to Financial Statements

Wood Flowline Products, LLC

Consolidated statements of members’ equity

December 31, 2010

 

		(thousands)
		Total members’ equity
Balance, December 31, 2009		$	1,925
Distributions to members			(317	)
Net income			8,124
Balance, December 31, 2010		$	9,732

The accompanying notes are an integral part of this financial statements.

 

F-108

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Index to Financial Statements

Wood Flowline Products, LLC

Statement of cash flows

December 31, 2010

 

		(thousands)
Cash flow from operating activities
Net income		$	8,124
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation expense			427
Bad debt expense			40
Loss on sale of equipment			4
Changes in operating assets and liabilities
Accounts receivable (increase)			(4,672	)
Inventories (increase)			(3,105	)
Prepaid expenses and other current assets (increase)			(262	)
Accounts payable and accrued expenses increase			1,687
Net cash provided by operating activities			2,243
Cash flow from investing activities
Net cash received from sale of assets			23
Purchase of property, plant and equipment			(1,055	)
Net cash used by investing activities			(1,032	)
Cash flow from financing activities
Proceeds from related party notes			390
Payments of related party notes			(544	)
Payments of equipment notes			(38	)
Distributions to members			(317	)
Net cash used by financing activities			(509	)
Net increase in cash			702
Cash and cash equivalents
Beginning of period			8
End of period		$	710
Supplemental cash flow information
Cash paid for interest		$	69
Noncash investing and financing activities
Property, plant and equipment acquired through note payable		$	203

The accompanying notes are an integral part of this financial statements.

 

F-109

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Index to Financial Statements

Wood Flowline Products, LLC

Notes to financial statements

December 31, 2010

1. Description of business and organization

Wood Flowline Products LLC (the “Company”), formed as a limited liability company in the State of Texas in September 2008, is a company focused on the manufacturing, distribution and maintenance of well-completion products. This includes the manufacturing, testing, rebuilding and recertification of swivel joints, pup joints, check valves, release valves, manifold trailers and other completion products. The Company has facilities in Oklahoma and Arkansas. The Company provides complete and detailed rebuild and recertification services for frac iron at its facilities. The Company also has a mobile rebuild and recertification team that provides flow line and valve maintenance, repair, ultrasonic testing and hydrostatic testing in the field.

2. Significant accounting policies

Cash and cash equivalents

Cash and cash equivalents include cash on hand and all highly liquid investments with original maturities of three months or less.

Revenue recognition

For product sales, the Company recognizes revenue when persuasive evidence of an arrangement exists, performance has occurred, collection is reasonably assured, the sale price is fixed and determinable, and risk of loss for products shipped has occurred.

For rebuild and recertification services, the Company recognizes revenue when the service is complete.

Shipping and handling fees

The Company includes shipping and handling fees billed to customers in product sales revenue. Shipping and handling costs associated with these sales were $258 thousand for the year ended December 31, 2010.

Accounts receivable

The Company extends credit to customers in the normal course of business. The Company estimates its bad debt exposure based upon aging its accounts receivable balances each period and records a bad debt provision for accounts receivable it believes it may not collect in full. The Company has recorded a reserve for uncollectible accounts receivable of $40 thousand at December 31, 2010.

Concentration of credit risk

The majority of the Company’s customers operate in the oil and gas industry. While current energy prices are important contributors to positive cash flow for the customers, expectations about future prices and price volatility are generally more important for determining future

 

F-110

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Index to Financial Statements

Wood Flowline Products, LLC

Notes to financial statements

December 31, 2010 (continued)

 

spending levels. Any prolonged increase or decrease in oil and natural gas prices affects the levels of exploration, development and production activity as well as the entire health of the oil and natural gas industry, and can therefore negatively impact spending by Company’s customers.

Revenue for the year ended December 31, 2010 includes sales to 5 customers that each individually represented more than 10% of total revenue. These customers accounted for 85% of revenue for the year ended December 31, 2010. Accounts receivable from these customers totaled 86% of accounts receivable at December 31, 2010.

The Company maintains its cash balances at one financial institution. The Federal Deposit Insurance Corporation insures account balances up to $250 thousand, and they have offered unlimited coverage for noninterest bearing accounts at participating FDIC insured institutions through June 30, 2012. The Company’s major bank participates in this program. The Company does not believe that it is exposed to any significant credit risk on any uninsured amounts.

Inventories

Inventories are stated at the lower of cost or market, cost being determined on an average cost basis. The Company reviews its inventory balances and writes down its inventory for estimated obsolescence or excess inventory equal to the difference between the cost of inventory and the estimated market value based upon assumptions about future demand and market conditions. There was no reserve recorded for inventory on hand at December 31, 2010.

Concentration of supplier risk

Purchases during the year ended December 31, 2010 include purchases from 3 suppliers that each individually represented more than 10% of total inventory purchases. These suppliers accounted for 59% of total inventory purchases for the year ended December 31, 2010. The Company’s accounts payable to these vendors totaled 60% of total accounts payable at December 31, 2010.

Property, plant and equipment

Property and equipment are recorded at cost. The costs of major renewals and betterments are capitalized; repair and maintenance costs are expensed as incurred. When assets are sold or retired, the cost and related accumulated depreciation are removed from the appropriate accounts, and the resulting gain or loss is included in current operations. Leasehold improvements are capitalized and amortized over the lesser of their estimated useful lives or 5 years.

 

F-111

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Index to Financial Statements

Wood Flowline Products, LLC

Notes to financial statements

December 31, 2010 (continued)

 

Depreciation of property and equipment is computed principally using the straight-line basis over the estimated useful lives of the assets as set forth below:

 

Description		Useful life
Leasehold and improvements			5 years
Furniture, fixtures			5 years
Machinery and equipment			7 years
Vehicles			3 years
Computers and software			3 years

Members’ equity

The Company has one class of equity. Members’ interests were determined based upon each member’s initial capital contribution in accordance with the Company Agreement. Initial capital contributions totaled $1 million.

Impairment of long-lived assets

Long-lived assets held and used by the Company are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. For purposes of evaluating the recoverability of long-lived assets, the recoverability test is performed using undiscounted future net cash flows of assets grouped at the lowest level for which there are identifiable cash flows that are independent of the cash flows of other groups of assets. If the undiscounted future net cash flows are less than the carrying amount of the asset, the asset is deemed impaired. The amount of the impairment is measured as the difference between carrying value and the fair value of the asset.

Income taxes

As a limited liability company, provision for income taxes is not made in the Company’s accounts since such taxes are the responsibility of the individual members. Further, the members capital account reflected in the accompanying balance sheet differs from amounts reported in the members’ income tax returns because of differences in the timing of certain expense and revenue items for financial and tax reporting purposes.

Use of estimates

The preparation of the financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Accordingly, actual results could differ from these estimates.

 

F-112

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Index to Financial Statements

Wood Flowline Products, LLC

Notes to financial statements

December 31, 2010 (continued)

 

3. Inventories

Inventories consist of the followings at December 31, 2010:

 

		(thousands)
Raw materials		$	4,026
Work-in-progress			335
Finished goods			431
		$	4,792

4. Property, plant and equipment

The following is a summary of property, plant and equipment at December 31, 2010:

 

		(thousands)
Machinery and equipment		$	1,534
Furniture, fixtures and computers and software			85
Automobile and other vehicles			382
Leasehold improvements			796
Less: Accumulated depreciation			(634	)
Construction in process			102
		$	2,265

Depreciation expense was $427 thousand for the year ended December 31, 2010, of which $279 thousand, $88 thousand and $60 thousand is recorded within products cost of revenue, services cost of revenue and selling, general and administrative expenses, respectively, in the accompanying statement of operations.

5. Accrued expenses

The following is a summary of accrued expenses at December 31, 2010:

 

		(thousands)
Accrued vacation		$	31
Accrued interest			13
Insurance payable			222
Sales, franchise taxes			110
Payroll accrual			114
Payroll liabilities			6
		$	496

 

F-113

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Table of Contents

Index to Financial Statements

Wood Flowline Products, LLC

Notes to financial statements

December 31, 2010 (continued)

 

6. Long-term debt

The Company entered into loan agreements with a related party for a total of $1.1 million. These loans were made from January 2009 to July 2009. The loans are unsecured and bear interest at 7% per year payable in equal installments of $35 thousand each month.

Additional loan agreements totaling $273 thousand were entered into with the related party from December 2009 to September 2010. These loans are also unsecured, bear interest at 7% per year and were due in full in February 2011.

Three equipment notes were entered into between June 2010 and August 2010. The notes are collateralized by assets and bear interest at rates between 6.5% and 7% per year, payable in installments totaling $6 thousand per month.

The long-term debt’s fair value approximates its carrying value.

Following are maturities of notes payable for each of the next five years:

 

2011		$	694
2012			254
2013			37
2014			8
2015			4
		$	997

7. Commitments and contingencies

At December 31, 2010 the Company had a commitment for $376 thousand to purchase machinery and equipment.

8. Related party transactions

The Company conducts business with another entity related through common ownership. Sales to that entity for the year ending December 31, 2010 were $519 thousand. Accounts receivable from that entity at December 31, 2010 was $257 thousand.

During the year ending December 31, 2010 the Company purchased fixed assets from an owner of the Company. The fixed assets purchased were two trucks and two trailers used in the mobile recertification/rebuild operations of the Company. One truck and trailer was purchased for $50 thousand, and the other was purchased for $127 thousand.

The Company entered into loan agreements with an investment company affiliated with two of the Company’s four ownership interests. See Note 6.

9. Subsequent events

On February 3, 2011 Forum Energy Technologies Inc., through one of its subsidiaries, purchased 100% of the stock of Wood Flowline Products LLC. Forum Energy Technologies is a global oilfield

 

F-114

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Table of Contents

Index to Financial Statements

Wood Flowline Products, LLC

Notes to financial statements

December 31, 2010 (continued)

 

products Company, serving the drilling, subsea, completion, production and process sectors of the oil and natural gas industry. All of the long-term debt outstanding at December 31, 2010 was repaid in connection with this transaction.

Events occurring after December 31, 2010 were evaluated as of June 24, 2011, the date this report was made available to be issued, to ensure any subsequent events that meet the criteria for recognition and/or disclosure in this report have been identified.

 

F-115

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Financial statements

for the year ended 30 April 2011

 

Contents
Report of Independent Registered Public Accounting Firm to the member of AMC Global Group Limited			F-117
Consolidated profit and loss account for the year ended 30 April 2011			F-118
Consolidated and Company balance sheets as at 30 April 2011			F-119
Consolidated cash flow statement for the year ended 30 April 2011			F-120
Notes to the consolidated financial statements for the year ended 30 April 2011			F-121

 

F-116

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Report of independent registered public accounting firm

to the member of AMC Global Group Limited

In our opinion, the accompanying consolidated and company balance sheets and the related consolidated profit and loss account and cash flow statement present fairly, in all material respects, the financial position of AMC Global Group Limited and its subsidiaries at 30 April 2011, and the results of their operations and their cash flows for the year ended 30 April 2011 in conformity with accounting principles generally accepted in the United Kingdom. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audits of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

Accounting principles generally accepted in the United Kingdom vary in certain significant respects from accounting principles generally accepted in the United States of America. Information relating to the nature of such differences is presented in notes 2 to the combined financial statements.

/s/ PricewaterhouseCoopers LLP

Aberdeen, United Kingdom

August 31, 2011

 

F-117

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Consolidated profit and loss account for the year ended

30 April 2011

 

		Note				2011 £
Turnover			3				12,832,852
Cost of sales							(5,755,776	)
Gross profit							7,077,076
Administrative expenses							(1,930,342	)
Other operating income							10,496
Operating profit			4				5,157,230
Interest receivable and similar income			7				16,209
Interest payable and similar charges			8				(15,011	)
Profit on ordinary activities before taxation							5,158,428
Tax on profit on ordinary activities			9				(1,522,053	)
Profit for the financial year			23				3,636,375

All amounts relate to continuing operations.

The Group has no recognised gains or losses other than those included in the profit and loss account above.

There is no difference between the profit on ordinary activities before taxation and the profit for the year above and their historical cost equivalents.

The accompanying notes are an integral part of these financial statements.

 

F-118

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Consolidated and company balance sheets as at

30 April 2011

 

		Note				Group 2011 £				Company 2011 £
Fixed assets
Intangible assets			12				2,975,987				—
Tangible assets			13				1,504,047				—
Investments			14				—				5,057,887
							4,480,034				5,057,887
Current assets
Stock			15				1,437,739				—
Debtors			16				2,958,619				—
Investments			17				550,000				—
Cash at bank and in hand							3,569,422				25,329
							8,515,780				25,329
Creditors: amounts falling due within one year			18				(2,586,354	)			(1,845,419	)
Net current assets/(liabilities)							5,929,426				(1,820,090	)
Total assets less current liabilities							10,409,460				3,237,797
Creditors: amounts falling due after more than one year			19				—				—
Provisions for liabilities			20				(8,706	)			—
Net assets							10,400,754				3,237,797
Capital and reserves
Called up share capital			21				2,550,000				2,550,000
Profit and loss account			22				7,850,754				687,797
Total shareholders’ funds			23				10,400,754				3,237,797

The financial statements on pages F-118 to F-132 were approved by the board of directors on August 31, 2011 and were signed on its behalf by:

 

/s/ James W. Harris

Director

Registered no. SC SC333600 (Scotland)

 

F-119

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Consolidated cash flow statement for the year ended

30 April 2011

 

		Note				£				£
Net cash inflow from operating activities			24								4,263,878
Returns on investments and servicing of finance
Interest received			7				16,209
Interest paid			8				(15,011	)
Net cash inflow from returns on investments and servicing of finance											1,198
Taxation											(762,940	)
Capital expenditure and financial investment
Purchase of tangible fixed assets			13				(453,155	)
Sale of tangible fixed assets							5,501
Net cash inflow for capital and financial investment											(447,654	)
Equity dividends paid to shareholders			11								(62,500	)
Net cash inflow before use of liquid resources and financing											2,991,982
Net cash outflow from management of liquid resources											(300,000	)
Financing
Redemption of loan notes							(752,845	)
Net cash inflow from financing											(752,845	)
Increase in net cash											1,939,137
Reconciliation to net cash
Net cash at 1 May											1,127,439
Decrease in net cash											1,939,138
Cash inflow from increase in liquid resources											300,000
Movement in borrowings											752,845
Net cash at 30 April 2011											4,119,422

 

F-120

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011

1. Business activities

The principal activity of the Group is the manufacture, sale and maintenance of torquing equipment (bucking machines) to the global oil and gas industry.

2. Accounting policies

(a) UK GAAP accounting policies

Accounting convention

These financial statements are prepared on a going concern basis, under the historical cost convention and in accordance with the Companies Act 2006 and applicable accounting standards in the United Kingdom. The principal accounting policies are set out below.

Basis of consolidation

The Group financial statements comprise the financial statements of the Company and all its subsidiary undertakings. The accounting reference date of the Company and its subsidiary undertakings is 30 April. Uniform accounting policies are applied throughout the Group. Profits or losses on intra-Group transactions are eliminated on consolidation.

Turnover

Turnover represents amounts receivable for goods and services net of VAT and trade discounts. It includes the relevant proportion of contract value for performance up to the year end.

Goodwill

When the fair value of the consideration for an acquired undertaking exceeds the fair value of its separable net assets the difference is treated as purchased goodwill and is capitalised and amortised through the profit and loss account on a straight line basis over its estimated economic life of 20 years. Impairment reviews are carried out to ensure that goodwill is not carried at above its recoverable amount.

 

F-121

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

Tangible fixed assets and depreciation

Tangible fixed assets are stated at cost less depreciation. Cost includes the original purchase price of the asset and the costs attributable to bringing the asset to its working condition for its intended use. Depreciation is provided at the following annual rates in order to write off each asset over its estimated useful life.

 

Land and buildings		10% Straight line
Plant & equipment		20% Straight line
Fixtures, fittings & equipment		20%—30% Straight line
Motor vehicles		25% Straight line

Investments

Investments in subsidiary undertakings are recorded at cost plus incidental expenses less any provision for impairment. Impairment reviews are performed by the directors when there has been an indication of potential impairment.

Current asset investments are stated at the lower of cost and net realisable value.

Stocks

Stock is valued at the lower of cost and net realisable value after making due allowance for any obsolete or slow-moving items.

Long-term contracts

Turnover and profit is recognised on long-term contracts as contract activity progresses and is calculated by reference to the value of work performed to date as a proportion of the total contract cost where the outcome can be assessed with reasonable certainty. Provisions for foreseeable losses are recognised in full when identified Turnover derived from variations on long-term contracts is recognised only when they have been accepted by the customer.

Where the invoiced value of work performed on a long-term contract is less than the actual value of the work performed by reference to the proportion of overall estimated contract costs incurred, the difference is recorded as amounts recoverable on long-term contracts and included within debtors due within one year.

Where payments are received from customers which exceed the value of work performed on a long-term contract the excess amounts are recorded as amounts payable under long-term contracts and included within creditors falling due within one year.

 

F-122

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

Pension costs

The Company operates a defined contribution scheme. The assets of the scheme are held separately from those of the Company in an independently administered fund. Contributions payable for the period are charged in the profit and loss account in the period to which they relate.

Current and deferred taxation

Corporation tax is provided on the assessable profits of the Company at the appropriate rates in force.

Deferred tax is recognised in respect of all timing differences that have originated but not reversed at the balance sheet date where transactions or events that result in an obligation to pay more tax or a right to pay less tax in the future have occurred at the balance sheet date. Timing differences are differences between the Company’s taxable profits and its results as stated in the financial statements. Deferred tax is measured at average tax rates that are expected to apply in the years in which the timing differences are expected to reverse, based on tax rates and laws that have been enacted or substantially enacted by the balance sheet date. Deferred tax assets and tax debtors arising from withholding tax credits are recognised to the extent that they are more likely than not to be recoverable. Deferred tax is measured on a non-discounted basis.

Foreign currency translation

The functional and presentational currency of the Company is Pounds Sterling.

Transactions in foreign currencies are recorded at the date ruling at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are retranslated at the rate of exchange ruling at the balance sheet date. All differences are taken to the profit and loss account.

Research and development

Research expenditure is written off to to cost of sales in the profit and loss account in the year in which it is incurred.

(b) Principal differences to US GAAP

The financial statements have been prepared in accordance with accounting principles generally accepted in the United Kingdom (‘UK GAAP”). Such principles differ in certain significant respects from generally accepted accounting principles in the United States (‘US GAAP’). A summary of principal differences applicable to AMC Global Group Limited are set out below.

 

F-123

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

Goodwill and intangible asset amortization

Under UK GAAP, goodwill arising and separately identifiable and separable intangible assets acquired on acquisitions made on or after 1 April 1998 are capitalized and amortized over their useful life, with a rebuttable presumption that the useful life will not exceed a period of 20 years. Prior to 1 April 1998, all goodwill and separately identifiable and separate intangible assets were written off to reserves on acquisition.

Under US GAAP, SFAS 142, “Goodwill and Other Intangible Assets” became effective for fiscal years beginning after 15 December 2001. Under SFAS 142, goodwill is not amortized but is tested for impairment on an annual basis or where there is an indicator of impairment. Prior to SFAS 142, goodwill was capitalized and amortized over its estimated useful life. Under SFAS 142, recognized intangible assets are amortized over their estimated useful lives.

Deferred income taxes

Under UK GAAP, deferred taxation is provided in full on all material timing differences. Deferred tax assets are recognized where their recovery is considered more likely than not. US GAAP requires deferred taxation to be provided in full, using the liability method. In addition, US GAAP requires the recognition of the deferred tax consequences of differences between the assigned values and the tax bases of the identifiable intangible assets, with the exception of non tax-deductible goodwill, in a purchase business combination. Consequently, a deferred tax liability attributable to identifiable intangible assets will be recognized and amortized over the useful economic lives of the underlying intangible assets.

Statement of cash flows

The statement of cash flows under UK GAAP is prepared in accordance with FRS 1 (revised) and presents substantially the same information as that required under US GAAP. Under US GAAP, however, there are certain differences from UK GAAP with regard to the classification of items within the cash flow statement and with regard to the definition of cash and cash equivalents.

Revenue Recognition—Long-term contract

Under UK GAAP, SSAP 9 defines a long-term contract as a contract entered into for the design, manufacture or construction of a single substantial asset where the time taken substantially to complete the contract is such that the contract activity falls into different accounts periods. This definition requires contracts with duration of less than one year to be accounted for as long-term contracts if they are sufficiently material to the activities of the period that failure to record turnover and profit on them would result in the accounts not giving a true and fair view. The Company recognizes revenue and cost of goods sold each period based upon the advancement of the work-in-progress unless the stage of completion is insufficient to enable a reasonably certain forecast of profit to be established. Under US GAAP, revenue would be accounted for on these contracts only when delivery has occurred.

 

F-124

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

Financial statement presentation

The format and presentation of the balance sheet, income statement and statement of cash flows under UK GAAP differs from that under US GAAP.

3. Turnover

In the opinion of the directors it would be seriously prejudicial to disclose segmental information by class of business or by geographical markets.

4. Operating profit

 

		2011
		£
Operating profit is stated after charging/(crediting):
Depreciation of tangible fixed assets
Owned assets			240,764
Amortisation of goodwill			175,920
Loss on disposal of fixed assets			6,133
Operating leases
Plant and machinery			12,000
Foreign exchange differences			(13,220	)
Services provided by the Company’s auditor
Audit fees			31,100

5. Directors’ remuneration

 

		2011
		£
Remuneration for qualifying services			300,292
Company contributions to defined benefit pension schemes			12,858
			313,150

The number of directors for whom retirement benefits are accruing under defined contribution schemes amounted to 3.

The remuneration disclosed above includes the following amounts paid to the highest paid director:

 

		2011
		£
Remuneration for qualifying services			119,755
Company contributions to defined benefit pension schemes			8,057

 

F-125

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

6. Employees

The average monthly number of persons (including executive directors) employed by the Group during the year was:

 

		2011
Direct			52
Administrative			19
Directors			3
			74

The staff costs for the Group including directors’ remuneration were as follows:

 

		2011
		£
Wages and salaries			2,252,408
Social security costs			275,434
Other pension costs			24,944
			2,552,786

7. Interest receivable and similar income

 

		2011
		£
Bank interest			16,209

8. Interest payable and similar charges

 

		2011
		£
On other loans			15,011

9. Taxation

(a) Analysis of tax charge in the year:

 

		2011
		£
Current tax:
UK corporation tax on profits for the year			1,522,053
Total current tax charge			1,522,053
Deferred tax:
Origination and reversal of timing differences			—
Total deferred tax charge			—
Tax on profits on ordinary activities			1,522,053

 

F-126

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

(b) Factors affecting tax charge for the year:

The tax assessed for the year is higher than the standard rate of corporation tax in the UK of 27.83%. The differences are explained below:

 

		2011
		£
Profit on ordinary activities before tax			5,158,428
Profit on ordinary activities at the standard rate of corporation tax in the UK of 27.83% (2009: 28%)			1,435,762
Effects of:
Expenses disallowed for tax purposes			5,378
Depreciation and amortisation in excess of capital allowances			97,702
Foreign tax adjustments			(18,496	)
Other tax adjustments			1,707
Current tax charge for year			1,522,053

(c) Factors that may affect future tax charges:

The UK substantively enacted on 20 July 2010 an amendment to the corporation tax rate from 28% to 27% effective from 1 April 2011. Further reductions to the UK corporation tax rate were announced in the March 2011 Government Budget. The changes propose to reduce the corporation tax rate to 26% on 1 April 2011 and reduce the rate by 1% per annum thereafter to 23% by 1 April 2014. The reduction of the main corporation tax rate to 26% was substantively enacted on 29 March 2011. The reduction to 25% from April 2012 was substantively enacted on 5 July 2011. The changes to the tax rates do not have a material impact on these financial statements.

10. Profit and loss account of the Company

The Company made a loss of £10,301. The directors have taken advantage of the exemption available under section 408 of the Companies Act 2006 and not presented a profit and loss account for the Company alone.

11. Dividends

 

		2011
		£
Equity—Ordinary
Interim paid: 31.25p per ordinary share			62,500

 

F-127

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

12. Intangible fixed assets

 

		Goodwill
Group		£
Cost
At 1 May 2010 and 30 April 2011			3,518,407
Accumulated amortisation
At 1 May 2010			366,500
Charge for the year			175,920
At 30 April 2011			542,420
Net book value
At 30 April 2011			2,975,987

13. Tangible fixed assets

 

Group		Land and buildings				Plant and machinery				Fixtures, fittings and equipment				Motor vehicles				Total
		£				£				£				£				£
Cost
At 1 May 2010			1,299,887				354,137				55,592				147,879				1,857,495
Additions			348,202				71,933				3,045				29,975				453,155
Disposals			—				(134,874	)			(40,598	)			(6,200	)			(181,672	)
At 30 April 2011			1,648,089				291,196				18,039				171,654				2,128,978
Accumulated depreciation
At 1 May 2010			255,173				189,886				40,885				68,259				554,203
Charge for the year			140,539				57,155				6,632				36,438				240,764
Disposals			—				(127,020	)			(40,187	)			(2,829	)			(170,036	)
At 30 April 2011			395,712				120,021				7,330				101,868				624,931
Net book value
At 30 April 2011			1,252,377				171,175				10,709				69,786				1,504,047

There are no assets held under finance leases or hire purchase contracts.

14. Fixed asset investments

 

		Subsidiary undertakings
Company		£
At 30 April 2011			5,057,887

 

F-128

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

In the opinion of the directors, the aggregate value of the Company’s investment in subsidiary undertakings is not less than the amount included in the balance sheet.

AMC Global Group Limited is a private Company, registered and domiciled in Scotland. Details of investments in which the Company hold more than 20% of the nominal value of any class of share capital are as follows:

 

Company		Country of incorporation		Class				Shares held %
AMC Global Engineering Limited		Scotland			Ordinary				100

AMC Global Engineering Limited holds 100% of the ordinary share capital of AMC Engineering Limited, a Company incorporated in Scotland and 100% of the ordinary share capital of AMC Torque Solutions Inc., a Company incorporated in the United States of America

The principal activities of subsidiary undertakings are as follows:

 

AMC Global Engineering Limited		Holding Company, operation of a property business for members of the Group and the provision of management services to its subsidiary.
AMC Engineering Limited		Manufacture, sale and maintenance of torquing equipment (bucking machines) to the global oil and gas industry.
AMC Torque Solutions Inc.		Sale and maintenance of torquing equipment (bucking machines) to the global oil and gas industry.

15. Stock

 

		2011
		£
Raw materials and consumables			1,437,739

16. Debtors

 

		2011
		£
Trade debtors			2,256,615
Amounts recoverable on long-term contracts			498,184
Corporation tax			—
Other debtors			199,729
Prepayments and accrued income			4,091
			2,958,619

 

F-129

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

17. Current asset investments

 

		2011
		£
Listed investments			550,000

Current asset investments comprise of deposit investments with a market value at 30 April 2011 of £603,170.

18. Creditors: amounts falling due within one year

 

		Group 2011				Company 2011
		£				£
Trade creditors			1,304,986				—
Payments on account on contracts			192,860				—
Amounts owed to Group undertakings			—				1,845,419
Corporation tax			966,709				—
Other taxation and social security			88,992				—
Other creditors			9,082				—
Accruals and deferred income			23,725				—
			2,586,354				1,845,419

Amounts owed by Group undertakings are unsecured, have no fixed date of repayment and are repayable on demand.

19. Provisions for liabilities

The liability for deferred taxation is analysed below:

 

		2011
		£
Accelerated capital allowances			8,706

The movement on the deferred tax liability is as follows:

 

Group		£
At 1 May 2010			8,706
Deferred tax charged to profit and loss account			—
At 30 April 2011			8,706

 

F-130

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

20. Pension and other post-retirement benefit commitments

The Group made the following contributions to defined contribution pension schemes:

 

		2011
		£
Contributions payable by the Group for the year			16,209

21. Share capital

 

Group and Company		2011
		£
Allotted, called up and fully paid
200,000 Ordinary shares of £1 each			200,000
2,350,000 Preference shares of £1 each			2,350,000
			2,550,000

The Preference shares do not entitle the holders to any dividends and have no set redemption date.

Preference shareholders are not entitled to attend or vote at any general meetings of the Company.

On a distribution of the Company assets, Preference shareholders are to be repaid £1 for each Preference share held. Any surplus remaining is to be distributed among the Ordinary shareholders.

22. Profit and loss account

 

		Group 2011				Company 2011
		£				£
At 1 May			4,276,879				760,598
Retained profit/(loss) for the year (note 23)			3,573,875				(72,801	)
At 30 April			7,850,754				687,797

23. Reconciliation of movements in shareholders’ funds

 

		Group 2011				Company 2011
		£				£
Profit/(loss) for the financial year			3,636,375				(10,301	)
Dividends			(62,500	)			(62,500	)
Retained profit/(loss) for the financial year			3,573,875				(72,801	)
Net addition/(reduction) to shareholder’s funds			3,573,875				(72,801	)
Closing shareholders funds			10,400,754				3,237,797

 

F-131

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Table of Contents

Index to Financial Statements

AMC Global Group Limited

Notes to the consolidated financial statements for the year ended 30 April 2011 (continued)

 

24. Net cash inflow from operating activities

 

		2011
		£
Operating profit			5,157,230
Depreciation			240,764
Goodwill amortisation			175,920
Loss on disposal of tangible fixed assets			6,134
Increase in debtors			(62,848	)
Increase in creditors			131,964
(Increase) in stock			(1,385,286	)
Net cash inflow from operating activities			4,263,878

25. Related party transactions

During the year the Group repaid £752,845 of loan notes to Kerry Polson, the wife of director, Andrew Polson. At 30 April 2011 the amount of loan notes outstanding was £nil. During the year interest of £15,011 was charged on the loan notes at 4% over base rate

The Company has taken advantage of the exemptions in FRS 8 not to disclose related party transactions with entities that are part of the Group headed by AMC Global Group Limited.

26. Operating lease commitments

At 30 April 2011 the Group was committed to making the following payments under non-cancellable operating leases:

 

		Other 2011
		£
Operating leases which expire:
Within one year			—
Between two and five years			12,000
			12,000

27. Ultimate controlling party

During the financial year the Group was controlled by its director, Andrew Polson, by virtue of the fact that he owns the majority of the issued Ordinary share capital of the Company.

On 1 July 2011 the Company was acquired by Forum Energy Technologies Inc.

From 1 July 2011 the ultimate parent undertaking and controlling party is Forum Energy Technologies Inc. (formerly Forum Oilfield Technologies Inc.), a Company incorporated in United States of America.

 

F-132

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Table of Contents

Index to Financial Statements

P-Quip Limited

Financial statements

For the year ended 31 May 2011

Contents

Report of Independent Registered Public Accounting Firm to the member of P-Quip Limited			F-134
Profit and loss account for the year ended 31 May 2011			F-135
Balance sheet as at 31 May 2011			F-136
Cash flow statement for the year ended 31 May 2011			F-137
Notes to the financial statements for the year ended 31 May 2011			F-138

 

F-133

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Table of Contents

Index to Financial Statements

P-Quip Limited

Report of independent registered public accounting firm to the member of P-Quip Limited

In our opinion, the accompanying balance sheet and the related profit and loss account and cash flow statement present fairly, in all material respects, the financial position of P-Quip Limited at 31 May 2011, and the results of its operations and its cash flows for the year ended 31 May 2011 in conformity with accounting principles generally accepted in the United Kingdom. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audit of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

Accounting principles generally accepted in the United Kingdom vary in certain significant respects from accounting principles generally accepted in the United States of America. Information relating to the nature of such differences is presented in note 2 to the financial statements.

/s/ PricewaterhouseCoopers LLP

Aberdeen, United Kingdom

August 31, 2011

 

F-134

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Table of Contents

Index to Financial Statements

P-Quip Limited

Profit and loss account for the year ended 31 May 2011

 

						2011
		Note				£
Turnover			3				9,097,357
Cost of sales							(4,659,977	)
Gross profit							4,437,380
Administrative expenses							(1,121,508	)
Operating profit			4				3,315,872
Interest receivable and similar income			7				7,649
Interest payable and similar charges			8				(2,442	)
Profit on ordinary activities before taxation							3,321,079
Tax on profit on ordinary activities			9				(578,534	)
Profit for the financial year			20				2,742,545

All amounts relate to continuing operations.

There were no recognised gains and losses other than those included in the profit and loss account above.

There is no difference between the profit on ordinary activities before taxation and the profit for the year above and their historical cost equivalents.

The accompanying notes are an integral part of these financial statements.

 

F-135

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Table of Contents

Index to Financial Statements

P-Quip Limited

Balance sheet as at 31 May 2011

 

						2011
		Note				£
Fixed assets
Tangible assets			11				73,033
Current assets
Stock			12				2,947,496
Debtors			13				5,518,157
Cash at bank and in hand							965,549
							9,431,202
Creditors: amounts falling due within one year			14				(2,946,836	)
Net current assets							6,484,366
Total assets less current liabilities							6,557,399
Creditors: amounts falling due after more than one year			15				(19,937	)
Net assets							6,537,462
Capital and reserves
Called up share capital			18				33,215
Profit and loss account			19				6,504,247
Total shareholder’s funds			20				6,537,462

The financial statements on pages F-135 to F-148 were approved by the board of directors on August 31, 2011 and were signed on its behalf by:

 

/s/ James W. Harris
Director

P-Quip Limited

Registered no. SC046702

 

F-136

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Table of Contents

Index to Financial Statements

P-Quip Limited

Cash flow statement for the year ended 31 May 2011

 

						2011
		Note				£				£
Net cash inflow from operating activities			21								3,501,799
Returns on investments and servicing of finance
Interest received			7				7,649
Interest paid			8				(2,442	)
Net cash inflow from returns on investments and servicing of finance											5,207
Taxation											(543,712	)
Capital expenditure and financial investment
Purchase of tangible fixed assets			11				(5,132	)
Net cash (outflow) for capital and financial investment											(5,132	)
Equity dividends paid to shareholders			10								(3,500,000	)
Net cash outflow before use of liquid resources and financing											(541,838	)
Financing
Capital element of hire purchase contracts							(16,958	)
Net cash outflow from financing											(16,958	)
Decrease in net cash											(558,796	)
Reconciliation to net (debt)/cash
Net cash at 1 June											1,498,594
Decrease in net cash											(558,796	)
Movement in borrowings											16,958
Other non-cash changes											(25,300	)
Net cash at 31 May											931,456

 

F-137

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011

1. Business activities

The principal activity of the company is the design, supply, manufacture, installation and commissioning of proprietary mud pump fluid end assemblies for the oil industry. P-Quip’s products include mud pump rod systems, a liner retention system, valve cover retention systems, discharge strainer systems, valve seat pulling jack, special mud pump pistons, an automatic self- supporting mud bucket and a washpipe system. These products are sold to drilling contractors and mud pump manufacturers.

2. Accounting policies

(a) UK GAAP accounting policies

Accounting convention

These financial statements are prepared on a going concern basis, under the historical cost convention and in accordance with the Companies Act 2006 and applicable accounting standards in the United Kingdom. The principal accounting policies are set out below:

Turnover

Turnover arising from the sale of goods is recognised once substantially all the risks and rewards of ownership of the goods are transferred to the customer. Typically this will be upon shipment of goods, but will depend on factors such as insurance arrangements for goods in transit, where if all risks of ownership are not deemed to have passed then revenues are deferred until risk is deemed transferred to the customer.

Tangible fixed assets and depreciation

Tangible fixed assets are stated at cost less depreciation. Cost includes the original purchase price of the asset and the costs attributable to bringing the asset to its working condition for its intended use. Depreciation is provided at the following annual rates in order to write off each asset over its estimated useful life or, if held under a finance lease, over the lease term, whichever is shorter:

 

Leasehold improvements			10 years
Fixtures and fittings			10 years
Plant and equipment			4 years
Computer equipment			3 years
Motor vehicles			4 years

Hire purchase and leasing commitments

Assets obtained under hire purchase contracts are capitalised in the balance sheet. Those held under hire purchase contracts are depreciated over their estimated useful lives.

 

F-138

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

The interest element of these obligations is charged to the profit and loss account over the relevant period. The capital element of the future payments is treated as a liability.

Rentals paid under operating leases are charged to the profit and loss account on a straight line basis over the period of the lease.

Benefits received and receivable as an incentive to sign an operating lease are recognised on a straight line basis over the period until the date the rent is expected to be adjusted to the prevailing market rate.

Stocks

Stocks are valued at the lower of cost and net realisable value after making due allowance for obsolete and slow-moving stocks. Cost includes all direct costs and an appropriate proportion of fixed and variable overheads.

Taxation

Corporation tax is provided on the assessable profits of the company at the appropriate rates in force.

Deferred tax is recognised in respect of all timing differences that have originated but not reversed at the balance sheet date where transactions or events that result in an obligation to pay more tax or a right to pay less tax in the future have occurred at the balance sheet date. Timing differences are differences between the company’s taxable profits and its results as stated in the financial statements. Deferred tax is measured at average tax rates that are expected to apply in the years in which the timing differences are expected to reverse, based on tax rates and laws that have been enacted or substantially enacted by the balance sheet date. Deferred tax assets and tax debtors arising from withholding tax credits are recognised to the extent that they are more likely than not to be recoverable. Deferred tax is measured on a non-discounted basis. Deferred tax assets are recognised to the extent that it is regarded as more likely than not that they will be recovered. Deferred tax assets and liabilities are not discounted.

Foreign currencies

The functional and presentational currency of the company is Pounds Sterling.

Transactions in foreign currencies are recorded at the date ruling at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are retranslated at the rate of exchange ruling at the balance sheet date. All differences are taken to the profit and loss account.

 

F-139

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

Pensions

The company operates a defined contribution scheme. The assets of the scheme are held separately from those of the company in an independently administered fund. Contributions payable for the period are charged in the profit and loss account in the period to which they relate.

(b) Principal differences to US GAAP

The financial statements have been prepared in accordance with accounting principles generally accepted in the United Kingdom (‘UK GAAP”). Such principles differ in certain significant respects from generally accepted accounting principles in the United States (‘US GAAP’). A summary of principal differences applicable to the company are set out below.

Deferred income taxes

Under UK GAAP, deferred taxation is provided in full on all material timing differences. Deferred tax assets are recognized where their recovery is considered more likely than not. US GAAP requires deferred taxation to be provided in full, using the liability method. In addition, US GAAP requires the recognition of the deferred tax consequences of differences between the assigned values and the tax bases of the identifiable intangible assets, with the exception of non tax-deductible goodwill, in a purchase business combination. Consequently, a deferred tax liability attributable to identifiable intangible assets will be recognized and amortized over the useful economic lives of the underlying intangible assets.

Statement of cash flows

The statement of cash flows under UK GAAP is prepared in accordance with FRS 1 (revised) and presents substantially the same information as that required under US GAAP. Under US GAAP, however, there are certain differences from UK GAAP with regard to the classification of items within the cash flow statement and with regard to the definition of cash and cash equivalents.

Financial statement presentation

The format and presentation of the balance sheet, income statement and statement of cash flows under UK GAAP differs from that under US GAAP.

3. Turnover

In the opinion of the directors it would be seriously prejudicial to disclose segmental information by class of business or by geographical markets.

 

F-140

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

4. Operating profit

 

		2011 £
Operating profit is stated after charging
Depreciation of tangible fixed assets
Owned assets			6,481
Leased assets			20,715
Auditors remuneration			23,400
Operating leases
Land and buildings			16,300
Plant and machinery			1,800
Foreign exchange differences			227,012

5. Staff costs

Staff costs, including directors’ remuneration, were as follows:

 

		2011 £
Wages and salaries			612,632
Social security costs			72,069
Other pension costs			20,298
			704,999

The average monthly number of employees, including directors, during the year was as follows:

 

		2011
Directors			1
Engineering			9
Administration			2
			12

6. Directors’ remuneration

 

		2011 £
Emoluments			169,337
Company pension contributions to defined contribution pension schemes			4,434

During the year retirement benefits were accruing to 1 director in respect of defined contribution pension schemes.

The amounts above relate to the emoluments of the highest paid director.

 

F-141

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

7. Interest receivable and similar income

 

		2011 £
Bank Interest			7,649

8. Interest payable and similar charges

 

		2011 £
On bank loans and overdrafts			55
On finance leases and hire purchase contracts			2,387
			2,442

9. Taxation

(a) Analysis of tax charge in the year

 

		2011 £
Current tax
UK corporation tax charge on profit for the year			655,792
Adjustments in respect of prior periods			(104,617	)
Total current tax			551,175
Deferred tax
Origination and reversal of timing differences			25,308
Adjustments in respect of prior periods			2,051
Total deferred tax (note 17)			27,359
Tax on profit on ordinary activities			578,534

 

F-142

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

(b) Factors affecting tax charge for the year

The tax assessed for the year is lower than the standard rate of corporation tax in the UK of 27.67% (2010: 28%). The differences are explained below:

 

		2011 £
Profit on ordinary activities before taxation			3,321,079
Profit on ordinary activities multiplied by standard rate of Corporation tax in the UK of 27.67%			918,942
Effects of:
Expenses not deductible for tax purposes			2,017
Group relief claimed			(238,234	)
Depreciation in excess of capital allowances			737
Other short term timing differences			(27,670	)
Adjustments to tax charge in respect of prior periods			(104,617	)
Current tax charge for the year			551,175

(c) Factors that may affect future tax charges

The UK substantively enacted on 20 July 2010 an amendment to the corporation tax rate from 28% to 27% effective from 1 April 2011. Further reductions to the UK corporation tax rate were announced in the March 2011 Government Budget. The changes propose to reduce the corporation tax rate to 26% on 1 April 2011 and reduce the rate by 1% per annum thereafter to 23% by 1 April 2014. The reduction of the main corporation tax rate to 26% was substantively enacted on 29 March 2011. The reduction to 25% from April 2012 was substantively enacted on 5 July 2011. The changes to the tax rates do not have a material impact on these financial statements.

 

F-143

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

10. Dividends

 

		2011 £
Dividends paid on equity capital: £105.37 per ordinary share			3,500,000

11. Tangible fixed assets

 

		Freehold property £				Plant and machinery £				Motor vehicles £				Fixtures & fittings £				Computer equipment £				Total £
Cost
At 1 June 2010			8,381				13,322				84,712				22,606				5,712				134,733
Additions			—				—				25,300				4,540				592				30,432
At 31 May 2011			8,381				13,322				110,012				27,146				6,304				165,165
Depreciation
At 1 June 2010			3,562				9,675				33,862				14,120				3,717				64,936
Charge for year			838				2,043				20,715				2,753				847				27,196
At 31 May 2011			4,400				11,718				54,577				16,873				4,564				92,132
Net book value
At 31 May 2011			3,981				1,604				55,435				10,273				1,740				73,033

The net book value of assets held under finance leases or hire purchase contracts, included above, are as follows:

 

		2011 £
Cost			110,012
Depreciation			(54,577	)
Net book value			55,435

12. Stock

 

		2011 £
Finished goods and goods for resale			2,947,496

 

F-144

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

13. Debtors

 

		2011 £
Trade debtors			2,883,647
Amounts owed by group undertakings			2,205,610
Other debtors			394,182
Prepayments and accrued income			33,367
Deferred tax ( note 17)			1,351
			5,518,157

Amounts owed by group undertakings are unsecured, interest free, have no fixed date of repayment and are repayable on demand.

14. Creditors: amounts falling due within one year

 

		2011 £
Trade creditors			2,345,251
Net obligations under finance leases and hire purchase contracts			14,156
Corporation tax			229,273
Social security and other taxes			9,791
Accruals and deferred income			348,365
			2,946,836

Amounts owed to group undertakings are unsecured, interest free, have no fixed date of repayment and are repayable on demand.

15. Creditors: amounts falling due after more than one year

 

		2011 £
Net obligations under finance leases and hire purchase contracts			19,937

16. Security

The bank holds a bond and floating charge over all the assets of the company.

The bank held a cross corporate guarantee between KLS Holdings Ltd, Lothian Steel Services Ltd, Ecosteel Ltd, P-Quip Ltd & Bridgeforth Engineering Ltd and third party.

The bank held standard security over 19/23 Bellknowes Industrial Estate, which was granted by KLS Holdings Limited.

 

F-145

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

Both the cross corporate guarantee and the standard security was removed following the acquisition of P-Quip Ltd by Forum Energy Technologies (UK) Ltd, on 5th July 2011.

17. Deferred tax asset

 

		2011 £
At 31 May 2010			28,710
Charged for during the year			(27,359	)
At 31 May 2011			1,351

The deferred tax asset is made up as follows:

 

		2011 £
Short term timing differences			—
Accelerated capital allowances			1,351
			1,351

18. Share Capital

 

		2011 £
Authorised
35,000 Ordinary shares of £1 each			35,000
Allotted, called up and fully paid
33,215 Ordinary shares of £1 each			33,215

19. Profit and loss account

 

		2011 £
1 June 2010			7,261,702
Retained loss for the financial year (note 20)			(757,455	)
31 May 2011			6,504,247

 

F-146

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

20. Reconciliation of movement in shareholder’s funds

 

		2011 £
Profit for the financial year			2,742,545
Dividends			(3,500,000	)
Retained loss for the financial year			(757,455	)
Net reduction to shareholder’s funds			(757,455	)
Closing shareholder’s funds			6,537,462

21. Cash flow from operating activities

 

		2011 £
Operating profit			3,315,872
Depreciation			27,196
Loss on disposal of tangible fixed assets			—
(Increase) in debtors			(720,216	)
Increase in creditors			1,786,659
(Increase) in stock and work in progress			(907,712	)
Net cash inflow from operating activities			3,501,799

22. Pension commitments

Contributions made by the company to defined contribution pension schemes amounted to £20,298. There were no pension contributions outstanding at the year end.

23. Operating lease commitments

 

		Land and buildings 2011				Other 2011
		£				£
Expiry date
Within one year			—				1,800
Between two and five years			16,300				—

24. Ultimate parent undertaking and controlling party

During the financial year the ultimate parent company was KLS (Holdings) Limited, a company incorporated in Scotland. This is the parent undertaking of the smallest and largest group to consolidate these financial statements.

 

F-147

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Table of Contents

Index to Financial Statements

P-Quip Limited

Notes to the financial statements for the year ended 31 May 2011 (continued)

 

The company has taken advantage of the exemptions in FRS 8 not to disclose related party transactions with entities that are part of the group headed by KLS (Holdings) Limited.

On 5 July 2011 the company was acquired by Forum Energy Technologies (UK) Limited.

From 5 July 2011, the ultimate parent undertaking and controlling party is Forum Energy Technologies Inc. (formerly Forum Oilfield Technologies Inc.), a company incorporated in United States of America.

 

F-148

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd. financial statements

for the year ended December 31, 2010

Index

 

		Page(s)
Report of Independent Registered Public Accounting Firm			F-150
Financial Statements
Balance Sheet			F-151
Statement of Income			F-152
Statement of Changes in Partners’ Capital			F-153
Statement of Cash Flows			F-154
Notes to Financial Statements			F-155

 

F-149

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Table of Contents

Index to Financial Statements

Report of independent registered public accounting firm

To the Partners of

Cannon Services, Ltd.

In our opinion, the accompanying balance sheet and the related statements of income, of changes in partners’ capital and of cash flows, present fairly, in all material respects, the financial position of Cannon Services, Ltd. at December 31, 2010 and the results of its operations and its cash flows for the year then ended in conformity with accounting principles generally accepted in the United States of America. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audit of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

August 19, 2011

 

F-150

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Balance sheet

December 31, 2010

(in thousands)

 

Assets
Current assets
Cash and cash equivalents		$	1,346
Accounts receivable, net			5,221
Inventories			4,920
Prepaid expenses and other current assets			127
Total current assets			11,614
Property and equipment, net			457
Total assets		$	12,071
Liabilities and Partners’ Capital
Current liabilities
Accounts payable		$	397
Accrued expenses and other payables			420
Total current liabilities			817
Commitments and contingencies (Note 6)
Partners’ Capital			11,254
Total liabilities and partners’ capital		$	12,071

The accompanying notes are an integral part of this financial statements.

 

F-151

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Statement of income

Year ended December 31, 2010

(in thousands)

 

Product sales		$	29,684
Cost of sales			16,039
Gross profit			13,645
Selling, general and administrative expenses			5,869
Income from operations			7,776
Other income			38
Net income		$	7,814

The accompanying notes are an integral part of this financial statements.

 

F-152

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Statement of changes in partners’ capital

December 31, 2010

(in thousands)

 

		Total partners’ capital
Balance at December 31, 2009		$	8,585
Distributions to partners			(5,145	)
Net income			7,814
Balance at December 31, 2010		$	11,254

The accompanying notes are an integral part of this financial statements.

 

F-153

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Statement of cash flows

December 31, 2010

(in thousands)

 

Cash flow from operating activities
Net income		$	7,814
Adjustments to reconcile net income to net cash provided by operating activities
Bad debt expense			19
Depreciation of property and equipment			165
Changes in operating assets and liabilities
Accounts receivable (increase)			(2,264	)
Inventories (increase)			(1,626	)
Prepaid expenses and other current assets (increase)			(24	)
Accounts payable and accrued expenses (decrease)			(131	)
Net cash provided in operating activities			3,953
Cash flow from investing activities
Purchase of property, plant and equipment			(232	)
Net cash used in investing activities			(232	)
Cash flow from financing activities
Distributions to partners			(5,145	)
Net cash used in financing activities			(5,145	)
Net decrease in cash			(1,424	)
Cash and cash equivalents
Beginning of period			2,770
End of period		$	1,346

The accompanying notes are an integral part of this financial statements.

 

F-154

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Notes to financial statements

December 31, 2010

(in thousands)

1. Description of business and organization

Cannon Services, Ltd. (the “Company”), was formed in 1986 and converted to a limited partnership in the State of Texas in January 2001. The Company manufactures and supplies protection systems for downhole completion control lines and cables. Products include protectors for ESP cable, TEC lines, gauges, control lines, intelligent well flat packs, sub-sea umbilicals and fiber optics. The Company has facilities in Stafford Texas. The accompanying financial statements and related footnotes are presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”).

2. Significant accounting policies

Cash and cash equivalents

Cash and cash equivalents include cash on hand and all highly liquid investments with original maturities of three months or less.

Revenue recognition

The Company recognizes revenue from its product sales when persuasive evidence of an arrangement exists, performance has occurred, collection is reasonably assured, the sale price is fixed and determinable, and the transfer of risk of loss for products shipped has occurred.

Accounts receivable

The Company extends credit to customers in the normal course of business. The Company estimates its bad debt exposure based upon the age of its accounts receivable balances each period and records a bad debt provision for accounts receivable that the Company believes it may not collect in full.

Concentration of credit risk

The majority of the Company’s customers operate in the oil and gas industry. While current energy prices are important contributors to positive cash flow for the customers, expectations about future prices and price volatility are generally more important for determining future spending levels. Any prolonged increase or decrease in oil and natural gas prices affects the levels of exploration, development and production activity as well as the entire health of the oil and natural gas industry, and can therefore negatively impact spending by Company’s customers.

Revenue for the year ended December 31, 2010 includes sales to 3 customers that each individually represented more than 10% of total revenue. These customers accounted for 40% of revenue for the year ended December 31, 2010. Accounts receivable from these customers totaled 58% of accounts receivable at December 31, 2010.

 

F-155

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Notes to financial statements

December 31, 2010 (continued)

(in thousands)

 

The Company maintains its cash balances at one financial institution. The Federal Deposit Insurance Corporation insures account balances up to $250 thousand, and they have offered unlimited coverage for noninterest bearing accounts at participating FDIC insured institutions through June 30, 2012. The Company’s financial institution participates in this program. The Company does not believe that it is exposed to any significant credit risk on any uninsured amounts.

Inventories

Inventories are stated at the lower of cost or market, cost being determined on an average cost basis. The Company reviews its inventory balances and writes down its inventory for estimated obsolescence or excess inventory equal to the difference between the cost of inventory and the estimated market value based upon assumptions about future demand and market conditions. There was no reserve recorded for inventory on hand at December 31, 2010.

Concentration of supplier risk

Purchases during the year ended December 31, 2010 include purchases from one supplier that represented 91% of total inventory purchases. The Company’s accounts payable to this vendor totaled 62% of total accounts payable at December 31, 2010.

Property and equipment

Property and equipment are recorded at cost. The costs of major renewals and betterments are capitalized; repair and maintenance costs are expensed as incurred. When assets are sold or retired, the cost and related accumulated depreciation are removed from the appropriate accounts, and the resulting gain or loss is included in current income.

Depreciation of property and equipment is computed principally using the straight-line basis over the estimated useful lives of the assets as set forth below:

 

Description		Useful Life
Furniture and fixtures			5
Machinery and equipment			7
Tooling			7
Computers and software			3

Impairment of Long-lived assets

Long-lived assets held and used by the Company are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. For purposes of evaluating the recoverability of long-lived assets, the recoverability test is performed using undiscounted future net cash flows of assets grouped at the lowest level

 

F-156

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Table of Contents

Index to Financial Statements

Cannon Services, Ltd.

Notes to financial statements

December 31, 2010 (continued)

(in thousands)

 

for which there are identifiable cash flows that are independent of the cash flows of other groups of assets. If the undiscounted future net cash flows are less than the carrying amount of the asset, the asset is deemed impaired. The amount of the impairment is measured as the difference between carrying value and the fair value of the asset.

Income taxes

As a limited partnership, provision for income taxes is not made in the Company’s accounts since such taxes are the responsibility of the individual members. Further, the partners’ capital account reflected in the accompanying balance sheet differs from amounts reported in the partners’ income tax returns because of differences in the timing of certain expense and revenue items for financial and tax reporting purposes.

Use of estimates

The preparation of the financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Accordingly, actual results could differ from these estimates.

3. Property and equipment

The following is a summary of property and equipment at December 31, 2010:

 

Machinery and equipment		$	451
Furniture, fixtures and computers and software			144
Tooling			929
Less: Accumulated depreciation			(1,067	)
		$	457

Depreciation expense was $165 thousand for the year ended December 31, 2010.

4. Accrued expenses

The following is a summary of accrued expenses at December 31, 2010:

 

Payroll		$	146
Commissions payable			237
Other			37
		$	420

 

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Cannon Services, Ltd.

Notes to financial statements

December 31, 2010 (continued)

(in thousands)

 

5. Commitments and contingencies

The Company rents its facilities from a company affiliated through common ownership (See note 6). Future minimum payments due under this agreement at December 31, 2010 are as follows:

 

2011		$	395
2012			415
2013			176
2014			—
2015			—
		$	986

6. Related party transactions

The Company rents its facilities from a company affiliated through common ownership. Rent expense for the year ended December 31, 2010 was $384 thousand. The Company pays a 5 percent royalty to a partner based upon annual product sales. The total royalty expense for the year ended December 31, 2010 was $1.455 million.

7. Subsequent events

On July 1, 2011 Forum Energy Technologies Inc., through one of its subsidiaries, purchased 100% of the partnership interests of Cannon Services, Ltd. Forum Energy Technologies is a global oilfield products Company, serving the drilling, subsea, completion, production and process sectors of the oil and natural gas industry.

Events occurring after December 31, 2010 were evaluated as of the date that this report was made available to be issued, to ensure any subsequent events that meet the criteria for recognition and/or disclosure in this report have been identified.

 

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Cannon Services, Ltd. Financial statements

for the six months ended June 30, 2010 and June 30, 2011

Index

 

		Page(s)
Condensed Financial Statements (unaudited)
Balance Sheets			F-160
Statements of Income			F-161
Statements of Cash Flows			F-162
Notes to Financial Statements			F-163

 

F-159

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Cannon Services, Ltd.

Condensed balance sheets (unaudited)

(in thousands)

 

		December 31, 2010				June 30, 2011
Assets
Current assets
Cash and cash equivalents		$	1,346			$	1,640
Accounts receivable, net			5,221				3,452
Inventories			4,920				5,537
Prepaid expenses and other current assets			127				1,125
Total current assets			11,614				11,754
Property, plant and equipment, net			457				497
Total assets		$	12,071			$	12,251
Liabilities and Partners’ Capital
Current liabilities
Accounts payable		$	397			$	1,178
Accrued expenses and other payables			420				560
Total current liabilities			817				1,738
Commitments and contingencies (Note 5)
Partners’ Capital			11,254				10,513
Total liabilities and partners’ capital		$	12,071			$	12,251

The accompanying notes are an integral part of these condensed financial statements.

 

F-160

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Cannon Services, Ltd.

Condensed statements of income (unaudited)

(in thousands)

 

		Six months ended June 30,
		2010				2011
Product sales		$	14,127			$	13,544
Cost of sales			7,661				5,633
Gross profit			6,466				7,911
Selling, general and administrative expenses			2,117				3,472
Income from operations			4,349				4,439
Other income			2				—
Net income		$	4,351			$	4,439

The accompanying notes are an integral part of these condensed financial statements.

 

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Cannon Services, Ltd.

Condensed statements of cash flows (unaudited)

(in thousands)

 

		Six months ended June 30,
		2010				2011
Cash flow from operating activities
Net income		$	4,351			$	4,439
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property and equipment			84				80
Changes in operating assets and liabilities
Accounts receivable (increase) decrease			(2,444	)			1,769
Inventories (increase)			(1,006	)			(617	)
Prepaid expenses and other current assets (increase) decrease			78				(998	)
Accounts payable and accrued expenses increase			1,114				921
Net cash provided by operating activities			2,177				5,594
Cash flow from investing activities
Purchase of property and equipment			(64	)			(120	)
Net cash used in investing activities			(64	)			(120	)
Cash flow from financing activities
Distributions to partners			(1,795	)			(5,180	)
Net cash used in financing activities			(1,795	)			(5,180	)
Net increase in cash			318				294
Cash and cash equivalents
Beginning of period			2,771				1,346
End of period		$	3,089			$	1,640

The accompanying notes are an integral part of these condensed financial statements.

 

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Cannon Services, Ltd.

Notes to condensed financial statements (unaudited)

(in thousands)

1. Description of business and organization

Cannon Services, Ltd (the “Company”), was formed in 1986 and was converted to a limited partnership in the State of Texas in January 2001. The Company manufactures and supplies protection systems for downhole completion control lines and cables. Products include protectors for ESP cable, TEC lines, gauges, control lines, intelligent well flat packs, sub-sea umbilicals and fiber optics. The Company has facilities in Stafford Texas. The accompanying financial statements and related footnotes are presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”).

Basis of presentation

The condensed balance sheet of the Company at December 31, 2010 was derived from the Company’s audited financial statements as of that date, but does not include all disclosures required by accounting principles generally accepted in the United States of America. The condensed balance sheet at June 30, 2011, the condensed statements of income for the six month periods ended June 30, 2011 and June 30, 2010, respectively, and the condensed statements of cash flows for the six month periods ended June 30, 2011 and June 30, 2010, respectively, were prepared by the Company.

In the opinion of Company management, all adjustments, consisting of normal recurring adjustments, necessary to state fairly the financial position, results of operations and cash flows were recorded. The results of operations for the six month period ended June 30, 2011 are not necessarily indicative of the operating results for a full year or of future operations.

Certain information and footnote disclosures normally included in financial statements presented in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted. The accompanying condensed financial statements should be read in conjunction with the financial statements and notes thereto contained in the Company’s financial statements for the year ended December 31, 2010.

2. Commitments and contingencies

The Company rents its facilities from a company affiliated through common ownership. Future minimum payments due under this agreement at June 30, 2011 are as follows:

 

2011		$	201
2012			415
2013			176
2014			—
2015			—
		$	792

 

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Cannon Services, Ltd.

Notes to condensed financial statements (unaudited) (continued)

(in thousands)

 

3. Related party transactions

The Company rents its facilities from a company affiliated through common ownership (Note 2).

The Company owes a 5 percent royalty to a partner based on sales. Total royalty expense for the six month periods ended June 30, 2010 and 2011 were $350 thousand and $661 thousand, respectively. On July 1, 2011 the Company purchased the patents underlying the above described royalty agreement and cancelled the royalty agreement in exchange for $1.0 million. This payment was made in June 2011 and is included in prepaid expenses and other current assets on the accompanying balance sheet at June 30, 2011.

4. Subsequent events

On July 1, 2011 Forum Energy Technologies Inc., through one of its subsidiaries, purchased 100% of the stock of Cannon Services, Ltd. Forum Energy Technologies is a global oilfield products Company, serving the drilling, subsea, completion, production and process sectors of the oil and natural gas industry.

Events occurring after June 30, 2011 were evaluated as the date these financial statements were made available to be issued, to ensure any subsequent events that meet the criteria for recognition and/or disclosure in this report have been identified.

 

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Glossary

Selected industry terms

The following industry terms defined in this section are used throughout this prospectus:

Bbl.    One stock tank barrel of 42 U.S. gallons liquid volume, used herein in reference to crude oil, condensate or natural gas liquids.

Blowout preventer (BOP).    A large valve at the top of a well that may be closed to regain control of a reservoir if the drilling crew or other wellsite personnel lose control of formation fluids.

Bottomhole assembly.    The lower end of a drill string composed of specialized components including the drill bit.

Casing.    Large-diameter pipe lowered into an openhole wellbore and cemented in place.

Catwalk.    The ramp at the side of the drilling rig where tubulars are laid to be lifted to the drill floor.

Choke.    A device incorporating an orifice that is used to control fluid flow rate or downstream system pressure.

Coiled tubing.    A long, continuous length of pipe wound on a spool. The pipe is straightened prior to pushing into a wellbore and recoiled to spool the pipe back onto the transport and storage spool.

Drilling rig.    The machine used to drill a wellbore.

Drill bit.    Tool attached to the bottom of a drill string that serves as the cutting or boring element used to drill the wellbore.

Drill floor.    The elevated platform where the majority of activity by a drilling rig crew occurs during drilling operations, including make-up and breakout of tubulars and supervision and monitoring of the drilling process.

Drill pipe.    Heavy tubular steel conduit fitted with special threaded ends called tool joints. The drill pipe connects the surface equipment with the bottomhole assembly, both to pump drilling fluid to the drill bit and to raise, lower and rotate the bottomhole assembly.

Drill string.    The combination of the drillpipe and the bottomhole assembly.

Elevator.    A set of clamps that grip tubulars so that the tubulars can be raised or lowered into the wellbore.

Flatpacks.    A method of encapsulating downhole control lines and electrical conduit material so as to protect against damage caused by pressure or temperature.

Flow Equipment.    The high pressure tubulars, piping, joints, valves, manifolds, fittings, assemblies, and other pressure control products used in the well stimulation process. Flow equipment also commonly refers to all of the pressure control products that connect the hydraulic fracturing pressure pump to the top of the well, and serves as the conduit though which the fracturing fluids travel.

 

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Hydrocarbon.    A naturally occurring organic compound comprising hydrogen and carbon. Hydrocarbons can be as simple as methane, but many are highly complex molecules, and can occur as gases, liquids or solids. Petroleum is a complex mixture of hydrocarbons. The most common hydrocarbons are natural gas, oil and coal.

Iron roughneck.    Machine on drill floor used to make-up or breakout tubulars.

Landing String.    A long string of drill pipe used to lower blowout preventer stacks and casing strings to the ocean floor from an offshore drilling rig.

Lease Automatic Custody Transfer (LACT) Unit.    Measurement systems used in the ownership transfer of crude oil and petroleum products from the well site to trucks, pipelines or storage tanks.

Make-up and breakout.    Process of spinning and torquing when connecting and disconnecting tubulars.

Manifold.    An arrangement of piping, valves and chokes designed to control, distribute and often monitor fluid flow. Manifolds are often configured for specific functions, such as a choke and kill manifold used in well-control operations and a squeeze manifold used in squeeze-cementing work.

Mcf.    One thousand cubic feet of natural gas.

Mud Pump.    A large reciprocating pump used to circulate the drilling fluid on a drilling rig.

Mousehole.    Shallow bores under the drill floor, usually lined with pipe, in which joints of drill pipe are temporarily suspended for later connection to the drill string.

Pick-up and lay-down.    Pipe handling systems that consist of truck mounted units that raise and lower tubulars to and from the drill floor. Pick-up and lay-down operations are typically conducted by specialized service company crews.

Pipe handling.    Equipment used to move and connect tubulars.

Rotary table.    Machine embedded into drill floor used to rotate the drill string.

Slips.    Wedge-shaped pieces of metal with gripping elements that are used to hold tubulars in place or to prevent tubulars from slipping down into the wellbore.

Tongs.    Large wrenches used for torquing when making-up or breaking-out tubulars.

Top Drive.    Machine used to rotate the drill string by attaching to the top of the drillpipe without the use of the rotary table.

Tubing.    String of pipe set inside the well casing, through which a reservoir’s oil or natural gas is produced.

Tubulars.    Drill pipe, casing, tubing, or other piping placed in the wellbore.

Wellbore.    The physical conduit from surface into the hydrocarbon reservoir.

Wireline.    A general term used to describe well-intervention operations conducted using single-strand or multistrand wire or cable for intervention in oil or gas wells.

 

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Definitions of categories used in revenue split analysis

Phase of well life driver.    This revenue split is intended to answer the question, “What phase in the development process of oil or natural gas reserves drives the need for our product or related service?”

 

•

Drilling—includes items on the rig, drill string, and items supporting drilling activities

 

•

Well Construction & Completion—includes items or activities used to construct, complete and stimulate the well before production comes online

 

•

Production—includes items or activities involved after the resource begins producing, to maintain or enhance production, or to conduct workover activities

 

•

Infrastructure—includes infrastructure items related to or used in pre-drilling field development, pipeline operation or construction, midstream processing, refining, petrochemical processing, or in other general processing industries

 

•

All others

Geographic exposure.    This revenue split is intended to answer the question, “Where is the activity that is driving our business, when estimated by product shipment destination?”

 

•

United States—includes items delivered or related services provided in the United States of America or surrounding waters

 

•

Canada—includes items delivered or related services provided in Canada

 

•

Europe—includes items delivered or related services provided in Europe or surrounding waters

 

•

Far East—includes items delivered or related services provided in Australasia or surrounding waters

 

•

Other—includes items delivered or related services provided everywhere else in the world

Land versus offshore.    This revenue split is intended to answer the question, “Is the activity that is driving our revenue related to land or offshore activity?”

 

•

Land—includes items delivered or related services provided on land

 

•

Offshore—includes items delivered or related services provided on water

Product Spend cycle.    This revenue split is intended to answer the question, “From our customers’ perspective, what type of spending is driving our revenue?”

 

•

Capital products—includes items and related services that are additive to the industry’s capacity; and/or used in major capital refurbishment or expansion projects of major processing facilities; and/or are expected to last at least 5 years. Our customers often, although not exclusively, procure these items and related services from their capital expenditure budgets.

 

•

Consumables, spare parts and aftermarket—includes items and related services that are consumed during the operation of other, often larger pieces of equipment or products; spare parts used to maintain other equipment; aftermarket service and parts used to maintain, refurbish, or recertify other equipment. Our customers often, although not always, procure these items and related services from their operating budgets. These products or related services are also often not discretionary in nature.

 

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•

Rental—includes all revenue generated by products that are rented to our customers

 

•

Other—includes all items or related services that generates revenue from other types of spending

Commodity exposure.    This revenue split is intended to answer the question, “What commodity is the target of the activity that is driving demand for our products or related services?”

 

•

Oil

 

•

Natural Gas

 

•

Other—this category can include precious metals, unrelated government program spending, renewable energy, scientific research activities.

 

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             shares

Common stock

Prospectus

J.P. Morgan

                    , 2011

You should rely only on the information contained in this prospectus and any free writing prospectus prepared by or on behalf of us or to which we have referred you. Neither we nor the selling stockholders have authorized anyone to provide you with information different from that contained in this prospectus and any free writing prospectus. We and the selling stockholders are offering to sell shares of common stock and seeking offers to buy shares of common stock only in jurisdictions where offers and sales are permitted. The information in this prospectus is accurate only as of the date of this prospectus, regardless of the time of delivery of this prospectus or any sale of the common stock.

No action is being taken in any jurisdiction outside the United States to permit a public offering of the common stock or possession or distribution of this prospectus in that jurisdiction. Persons who come into possession of this prospectus in jurisdictions outside the United States are required to inform themselves about and to observe any restrictions as to this offering and the distribution of this prospectus applicable to that jurisdiction.

Until                     , 2011, all dealers that buy, sell or trade our common stock, whether or not participating in this offering, may be required to deliver a prospectus. This requirement is in addition to the dealers’ obligation to deliver a prospectus when acting as underwriters and with respect to their unsold allotments or subscriptions.

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Part II

Information not required in prospectus

 

Item 13.

Other expenses of issuance and distribution

The following table sets forth an itemized statement of the amounts of all expenses (excluding underwriting discounts and commissions) payable by us in connection with the registration of the common stock offered hereby. With the exception of the Registration Fee, FINRA Filing Fee and New York Stock Exchange listing fee), the amounts set forth below are estimates. The selling stockholders will not bear any portion of such expenses.

 

SEC Registration Fee		$	34,830
FINRA Filing Fee		$	30,500
New York Stock Exchange listing fee
Accountants’ fees and expenses
Legal fees and expenses
Printing and engraving expenses
Transfer agent and registrar fees
Miscellaneous
Total		$

 

Item 14.

Indemnification of directors and officers

Our amended and restated certificate of incorporation will provide that a director will not be liable to the corporation or its stockholders for monetary damages to the fullest extent permitted by the DGCL. In addition, if the DGCL is amended to authorize the further elimination or limitation of the liability of directors, then the liability of a director of the corporation, in addition to the limitation on personal liability provided for in our certificate of incorporation, will be limited to the fullest extent permitted by the amended DGCL. Our amended and restated bylaws will provide that the corporation will indemnify, and advance expenses to, any officer or director to the fullest extent authorized by the DGCL.

Section 145 of the DGCL provides that a corporation may indemnify directors and officers as well as other employees and individuals against expenses, including attorneys’ fees, judgments, fines and amounts paid in settlement in connection with specified actions, suits and proceedings whether civil, criminal, administrative, or investigative, other than a derivative action by or in the right of the corporation, if they acted in good faith and in a manner they reasonably believed to be in or not opposed to the best interests of the corporation and, with respect to any criminal action or proceeding, had no reasonable cause to believe their conduct was unlawful. A similar standard is applicable in the case of derivative actions, except that indemnification extends only to expenses, including attorneys’ fees, incurred in connection with the defense or settlement of such action and the statute requires court approval before there can be any indemnification where the person seeking indemnification has been found liable to the corporation. The statute provides that it is not exclusive of other indemnification that may be granted by a corporation’s certificate of incorporation, bylaws, disinterested director vote, stockholder vote, agreement or otherwise.

 

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Our amended and restated certificate of incorporation will also contain indemnification rights for our directors and our officers. Specifically, our amended and restated certificate of incorporation will provide that we shall indemnify our officers and directors to the fullest extent authorized by the DGCL. Further, we may maintain insurance on behalf of our officers and directors against expense, liability or loss asserted incurred by them in their capacities as officers and directors.

We have obtained directors’ and officers’ insurance to cover our directors, officers and some of our employees for certain liabilities.

Each of our current and former directors and officers and that of Allied, Global Flow, Triton and Subsea and their respective subsidiaries, as applicable, are indemnified pursuant to an indemnification agreement and to the fullest extent possible under law against all losses pertaining to certain actions taken by them, or failures to act, while serving in those capacities before the Combination. For six years after the Combination, we will honor all rights to indemnification under our charter and that of the Allied Charter, the Global Flow Charter, the Triton LLC Agreement and the Subsea Charter, and any our indemnification agreements or that of Allied, Global Flow, Triton and Subsea existing in favor of any of our current or former directors or officers or that of Allied, Global Flow, Triton and Subsea arising from any act or omission occurring prior to the closing of the Combination. Pursuant to these proposed agreements, if an officer or director makes a claim of indemnification to us, either a majority of the independent directors or independent legal counsel selected by the independent directors must review the relevant facts and make a determination whether the officer or director has met the standards of conduct under Delaware law that would permit (under Delaware law) and require (under the indemnification agreement) us to indemnify the officer or director.

 

Item 15.

Recent sales of unregistered securities.

During the past three years, we have issued unregistered securities to a limited number of persons, as described below. None of these transactions involved any underwriters, underwriting discounts or commissions or any public offering, and we believe that each of these transactions was exempt from the registration requirements pursuant to Section 4(2) of the Securities Act, Regulation D or Regulation S promulgated thereunder or Rule 701 of the Securities Act. The recipients of these securities represented their intention to acquire the securities for investment only and not with a view to or for sale in connection with any distribution thereof, and appropriate legends were affixed to the share certificates and instruments issued in these transactions. All share and price information included in this section does not reflect the impact of the expected pre-offering split of our common stock previously described in the section titled “Stock split.”

On August 2, 2010, we completed the Combination, through which FOT, Global Flow, Triton, Allied and Subsea were combined. In the Combination, FOT became the parent company and was renamed Forum Energy Technologies, Inc., all of the outstanding shares held by each of the former Allied shareholders in Allied were acquired in exchange for 77,109 of our shares, all of the outstanding shares held by each of the former Global Flow shareholders in Global Flow were acquired in exchange for 183,321 of our shares, all of the outstanding shares held by each of the former Triton unitholders in Triton were acquired in exchange for 283,239 of our shares and all of the outstanding shares held by each of the former Subsea shareholders in Subsea were acquired in exchange for 90,761 of our shares.

 

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The following table sets forth information on the restricted stock awards issued by us and common stock issued pursuant to the exercise of stock options in the three years preceding the filing of this registration statement.

 

Person or class of person		Date of issuance/option exercise		Total shares of restricted stock				Common stock issued pursuant to options exercises				Total consideration
FOT Employee		September 30, 2008			300								*
FOT Directors		September 15, 2009			1,248								*
FOT Employee		December 22, 2009							607			$	75,875
FOT Employee		March 31, 2010			300								*
Former Holders of Triton Management Units**		August 2, 2010			1,447								*
FET Executive Officer		October 25, 2010			1,760								*
FET Executive Officer		November 1, 2010			2,638								*
FOT Director		November 17, 2010							500			$	100,000
FET Executive Officer		November 29, 2010			431								*
FET Employees		March 28, 2011			817								*
FET Employee		May 18, 2011							500			$	50,580
FET Employees		May 19, 2011							84			$	12,180
FET Executive Officer		May 19, 2011							500			$	100,000
FET Employees		July 1, 2011			287								*
FOT Employee		July 19, 2011							145			$	42,525
FOT Employee		August 12, 2011							1,897			$	275,065
FOT Employee		August 16, 2011							125			$	28,125
FOT Employee		August 17, 2011							50			$	12,732.25

 

*

No cash consideration was paid to us by any recipient of any restricted stock award.

 

**

In connection with the Combination, we issued 1,447 shares of our restricted stock to former holders of Triton management units.

 

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The following table sets forth information on the stock options issued by us in the three years preceding the filing of this registration statement.

 

Date of issuance		Number of options granted				Grant date exercise price ($/sh)
September 9, 2010			1,056				284.29
October 4, 2010			700				284.29
October 18, 2010			350				284.29
October 25, 2010			6,000				284.29
November 29, 2010			569				284.29
February 4, 2011			1,000				340.00
February 22, 2011			500				340.00
February 24, 2011			253				395.00
March 28, 2011			1,045				395.00
May 2, 2011			600				395.00
May 16, 2011			100				395.00
May 17, 2011			250				395.00
June 6, 2011			600				513.00
July 1, 2011			322				513.00
July 8, 2011			1,600				513.00
July 18, 2011			900				565.00
August 17, 2011			616				568.00

No cash consideration was paid to us by any recipient of any of the foregoing options for the grant of such options. All of the stock options described above issued prior to the Combination, August 2, 2010, were granted under the Forum Oilfield Technologies, Inc. 2005 Stock Incentive Plan, or Prior Plan, to the officers, employees and consultants of FOT. In connection with the Combination, we amended and restated the Prior Plan to change, among other things, the name of the plan to the Forum Energy Technologies, Inc. 2010 Stock Incentive Plan, or 2010 Plan. At the time of the Combination, both vested and unvested stock options of Allied, Global Flow and Subsea outstanding under a Pre-Combination Equity Plan were converted into an option under the 2010 Plan to acquire the number of shares of our common stock that resulted from multiplying the applicable exchange ratio by the number of shares still subject to the original award. Because Triton’s management units were not convertible into our options, at the time of the Combination, holders of those management units were granted options under the 2010 Plan to purchase 11,314 shares of common stock. All of the stock options described above issued on or after the Combination were granted under the 2010 Plan to our officers, employees and consultants.

In connection with the Combination and pursuant to a subscription agreement dated August 20, 2010, we offered each of our stockholders who were accredited investors or non-U.S. persons (as such term is defined for purposes of the Securities Act of 1933) the opportunity to purchase shares of our common stock worth $115 million in the aggregate, up to their pro-rata ownership of us. In connection with this subscription offer, 34 stockholders, including some of our executive officers and directors, subscribed to purchase 11,707 shares of our common stock in exchange for aggregate cash payments of $3,328,183. In connection with the purchase of these shares of our common stock pursuant to the subscription agreement, we issued to those stockholders who purchased shares of our common stock a warrant to purchase additional shares of our common

 

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stock on the basis of one warrant share for every two shares purchased in the subscription offer, resulting in warrants issued to purchase an aggregate of 5,853 shares of our common stock. The warrants were exercisable upon their issuance and will remain exercisable until the date that is the 30 month anniversary following the consummation of this offering. The initial exercise price of the warrants was $284.29 per share, and the exercise price increases by 0.5% of the then-current exercise price on the last day of each month following their original issuance. For more information about these warrants, please see “Description of capital stock—Warrants” (in the prospectus included in this registration statement).

In connection with the Combination and pursuant to a subscription agreement dated August 2, 2010, each of SCF-VII, L.P., Sunray Capital and Messrs. Gaut and Connelly subscribed to purchase 175,876, 17,587, 12,311 and 1,055 shares of our common stock in exchange for a cash payment of $49,999,788.04, $4,999,808.23, $3,499,894.19 and $299,925.95, respectively. In connection with the purchase of these shares of our common stock pursuant to the Subscription Agreement, each of SCF-VII, L.P., Sunray Capital and Messrs. Gaut and Connelly received a warrant to purchase 87,938, 8,794, 6,156 and 528 shares of our common stock, respectively. Each of these warrants entitle the holder to purchase shares of our common stock at a purchase price per share of $284.29, subject to a monthly increase of the then-current exercise price by 0.5%, and expire on the 30 month anniversary of the completion of this offering. For more information about these warrants, please see “Description of capital stock—Warrants” (in the prospectus included in this registration statement).

Pursuant to a subscription agreement dated October 25, 2010, Mr. McCulloch subscribed to purchase 7,035 shares of our common stock in exchange for a cash payment of $1,999,980.

Pursuant to that certain Subscription Agreement dated November 18, 2010, Mr. Jones subscribed to purchase 2,638 shares of our common stock in exchange for a cash payment of $749,957.

On January 31, 2011, we issued 35,000 shares of common stock to the former members of Wood Flowline Products, LLC as consideration for the WFP Acquisition.

On April 29, 2011, we issued 20,252 shares of common stock to the former members of Phoinix Global LLC as consideration for the Phoinix Acquisition.

On May 17, 2011, we issued 4,075 shares of restricted stock to former shareholders of Specialist ROV Tooling Services, Ltd. as consideration for the Specialist Acquisition.

On July 1, 2011, we issued 20,944 shares of common stock to the former unitholders of Cannon Services LP as consideration for the Cannon Acquisition.

On July 1, 2011, we issued 16,200 shares of common stock to the former shareholders of AMC Global Group Ltd. as consideration for the AMC Acquisition.

On July 1, 2011, we issued 5,847 restricted shares of common stock to a former shareholder and its affiliate of SVP Products Inc. as consideration for the SVP Acquisition.

Pursuant to a Subscription Agreement dated August 2, 2011 between Forum Energy Technologies, Inc. and Mr. John A. Carrig, Mr. Carrig subscribed to purchase 884 shares of our common stock in exchange for a cash payment of $499,460.

Pursuant to a Subscription Agreement dated August 3, 2011 between Forum Energy Technologies, Inc. and Ms. Evelyn Angelle, Ms. Angelle subscribed to purchase 176 shares of our common stock in exchange for a cash payment of $99,440.

 

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Index to Financial Statements

Pursuant to the terms of the Subscription Agreement among Forum Energy Technologies, Inc., SCF-VII, L.P., Sunray Capital and Messrs. Gaut and Connelly, SCF-VII, L.P. purchased an additional 168,236 shares of our common stock in August 2011 in exchange for a cash payment of $50.0 million. In connection with the purchase of these shares, SCF-VII, L.P. also received a warrant to purchase 84,118 shares of our common stock pursuant to the Subscription Agreement.

Pursuant to the terms of those Subscription Agreements dated July 29, 2011 between Forum Energy Technologies, Inc. and certain shareholders of Davis-Lynch, such shareholders subscribed to purchase a total of 710 shares of our common stock in exchange for a cash payment of $401,150.

Certain transactions, including (i) the issuance of shares to SCF, former Allied shareholders, former Global Flow shareholders, former Triton and former Subsea shareholders in connection with the Combination, (ii) certain of the above-described issuances of restricted stock and option grants to accredited investors, (iii) issuances of our common stock and warrants made pursuant to the Subscription Agreements described above and (iv) issuances of our common stock as consideration for acquisitions as described above were made in reliance upon the exemption from registration requirements of the Securities Act available under Section 4(2) of the Securities Act, Rule 506 of Regulation D and Regulation S. The recipients of the securities in these transactions represented that they were sophisticated persons and that they intended to acquire the securities for investment only and not with a view to, or for sale in connection with, any distribution thereof, and appropriate legends were affixed to the share certificates and instruments issued in such sales. We believe that the purchasers either received adequate information about us or had adequate access, through their relationships with us, to such information.

All other issuances of common stock described above either represent grants of restricted stock under, or were made pursuant to the exercise of stock options granted under, our Prior Plan or 2010 Plan to our officers, directors, employees and consultants in reliance upon an available exemption from the registration requirements of the Securities Act, including those contained in Rule 701 promulgated under Section 3(b) of the Securities Act. Among other things, we relied on the fact that, under Rule 701, companies that are not subject to the reporting requirements of Section 13 or Section 15(d) of the Exchange Act are exempt from registration under the Securities Act with respect to certain offers and sales of securities pursuant to “compensatory benefit plans” as defined under that rule. We believe that our Prior Plan and our 2010 Plan qualify as compensatory benefit plans.

 

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Index to Financial Statements

Item 16.

Exhibits and financial statement schedules

 

(a)

Exhibits

 

Exhibit number				Description
	*1.1			Form of Underwriting Agreement
	**2.1			Combination Agreement dated July 16, 2010 by and among Forum Oilfield Technologies, Inc., Allied Production Services, Inc., Allied Merger Sub, LLC, Global Flow Technologies, Inc., Global Flow Merger Sub, LLC, Subsea Services International, Inc., Subsea Merger Sub, LLC, Triton Group Holdings LLC, Triton Merger Sub, LLC and SCF-VII, L.P.
	**2.2			Purchase and Sale Agreement among Davis-Lynch Holding Co., Inc., Carl A. Davis and Forum Energy Technologies, Inc., dated June 25, 2011
	3.1			Second Amended and Restated Certificate of Incorporation of Forum Energy Technologies, Inc.
	3.2			Amended and Restated Bylaws of Forum Energy Technologies, Inc.
	*3.3			Form of Third Amended and Restated Certificate of Incorporation of Forum Energy Technologies, Inc.
	*3.4			Form of Second Amended and Restated Bylaws of Forum Energy Technologies, Inc.
	*4.1			Form of Common Stock Certificate
	4.2			Amended and Restated Stockholders Agreement dated as of August 2, 2010 by and among the Company and certain of its stockholders, as amended
	4.3			Registration Rights Agreement by and among Forum Energy Technologies and the other parties thereto (included as Exhibit B to Exhibit 4.2 hereto)
	*5.1			Opinion of Vinson & Elkins L.L.P. as to the legality of the securities being registered
	10.1			Credit Agreement, dated as of August 2, 2010, among Forum Energy Technologies, Inc., as Borrower, Wells Fargo Bank, National Association, as Administrative Agent and Swing Line Lender, Wells Fargo Bank, National Association, JPMorgan Chase Bank, N.A. and Bank of America, N.A. and such other lenders designated from time to time as issuing lenders.
	†10.2			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and C. Christopher Gaut
	†10.3			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and Charles E. Jones
	†10.4			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and Steven W. Twellman
	†10.5			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and Wendell Brooks
	†10.6			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and James W. Harris
	†10.7			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and James L. McCulloch
	†10.8			Secondment Agreement dated as of August 2, 2010 by and among Forum Energy Technologies, L.E. Simmons & Associates, Inc. and W. Patrick Connelly

 

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Table of Contents

Index to Financial Statements

Exhibit number				Description
	†10.9			Indemnification Agreement dated as of August 2, 2010 between Forum Energy Technologies and C. Christopher Gaut
	†10.10			Form of Indemnification Agreement between Forum Energy Technologies, Inc. and the executive officers identified on Annex A thereto
	†10.11			Form of Indemnification Agreement between Forum Energy Technologies and each of the non-SCF directors identified on Annex A thereto
	†10.12			Form of Indemnification Agreement between Forum Energy Technologies and each of the SCF directors identified on Annex A thereto
	†10.13			2011 Management Incentive Plan
	†10.14			Forum Energy Technologies, Inc. 2010 Stock Incentive Plan
	†10.15			Forum Energy Technologies, Inc. Severance Plan
	†10.16			Form of Restricted Stock Agreement
	*†10.17			Form of Notice of Grant of Restricted Stock Unit
	*†10.18			Form of Restricted Stock Unit Agreement
	†10.19			Form of Nonstatutory Stock Option Agreement (Employees)
	†10.20			Form of Nonstatutory Stock Option Agreement (Directors)
	10.21			Subscription Agreement dated July 16, 2010 by and among Forum Oilfield Technologies, Inc., SCF-VII, L.P., Sunray Capital, LP, C. Christopher Gaut and W. Patrick Connelly, as amended
	10.22			Subscription Agreement dated August 20, 2010 by and among Forum Energy Technologies, Inc. and the parties thereto (with attached schedule of parties thereto), as amended
	10.23			Form of Warrant Agreement (with attached schedule of parties thereto)
	10.24			Subscription Agreement dated October 25, 2010 between Forum Energy Technologies, Inc. and James L. McCulloch
	10.25			Subscription Agreement dated November 8, 2010 between Forum Energy Technologies, Inc. and Charles E. Jones
	10.26			Subscription Agreement dated August 2, 2011 between Forum Energy Technologies, Inc. and John A. Carrig
	10.27			Subscription Agreement dated August 3, 2011 between Forum Energy Technologies, Inc. and Evelyn Angelle
	**10.28			Agreement and Amendment No. 1 to Credit Agreement, dated as of June 29, 2011, among Forum Energy Technologies, Inc., as Borrower, Wells Fargo Bank, National Association, as Administrative Agent and Swing Line Lender, Wells Fargo Bank, National Association, JPMorgan Chase Bank, N.A. and Bank of America, N.A. and such other lenders designated from time to time as issuing lenders
	*21.1			List of Subsidiaries of Forum Energy Technologies, Inc.
	23.1			Consent of PricewaterhouseCoopers LLP (Forum Energy Technologies, Inc.)
	23.2			Consent of Ernst & Young LLP (Allied Production Services, Inc.)

 

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Index to Financial Statements

Exhibit number				Description
	23.3			Consent of Deloitte & Touche LLP (Allied Production Services, Inc.)
	23.4			Consent of Pannell Kerr Forster of Texas, P.C. (Subsea Services International, Inc.)
	23.5			Consent of Deloitte LLP (Triton Group Holdings LLC)
	23.6			Consent of UHY LLP (Davis-Lynch, Inc.)
	23.7			Consent of PricewaterhouseCoopers LLP (Wood Flowline LLC)
	23.8			Consent of PricewaterhouseCoopers LLP (AMC Global Group Limited)
	23.9			Consent of PricewaterhouseCoopers LLP (P-Quip Limited)
	23.10			Consent of PricewaterhouseCoopers LLP (Cannon Services, Ltd.)
	*23.11			Consent of Vinson & Elkins L.L.P. (included as part of Exhibit 5.1 hereto)
	24.1			Power of Attorney (included on the signature page of this Registration Statement)

 

*

To be filed by amendment.

 

**

Certain schedules and exhibits to the Combination Agreement are not filed herewith in accordance with Item 601(b)(2) of Regulation S-K. Forum agrees to furnish supplementally a copy of any omitted schedule or exhibit to the Combination Agreement to the Securities and Exchange Commission upon request.

 

†

Management contract or compensatory plan or arrangement.

 

Item 17.

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 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 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 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, 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, each post-effective amendment that contains a form of prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

 

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Index to Financial Statements

Signatures

Pursuant to the requirements of the Securities Act of 1933, the registrant has duly caused this Registration Statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Houston, State of Texas, on August 31, 2011.

 

Each person whose signature appears below appoints C. Christopher Gaut, James W. Harris and James L. McCulloch, and each of them, any of whom may act without the joinder of the other, as his or her true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him or her and in his name, place and stead, in any and all capacities, to sign any and all amendments (including post-effective amendments) to this Registration Statement and any Registration Statement (including any amendment thereto) for this offering that is to be effective upon filing pursuant to Rule 462(b) under the Securities Act of 1933, as amended, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he or she might or would do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

Pursuant to the requirements of the Securities Act of 1933, as amended, this Registration Statement has been signed below by the following persons in the capacities and the dates indicated.

 

Signature		Title		Date
/s/ C. Christopher Gaut C. Christopher Gaut		President, Chief Executive Officer and Chairman of the Board (Principal Executive Officer)		August 31, 2011
/s/ James W. Harris James W. Harris		Senior Vice President and Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)		August 31, 2011
/s/ Evelyn Angelle Evelyn Angelle		Director		August 31, 2011
/s/ David C. Baldwin David C. Baldwin		Director		August 31, 2011
/s/ John A. Carrig John A. Carrig		Director		August 31, 2011
/s/ Michael McShane Michael McShane		Director		August 31, 2011

 

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Index to Financial Statements

Signature		Title		Date
/s/ Franklin Myers Franklin Myers		Director		August 31, 2011
/s/ John Schmitz John Schmitz		Director		August 31, 2011
/s/ Andrew L. Waite Andrew L. Waite		Director		August 31, 2011

 

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Table of Contents

Index to Financial Statements

Index to exhibits

 

Exhibit number				Description
	*1.1			Form of Underwriting Agreement
	**2.1			Combination Agreement dated July 16, 2010 by and among Forum Oilfield Technologies, Inc., Allied Production Services, Inc., Allied Merger Sub, LLC, Global Flow Technologies, Inc., Global Flow Merger Sub, LLC, Subsea Services International, Inc., Subsea Merger Sub, LLC, Triton Group Holdings LLC, Triton Merger Sub, LLC and SCF-VII, L.P.
	**2.2			Purchase and Sale Agreement among Davis-Lynch Holding Co., Inc., Carl A. Davis and Forum Energy Technologies, Inc., dated June 25, 2011
	3.1			Second Amended and Restated Certificate of Incorporation of Forum Energy Technologies, Inc.
	3.2			Amended and Restated Bylaws of Forum Energy Technologies, Inc.
	*3.3			Form of Third Amended and Restated Certificate of Incorporation of Forum Energy Technologies, Inc.
	*3.4			Form of Second Amended and Restated Bylaws of Forum Energy Technologies, Inc.
	*4.1			Form of Common Stock Certificate
	4.2			Amended and Restated Stockholders Agreement dated as of August 2, 2010 by and among the Company and certain of its stockholders, as amended
	4.3			Registration Rights Agreement by and among Forum Energy Technologies and the other parties thereto (included as Exhibit B to Exhibit 4.2 hereto)
	*5.1			Opinion of Vinson & Elkins L.L.P. as to the legality of the securities being registered
	10.1			Credit Agreement, dated as of August 2, 2010, among Forum Energy Technologies, Inc., as Borrower, Wells Fargo Bank, National Association, as Administrative Agent and Swing Line Lender, Wells Fargo Bank, National Association, JPMorgan Chase Bank, N.A. and Bank of America, N.A. and such other lenders designated from time to time as issuing lenders.
	†10.2			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and C. Christopher Gaut
	†10.3			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and Charles E. Jones
	†10.4			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and Steven W. Twellman
	†10.5			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and Wendell Brooks
	†10.6			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and James W. Harris
	†10.7			Employment Agreement dated as of August 2, 2010 between Forum Energy Technologies, Inc. and James L. McCulloch
	†10.8			Secondment Agreement dated as of August 2, 2010 by and among Forum Energy Technologies, L.E. Simmons & Associates, Inc. and W.Patrick Connelly

 

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Table of Contents

Index to Financial Statements

Exhibit number				Description
	†10.9			Indemnification Agreement dated as of August 2, 2010 between Forum Energy Technologies and C. Christopher Gaut
	†10.10			Form of Indemnification Agreement between Forum Energy Technologies, Inc. and the executive officers identified on Annex A thereto
	†10.11			Form of Indemnification Agreement between Forum Energy Technologies and each of the non-SCF directors identified on Annex A thereto
	†10.12			Form of Indemnification Agreement between Forum Energy Technologies and each of the SCF directors identified on Annex A thereto
	†10.13			2011 Management Incentive Plan
	†10.14			Forum Energy Technologies, Inc. 2010 Stock Incentive Plan
	†10.15			Forum Energy Technologies, Inc. Severance Plan
	†10.16			Form of Restricted Stock Agreement
	*†10.17			Form of Notice of Grant of Restricted Stock Unit
	*†10.18			Form of Restricted Stock Unit Agreement
	†10.19			Form of Nonstatutory Stock Option Agreement (Employees)
	†10.20			Form of Nonstatutory Stock Option Agreement (Directors)
	10.21			Subscription Agreement dated July 16, 2010 by and among Forum Oilfield Technologies, Inc., SCF-VII, L.P., Sunray Capital, LP, C. Christopher Gaut and W. Patrick Connelly, as amended
	10.22			Subscription Agreement dated August 20, 2010 by and among Forum Energy Technologies, Inc. and the parties thereto (with attached schedule of parties thereto), as amended
	10.23			Form of Warrant Agreement (with attached schedule of parties thereto)
	10.24			Subscription Agreement dated October 25, 2010 between Forum Energy Technologies, Inc. and James L. McCulloch
	10.25			Subscription Agreement dated November 8, 2010 between Forum Energy Technologies, Inc. and Charles E. Jones
	10.26			Subscription Agreement dated August 2, 2011 between Forum Energy Technologies, Inc. and John A. Carrig
	10.27			Subscription Agreement dated August 3, 2011 between Forum Energy Technologies, Inc. and Evelyn Angelle
	**10.28			Agreement and Amendment No. 1 to Credit Agreement, dated as of June 29, 2011, among Forum Energy Technologies, Inc., as Borrower, Wells Fargo Bank, National Association, as Administrative Agent and Swing Line Lender, Wells Fargo Bank, National Association, JPMorgan Chase Bank, N.A. and Bank of America, N.A. and such other lenders designated from time to time as issuing lenders
	*21.1			List of Subsidiaries of Forum Energy Technologies, Inc.
	23.1			Consent of PricewaterhouseCoopers LLP (Forum Energy Technologies, Inc.)
	23.2			Consent of Ernst & Young LLP (Allied Production Services, Inc.)

 

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Table of Contents

Index to Financial Statements

Exhibit number				Description
	23.3			Consent of Deloitte & Touche LLP (Allied Production Services, Inc.)
	23.4			Consent of Pannell Kerr Forster of Texas, P.C. (Subsea Services International, Inc.)
	23.5			Consent of Deloitte LLP (Triton Group Holdings LLC)
	23.6			Consent of UHY LLP (Davis-Lynch, Inc.)
	23.7			Consent of PricewaterhouseCoopers LLP (Wood Flowline LLC)
	23.8			Consent of PricewaterhouseCoopers LLP (AMC Global Group Limited)
	23.9			Consent of PricewaterhouseCoopers LLP (P-Quip Limited)
	23.10			Consent of PricewaterhouseCoopers LLP (Cannon Services, Ltd.)
	*23.11			Consent of Vinson & Elkins L.L.P. (included as part of Exhibit 5.1 hereto)
	24.1			Power of Attorney (included on the signature page of this Registration Statement)

 

*

To be filed by amendment.

 

**

Certain schedules and exhibits to the Combination Agreement are not filed herewith in accordance with Item 601(b)(2) of Regulation S-K. Forum agrees to furnish supplementally a copy of any omitted schedule or exhibit to the Combination Agreement to the Securities and Exchange Commission upon request.

 

†

Management contract or compensatory plan or arrangement.

 

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