DRIL-QUIP INC - Annual Report: 2010 (Form 10-K)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(MARK ONE)

For the fiscal year ended December 31, 2010

or

For the transition period from             to             .

Commission file number: 001-13439

Dril-Quip, Inc.

(Exact name of registrant as specified in its charter)

Registrant’s telephone number, including area code: (713) 939-7711

Securities registered pursuant to Section 12(b) of the Act:

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined by Rule 405 of the Securities Act.     Yes  x    No  ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.    Yes  ¨    No  x

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of regulations S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No  ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ¨

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 definition of “accelerated filer,” “large accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (check one):

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x

At June 30, 2010, the aggregate market value of the registrant’s Common Stock held by non-affiliates of the registrant was approximately $1,500,000,000 based on the closing price of such stock on such date of $44.02.

At February 23, 2011, the number of shares outstanding of registrant’s Common Stock was 40,049,497.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Registrant’s Proxy Statement for its 2011 Annual Meeting of Stockholders to be filed pursuant to Regulation 14A are incorporated by reference in Part III of this Form 10-K.

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FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10-K includes certain statements that may be deemed to be “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Statements contained in all parts of this document that are not historical facts are forward-looking statements that involve risks and uncertainties that are beyond the control of Dril-Quip, Inc. (the “Company” or “Dril-Quip”). You can identify the Company’s forward-looking statements by the words “anticipate,” “estimate,” “expect,” “may,” “project,” “believe” and similar expressions, or by the Company’s discussion of strategies or trends. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, no assurances can be given that these expectations will prove to be correct. These forward-looking statements include the following types of information and statements as they relate to the Company:

These statements are based on assumptions and analyses in light of the Company’s experience and perception of historical trends, current conditions, expected future developments and other factors the Company believes were appropriate in the circumstances when the statements were made. Forward-looking statements by their nature involve substantial risks and uncertainties that could significantly impact expected results, and actual future results could differ materially from those described in such statements. While it is not possible to identify all factors, the Company continues to face many risks and uncertainties. Among the factors that could cause actual future results to differ materially are the risks and uncertainties discussed under “Item 1A. Risk Factors” in this report and the following:

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Many of such factors are beyond the Company’s ability to control or predict. Any of the factors, or a combination of these factors, could materially affect the Company’s future results of operations and the ultimate accuracy of the forward-looking statements. Management cautions against putting undue reliance on forward-looking statements or projecting any future results based on such statements or present or prior earnings levels. Every forward-looking statement speaks only as of the date of the particular statement, and the Company undertakes no obligation to publicly update or revise any forward-looking statement.

PART I

General

Dril-Quip, Inc., a Delaware corporation (the “Company” or “Dril-Quip”), designs, manufactures, sells and services highly engineered offshore drilling and production equipment that is well suited for use in deepwater, harsh environment and severe service applications. The Company’s principal products consist of subsea and surface wellheads, subsea and surface production trees, subsea control systems and manifolds, mudline hanger systems, specialty connectors and associated pipe, drilling and production riser systems, liner hangers, wellhead connectors and diverters. Dril-Quip’s products are used by major integrated, large independent and foreign national oil and gas companies in offshore areas throughout the world. Dril-Quip also provides technical advisory assistance on an as-requested basis during installation of its products, as well as rework and reconditioning services for customer-owned Dril-Quip products. In addition, Dril-Quip’s customers may rent or purchase running tools from the Company for use in the installation and retrieval of the Company’s products.

Dril-Quip has developed its broad line of subsea equipment, surface equipment and offshore rig equipment primarily through its internal product research and development efforts. The Company believes that it has achieved significant market share and brand name recognition with respect to its established products due to the technological capabilities, reliability, cost effectiveness and operational timesaving features of these products.

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The Company’s operations are organized into three geographic segments: Western Hemisphere (including North and South America; headquartered in Houston, Texas), Eastern Hemisphere (including Europe and Africa; headquartered in Aberdeen, Scotland) and Asia-Pacific (including the Pacific Rim, Southeast Asia, Australia, India and the Middle East; headquartered in Singapore). Each of these segments sells similar products and services and the Company has major manufacturing facilities in all three of its headquarter locations as well as Macae, Brazil. The Company maintains additional facilities for fabrication and/or reconditioning in Norway, Denmark, China and Australia. The Company’s manufacturing operations are vertically integrated, allowing it to perform substantially all of its forging, heat treating, machining, fabrication, inspection, assembly and testing at its own facilities. The Company’s major subsidiaries are Dril-Quip (Europe) Limited (DQE), located in Aberdeen with branches in Denmark, Norway and Holland; Dril-Quip Asia Pacific PTE Ltd. (DQAP), located in Singapore; Dril-Quip do Brasil LTDA (DQB), located in Macae, Brazil; and Dril-Quip Holdings Pty Ltd. (DQH), located in Perth, Australia. Dril-Quip (Nigeria) Ltd. is located in Port Harcourt, Nigeria and Dril-Quip Egypt for Petroleum Services S.A.E. is located in Alexandria, Egypt. Dril-Quip Oilfield Services (Tianjin) Co. Ltd. (DQT) is located in Tianjin, China. For additional discussion of our geographic segments, please see Note 11 of Notes to Consolidated Financial Statements.

Dril-Quip markets its products through its offices and sales representatives located in the major international energy markets throughout the world. In 2010, the Company generated approximately 61% of its revenues from foreign sales compared to 66% in 2009 and 69% in 2008.

The Company was co-founded in 1981 by Larry E. Reimert, Gary D. Smith, J. Mike Walker and an investor who is no longer affiliated with the Company. In September 2009, Mr. Smith unexpectedly passed away. In December 2010, Mr. Reimert announced he would step down from his duties as Co-Chief Executive Officer effective December 31, 2010. Mr. Reimert will act as Technical Strategic Advisor for the Company on a part-time basis. He will retain his duties as Co-Chairman of the Board of Directors along with Mr. Walker. Mr. Walker has over 30 years of experience in the oilfield equipment industry, essentially all of which has been with the Company and its major competitors. In addition, most of the Company’s key department managers have been with the Company over 10 years.

The Company makes available free of charge on its website its annual report on Form 10-K, quarterly reports on Form 10-Q (in both HTML and XBRL formats), current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after it electronically files such reports with, or furnishes them to, the Securities and Exchange Commission (“SEC”). The Company’s website address is www.dril-quip.com. Except to the extent explicitly stated herein, documents and information on the Company’s website are not incorporated by reference herein. Any materials we file with the SEC may be read and copied at the SEC’s Public Reference Room at 100 F Street, NE, Washington, D.C. 20549. Information concerning the Public Reference Room may be obtained by calling 1-800-SEC-0330. In addition, the SEC maintains a website (www.sec.gov) that contains reports the Company has filed with the SEC.

The Company also makes available free of charge on its website (www.dril-quip.com/govern.htm) its:

Any stockholder, who so requests, may obtain a printed copy of any of these documents from the Company. Changes in or waivers to our Code of Business Conduct and Ethical Practices involving directors and executive officers of the Company will be posted on our website.

The information on the Company’s website or any other website is not incorporated by reference into this Form 10-K.

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Overview and Industry Outlook

Both the market for offshore drilling and production equipment and services and the Company’s business are substantially dependent on the condition of the oil and gas industry and, in particular, the willingness of oil and gas companies to make capital expenditures on exploration, drilling and production operations offshore. The level of capital expenditures has generally been dependent upon the prevailing view of future oil and gas prices, which are influenced by numerous factors affecting the supply and demand for oil and gas, including worldwide economic activity, interest rates and the cost of capital, environmental regulation, tax policies, and the ability of OPEC and other producing nations to set and maintain production levels and prices. Capital expenditures are also dependent on the cost of exploring for and producing oil and gas, the sale and expiration dates of offshore leases, the discovery rate of new oil and gas reserves in offshore areas and technological advances. Oil and gas prices and the level of offshore drilling and production activity have historically been characterized by significant volatility. In general, increases in oil and gas prices, rig counts and new rig construction result in an increase in demand for the Company’s products and services.

Increasing oil and gas prices from 2005 through mid-2008 resulted in oil operators increasing capital spending for both exploration and development programs. As various geopolitical issues have limited the ability of oil and gas companies to invest in certain geographic areas, such as Russia and the Middle East, an increasing amount of this capital spending was in the deepwater areas. However, in mid-2008, oil and gas prices began to decline. This decline resulted in reduced capital spending by some oil and gas companies. The economic volatility continued in the first half of 2009 and began to stabilize somewhat in the latter half of that year. In 2010, oil prices began to rise and generally ranged between $70 to $80 per barrel and ended the year at $91.38 per barrel. In April 2010, the Deepwater Horizon incident resulted in a temporary drilling moratorium in the U.S. Gulf of Mexico. Although the moratorium was lifted sooner than anticipated, the stagnation of the permitting process continues to be a significant issue. According to Fuelfix.com (“Fuelfix”), a website maintained by Hearst Communications, as of mid-February 2011, the U.S. government had not approved any proposed projects that were blocked by the drilling moratorium. The Bureau of Ocean Energy Management, Regulations and Enforcement of the U.S. Department of the Interior (the “BOEM”) has indicated that the agency expects to begin granting permits before the end of the second quarter of 2011, although no assurances can be given that this will occur by then or any time thereafter. Disruptions of this nature could have a material effect on the Company’s customers regarding future capital expenditures. Except for the continued issues and concerns in the U.S. Gulf of Mexico, the Company expects that the need for specialized products on a global basis will continue and, to date, the Company has not seen a material dropoff in demand for its products during this volatile market period. See “Item 1A. Risk Factors—A material or extended decline in expenditures by the oil and gas industry could significantly reduce our revenue and income.”

Products and Services

Products

Dril-Quip designs, manufactures, fabricates, inspects, assembles, tests and markets subsea equipment, surface equipment and offshore rig equipment. The Company derived approximately 86% of its revenues from the sale of its products in 2010 compared to 84% in 2009 and 2008. The Company’s products are used to explore for oil and gas on offshore drilling rigs, such as floating rigs and jack-ups, and for drilling and production of oil and gas wells on offshore platforms, tension leg platforms (“TLPs”), Spars and moored vessels such as FPSOs. TLPs are floating production platforms that are connected to the ocean floor via vertical mooring tethers. A Spar is a floating cylindrical structure approximately six or seven times longer than its diameter and is anchored in place (like a Spar buoy). FPSOs are floating production, storage and offloading monohull moored vessels.

Subsea Equipment. Subsea equipment is used in the drilling and production of offshore oil and gas wells around the world. Included in the subsea equipment product line are subsea wellheads, mudline hanger systems, specialty connectors and associated pipe, subsea production trees, liner hangers, subsea control systems and subsea manifolds.

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Subsea wellheads are pressure-containing forged and machined metal housings in which casing hangers are landed and sealed subsea to suspend casing (downhole pipe). As drilling depth increases, successively smaller diameter casing strings are installed, each suspended by an independent casing hanger. Subsea wellheads are utilized when drilling from floating drilling rigs, either semi-submersible or drill ship types, and TLPs and Spars. The Company’s SS-15 Big Bore Subsea Wellhead System is designed to accommodate additional casing strings installed through a conventional marine riser and a subsea blowout preventer.

Mudline hanger systems are used in jack-up drilling operations to support the weight of the various casing strings at the ocean floor while drilling a well. They also provide a method to disconnect the casing strings in an orderly manner at the ocean floor after the well has been drilled, and subsequently reconnect to enable production of the well by either tying it back vertically to a subsequently installed platform or by installing a subsea tree.

Large diameter weld-on specialty connectors (threaded or stab type) are used in offshore wells drilled from floating drilling rigs, jack-ups, fixed platforms, TLPs and Spars. Specialty connectors join lengths of conductor or large diameter (16-inch or greater) casing. Specialty connectors provide a more rapid connection than other methods of connecting lengths of pipe. Connectors may be sold individually or as an assembly after being welded to sections of Company or customer supplied pipe. Dril-Quip’s weld-on specialty connectors are designed to prevent cross threading and provide a quick, convenient method of joining casing joints with structural integrity compatible with casing strength.

A subsea production tree is an assembly composed of valves, a wellhead connector, control equipment and various other components installed on a subsea wellhead or a mudline hanger system and used to control the flow of oil and gas from a producing well. Subsea trees may be either stand alone satellite type or template mounted cluster arrangements. Both types typically produce via flowlines to a central control point located on a platform, TLP, Spar or FPSO. The use of subsea production trees has become an increasingly important method for producing wells located in hard-to-reach deepwater areas or economically marginal fields located in shallower waters. The Company is an established manufacturer of more complicated dual-bore production trees, which are used in severe service applications. In addition, Dril-Quip manufactures a patented single bore (SingleBore™) subsea completion system which features a hydraulic mechanism instead of a wireline-installed mechanism that allows the operator to plug the tubing hanger annulus remotely from the surface via a hydraulic control line and subsequently unplug it when the well is put on production. This mechanism eliminates the need for an expensive multibore installation and workover riser, thereby saving both cost and installation time. Dril-Quip’s guidelineless subsea production tree is used in ultra-deepwater applications. This tree features remote multiple flowline and control connections, utilizing remotely operated intervention tools. The Company’s subsea production trees are generally custom designed and manufactured to customer specifications.

A liner hanger is used to hang-off and seal casing into a previously installed casing string in the well bore, and can provide a means of tying back the liner for production to surface. Dril-Quip has developed a state-of-the-art liner hanger system and has installed its liner hangers in a number of difficult well applications, resulting in improved industry recognition and market opportunities.

A subsea control system provides control of subsea trees, manifolds and other ocean floor process equipment. Dril-Quip has developed a variety of subsea control systems, including fiber optic based multiplex control systems that provide real time access to tree functions and tree equipment status. The control system can be packaged for shallow water or deepwater applications. Dril-Quip also manufactures control systems used in the installation, retrieval and workover of production equipment.

A subsea manifold is a structure located on the ocean floor consisting of valves, chokes, flowline connections and a control module used to collect and control the flow of oil and gas from subsea wells for delivery to a terminal.

Surface Equipment. Surface equipment is principally used for flow control on offshore production platforms, TLPs and Spars. Included in the Company’s surface equipment product line are platform wellheads

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and platform production trees. Dril-Quip’s development of platform wellheads and platform production trees was facilitated by adaptation of its existing subsea wellhead and tree technology to surface wellheads and trees.

Platform wellheads are pressure-containing forged and machined metal housings in which casing hangers are landed and sealed at the platform deck to suspend casings. The Company emphasizes the use of metal-to-metal sealing wellhead systems with operational time-saving features which can be used in high pressure, high temperature and corrosive drilling and production applications.

After installation of a wellhead, a platform production tree, consisting of gate valves, a wellhead connector, controls, tree cap and associated equipment, is installed on the wellhead to control and regulate oil or gas production. Platform production trees are similar to subsea production trees but utilize less complex equipment and more manual, rather than hydraulically activated, valves and connectors. Platform wellheads and platform production trees and associated equipment are designed and manufactured in accordance with customer specifications.

Offshore Rig Equipment. Offshore rig equipment includes drilling and completion riser systems, wellhead connectors and diverters. The drilling riser system consists of (i) lengths of riser pipe and associated riser connectors that secure one to another; (ii) the telescopic joint, which connects the entire drilling riser system to the diverter at the rig and provides a means to compensate for vertical motion of the rig relative to the ocean floor; and (iii) the wellhead connector, which provides a means for remote connection and disconnection of the drilling riser system to and from the blowout preventer stack. Completion risers provide a vertical conduit from the subsea wellhead to a TLP, Spar or FPSO. The wellhead connector also provides remote connection/disconnection of the blowout preventer stack, production tree or production riser to/from the wellhead. Diverters are used to provide protection from shallow gas blowouts and to divert gases off of the rig during the drilling operation.

Wellhead connectors and drilling and production riser systems are also used on both TLPs and Spars, which are being installed more frequently in deepwater applications. The principal markets for offshore rig equipment are new rigs, rig upgrades, TLPs and Spars. Diverters, drilling and production risers and wellhead connectors are generally designed and manufactured to customer specifications.

Certain products of the Company are used in potentially hazardous drilling, completion and production applications that can cause personal injury, product liability and environmental claims. See “Item 1A. Risk Factors—Our business involves numerous operating hazards that may not be covered by insurance. The occurrence of an event not fully covered by insurance could have a material adverse effect on the financial conditions and results of operations.”

Services

Services provided by Dril-Quip include technical advisory services, reconditioning of its products which are customer-owned, and rental of running tools for installation and retrieval of its products. These services are provided from the Company’s worldwide locations and represented approximately 14% of revenues in 2010 compared to 16% in 2009 and 2008.

Technical Advisory. Dril-Quip does not install products for its customers, but provides technical advisory assistance to the customer, if requested, in the installation of its products. The customer is not obligated to utilize these services and may use its own personnel or a third party to perform these services. Technical advisory services performed by the Company are negotiated and sold separately from the Company’s products. These services are not a prerequisite to the sale of the Company’s products as its products are fully functional on a stand alone basis. The Company’s technicians provide assistance in the onsite installation of the Company’s products and are available on a 24-hour call out from the Company’s facilities located in Houston, Texas; Aberdeen, Scotland; Stavanger, Norway; Esbjerg, Denmark; Singapore; Perth, Australia; Macae, Brazil; Alexandria, Egypt; and Tianjin, China.

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Reconditioning. The Company provides reconditioning of its products at its facilities in Houston, Texas; Aberdeen, Scotland; Stavanger, Norway; Singapore; and Macae, Brazil. The Company does not service, repair or recondition its competitors’ products.

Rental. The Company rents running and installation tools for use in installing its products. These tools are used to install and retrieve the Company’s products which are purchased by customers. Rental or purchase of running tools is not a condition of the sale of the Company’s products and are contracted for separately from product sales and other services offered by the Company. Running tools are available from Dril-Quip’s locations in Houston, Texas; Aberdeen, Scotland; Stavanger, Norway; Esbjerg, Denmark; Beverwijk, Holland; Singapore; Perth, Australia; Tianjin, China; Alexandria, Egypt; and Macae, Brazil.

Manufacturing

Dril-Quip has major manufacturing facilities in Houston, Texas; Aberdeen, Scotland; Singapore; and Macae, Brazil. Each location conducts a broad variety of processes, including machining, fabrication, inspection, assembly and testing. The Houston facility also provides forged and heat treated products to all the major manufacturing facilities.

The Company’s Houston, Aberdeen and Singapore manufacturing plants are ISO 9001:2008 certified and licensed to applicable API product specifications. The Company’s Macae manufacturing plant is ISO 9001:2008 certified. See “Properties—Major Manufacturing Facilities.” Dril-Quip maintains its high standards of product quality through the use of quality assurance specialists who work with product manufacturing personnel throughout the manufacturing process by inspecting and documenting equipment as it is processed through the Company’s manufacturing facilities. The Company has the capability to manufacture various products from each of its product lines at its major manufacturing facilities and believes that this localized manufacturing capability is essential in order to compete with the Company’s major competitors.

The Company’s manufacturing process is vertically integrated, producing a majority of its forging requirements and essentially all of its heat treatment, machining, fabrication, inspection, assembly and testing in-house. The Company’s primary raw material is cast steel ingots, from which it produces steel shaped forgings at its forging and heat treatment facility. The Company routinely purchases steel ingots from multiple suppliers on a purchase order basis and does not have any long-term supply contracts. The Company’s Houston facility provides forgings and heat treatment for its Houston, Aberdeen, Singapore and Macae facilities. The Company’s major competitors depend on outside sources for all or a substantial portion of their forging and heat treatment requirements. The Company has made significant capital investments in developing its vertically integrated manufacturing capability. Prolonged periods of low demand in the market for offshore drilling and production equipment could have a greater effect on the Company than on certain of its competitors that have not made such large capital investments in their facilities.

Dril-Quip’s manufacturing facilities utilize state-of-the-art computer numerically controlled (“CNC”) machine tools and equipment, which contribute to the Company’s product quality and timely delivery. The Company has also developed a cost effective, in-house machine tool rebuild capability which produces “like new” machine upgrades with customized features to enhance the economic manufacture of its specialized products. The Company purchases quality used machine tools as they become available and stores them at its facilities to be rebuilt and upgraded as the need arises. Rebuilding used machine tools allows for greater customization suitable for manufacturing Dril-Quip proprietary product lines. This strategy provides the added advantage of in-house expertise for repairs and maintenance of these machines. A significant portion of the Company’s manufacturing capacity growth has been through the rebuild/upgrade of quality used machine tools, including the replacement of outdated control systems with state-of-the-art CNC controls.

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Customers

The Company’s principal customers are major integrated, large independent and foreign national oil and gas companies. Offshore drilling contractors and engineering and construction companies also represent a portion of the Company’s customer base. The Company’s customers are generally oil and gas companies that are well-known participants in offshore exploration and production.

The Company is not dependent on any one customer or group of customers. In 2010, the Company’s top 15 customers represented approximately 63% of total revenues, with one customer, Keppel Fels, accounting for approximately 13% of the Company’s total revenues. No other customer accounted for more than 10% of the Company’s total revenues in 2010. In 2009, the Company’s top 15 customers represented approximately 60% of total revenues, and one customer, ConocoPhillips, accounted for approximately 10% of the Company’s total revenues. In 2008, the Company’s top 15 customers represented approximately 45% of total revenues with no customer accounting for more than 10% of the Company’s total revenues. The number and variety of the Company’s products required in a given year by any one customer depends upon the amount of that customer’s capital expenditure budget devoted to offshore exploration and production and on the results of competitive bids for major projects. Consequently, a customer that accounts for a significant portion of revenues in one fiscal year may represent an immaterial portion of revenues in subsequent years. While the Company is not dependent on any one customer or group of customers, the loss of one or more of its significant customers could, at least on a short-term basis, have an adverse effect on the Company’s results of operations.

Backlog

Backlog consists of firm customer orders for which a purchase order or signed contract has been received, satisfactory credit or financing arrangements exist and delivery is scheduled. The Company’s revenues for a specific period have not been directly related to its backlog as stated at a particular point in time. The Company’s backlog was approximately $627 million, $563 million and $603 million at December 31, 2010, 2009 and 2008, respectively. The 2010 amount represents an increase of approximately $64 million, or 11%, from 2009 to 2010 and an increase of approximately $24 million, or 4%, from 2008 to 2010. The Company expects to fill approximately 68% of the December 31, 2010 backlog by December 31, 2011. The remaining backlog at December 31, 2010 consists of longer-term projects which are being designed and manufactured to customer specifications requiring longer lead times. Our reported backlog at December 31, 2009 and 2008 excludes $27 million related to the MPF contract which was resolved in 2010 as described in Note 9 of Notes to Consolidated Financial Statements.

The Company can give no assurance that backlog will remain at current levels. Sales of the Company’s products are affected by prices for oil and natural gas, which may fluctuate significantly. Additional future declines in oil and natural gas prices could reduce new customer orders, possibly causing a decline in the Company’s future backlog. All of the Company’s projects currently included in its 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 the Company 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 significant to the Company’s overall operating results.

Marketing and Sales

Dril-Quip markets its products and services throughout the world directly through its sales personnel in two domestic and fifteen international locations. In addition, in certain foreign markets where the Company does not maintain offices, it utilizes independent sales representatives to enhance its marketing and sales efforts. Some of the locations in which Dril-Quip has sales representatives are India, Mexico, Brazil, Indonesia, Malaysia, China, Egypt, Libya, Nigeria, Qatar, Saudi Arabia and United Arab Emirates. Although they do not have authority to contractually bind the Company, these representatives market the Company’s products in their respective territories in return for sales commissions. The Company advertises its products and services in trade and technical publications targeted to its customer base. The Company also participates in industry conferences and trade shows to enhance industry awareness of its products.

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The Company’s customers generally order products on a purchase order basis. Orders, other than those considered to be long-term projects, are typically filled within six to nine months after receipt of a purchase order, depending on the type of product and whether it is sold out of inventory or requires some customization. Contracts for certain of the Company’s larger, more complex products, such as subsea production trees, drilling risers and equipment for TLPs and Spars can take a year or more to complete.

The primary factors influencing a customer’s decision to purchase the Company’s products are the quality, reliability and reputation of the product, price and technologically superior features. Timely delivery of equipment is also very important to customer operations and the Company maintains an experienced sales coordination staff to help assure such delivery. For large drilling and production system orders, project management teams coordinate customer needs with the Company’s engineering, manufacturing and service organizations, as well as with subcontractors and vendors.

A portion of the Company’s business consists of designing, manufacturing and selling equipment, as well as offering technical advisory assistance during installation of the equipment, for major projects pursuant to competitive bids. The number of such projects in any year may fluctuate. The Company’s profitability on such projects is critically dependent on making accurate and cost effective bids and performing efficiently in accordance with bid specifications. Various factors can adversely affect the Company’s performance on individual projects, with potential material adverse effects on project profitability.

Product Development and Engineering

The technological demands of the oil and gas industry continue to increase as offshore exploration and drilling expand into more hostile environments. Conditions encountered in these environments include well pressures of up to 15,000 psi (pounds per square inch), mixed flows of oil and gas under high pressure that may also be highly corrosive and water depths in excess of 10,000 feet. Since its founding, Dril-Quip has actively engaged in continuing product development to generate new products and improve existing products. When developing new products, the Company typically seeks to design the most technologically advanced version for a particular application to establish its reputation and qualification in that product. Thereafter, the Company leverages its expertise in the more technologically advanced product to produce less costly and complex versions of the product for less demanding applications. The Company also focuses its activities on reducing the overall cost to the customer, which includes not only the initial capital cost but also operating and installation costs associated with its products.

The Company has continually introduced new products and product enhancements since its founding in 1981. In the 1990s, the Company introduced a series of new products, including diverters, wellhead connectors, SingleBore™ subsea trees, improved severe service dual bore subsea trees, subsea and platform valves, platform wellheads, platform trees, subsea tree workover riser systems, drilling risers and TLP and Spar production riser systems. Since the year 2000, Dril-Quip has introduced multiple new products including liner hangers, subsea control systems and subsea manifolds.

Dril-Quip’s product development work is conducted at its facilities in Houston, Texas and Aberdeen, Scotland. In addition to the work of its product development staff, the Company’s application engineering staff provides engineering services to customers in connection with the design and sales of its products. The Company’s ability to develop new products and maintain technological advantages is important to its future success. There can be no assurance that the Company will be able to develop new products, successfully differentiate itself from its competitors or adapt to evolving markets and technologies.

The Company believes that the success of its business depends more on the technical competence, creativity and marketing abilities of its employees than on any individual patent, trademark or copyright. Nevertheless, as part of its ongoing product development and manufacturing activities, Dril-Quip’s policy has been to seek patents when appropriate on inventions concerning new products and product improvements. All patent rights for

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products developed by employees are assigned to the Company and almost all of the Company’s products have components that are covered by patents.

Dril-Quip has numerous U.S. registered trademarks, including Dril-Quip^®, Quik-Thread^®, Quick-Stab^®, Multi-Thread^®, MS-15^®, SS-15^®, SS-10^® and SU-90^®. The Company has registered its trademarks in the countries where such registration is deemed material.

Although in the aggregate the Company’s patents and trademarks are of considerable importance to the manufacturing and marketing of many of its products, the Company does not consider any single patent or trademark or group of patents or trademarks to be material to its business as a whole, except the Dril-Quip^® trademark. The Company also relies on trade secret protection for its confidential and proprietary information. The Company routinely enters into confidentiality agreements with its employees and suppliers. There can be no assurance, however, that others will not independently obtain similar information or otherwise gain access to the Company’s trade secrets.

Competition

Dril-Quip faces significant competition from other manufacturers and suppliers of exploration and production equipment. Several of its primary competitors are diversified multinational companies with substantially larger operating staffs and greater capital resources than those of the Company and which, in many instances, have been engaged in the manufacturing business for a much longer period of time than the Company. The Company competes principally with GE Oil and Gas (formerly Vetco Gray), and the petroleum production equipment segments of Cameron International Corporation, FMC Technologies, Inc. and Aker Solutions.

Because of their relative size and diversity of products, several of the Company’s competitors have the ability to provide “turnkey” services for offshore drilling and production applications, which enables them to use their own products to the exclusion of Dril-Quip’s products. See “Item 1A. Risk Factors—We may be unable to successfully compete with other manufacturers of drilling and production equipment.” The Company also competes to a lesser extent with a number of other companies in various products. The principal competitive factors in the petroleum drilling and production equipment markets are quality, reliability and reputation of the product, price, technology, service and timely delivery.

Employees

The total number of the Company’s employees as of December 31, 2010 was 2,127. Of these, 1,204 were located in the United States. Substantially all of the Company’s employees are not covered by collective bargaining agreements, and the Company considers its employee relations to be good.

The Company’s operations depend in part on its ability to attract quality employees. While the Company believes that its wage and salary rates are competitive and that its relationship with its labor force is good, a significant increase in the wages and salaries paid by competing employers could result in a reduction of the Company’s labor force, increases in the wage and salary rates paid by the Company or both. If either of these events were to occur, in the near-term, the profits realized by the Company from work in progress would be reduced and, in the long-term, the production capacity and profitability of the Company could be diminished and the growth potential of the Company could be impaired. See “Item 1A. Risk Factors—Loss of our key management or other personnel could adversely impact our business.”

Governmental Regulations

Many aspects of the Company’s operations are affected by political developments and are subject to both domestic and foreign governmental regulations, including those relating to oilfield operations, worker safety and the protection of the environment. In addition, the Company depends on the demand for its services from the oil and gas industry and, therefore, is affected by changing taxes, price controls and other laws and regulations

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relating to the oil and gas industry in general, including those specifically directed to offshore operations. The adoption of laws and regulations curtailing exploration and development drilling for oil and gas for economic or other policy reasons could adversely affect the Company’s operations by limiting demand for the Company’s products. See “Item 1A. Risk Factors—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.”

In recent years, increased concern has been raised over the protection of the environment. Legislation to regulate emissions of greenhouse gases has been introduced in Congress, and there has been a wide-ranging policy debate, both nationally and internationally, regarding the impact of these gases and possible means for their regulation. In addition, efforts have been made and continue to be made in the international community toward the adoption of international treaties or protocols that would address global climate change issues, such as the annual United Nations Climate Change Conferences. Also, the EPA has undertaken new efforts to collect information regarding greenhouse gas emissions and their effects. Following a finding by the EPA that certain greenhouse gases represent a danger to human health, the EPA proposed to expand its regulations relating to those emissions and has adopted rules imposing permitting and reporting obligations. The results of the permitting and reporting requirements could lead to further regulation of these greenhouse gases by the EPA. Moreover, offshore drilling in certain areas has been opposed by environmental groups and, in certain areas, has been restricted. To the extent that new laws or other governmental actions prohibit or restrict offshore drilling or impose additional environmental protection requirements that result in increased costs to the oil and gas industry in general and the offshore drilling industry in particular, the business of the Company could be adversely affected. The Company cannot determine to what extent its future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations. See “Item 1A. Risk Factors—Our business and our customers’ businesses are subject to environmental laws and regulations that may increase our costs, limit the demand for our products and services or restrict our operations.”

Based on the Company’s experience to date, the Company does not currently anticipate any material adverse effect on its business or consolidated financial position as a result of future compliance with existing environmental laws and regulations controlling the discharge of materials into the environment. However, future events, such as changes in existing laws and regulations or their interpretation, more vigorous enforcement policies of or by regulatory agencies, or stricter or different interpretations of existing laws and regulations, may require additional expenditures by the Company, which may be material.

In 2010, the incident involving the Deepwater Horizon and the ensuing oil spill caused the U.S. government to issue a moratorium on offshore drilling in the U.S. Gulf of Mexico. The moratorium has since been lifted, but little to no activity, including shallow water drilling, has resumed. According to Fuelfix, as of mid-February 2011, there had been no approval of any proposed projects that were blocked by the ban and the industry is having difficulty understanding some of the rules regarding environment and safety standards. To the extent there continues to be permitting delays and concerns with new or revised rules and regulations, the Company’s financial operations could be materially or adversely affected. See “Item 1A” Risk Factors – Certain matters relating to the Deepwater Horizon explosion, subsequent oil spill, moratorium and related regulations on deepwater drilling offshore in the U.S. Gulf of Mexico may adversely affect our business located in the U.S. Gulf of Mexico and potential other worldwide locations.”

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In this Item 1A, the terms “we,” “our,” “us,” and “Dril-Quip” used herein refer to Dril-Quip, Inc. and its subsidiaries unless otherwise indicated or as the context so requires.

A material or extended decline in expenditures by the oil and gas industry could significantly reduce our revenue and income.

Our business depends upon the condition of the oil and gas industry and, in particular, the willingness of oil and gas companies to make capital expenditures on exploration, drilling and production operations offshore. The level of capital expenditures is generally dependent on the prevailing view of future oil and gas prices, which are influenced by numerous factors affecting the supply and demand for oil and gas, including:

Oil and gas prices and the level of offshore drilling and production activity have been characterized by significant volatility in recent years. Worldwide military, political and economic events have contributed to oil and natural gas price volatility and are likely to continue to do so in the future. Oil prices declined from record levels in July 2008 of over $140 per barrel to $45 per barrel in December 2008 and natural gas prices declined from over $13 per thousand cubic feet to below $6 per thousand cubic feet over the same period. Oil prices in 2009 ranged from $34 per barrel to $81 per barrel. In 2010, oil prices were above $70 per barrel for nearly the entire year and ended the year at $91 per barrel. We expect continued volatility in both crude oil and natural gas prices as well as in the level of drilling and production related activities. Even during periods of high prices for oil and natural gas, companies exploring for oil and gas may cancel or curtail programs, or reduce their levels of capital expenditures for exploration and production for a variety of reasons. In addition, future significant or prolonged declines in hydrocarbon prices may have a material adverse effect on our results of operations.

Certain matters relating to the Deepwater Horizon explosion, subsequent oil spill, moratorium and related regulations on deepwater drilling offshore in the U. S. Gulf of Mexico may adversely affect our business located in the U.S. Gulf of Mexico and potential other worldwide locations.

On April 22, 2010, a deepwater U.S. Gulf of Mexico drilling rig known as the Deepwater Horizon that was operated by BP Exploration & Production, Inc. (“BP”) sank after an explosion and fire that began on April 20, 2010. We are a party to an ongoing contract with an affiliate of BP to supply wellhead systems in connection

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with BP’s U.S. Gulf of Mexico operations, and our wellhead and certain of our other equipment were in use on the Deepwater Horizon at the time of the incident. A moratorium was placed on offshore deepwater drilling by the U.S. government in the U.S. Gulf of Mexico that was lifted on October 12, 2010. During the pendency of the moratorium, the BOEM issued various new regulations intended to improve offshore safety systems and environmental protection. We believe these new regulations, which increase the complexity of the drilling permit process, will result in delays for the receipt of drilling permits by the Company’s customers relative to past experience. According to Fuelfix, as of mid-February 2011, the U.S. government had not approved any projects that were blocked by the moratorium. The BOEM’s office of Regulation and Enforcement has indicated that deepwater permits will begin to be granted before the end of the second quarter of 2011, although no assurances can be given that this will occur by then or any time thereafter.

Although the drilling moratorium has been lifted, we are currently unable to quantify the extent of the impact that it, and related permitting delays, will have on our future revenues. Revenues associated with the U.S. Gulf of Mexico totaled approximately 39% of our worldwide revenues during 2010. Although we believe that the drilling moratorium and permitting delays will have little or no impact on revenues related to sales of our offshore rig equipment, the drilling moratorium and permitting delays could have a significant adverse impact on revenues related to subsea equipment, and, to a lesser extent, surface equipment revenues, in 2011. We believe that U.S. Gulf of Mexico service revenues (which were approximately 5% of our total revenues during 2010) could be substantially negatively impacted in 2011 by the U.S. Gulf of Mexico drilling moratorium and permitting delays. The Company’s service revenues in the U.S. Gulf of Mexico declined significantly each quarter since the first quarter of 2010, generally as a result of the drilling moratorium and related permit delays. Additionally, the drilling moratorium and the stagnation of the permitting process could result in delayed product and service orders in 2011 and could have an adverse impact on our financial results in 2011 and future years depending on new rules and regulations that are being adopted and modified on a continual basis.

We do not yet know the extent to which this incident may cause the United States or other countries to restrict or further regulate offshore drilling. In addition to the newly issued BOEM regulations, we believe the U.S. government is likely to issue additional safety and environmental guidelines or regulations for drilling in the U.S. Gulf of Mexico, which may result in substantial increases in cost or further delays in drilling in the U.S. Gulf of Mexico. Any increases in the costs to our customers could cause some projects to become non-economical, and as a result, reduce demand for our products and services.

Investigations into the incident are being conducted by the Departments of Homeland Security, Interior and Justice, the U.S. Chemical Safety and Hazard Investigation Board and the National Commission on the BP Deepwater Horizon Oil Spill and Offshore Drilling. We have been designated as a party-in-interest, received requests for certain information and provided testimony in connection with the joint investigation being conducted by the Departments of Homeland Security and Interior. We have also received requests to preserve information from the joint investigation team, the Department of Justice and the U.S. Chemical Investigation and Hazardous Incident Board. While the focus of some of these investigations is to develop options for guarding against future oil spills associated with offshore drilling, the Department of Justice has announced that it is reviewing, among other criminal statutes, The Clean Water Act, which carries civil penalties and fines as well as criminal penalties, The Oil Pollution Act of 1990, which can be used to hold parties liable for cleanup costs and reimbursement for government efforts, and The Migratory Bird Treaty Act of 1918 and Endangered Species Act of 1973, which provide penalties for injury and death to wildlife and bird species. In December 2010, the U.S. government filed a civil lawsuit against BP and eight other companies seeking monetary penalties under the Clean Water Act.

We have been named or added as defendants, along with other unaffiliated entities, in multiple lawsuits arising out of the Deepwater Horizon incident. The lawsuits generally allege, among other things, violation of state and federal environmental and other laws and regulations, negligence, gross negligence, strict liability and/or property damages and generally seek awards of unspecified economic, compensatory and punitive damages and/or declaratory relief.

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Additional lawsuits may be filed and additional investigations may be launched in the future. An adverse outcome with respect to any of these lawsuits or investigations, or any lawsuits or investigations that may arise in the future, could have a material adverse effect on our results of operations.

At the time of the Deepwater Horizon incident, we had a general liability insurance program with an aggregate coverage limit of $100 million for claims with respect to property damage, injury or death and pollution. The insurance policies may not cover all potential claims and expenses relating to the Deepwater Horizon incident. In addition, our policies may not cover fines, penalties or costs and expenses related to government-mandated clean up of pollution. The incident may also lead to further tightening of the availability of insurance coverage. We may not be able to obtain adequate insurance at a reasonable price, thereby making certain projects unfeasible from an economic standpoint. If liability limits are increased or the insurance market becomes more restricted, the risks and costs of conducting offshore exploration and development activities may increase, which could materially impact our results of operations.

We are continuing to assess our rights to indemnification from BP’s affiliate and other parties for potential claims and expenses arising from the Deepwater Horizon incident under our existing contract with the affiliate of BP. Our indemnity rights under the contract cover potential claims for personal injury, property damage and the control and removal of pollution or contamination, except for, among other things, claims brought by our employees and claims brought by third parties to the extent we are at fault or as a result of a defect in our products. Under the contract, we have generally agreed to indemnify BP and its affiliates for claims for personal injury of our employees or subcontractors, for claims brought by third parties to the extent we are at fault, and for claims resulting from pollution or contamination as a result of a defect in our products. Our indemnification obligation for pollution or contamination arising from a defect in our products is limited to $5 million under the contract. To the extent that BP’s other contractors performing work on the well agreed in their contracts with BP to indemnify us for claims of personal injury of such contractor’s employees or subcontractors as well as for claims of damages to their property, we have entered into a reciprocal agreement to indemnify those other contractors.

We may be unable to successfully compete with other manufacturers of drilling and production equipment.

Several of our primary competitors are diversified multinational companies with substantially larger operating staffs and greater capital resources than ours and which have been engaged in the manufacturing business for a much longer time than us. If these competitors substantially increase the resources they devote to developing and marketing competitive products and services, we may not be able to compete effectively. Similarly, consolidation among our competitors could enhance their product and service offerings and financial resources, further intensifying competition.

The loss of a significant customer could have an adverse impact on our financial results.

Our principal customers are major integrated oil and gas companies, large independent oil and gas companies and foreign national oil and gas companies. Offshore drilling contractors and engineering and construction companies also represent a portion of our customer base. In 2010, our top 15 customers represented approximately 63% of total revenues, with one customer, Keppel Fels, accounting for approximately 13% of our total revenues. In 2009, our top 15 customers represented approximately 60% of total revenues, and one customer, ConocoPhillips, accounted for approximately 10% of our total revenues. In 2008, our top 15 customers represented approximately 45% of total revenues, with no customer accounting for more than 10% of our total revenues. While we are not dependent on any one customer or group of customers, the loss of one or more of our significant customers could, at least on a short-term basis, have an adverse effect on our results of operations, financial position and cash flows.

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Our customers’ industries are undergoing continuing consolidation that may impact our results of operations.

The oil and gas industry is rapidly consolidating and, as a result, some of our largest customers have consolidated and are using their size and purchasing power to seek economies of scale and pricing concessions. This consolidation may result in reduced capital spending by some of our customers or the acquisition of one or more of our primary customers, which may lead to decreased demand for our products and services. We cannot assure you that we will be able to maintain our level of sales to a customer that has consolidated or replace that revenue with increased business activity with other customers. As a result, the acquisition of one or more of our primary customers may have a significant negative impact on our results of operations or our financial condition. We are unable to predict what effect consolidations in the industry may have on price, capital spending by our customers, our selling strategies, our competitive position, our ability to retain customers or our ability to negotiate favorable agreements with our customers.

Increases in the cost of raw materials and energy used in our manufacturing processes could negatively impact our profitability.

Any increases in commodity prices for items such as nickel, molybdenum and heavy metal scrap that are used to make the steel alloys required for our products would result in an increase in our raw material costs. Similarly, any increase in energy costs would increase our product costs. If we are not successful in raising our prices on products to compensate for any increased raw material or energy costs, our margins will be negatively impacted.

We depend on third party suppliers for timely deliveries of raw materials, and our results of operations could be adversely affected if we are unable to obtain adequate supplies in a timely manner.

Our manufacturing operations depend upon obtaining adequate supplies of raw materials from third parties. The ability of these third parties to deliver raw materials may be affected by events beyond our control. Any interruption in the supply of raw materials needed to manufacture our products could adversely affect our business, results of operations and reputation with our customers.

The unsettled conditions in the global financial system may have impacts on our business and financial condition that we currently cannot predict.

The recent credit crisis and unsettled conditions in the global financial system may have an impact on our business and our financial condition. Uncertainty and turmoil in the credit markets may negatively impact the ability of our customers to finance purchases of our products and services and could result in a decrease in, or cancellation of, orders included in our backlog or adversely affect the collectability of our receivables. If the availability of credit to our customers is reduced, they may reduce their drilling and production expenditures, thereby decreasing demand for our products and services, which could have a negative impact on our financial condition. Additionally, unsettled conditions could have an impact on our suppliers, causing them to be unable to meet their obligations to us. Although we do not currently anticipate a need to access the credit markets in the short term, a prolonged constriction on future lending by banks or investors could result in higher interest rates on future debt obligations or could restrict our ability to obtain sufficient financing to meet our long-term operational and capital needs.

Our international operations expose us to instability and changes in economic and political conditions and other risks inherent to international business, which could have a material adverse effect on our operations or financial condition.

We have substantial international operations, with approximately 61%, 66% and 69% of our revenues derived from foreign sales in each of 2010, 2009 and 2008, respectively. We operate our business and market our products and services in all of the significant oil and gas producing areas in the world and are, therefore, subject

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to the risks customarily attendant to international operations and investments in foreign countries. Risks associated with our international operations include:

Any of these risks could have an adverse effect on our ability to manufacture products abroad or the demand for our products and services in some locations. To date, we have not experienced any significant problems in foreign countries arising from local government actions or political instability, but there is no assurance that such problems will not arise in the future. Interruption of our international operations could have a material adverse effect on our overall operations.

We are subject to taxation in many jurisdictions and there are inherent uncertainties in the final determination of our tax liabilities.

As a result of our international operations, we are subject to taxation in many jurisdictions. Therefore, the final determination of our tax liabilities involves the interpretation of the statutes and requirements of taxing authorities worldwide. Foreign income tax returns of foreign subsidiaries and related entities are routinely examined by foreign tax authorities. These tax examinations may result in assessments of additional taxes or penalties or both. Please see “Item 3. Legal Proceedings” regarding tax assessments in Brazil.

Our excess cash is invested in various financial instruments which may subject us to potential losses.

We invest excess cash in various financial instruments including interest bearing accounts, money market mutual funds and funds which invest in U.S. Treasury obligations and repurchase agreements backed by U.S. Treasury obligations. However, changes in the financial markets, including interest rates, as well as the performance of the issuers, can affect the market value of our short-term investments.

We may suffer losses as a result of foreign currency fluctuations and limitations on the ability to repatriate income or capital to the U.S.

We conduct a portion of our business in currencies other than the United States dollar, and our operations are subject to fluctuations in foreign currency exchange rates. We cannot assure you that we will be able to protect the Company against such fluctuations in the future. Historically, we have not conducted business in countries that limit repatriation of earnings. However, as we expand our international operations, we may begin operating in countries that have such limitations. Further, we cannot assure you that the countries in which we currently operate will not adopt policies limiting repatriation of earnings in the future.

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Our business involves numerous operating hazards that may not be covered by insurance. The occurrence of an event not fully covered by insurance could have a material adverse effect on our financial conditions and results of operations.

Our products are used in potentially hazardous drilling, completion and production applications that can cause personal injury, product liability and environmental claims. In addition, certain areas where our products are used, including in and near the U.S. Gulf of Mexico, are close to high population areas and subject to hurricanes and other extreme weather conditions on a relatively frequent basis. A catastrophic occurrence at a location where our equipment and/or services are used may expose us to substantial liability for personal injury, wrongful death, product liability or commercial claims. To the extent available, we maintain insurance coverage that we believe is customary in the industry. Effective October 1, 2010, we have a general liability insurance program with an aggregate coverage limit of $200 million for claims with respect to property damage, injury or death and pollution. However, our insurance policies may not cover fines, penalties or costs and expenses related to government-mandated clean up of pollution. In addition, our insurance does not provide coverage for all liabilities, and we cannot assure you that our insurance coverage will be adequate to cover claims that may arise or that we will be able to maintain adequate insurance at rates we consider reasonable. The occurrence of an event not fully covered by insurance could have a material adverse effect on our results of operations, financial position and cash flows.

We attempt to further limit our liability through contractual indemnification provisions with our customers. We generally seek to enter into contracts for the provision of our products and services that provide for (1) the responsibility of each party to the contract for personal injuries to, or the death of, its employees and damages to its property, (2) cross-indemnification with other contractors providing products and/or services to the other party to the contract with respect to personal injury, death and property damage and (3) the responsibility of each party to the contract for claims brought by third parties for personal injury, death, property loss or damage to the extent of each party’s negligence or fault. We may not be able to successfully obtain favorable contractual provisions, and a failure to do so may increase our risks and costs, which could materially impact our results of operations. In addition, we cannot assure you that any party that is contractually obligated to indemnify us will be financially able to do so.

We may lose money on fixed-price contracts.

A portion of our business consists of the designing, manufacturing and selling of our equipment for major projects pursuant to competitive bids, and is performed on a fixed-price basis. Under these contracts, we are typically responsible for all cost overruns, other than the amount of any cost overruns resulting from requested changes in order specifications. Our actual costs and any gross profit realized on these fixed-price contracts will often vary from the estimated amounts on which these contracts were originally based. This may occur for various reasons, including:

These variations and the risks inherent in our projects may result in reduced profitability or losses on projects. Depending on the size of a project, variations from estimated contract performance could have a material adverse impact on our operating results.

Our business could be adversely affected if we do not develop new products and secure and retain patents related to our products.

Technology is an important component of our business and growth strategy, and our success as a company depends to a significant extent on the development and implementation of new product designs and improvements. Whether we can continue to develop systems and services and related technologies to meet

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evolving industry requirements and, if so, at prices acceptable to our customers will be significant factors in determining our ability to compete in the industry in which we operate. Many of our competitors are large multinational companies that may have significantly greater financial resources than we have, and they may be able to devote greater resources to research and development of new systems, services and technologies than we are able to do.

Our ability to compete effectively will also depend on our ability to continue to obtain patents on our proprietary technology and products. Although we do not consider any single patent to be material to our business as a whole, the inability to protect our future innovations through patents could have a material adverse effect.

We may be required to recognize a charge against current earnings because of percentage-of-completion accounting.

Revenues and profits on long-term project contracts are recognized on a percentage-of-completion basis. We calculate the percent complete and apply the percentage to determine revenues earned and the appropriate portion of total estimated costs. Accordingly, purchase order price and cost estimates are reviewed periodically as the work progresses, and adjustments proportionate to the percentage complete are reflected in the period when such estimates are revised. To the extent that these adjustments result in a reduction or elimination of previously reported profits, we would have to recognize a charge against current earnings, which could be significant depending on the size of the project or the adjustment.

Loss of our key management or other personnel could adversely impact our business.

We depend on the services of our management team, which until recently was composed of J. Mike Walker and Larry E. Reimert. On December 31, 2010 Mr. Reimert stepped down as Co-Chief Executive Officer, but will retain his duties as Co-Chairman of the Board along with Mr. Walker and will act as an advisor on a part-time basis. The loss of either of these gentlemen could have a material adverse effect on our operations and financial condition. In addition, competition for skilled machinists, fabricators and technical personnel among companies that rely heavily on engineering and technology is intense, and the loss of qualified employees or an inability to attract, retain and motivate additional highly skilled employees required for the operation and expansion of our business could hinder our ability to conduct research activities successfully and develop and produce marketable products and services. 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 paid by us or both. If either of these events were to occur, in the near-term, the profits realized by us from work in progress would be reduced and, in the long-term, our production capacity and profitability could be diminished and our growth potential could be impaired.

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:

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, including those specifically directed to offshore operations. For example, the adoption of

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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. 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 foreign operations and sales, we are also subject to changes in foreign laws and regulations that may encourage or require hiring of local contractors or require foreign 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.

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

Our operations and the operations of our customers are also subject to federal, state, local and foreign laws and regulations relating to the protection of the environment. These environmental laws and regulations affect the products and services we design, market and sell, as well as the facilities where we manufacture our products. In addition, environmental laws and regulations could limit our customers’ exploration and production activities. We are required to invest financial and managerial resources to comply with environmental laws and regulations and anticipate that we will continue to be required to do so in the future. These laws and regulations change frequently, which makes it impossible for us to predict their cost or impact on our future operations. Legislation to regulate emissions of greenhouse gases has been introduced in Congress, and there has been a wide-ranging policy debate, both nationally and internationally, regarding the impact of these gases and possible means for their regulation. In addition, efforts have been made and continue to be made in the international community toward the adoption of international treaties or protocols that would address global climate change issues, such as the annual United Nations Climate Change Conferences. Also, the EPA has undertaken new efforts to collect information regarding greenhouse gas emissions and their effects. Following a finding by the EPA that certain greenhouse gases represent a danger to human health, the EPA proposed to expand its regulations relating to those emissions and has adopted rules imposing permitting and reporting obligations. The results of the permitting and reporting requirements could lead to further regulation of these greenhouse gases by the EPA. It is too early to determine whether, or in what form, further regulatory action regarding greenhouse gas emissions will be adopted or what specific impacts a new regulatory action might have on us or our customers. Generally, the anticipated regulatory actions do not appear to affect us in any material respect that is different, or to any materially greater or lesser extent, than other companies that are our competitors. However, our business and prospects could be adversely affected to the extent laws are enacted or modified or other governmental action is taken that prohibits or restricts our customers’ exploration and production activities or imposes environmental protection requirements that result in increased costs to us or our customers.

These laws may provide for “strict liability” for damages to natural resources or threats to public health and safety, rendering a party liable for environmental damage without regard to negligence or fault on the part of such party. Sanctions for noncompliance may include revocation of permits, corrective action orders, administrative or civil penalties, and criminal prosecution. Some environmental laws and regulations provide for joint and several strict liability for remediation of spills and releases of hazardous substances. In addition, we may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances, as well as damage to natural resources. These laws and regulations also may expose us to liability for the conduct of or conditions caused by others, or for our acts that were in compliance with all applicable laws and regulations at the time such acts were performed. Any of these laws and regulations could result in claims, fines or expenditures that could be material to results of operations, financial position and cash flows.

Certain of our principal stockholders have the ability to significantly influence our management and affairs and matters on which shareholders may vote.

Certain of our principal stockholders, J. Mike Walker and Larry E. Reimert and an entity Mr. Reimert controls, beneficially own approximately 14% of our common stock and are able to exert significant control

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over us. The collective ownership of Messrs. Reimert and Walker may have the effect of delaying or preventing a change of control. In addition, our principal stockholders are generally not prohibited from selling their interest in us to a third party.

Our shares that are eligible for future sale may have an adverse effect on the price of our common stock.

Future sales of substantial amounts of our common stock, or a perception that such sales could occur, could adversely affect the market price of our common stock and could impair our ability to raise capital through the sale of our equity securities. This risk is compounded by the fact that a substantial portion of our common stock is owned by Messrs. Reimert and Walker and an entity Mr. Reimert controls. Messrs. Reimert and Walker and an entity Mr. Reimert controls have piggyback and demand registration rights that provide for the registration of the resale of shares at our expense which will allow those shares to be sold in the public market generally without restriction.

The market price of our common stock is volatile.

The trading price of our common stock and the price at which we may sell common stock in the future are subject to large fluctuations in response to any of the following:

We do not anticipate paying dividends on our common stock in the near future.

We have not paid any dividends in the past and do not intend to pay cash dividends on our common stock in the foreseeable future. Our Board of Directors reviews this policy on a regular basis in light of our earnings, financial condition and market opportunities. We currently intend to retain any earnings for the future operation and development of our business.

None.

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Major Manufacturing Facilities

Dril-Quip has manufacturing facilities in Houston, Aberdeen, Singapore and Macae. The Houston facility at Eldridge produces in-house a majority of the Company’s forging and heat treatment requirements.

Sales, Service and Reconditioning Facilities

The Company also performs sales, service and reconditioning activities at its facilities in Houston, Aberdeen, Singapore and Macae.

On April 22, 2010, a deepwater U.S. Gulf of Mexico drilling rig known as the Deepwater Horizon that was operated by BP Exploration & Production, Inc. (“BP”) sank after an explosion and fire that began on April 20, 2010. The Company is a party to an ongoing contract with an affiliate of BP to supply wellhead systems in connection with BP’s U.S. Gulf of Mexico operations, and the Company’s wellhead and certain of its other equipment were in use on the Deepwater Horizon at the time of the incident.

The Company has been designated as a party-in-interest, received requests for certain information and provided testimony in connection with the joint investigation being conducted by the Departments of Homeland

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Security and Interior. The Company has also received requests to preserve information from the joint investigation team, the Department of Justice and the U.S. Chemical Investigation and Hazardous Incident Board.

The Company has been named, along with other unaffiliated defendants, in nine class action lawsuits and nine other lawsuits arising out of the Deepwater Horizon incident. These actions were filed against the Company between April 28, 2010 and January 17, 2011. As of February 22, 2011, sixteen of the lawsuits have been consolidated, along with hundreds of other lawsuits not directly involving the Company, in the multi-district proceeding In Re: Oil Spill by the Oil Rig “Deepwater Horizon” in the Gulf of Mexico, on April 20, 2010 (“MDL Proceeding”), and are pending in the federal court for the Eastern District of Louisiana. The remaining two cases are pending in the federal courts for the Southern District of Alabama and the Northern District of Alabama. The lawsuits generally allege, among other things, violation of state and federal environmental and other laws and regulations, negligence, gross negligence, strict liability and/or property damages and generally seek awards of unspecified economic, compensatory and punitive damages and/or declaratory relief.

The judge presiding over the MDL Proceeding is also presiding over a separate proceeding filed by affiliates of Transocean Ltd. (“Transocean”) under the Limitation of Liability Act (“Limitation Action”) in the federal court for the Eastern District of Louisiana. In the Limitation Action, Transocean seeks to limit its liability for claims arising out of the Deepwater Horizon incident to the value of its rig and freight. On February 18, 2011, Transocean impleaded the Company in the Limitation Action. The procedural effect of Transocean’s action is to make the Company a defendant in any of the actions consolidated in the MDL Proceeding where the plaintiffs file or have filed a claim in the Limitation Action. However, at this time there are no new allegations against the Company as a result of Transocean’s action, and the Company is entitled to assert all the defenses available to it in the actions to which it was already a party.

The Company intends to vigorously defend any litigation, fine and/or penalty relating to the Deepwater Horizon incident. Accordingly, no liability has been accrued in conjunction with these matters.

Additional lawsuits may be filed and additional investigations may be launched in the future. An adverse outcome with respect to any of these lawsuits or investigations, or any lawsuits or investigations that may arise in the future, could have a material adverse effect on the Company’s results of operations.

The Company is continuing to assess its rights to indemnification from BP’s affiliate and other parties for potential claims and expenses arising from the Deepwater Horizon incident under the Company’s existing contract with the affiliate of BP. The Company’s indemnity rights under the contract cover potential claims for personal injury, property damage and the control and removal of pollution or contamination, except for, among other things, claims brought by employees of the Company and claims brought by third parties to the extent the Company is at fault or as a result of a defect in the Company’s products. Under the contract, the Company has generally agreed to indemnify BP and its affiliates for claims for personal injury of the Company’s employees or subcontractors, for claims brought by third parties to the extent the Company is at fault, and for claims resulting from pollution or contamination as a result of a defect in the Company’s products. The Company’s indemnification obligation for pollution or contamination arising from a defect in the Company’s products is limited to $5 million under the contract. To the extent that BP’s other contractors performing work on the well agreed in their contracts with BP to indemnify the Company for claims of personal injury of such contractor’s employees or subcontractors as well as for claims of damages to their property, the Company has entered into a reciprocal agreement to indemnify those other contractors.

In August 2007, the Company’s Brazilian subsidiary was served with assessments collectively valued at approximately BRL23.3 million (approximately USD13.1 million as of March 2010) from the State of Rio de Janeiro, Brazil, to collect a state tax on the importation of goods. Since 2007, the Company had vigorously contested the assessments in the Brazilian administrative and judicial systems. While pending, the amount of interest, penalties and monetary restatement of fees on the tax assessments continued to accrue and totaled

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approximately BRL35.4 million (approximately USD19.9 million) as of March 2010. Under the terms of an amnesty law enacted by the State of Rio de Janeiro in January 2010, the Company settled the pending assessments in March 2010 in the amount of BRL21.7 million (approximately USD12.2 million as of March 2010), pursuant to which all penalties were waived and accrued interest was reduced by 45%. In December 2010, the Company’s Brazilian subsidiary was served with additional assessments collectively valued at approximately BRL7.2 million (approximately USD4.3 million as of December 2010) from the State of Rio de Janeiro, Brazil, to collect the remaining state tax on the importation of goods. The Company settled and paid the additional assessment with a 50% reduction in penalty for approximately BRL6.5 million (approximately USD3.9 million as of December 2010). Of the total amount paid of BRL28.2 million, BRL13.8million (approximately USD7.8 million as of December 2010) is reflected in “Special Items” on the Consolidated Statements of Income for the year ended December 31, 2010. The remaining BRL14.4 million (approximately USD8.6 million as of December 2010) is considered a prepaid tax that the Company’s Brazilian subsidiary will utilize to offset future liabilities for state taxes on the importation of goods over the next five years. Currently, the Company’s Brazilian subsidiary is in the process of having these tax credits certified by the State of Rio de Janeiro. If the certification of the tax credits is not made in a timely manner, the Company’s usage of these tax credits against future import tax liabilities could be impaired.

In December 2010 and January 2011, our Brazilian subsidiary was also served with assessments collectively valued at approximately BRL24.4 million (approximately USD14.6 million as of January 2011) from the State of Rio de Janiero, Brazil, to disallow the netting of certain importation taxes against exportation taxes of goods taken in prior years. The Company believes that its subsidiary should not be subject to the disallowances and is vigorously contesting the assessments in the Brazilian administrative systems. At this time, the ultimate disposition of this matter cannot be determined. Because it is not possible to reasonably estimate the amount of loss or the range of possible losses that might result from an adverse judgment or settlement of these assessments, no liability has been accrued in conjunction with this matter. The Company does not expect the liability, if any, resulting from these assessments to have a material adverse effect on its operations, financial position or cash flows.

For a further description of the Company’s legal proceedings, see “Commitments and Contingencies,” Note 9 of Notes to Consolidated Financial Statements. The Company also is involved in a number of legal actions arising in the ordinary course of business. Although no assurance can be given with respect to the ultimate outcome of such legal actions, in the opinion of management, the ultimate liability with respect thereto will not have a material adverse effect on the Company’s financial position.

Pursuant to Instruction 3 to Item 401(b) of Regulation S-K and General Instruction G(3) to Form 10-K, the following information is included in Part I of this Form 10-K:

The following table sets forth the names, ages (as of February 25, 2011) and positions of the Company’s executive officers:

J. Mike Walker is Co-Chairman of the Board and Chief Executive Officer. Mr. Walker served as the Co-Chief Executive Officer with responsibility for manufacturing, purchasing and facilities from 1981 until

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September 2009, and the Co-Chief Executive Officer with responsibility for manufacturing, purchasing and facilities, service and administration from September 2009 until December 2010. Mr., Walker became the Company’s Chief Executive Office on January 1, 2011. He has been a member of the Board of Directors and a Co-Chairman since the Company’s inception in 1981. Prior to 1981, he served as the Director of Engineering, Manager of Engineering and Manager of Research and Development with Vetco Offshore, Inc. Mr. Walker holds a BSME degree from Texas A&M University, an MSME degree from the University of Texas at Austin and a Ph.D. in mechanical engineering from Texas A&M University.

Jerry M. Brooks is the Company’s Vice-President—Finance and Chief Financial Officer and Secretary. He has been Vice President since 2007, Chief Financial Officer since 1999 and Secretary since 2009. From 1992 until March 1999, Mr. Brooks served as Chief Accounting Officer. From 1980 to 1991, he held various positions with Chiles Offshore Corporation, most recently as Chief Financial Officer, Secretary and Treasurer. Mr. Brooks holds a BBA in Accounting and a MBA in Finance from the University of Texas at Austin.

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PART II

The Company’s Common Stock is publicly traded on the New York Stock Exchange under the symbol DRQ. The following table sets forth the quarterly high and low sales prices of the Common Stock as reported on the New York Stock Exchange for the indicated quarters of fiscal 2010 and 2009.

There were approximately 33 stockholders of record of the Company’s Common Stock as of December 31, 2010. This number does not include the number of security holders for whom shares are held in a “nominee” or “street” name.

The Company has not paid any dividends in the past. The Company currently intends to retain any earnings for the future operation and development of its business and does not currently anticipate paying any dividends in the foreseeable future. The Board of Directors will review this policy on a regular basis in light of the Company’s earnings, financial condition and market opportunities.

Information concerning securities authorized for issuance under equity compensation plans is included in Note 12 of Notes to Consolidated Financial Statements.

Repurchases of Equity Securities

In May 2008, the Company announced that its Board of Directors had authorized a share repurchase program under which the Company could repurchase up to $100 million of its common stock. At the end of the third quarter of 2008, the Company had repurchased 1,799,928 shares at an average price of $55.58 per share (including commissions) for a total of approximately $100 million. All repurchased shares were retired in 2008.

There were no repurchases of the Company’s equity securities during 2010 or 2009.

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The information set forth below should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the Consolidated Financial Statements and Notes thereto included elsewhere in this report on Form 10-K.

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The Company adopted Financial Accounting Standards Board (“FASB”) Accounting Standards Codification^TM (“ASC”) Topic 718 effective January 1, 2006. During the years ended December 31, 2010, 2009 and 2008, stock-based compensation expense on a pre-tax basis totaled $5.0 million, $4.0 million and $3.2 million, respectively. The 2010 amount excludes $2.0 million for the acceleration of vesting of stock options for Mr. Reimert, the Company’s former Co-CEO. Mr. Reimert’s employment as Co-Chief Executive Officer of the Company terminated effective December 31, 2010 under circumstances entitling him to severance under his employment agreement with the Company. Stock option expense in 2009 excludes $1.3 million, for the accelerated vesting of stock options for Gary D. Smith, former Co-Chief Executive Officer of the Company, due to his death in 2009. The 2010 and 2009 amounts for the acceleration of vesting of stock options amounts were reclassified to Special items in the Consolidated Statements of Income. No stock-based compensation expense was capitalized during these years.

The following is management’s discussion and analysis of certain significant factors that have affected certain aspects of the Company’s financial position, results of operations and cash flows during the periods included in the accompanying consolidated financial statements. This discussion should be read in conjunction with the Company’s consolidated financial statements and notes thereto presented elsewhere in this Report.

Overview

Dril-Quip designs, manufactures, sells and services highly engineered offshore drilling and production equipment that is well suited for use in deepwater, harsh environment and severe service applications. The Company designs and manufactures subsea equipment, surface equipment and offshore rig equipment for use by major integrated, large independent and foreign national oil and gas companies in offshore areas throughout the world. The Company’s principal products consist of subsea and surface wellheads, subsea and surface production trees, subsea control systems and manifolds, mudline hanger systems, specialty connectors and associated pipe, drilling and production riser systems, liner hangers, wellhead connectors and diverters. Dril-Quip also provides technical advisory services on an as-requested basis during installation of its products, as well as rework and reconditioning services for customer-owned Dril-Quip products and rental of running tools for use in connection with the installation and retrieval of the Company’s products.

Oil and Gas Prices

Both the market for offshore drilling and production equipment and services and the Company’s business are substantially dependent on the condition of the oil and gas industry and, in particular, the willingness of oil and gas companies to make capital expenditures on exploration, drilling and production operations offshore. Oil and gas prices and the level of offshore drilling and production activity have historically been characterized by significant volatility. See “Item 1A. Risk Factors—A material or extended decline in expenditures by the oil and gas industry could significantly reduce our revenue and income.”

According to the Energy Information Administration (“EIA”) of the U.S. Department of Energy, average crude oil (West Texas Intermediate Cushing) and natural gas (Henry Hub) closing prices are listed below for periods covered by this report:

In mid July 2008, crude oil prices spiked to $145.16 per barrel and ended the year in 2008 at $44.60 per barrel. During 2009, the average West Texas Intermediate crude oil price was $62.18 per barrel with a high of $81.37 per barrel and a low of $33.98 per barrel. Crude oil ended 2009 at $79.36 per barrel. In 2010, crude oil

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prices began the year at $81.52 per barrel and reached a peak in December at $91.48 per barrel. Crude oil prices averaged $79.48 per barrel for 2010.

According to the January 11, 2011 release of the Short-Term Energy Outlook published by the EIA, West Texas Intermediate crude oil prices are projected to average $93.42 per barrel in 2011 and $97.50 in 2012. These projections are based upon the assumption that the U.S. real gross domestic product (GDP) grows by 2.2% in 2011 and 2.9% in 2012.

In its January 11, 2011 report, the EIA expects Henry Hub natural gas prices to average $4.14 per Mcf in 2011 and $4.64 per Mcf in 2012. Henry Hub natural gas were $4.54 per Mcf at the end of December 2010.

In its January 18, 2011 Oil Market Report, the International Energy Agency projected global oil demand to be 89.1 million barrels per day in 2011 compared to 87.7 million barrels per day in 2010.

Rig Count

Detailed below is the average contracted offshore rig count for the Company’s geographic regions for the years ended December 31, 2010, 2009 and 2008. The rig count data includes floating rigs (semi-submersibles and drillships) and jack-ups. The Company has included only these types of rigs as they are the primary end users of the Company’s products.

The table represents rigs under contract and includes rigs currently drilling as well as rigs committed, but not yet drilling. According to ODS-Petrodata RigBase, as of December 31, 2010, there were 55 rigs under contract (29 jack-ups and 26 floating rigs) in the U.S. Gulf of Mexico, 35 of which were actively drilling (28 jack-ups and 7 floating rigs). In 2009 there were 59 rigs under contract in the U.S. Gulf of Mexico (27 jack-ups and 32 floating rigs), of which 58 were actively drilling, and in 2008 there were 81 rigs under contract (53 jack-ups and 28 floating rigs), all of which were actively drilling.

The Company believes that the number of rigs (semi-submersibles, jack-ups and drillships) under construction impacts its revenues because in certain cases, its customers order some of the Company’s products during the construction of such rigs. As a result, an increase in rig construction activity tends to favorably impact the Company’s backlog, while a decrease in rig construction activity tends to negatively impact the Company’s backlog. According to ODS-Petrodata, at the end of 2010, 2009 and 2008, there were 117, 130 and 172 rigs, respectively, under construction and the expected delivery dates for the rigs under construction on December 31, 2010 are as follows:

Regulation

The demand for the Company’s products and services is also affected by laws and regulations relating to the oil and gas industry in general, including those specifically directed to offshore operations. The adoption of new laws and regulations, or changes to existing laws or regulations, that curtail exploration and development drilling

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for oil and gas for economic or other policy reasons could adversely affect the Company’s operations by limiting demand for its products. For a description of certain actions taken by the U.S. government related to the Deepwater Horizon incident, see “Commitments and Contingencies” in Note 9 of Notes to Consolidated Financial Statements.

Business Environment

Oil and gas prices and the level of offshore drilling and production activity have been characterized by significant volatility in recent years. Worldwide military, political, economic and other events have contributed to oil and natural gas price volatility and are likely to continue to do so in the future. Oil and gas prices fell from previously historic levels beginning in mid-2008 and continued into 2009, and began to stabilize somewhat in the latter half of 2009. For 2010, crude oil prices generally were over $70 per barrel on a daily basis, averaged $79.48 per barrel and ended the year at $91.38 per barrel. The Company expects continued volatility in both crude oil and natural gas prices, as well as in the level of drilling and production related activities. The volatility in prices appears to have impacted land drilling activity more so than offshore drilling, particularly in deeper offshore waters, where Dril-Quip’s products are more often utilized. Even during periods of high prices for oil and natural gas, companies exploring for oil and gas may cancel or curtail programs, or reduce their levels of capital expenditures for exploration and production for a variety of reasons. In addition, a significant and prolonged decline in hydrocarbon prices or continued delays in the resumption of drilling in the U.S. Gulf of Mexico would likely have a material adverse effect on the Company’s results of operations.

The Company operates its business and markets its products and services in most of the significant oil and gas producing areas in the world and is, therefore, subject to the risks customarily attendant to international operations and investments in foreign countries. These risks include nationalization, expropriation, war, acts of terrorism and civil disturbance, restrictive action by local governments, limitation on repatriation of earnings, change in foreign tax laws and change in currency exchange rates, any of which could have an adverse effect on either the Company’s ability to manufacture its products in its facilities abroad or the demand in certain regions for the Company’s products or both. To date, the Company has not experienced any significant problems in foreign countries arising from local government actions or political instability, but there is no assurance that such problems will not arise in the future. Interruption of the Company’s international operations could have a material adverse effect on its overall operations. See “Item 1A. Risk Factors—Our international operations expose us to instability and changes in economic and political conditions and other risks inherent to international business, which could have a material adverse effect on our operations or financial condition.”

Revenues. Dril-Quip’s revenues are generated from two sources: products and services. Product revenues are derived from the sale of offshore drilling and production equipment. Service revenues are earned when the Company provides technical advisory assistance for installation of the Company’s products, reconditioning services and rental of running tools for installation and retrieval of the Company’s products. In 2010, the Company derived 86% of its revenues from the sale of its products and 14% of its revenues from services compared to 84% and 16% in both 2009 and 2008. Service revenues generally correlate to revenues from product sales because increased product sales typically generate increased demand for technical advisory services during installation and rental of running tools. The Company has substantial international operations, with approximately 61%, 66% and 69% of its revenues derived from foreign sales in 2010, 2009 and 2008, respectively. Substantially all of the Company’s domestic revenue relates to operations in the U. S. Gulf of Mexico. Domestic revenue approximated 39%, 34% and 31%, respectively, of the Company’s total revenues for 2010, 2009 and 2008.

Product contracts are negotiated and sold separately from service contracts. In addition, service contracts are not included in the product contracts or related sales orders and are not offered to the customer as a condition of the sale of the Company’s products. The demand for products and services is generally based on world-wide economic conditions in the offshore oil and gas industry, and is not based on a specific relationship between the two types of contracts. Substantially all of the Company’s sales are made on a purchase order basis. Purchase

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orders are subject to change and/or termination at the option of the customer. In case of a change or termination, the customer is required to pay the Company for work performed and other costs necessarily incurred as a result of the change or termination.

Generally, the Company attempts to raise its prices as its costs increase. However, the actual pricing of the Company’s products and services is impacted by a number of factors, including competitive pricing pressure, the level of utilized capacity in the oil service sector, maintenance of market share, the introduction of new products and general market conditions.

The Company accounts for larger and more complex projects that have relatively longer manufacturing time frames on a percentage-of-completion basis. During 2010 and 2009 there were 19 and 17 projects, respectively, that were accounted for using the percentage-of-completion method, which represented approximately 19% and 13% of the Company’s total revenues and 23% and 16% of the Company’s product revenues, respectively. During 2008, there were 23 projects representing 25% of the Company’s total revenues and 30% of the Company’s product revenues. This percentage may fluctuate in the future. Revenues accounted for in this manner are generally recognized based upon a calculation of the percentage complete, which is used to determine the revenue earned and the appropriate portion of total estimated cost of sales. Accordingly, price and cost estimates are reviewed periodically as the work progresses, and adjustments proportionate to the percent complete are reflected in the period when such estimates are revised. Losses, if any, are recognized when they become known. Amounts received from customers in excess of revenues recognized are classified as a current liability. See “Item 1A. Risk Factors—We may be required to recognize a charge against current earnings because of percentage-of-completion accounting.”

The following table sets forth, for the periods indicated, a breakdown of the Company’s U.S. Gulf of Mexico products and services revenues:

At this time, the Company is unable to quantify the extent of the impact that the 2010 drilling moratorium in the U.S. Gulf of Mexico and related permitting delays will have on its future revenues. The Company believes that the effects of the drilling moratorium and permitting delays will have little or no impact on revenues related to offshore rig equipment, but could have a significant adverse impact on revenues related to subsea equipment, and, to a lesser extent, surface equipment revenues, in 2011. In addition, service revenues in the Gulf of Mexico (which were $26.2 million, or approximately 4.6% of the Company’s total revenues during 2010) could be substantially negatively impacted by permitting delays related to the drilling moratorium. The Company’s service revenues in the U.S. Gulf of Mexico declined significantly each quarter since the first quarter of 2010, generally as a result of the drilling moratorium and related permitting delays. Accordingly, the Company will continue to monitor the effects of the drilling moratorium and permitting delays on its ongoing business operations.

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Cost of Sales. The principal elements of cost of sales are labor, raw materials and manufacturing overhead. Cost of sales as a percentage of revenues is influenced by the product mix sold in any particular period and market conditions. The Company’s costs related to its foreign operations do not significantly differ from its domestic costs.

Selling, General and Administrative Expenses. Selling, general and administrative expenses include the costs associated with sales and marketing, general corporate overhead, compensation expense, stock option expense, legal expenses, foreign currency transaction gains and losses and other related administrative functions.

Engineering and Product Development Expenses. Engineering and product development expenses consist of new product development and testing, as well as application engineering related to customized products.

Income Tax Provision. The Company’s effective income tax rate has historically been lower than the statutory rate primarily due to foreign income tax rate differentials, research and development credits and deductions related to domestic production activities.

Results of Operations

The following table sets forth, for the periods indicated, certain consolidated statements of income data expressed as a percentage of revenues:

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The following table sets forth, for the periods indicated, a breakdown of our products and service revenues:

Year ended December 31, 2010 Compared to Year Ended December 31, 2009

Revenues. Revenues increased by $26.1 million, or approximately 4.8%, to $566.3 million in 2010 from $540.2 million in 2009. Product revenues increased by approximately $30.1 million for the year ended December 31, 2010 compared to the same period in 2009 as a result of increased revenues of $8.5 million in subsea equipment and $26.3 million in offshore rig equipment, partially offset by a $4.7 million decrease in surface equipment. Product revenues increased in the Western Hemisphere by $53.6 million and $11.9 million in Asia-Pacific, partially offset by a decrease in the Eastern Hemisphere of $35.4 million. Service revenues decreased by approximately $4.0 million resulting from decreased service revenues in the Eastern Hemisphere of $5.6 million and $0.5 million in the Western Hemisphere, partially offset by a $2.1 million increase in Asia Pacific. The majority of the decreases in service revenues related to decreases in the rental of running and installation tools, slightly offset by increases in technical advisory services and reconditioning services.

Cost of Sales. Cost of sales increased by $12.3 million, or approximately 4.0%, to $322.6 million for 2010 from $310.3 million for the same period in 2009. As a percentage of revenues, cost of sales were approximately 57.0% in 2010 and 57.4% in 2009. Cost of sales as a percentage of revenue remained relatively consistent between 2010 and 2009.

Selling, General and Administrative Expenses. For 2010, selling, general and administrative expenses increased by approximately $5.6 million, or 10.1%, to $61.1 million from $55.5 million in 2009. The increase in selling, general and administrative expenses was primarily due to the effect of a reduction in foreign currency transaction gains and increased stock option expenses. The Company experienced approximately $1.4 million in pre-tax foreign currency transaction gains during 2010 compared to approximately $4.6 million in pre-tax foreign currency transaction gains during 2009. The gain in 2010 was basically due to the weakening U.S. dollar compared to the Brazilian real, slightly offset by the strengthening of the U.S. dollar compared to the British pound sterling. The gain in 2009 was primarily due to the weakening of the U.S. dollar compared to the British pound sterling and the Brazilian real. Stock option expense for 2010 totaled $5.0 million compared to $4.0 million in 2009. The stock option expense in 2010 excludes the vesting acceleration of $2.0 million due to the termination of Mr. Reimert’s employment with the Company and $1.3 million in 2009 due to the death of Mr. Smith, both of whom were Co-CEO’s of the Company. These expenses are included in Special Items below. Selling, general and administrative expenses as a percentage of revenues were 10.7% in 2010 and 10.3% in 2009.

Engineering and Product Development Expenses. For 2010, engineering and product development expenses increased by approximately $2.0 million, or 7.4%, to approximately $29.2 million from $27.2 million in 2009. The increase was primarily due to additional personnel. Engineering and product development expenses as a percentage of revenues increased to 5.2% in 2010 from 5.0% in 2009.

Special Items. In August 2007, the Company’s Brazilian subsidiary was served with assessments collectively valued at approximately BRL23.3 million (approximately USD13.1 million as of March 2010) from

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the State of Rio de Janeiro, Brazil, to collect a state tax on the importation of goods. The amount of interest, penalties and monetary restatement of fees on the tax assessments totaled approximately BRL35.4 million (approximately USD19.9 million as of March 2010). Under the terms of an amnesty law enacted by the State of Rio de Janeiro in January 2010, the Company settled the pending assessments in March 2010 in the amount of BRL21.7 million (approximately USD12.2 million as of March 2010), pursuant to which all penalties were waived and accrued interest was reduced by 45%.

In December 2010, the Company’s Brazilian subsidiary was served with additional assessments collectively valued at approximately BRL7.2 million (approximately USD4.3 million as of December 2010) from the State of Rio de Janeiro, Brazil, to collect state taxes on the importation of goods. The Company settled and paid the additional assessment for approximately BRL6.5 million (approximately USD3.9 million as of December 2010).

Of the total amount paid of BRL28.2 million, BRL13.8. million (approximately USD7.8 million as of December 2010) is reflected in “Special items” on the Consolidated Statements of Income for the year ended December 31, 2010. The remaining BRL14.4 million (approximately USD8.6 million as of December 2010) is considered a prepaid tax that the Company’s Brazilian subsidiary will utilize to offset future liabilities for state taxes on the importation of goods over the next five years. Currently, the Company’s Brazilian subsidiary is in the process of having these tax credits certified by the State of Rio de Janeiro. If the certification of the tax credits is not made in a timely manner, the Company’s usage of these tax credits against future import tax liabilities could be impaired.

In December 2010, Larry E. Reimert’s employment as Co-Chief Executive Officer of the Company was terminated effective December 31, 2010 under circumstances entitling him to severance under his employment agreement with the Company. Under the terms of Mr. Reimert’s employment agreement, the Company is obligated to pay Mr. Reimert’s base salary and his annual bonus through the remaining employment period (October 27, 2014). In addition, stock options owned by Mr. Reimert that were outstanding at the date of the termination of his employment were immediately vested under the terms of the contract. Accordingly, the Company recognized a pre-tax expense of $6.9 million during the fourth quarter of 2010. The amount related to base salary and bonus, including payroll taxes, which totaled $4.9 million, is reflected in the accounts payable balance on the Consolidated Balance Sheets as of December 31, 2010. The acceleration of the vesting increased pre-tax non-cash expenses by $2.0 million.

In September 2009, Gary D. Smith, one of the Company’s Co-Chief Executive Officers, unexpectedly passed away. Under the terms of Mr. Smith’s employment contract, the Company was obligated to pay Mr. Smith’s base salary, including accrued vacation, and his annual bonus through the remaining employment period (October 27, 2012). In addition, stock options owned by Mr. Smith that were outstanding at the date of his death were immediately vested under the terms of the contract. Accordingly, the Company recognized a pre-tax expense of $5.2 million during the third quarter of 2009. The amount related to base salary, vacation and bonus, including payroll taxes, which totaled $4.3 million, of which $434,000 had been previously accrued. The acceleration of the vesting increased pre-tax non-cash expenses by $1.3 million.

Interest Income. Interest income for 2010 was approximately $321,500 as compared to $507,000 in 2009. This decrease was due to reduced interest earned on short-term investments from lower interest rates. The Company keeps the majority of its short-term investments in funds that invest in U.S. Treasury obligations, which normally earn lower interest rates than money market funds.

Interest expense. Interest expense for 2010 was approximately $131,000 compared to $156,000 in 2009.

Income tax provision. Income tax expense for 2010 was $36.7 million on income before taxes of $138.9 million, resulting in an effective income tax rate of approximately 26.4%. Income tax expense in 2009 was $37.2 million on income before taxes of $142.4 million, resulting in an effective tax rate of approximately 26.2%. The increase in the effective income tax rate reflects the difference in income before income taxes among the Company’s three geographic areas, which have different income tax rates.

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Net Income. Net income was approximately $102.2 million in 2010 and $105.1 million in 2009, for the reasons set forth above.

Year ended December 31, 2009 Compared to Year Ended December 31, 2008

Revenues decreased by $2.6 million, or approximately 0.5%, to $540.2 million in 2009 from $542.8 million in 2008, primarily due to a decrease in service revenues of $5.3 million in 2009 compared to 2008. Product revenues increased by approximately $2.7 million for the year ended December 31, 2009 compared to the same period in 2008 as a result of increased revenues of $39.1 million in subsea equipment and $600,000 in surface equipment, partially offset by a $37.0 million decrease in offshore rig equipment. The decrease in offshore rig equipment was primarily due to the decrease in the number of long-term projects. During 2009, there were 17 projects, compared to 23 projects during 2008. The majority of the projects in 2009 and 2008 related to offshore rig equipment. Product revenues increased in the Eastern Hemisphere by $12.0 million, partially offset by decreases in the Western Hemisphere of $4.7 million and $4.6 million in Asia-Pacific. Service revenues decreased by approximately $5.3 million resulting from decreased service revenues in the Western Hemisphere of $6.0 million and $0.6 million in Asia-Pacific, partially offset by a $1.3 million increase in the Eastern Hemisphere. The majority of the decreases in service revenues related to decreases in the rental of running and installation tools and reconditioning services.

Cost of Sales. Cost of sales decreased by $2.0 million, or approximately 0.6%, to $310.3 million for 2009 from $312.3 million for the same period in 2008. As a percentage of revenues, cost of sales were approximately 57.4% in 2009 and 57.5% in 2008. Cost of sales as a percentage of revenue remained relatively consistent between 2009 and 2008.

Selling, General and Administrative Expenses. For 2009, selling, general and administrative expenses decreased by approximately $6.9 million, or 11.1%, to $55.5 million from $62.4 million in 2008. The decrease in selling, general and administrative expenses was primarily due to the effect of foreign currency transaction gains, partially offset by increased stock option expenses. The Company experienced approximately $4.6 million in pre-tax foreign currency transaction gains during 2009 versus approximately $2.1 million in pre-tax foreign currency transaction losses during 2009. The gain in 2009 is primarily due to the weakening of the U.S. dollar compared to the British pound sterling and the Brazilian real. The loss in 2008 is primarily due to the increasing strength of the U.S. dollar in the later part of 2008 as compared to the Brazilian real. Stock option expense for 2009 totaled $4.0 million compared to $3.2 million in 2008. The stock option expense for 2009 excludes $1.3 million for the accelerated vesting of Mr. Smith’s remaining options upon his death as discussed in Special Items below. Selling, general and administrative expenses as a percentage of revenues were 10.3% in 2009 and 11.5% in 2008.

Engineering and Product Development Expenses. For 2009, engineering and product development expenses increased by approximately $800,000, or 3.0%, to approximately $27.2 million from $26.4 million in 2008. The increase was primarily due to additional personnel. Engineering and product development expenses as a percentage of revenues increased to 5.0% in 2009 from 4.9% in 2008.

Special Items. In September 2009, Gary D. Smith, one of the Company’s Co-Chief Executive Officers, unexpectedly passed away. Under the terms of Mr. Smith’s employment contract, the Company was obligated to pay Mr. Smith’s base salary, including accrued vacation, and his annual bonus through the remaining employment period (October 27, 2012). In addition, stock options owned by Mr. Smith that were outstanding at the date of his death were immediately vested under the terms of the contract. Accordingly, the Company recognized a pre-tax expense of $5.2 million during the third quarter of 2009. The amount related to base salary, vacation and bonus, including related payroll taxes, which totaled $4.3 million, of which $434,000 had been previously accrued. The acceleration of the vesting increased non-cash expenses by $1.3 million.

Interest Income. Interest income for 2009 was approximately $507,000 as compared to $3.5 million in 2008. This decrease was due to reduced interest earned on short-term investments from lower interest rates and reduced balances in short-term investments. Due to the global financial crisis, the Company has transferred the majority

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of its short-term investments to funds which invest in U.S. Treasury obligations, which normally earn lower interest rates than money market funds.

Interest expense. Interest expense for 2009 was approximately $156,000 compared to $182,000 in 2008.

Income tax provision. Income tax expense for 2009 was $37.2 million on income before taxes of $142.4 million, resulting in an effective income tax rate of approximately 26.2%. Income tax expense in 2008 was $39.4 million on income before taxes of $145.0 million, resulting in an effective tax rate of approximately 27.2%. The decrease in the effective income tax rate reflects the difference in income before income taxes among the Company’s three geographic areas, which have different income tax rates.

Net Income. Net income was approximately $105.1 million in 2009 and $105.6 million in 2008, for the reasons set forth above.

Liquidity and Capital Resources

Cash flows provided by (used in) operations by type of activity were as follows:

Statements of cash flows for entities with international operations that are local currency functional exclude the effects of the changes in foreign currency exchange rates that occur during any given year, as these are noncash changes. As a result, changes reflected in certain accounts on the Consolidated Statements of Cash Flows, may not reflect the changes in corresponding accounts on the Consolidated Balance Sheets.

The primary liquidity needs of the Company are (i) to fund capital expenditures to improve and expand facilities and manufacture additional running tools and (ii) to fund working capital. Recently, the Company’s principal sources of funds have been cash flows from operations.

During 2010, the Company generated $107.2 million of cash from operations as compared to $136.4 million for the same period in 2009. The primary reason for the decrease was the changes in operating assets and liabilities during 2010 as compared to the same period in 2009. Cash totaling approximately $20.7 million was utilized during 2010 from changes in operating assets and liabilities, compared to a $13.7 million that was provided during the same period in 2009. The decrease in operating assets and liabilities during 2010 primarily reflected an increase of $28.8 million in trade receivables, resulting primarily from an increase in 2010 revenues. Prepaid and other assets increased by $6.5 million in 2010 primarily due to the settlement between the Company and the State of Rio de Janeiro, Brazil for prepaid state taxes on the importation of future goods. Inventory decreased by $7.3 million primarily due to reductions in work in progress. Trade accounts payable and accrued expenses increased by $10.0 million primarily due to increases in accounts payable for the contractual obligation for Mr. Reimert’s termination of employment ($4.9 million) and ongoing facilities construction.

Capital expenditures by the Company were $74.8 million, $44.7 million and $50.1 million in 2010, 2009 and 2008, respectively. Capital expenditures in 2010, 2009 and 2008 included expanding manufacturing facilities

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in the Asia Pacific, Eastern and Western Hemispheres and increased expenditures on machinery and equipment and running tools due to expanded operations. The capital expenditures for 2010 were primarily $49.1 million for facilities, $10.7 million for machinery and equipment, $6.9 million for running tools, $4.7 million for land and improvements and other expenditures of $3.4 million. Principal payments on long-term debt were approximately $700,000, $700,000 and $800,000 in 2010, 2009 and 2008, respectively.

In October 2009, Dril-Quip Asia Pacific Pte Ltd, a wholly owned subsidiary of Dril-Quip, Inc. entered into an agreement for the construction of a new manufacturing facility in Singapore valued at SGD46.5 million (USD36.3 million as of December 31, 2010).

In May 2008 the Company announced that its Board of Directors had authorized a share repurchase program under which the Company could repurchase up to $100 million of its common stock. At the end of the third quarter of 2008, the Company had repurchased 1,799,928 shares at an average price of $55.58 per share (including commissions) for a total of approximately $100 million. All repurchased shares were retired and the share repurchase program as authorized by the Board of Directors was completed as of December 31, 2008.

The following table presents long-term contractual obligations of the Company and the related payments, excluding the effects of interest due, in total and by year as of December 31, 2010:

Dril-Quip (Europe) Limited has a term credit agreement with the Bank of Scotland dated March 21, 2001 in the original amount of U.K. Pounds Sterling 4.0 million (approximately USD6.2 million as of December 31, 2010). Borrowing under this facility bears interest at the Bank of Scotland base rate, which was 0.50% at December 31, 2010, plus 1%, and is repayable in 120 equal monthly installments, plus interest. Substantially all of this facility was used to finance capital expenditures in Norway. The outstanding balance of this facility at December 31, 2010 and 2009 was approximately USD207,000 and USD865,000, respectively. The facility is secured by land and buildings in Aberdeen, Scotland and contains no restrictive financial covenants.

In addition to the above, the Company has issued purchase orders in the ordinary course of business for the purchase of goods and services. These purchase orders are enforceable and legally binding. However, none of the Company’s purchase obligations call for deliveries of goods or services for time periods in excess of one year.

The Company believes that cash generated from operations plus cash on hand will be sufficient to fund operations, working capital needs and anticipated capital expenditure requirements in 2011. However, any significant future declines in hydrocarbon prices could have a material adverse effect on the Company’s liquidity. Should market conditions result in unexpected cash requirements, the Company believes that additional borrowing from commercial lending institutions would be available and more than adequate to meet such requirements.

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Backlog

Backlog consists of firm customer orders for which a purchase order or signed contract has been received, satisfactory credit or financing arrangements exist and delivery is scheduled. The Company’s revenues for a specific period have not been directly related to its backlog as stated at a particular point in time. The Company’s backlog was approximately $627 million, $563 million and $603 million at December 31, 2010, 2009 and 2008, respectively. This represents an increase of approximately $64 million, or 11%, from 2009 to 2010 and an increase of approximately $24 million, or 4%, from 2008 to 2010. The Company expects to fill approximately 68% of the December 31, 2010 backlog by December 31, 2011. The remaining backlog at December 31, 2010 consists of longer-term projects which are being designed and manufactured to customer specifications requiring longer lead times. The backlog amount at December 31, 2009 and 2008 excludes $27 million related to the MPF contract which was resolved in 2010 as described in Note 9 of Notes to Consolidated Financial Statements.

The Company can give no assurance that its backlog will remain at current levels. Sales of the Company’s 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 the Company’s future backlog. All of the Company’s projects currently included in its 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 the Company for work performed and other costs necessarily incurred as a result of the change or termination. In the past, terminations and cancellations have been immaterial to the Company’s overall operating results.

Geographic Segments

The Company’s operations are organized into three geographic segments—Western Hemisphere (including North and South America; headquartered in Houston, Texas), Eastern Hemisphere (including Europe and Africa; headquartered in Aberdeen, Scotland) and Asia-Pacific (including the Pacific Rim, Southeast Asia, Australia, India and the Middle East; headquartered in Singapore). Each of these segments sells similar products and services and the Company has major manufacturing facilities in all three of its headquarter locations, as well as Macae, Brazil.

Revenues for each of these segments are dependent upon the ultimate sale of products and services to the Company’s customers. For information on revenues by geographic segment, see Note 11 of Notes to Consolidated Financial Statements. Revenues of the Western Hemisphere are also influenced by its sale of products to the Eastern Hemisphere and Asia-Pacific segments. Accordingly, the operating incomes of each area are closely tied to third-party sales, and the operating income of the Western Hemisphere is also dependent upon its level of intercompany sales.

Currency Risk

Through its subsidiaries, the Company conducts a portion of business in currencies other than the United States dollar, principally the British pound sterling (“GBP”) in the Eastern Hemisphere and the Brazilian real (“BRL”) in Brazil. The Company generally attempts to minimize its currency exchange risk by seeking international contracts payable in local currency in amounts equal to the Company’s estimated operating costs payable in local currency and in U.S. dollars for the balance of the contract. Because of this strategy, the Company has not experienced significant transaction gains or losses associated with changes in currency exchange rates and does not anticipate such exposure to be material in the future. In 2010, 2009 and 2008, the Company had, net of income taxes, transaction gains of $1.0 million and $3.4 million and transaction losses of $1.5 million, respectively. The gain in 2010 was primarily due to the weakening of the U.S. dollar compared to the Brazilian real, partially offset by the strengthening of the U.S. dollar compared to the British pound sterling. The gain in 2009 was primarily due to the weakening of the U.S. dollar compared to the British pound sterling and the Brazilian real. The loss in 2008 was primarily due to strengthening of the U.S. dollar compared to the British pound sterling and the Brazilian real.

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There is no assurance that the Company will be able to protect itself against such fluctuations in the future. Historically, the Company has not conducted business in countries that limit repatriation of earnings. However, as the Company expands its international operations, it may begin operating in countries that have such limitations. Further, there can be no assurance that the countries in which the Company currently operates will not adopt policies limiting repatriation of earnings in the future. The Company also has significant investments in countries other than the United States, principally its manufacturing operations in Aberdeen, Scotland, Singapore, Brazil and, to a lesser extent, Norway. The functional currency of these foreign operations is the local currency except for Singapore, where the U.S. dollar is used. Financial statement assets and liabilities are translated at the end of the period exchange rates. Resulting translation adjustments are reflected as a separate component of stockholders’ equity and have no current effect on earnings or cash flow.

Critical Accounting Policies

The Company’s discussion and analysis of its financial condition and results of operations are based on the Company’s consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States of America under guidance from the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”). The preparation of the consolidated financial statements requires the Company to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. There can be no assurance that actual results will not differ from those estimates. The Company believes the following accounting policies affect its more significant judgments and estimates used in preparation of its consolidated financial statements.

Revenue Recognition.

Product Revenue

The Company earns product revenues from two sources:

Revenues recognized under the percentage-of-completion method

The Company uses the percentage-of-completion method on long-term project contracts pursuant to ASC Topic 605-35, which provides guidance on accounting for the performance of contracts. Long-term project contracts have the following characteristics:

For each project, the Company prepares a detailed analysis of estimated costs, profit margin, completion date and risk factors which include availability of material, production efficiencies and other factors that may impact the project. On a quarterly basis, management reviews the progress of each project, which may result in revisions of previous estimates, including revenue recognition. The Company calculates the percent complete and applies the percentage to determine the revenues earned and the appropriate portion of total estimated costs. Losses, if any, are recorded in full in the period they first become evident. Historically, the Company’s estimates of total costs and costs to complete have approximated actual costs incurred to complete the project.

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Under the percentage-of-completion method, billings do not always correlate directly to the revenue recognized. Based upon the terms of the specific contract, billings may be in excess of the revenue recognized, in which case the amounts are included in customer prepayments as a liability on the Consolidated Balance Sheets. Likewise, revenue recognized may exceed customer billings in which case the amounts are reported in trade receivables. Unbilled revenues are expected to be billed and collected within one year. At December 31, 2010 and 2009, trade receivables included $26.5 million and $24.8 million of unbilled receivables, respectively. During 2010, there were 19 projects representing approximately 19% and 23% of the Company’s total revenues and product revenues, respectively, which were accounted for using percentage-of-completion accounting, compared to 17 projects during 2009 representing approximately 13% of the Company’s total revenues and 16% of product revenues, respectively.

Revenues not recognized under the percentage-of-completion method

Revenues from the sale of inventory products, not accounted for under the percentage-of-completion method, are recorded at the time the manufacturing processes are complete and ownership is transferred to the customer.

Service revenue

The Company earns service revenues from three sources:

The recognition of service revenue is the same for all products, including those accounted for under the percentage-of-completion method. The Company does not install products for its customers, but it does provide technical advisory assistance. At the time of delivery of the product, the customer is not obligated to buy or rent the Company’s running tools and the Company is not obligated to perform any subsequent services related to installation. Technical advisory assistance service revenue is recorded at the time the service is rendered. Service revenues associated with the rental of running and installation tools are recorded as earned. Rework and reconditioning service revenues are recorded when the refurbishment process is complete.

The Company normally negotiates contracts for products, including those accounted for under the percentage-of-completion method, and services separately. For all product sales, it is the customer’s decision as to the timing of the product installation as well as whether Dril-Quip running tools will be purchased or rented. Furthermore, the customer is under no obligation to utilize the Company’s technical advisory services. The customer may use a third party or their own personnel.

Inventories . Inventory costs are determined principally by the use of the first-in, first-out (FIFO) costing method and are stated at the lower of cost or market. Company manufactured inventory is valued principally using standard costs, which are calculated based upon direct costs incurred and overhead allocations. Inventory purchased from third party vendors is principally valued at the weighted average cost. Periodically, obsolescence reviews are performed on slow-moving inventories and reserves are established based on current assessments about future demands and market conditions. The inventory values have been reduced by a reserve for excess and obsolete inventories. Inventory reserves of $24.9 million and $24.2 million have been established as of December 31, 2010 and 2009, respectively. If market conditions are less favorable than those projected by management, additional inventory reserves may be required.

Contingent liabilities. The Company establishes reserves for estimated loss contingencies when the Company believes a loss is probable and the amount of the loss can be reasonably estimated. Revisions to

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contingent liabilities are reflected in income in the period in which different facts or information become known or circumstances change that affect the Company’s previous assumptions with respect to the likelihood or amount of loss. Reserves for contingent liabilities are based upon the Company’s assumptions and estimates regarding the probable outcome of the matter. Should the outcome differ from the Company’s assumptions and estimates, revisions to the estimated reserves for contingent liabilities would be required.

Off-Balance Sheet Arrangements

The Company has no derivative instruments and no off-balance sheet hedging or financing arrangements, contracts or operations.

New Accounting Standards

In April 2010, the FASB issued Accounting Standards Update (“ASU”) 2010-17, Revenue Recognition—Milestone Method (Topic 605). This ASU applies to the milestone method of revenue recognition for research and development transactions. These types of arrangements include payment provisions whereby a portion of the consideration is contingent upon achieving a specific result from research and development efforts. The update provides guidance on the criteria that should be met for determining whether the milestone method of revenue recognition is appropriate. The ASU is effective on a prospective basis for milestones achieved in fiscal years, and interim periods within those years, beginning on or after June 15, 2010. The adoption of this accounting standard update will not have a material impact on the Company’s consolidated financial statements or the Company’s revenue recognition policy.

In January 2010, the FASB issued ASU 2010-06, Fair Value Measurements and Disclosures (Topic 820)—Improving Disclosures about Fair Value Measurements. This ASU requires some new disclosures and clarifies some existing disclosure requirements about fair value measurement as set forth in Codification Subtopic 820-10. The FASB’s objective is to improve these disclosures and, thus, increase transparency in financial reporting. The ASU 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 roll forward 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. Early application is permitted. The adoption of this accounting standard update did not have a material impact on the Company’s consolidated financial statements or the Company’s revenue recognition policy.

In October 2009, the FASB issued ASU 2009-13, Multiple-Deliverable Revenue Arrangements (Topic 605), (“ASU 2009-13”). The new standard changes the requirements for establishing separate units of accounting in a multiple element arrangement and requires the allocation of arrangement consideration to each deliverable based on the relative selling price. The selling price for each deliverable is based on vendor-specific objective evidence (“VSOE”) if available, third-party evidence if VSOE is not available, or estimated selling price if neither VSOE or third-party evidence is available. ASU 2009-13 is effective for revenue arrangements entered in fiscal years beginning on or after June 15, 2010. The adoption of this accounting standard update will not have a material impact on the Company’s consolidated financial statements or the Company’s revenue recognition policy.

The Company is currently exposed to certain market risks related to interest rate changes and fluctuations in foreign exchange rates. The Company does not engage in any material hedging transactions, forward contracts or currency trading which could mitigate the market risks inherent in such transactions.

Foreign Exchange Rate Risk

Through its subsidiaries, the Company conducts a portion of its business in currencies other than the United States dollar, principally the British pound sterling and, to a lesser extent, the Brazilian real. The Company has not experienced significant transaction gains or losses associated with changes in currency exchange rates and

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does not anticipate such exposure to be material in the future. However, there is no assurance that the Company will be able to protect itself against currency fluctuations in the future. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Currency Risk” in Item 7 of this report.

The Company uses a sensitivity analysis model to measure the impact on revenue and net income of a 10% adverse movement of foreign currency exchange rates against the U.S. dollar over the previous year. Based upon this model, a 10% decrease would have resulted in a decrease in revenues of approximately $22 million and a decrease in net income of approximately $6 million over the year ended December 31, 2010. There can be no assurance that the exchange rate decrease projected above will materialize as fluctuations in exchange rates are beyond the Company’s control.

Interest Rate Risk

As described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources,” the Company has a loan that requires the Company to pay interest at a floating rate. This floating-rate obligation exposes the Company to the risk of increased interest expense in the event of increases in the short-term interest rates. Based upon the December 31, 2010 balance of approximately $207,000 related to this floating rate obligations, each 1.0% rise in interest rates would result in additional annual interest expense to the Company of approximately $2,100, or $525 per quarter.