10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(MARK ONE)

x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2010

or

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from             to             .

Commission file number: 001-13439

Dril-Quip, Inc.

(Exact name of registrant as specified in its charter)

Delaware	74-2162088
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)
13550 Hempstead Highway Houston, Texas	77040
(Address of principal executive offices)	(Zip code)

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

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

Title of Each Class	Name of Each Exchange On Which Registered
Common Stock, $.01 par value per share	New York Stock Exchange
Rights to Purchase Series A Junior Participating Preferred Stock	New York Stock Exchange

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):

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

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.

TABLE OF CONTENTS

PART I
Item 1.	Business	2
Item 1A.	Risk Factors	12
Item 1B.	Unresolved Staff Comments	20
Item 2.	Properties	21
Item 3.	Legal Proceedings	21
Item 4.	[Removed and Reserved]	23
Item S-K 401(b).	Executive Officers of the Registrant	23
PART II
Item 5.	Market for Registrant’s Common Stock, Related Stockholder Matters and Issuer Purchases of Equity Securities	25
Item 6.	Selected Financial Data	26
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	40
Item 8.	Financial Statements and Supplementary Data	41
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	65
Item 9A.	Controls and Procedures	66
Item 9B.	Other Information	66
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	67
Item 11.	Executive Compensation	67
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	67
Item 13.	Certain Relationships and Related Transactions, and Director Independence	67
Item 14.	Principal Accountant Fees and Services	67
PART IV
Item 15.	Exhibits and Financial Statement Schedules	68
	Signatures	70

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:

• future operating results and cash flow;

• scheduled, budgeted and other future capital expenditures;

• working capital requirements;

• the availability of expected sources of liquidity;

• the introduction into the market of the Company’s future products;

• the market for the Company’s existing and future products;

• the Company’s ability to develop new applications for its technologies;

• the exploration, development and production activities of the Company’s customers;

• compliance with present and future environmental regulations and costs associated with environmentally related penalties, capital expenditures, remedial actions and proceedings;

• effects of pending legal proceedings; and

• future operations, financial results, business plans and cash needs.

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:

• the volatility of oil and natural gas prices;

• the cyclical nature of the oil and gas industry;

• uncertainties associated with the United States and worldwide economies;

• uncertainties regarding political tensions in the Middle East, Africa and elsewhere;

• current and potential governmental regulatory actions in the United States and regulatory actions and political unrest in other countries;

• uncertainties regarding future oil and gas exploration and production activities in the U.S. Gulf of Mexico and elsewhere, including activities impacted by the 2010 drilling moratorium and related permitting delays in the U.S. Gulf of Mexico;

• operating interruptions (including explosions, fires, weather-related incidents, mechanical failure, unscheduled downtime, labor difficulties, transportation interruptions, spills and releases and other environmental risks);

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• the Company’s reliance on product development;

• technological developments;

• the Company’s dependence on key employees and skilled machinists, fabricators and technical personnel;

• the Company’s reliance on sources of raw materials;

• control by certain stockholders;

• impact of environmental matters, including future environmental regulations;

• competitive products and pricing pressures;

• fluctuations in foreign currency;

• the Company’s reliance on significant customers;

• creditworthiness of the Company’s customers;

• fixed-price contracts;

• changes in general economic, market or business conditions;

• access to capital markets;

• negative outcome of litigation, threatened litigation or government proceedings; and

• war and terrorist acts.

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

Item 1. Business

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:

• Code of Business Conduct and Ethical Practices,

• Corporate Governance Guidelines,

• Nominating, Governance and Compensation Committee Charter, and

• Audit Committee Charter.

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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Item 1A. Risk Factors

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:

• worldwide economic activity;

• the level of exploration and production activity;

• interest rates and the cost of capital;

• environmental regulation;

• federal, state and foreign policies regarding exploration and development of oil and gas;

• the ability of the Organization of Petroleum Exporting Countries (OPEC) to set and maintain production levels and pricing;

• governmental regulations regarding future oil and gas exploration and production in the U.S. Gulf of Mexico and elsewhere, including activities impacted by the 2010 drilling moratorium in the U.S. Gulf of Mexico and related permitting delays;

• the cost of exploring and producing oil and gas;

• the cost of developing alternative energy sources;

• the sale and expiration dates of offshore leases in the United States and overseas;

• the discovery rate of new oil and gas reserves in offshore areas;

• technological advances; and

• weather conditions.

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:

• volatility in general economic, social and political conditions;

• terrorist acts, war and civil disturbances;

• expropriation or nationalization of assets;

• renegotiation or nullification of existing contracts;

• foreign taxation, including changes in law or interpretation of existing law;

• assaults on property or personnel;

• restrictive action by local governments;

• foreign and domestic monetary policies;

• limitations on repatriation of earnings;

• travel limitations or operational problems caused by public health threats; and

• changes in currency exchange rates.

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:

• errors in estimates or bidding;

• changes in availability and cost of labor and materials; and

• variations in productivity from our original estimates.

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:

• federal, state and local and foreign laws and other regulations relating to the oilfield operations, worker safety and the protection of the environment;

• changes in these laws and regulations; and

• the level of enforcement of these laws and regulations.

In addition, we depend on the demand for our products and services from the oil and gas industry. This demand is affected by changing taxes, price controls and other laws and regulations relating to the oil and gas industry in general, 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:

• limited trading volume in our common stock;

• quarterly variations in operating results;

• general financial market conditions;

• the prices of natural gas and oil;

• announcements by us and our competitors;

• our liquidity;

• changes in government regulations;

• our ability to raise additional funds;

• our involvement in litigation; and

• other events.

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.

Item 1B. Unresolved Staff Comments

None.

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Item 2. Properties

Major Manufacturing Facilities

Location	Building Size (Approximate Square Feet)		Land (Approximate Acreage)		Owned or Leased
Houston, Texas
—Hempstead Highway		175,000		15.0		Owned
		14,000		—		Leased
—N. Eldridge Parkway		1,519,000		218.0		Owned
Aberdeen, Scotland		216,100		24.1		Owned
		3,200		0.8		Leased
Singapore		56,000		—		Owned
		10,500		18.3		Leased
Macae, Brazil		112,700		10.6		Owned

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

Location(1)	Building Size (Approximate Square Feet)		Land (Approximate Acreage)		Activity
New Orleans, Louisiana		2,300		—	Sales/Service
Beverwijk, Holland		5,200		0.4	Sales/Warehouse
Perth, Australia		1,700		—	Sales/Service
Darwin, Australia		10,800		1.4	Service/Warehouse/Reconditioning
Stavanger, Norway		42,000		6.1	Sales/Service/Reconditioning/Warehouse/Fabrication
Esbjerg, Denmark		19,400		1.2	Sales/Service/Reconditioning/Warehouse
Port Harcourt, Nigeria		8,300		0.5	Sales/Service/Reconditioning/Warehouse
Tianjin, China		12,200		—	Service/Reconditioning/Warehouse
Cairo, Egypt		2,200		—	Sales
Alexandria, Egypt		5,200		0.6	Service/Reconditioning/Warehouse
Ghana, West Africa		1,700		—	Service/Reconditioning/Warehouse

(1) All facilities are leased except Stavanger, Norway, which is owned.

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

Item 3. Legal Proceedings

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.

Item 4. Removed and Reserved

Item S-K 401(b).      Executive Officers of the Registrant

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:

Name	Age	Position
J. Mike Walker	67	Co-Chairman of the Board and Chief Executive Officer
Jerry M. Brooks	59	Vice President –Finance, Chief Financial Officer and Secretary

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

Item 5. Market for Registrant’s Common Stock, Related Stockholder Matters and Issuer Purchases of Equity Securities

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.

	Sales Price ($)
	2010				2009
Quarter Ended	High		Low		High		Low
March 31		64.13		48.71		33.22		18.13
June 30		70.78		40.38		46.40		29.31
September 30		63.53		42.35		50.52		33.95
December 31		83.80		61.69		59.00		47.07

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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Item 6. Selected Financial Data

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.

	Year ended December 31,
	2010			2009			2008			2007			2006
	(In thousands, except per share amounts)
Statement of Operations Data:
Revenues:
Products	$	486,050		$	456,022		$	453,315		$	417,970		$	372,540
Services		80,201			84,182			89,456			77,587			70,202
Total revenues		566,251			540,204			542,771			495,557			442,742
Cost and expenses:
Cost of sales:
Products		272,619			260,780			260,626			237,728			217,847
Services		49,988			49,513			51,673			47,553			38,841
Total cost of sales		322,607			310,293			312,299			285,281			256,688
Selling, general and administrative expenses		61,069			55,474			62,390			49,313			44,085
Engineering and product development expenses		29,202			27,173			26,369			22,578			19,559
Special items(1)		14,660			5,224			—			—			—
Operating income		138,713			142,040			141,713			138,385			122,410
Interest income		321			507			3,453			8,275			3,632
Interest expense		(131	)		(156	)		(182	)		(370	)		(669	)
Income before income taxes		138,903			142,391			144,984			146,290			125,373
Income tax provision		36,677			37,250			39,399			38,349			38,482
Net income	$	102,226		$	105,141		$	105,585		$	107,941		$	86,891
Earnings per common share:
Basic	$	2.57		$	2.68		$	2.65		$	2.67		$	2.21
Diluted	$	2.55		$	2.66		$	2.62		$	2.63		$	2.15
Weighted average common shares outstanding:
Basic		39,828			39,164			39,918			40,447			39,340
Diluted		40,060			39,538			40,292			41,007			40,342
Statement of Cash Flows Data:
Net cash provided by operating activities	$	107,160		$	136,412		$	40,677		$	82,663		$	93,482
Net cash used in investing activities		(72,950	)		(44,325	)		(49,527	)		(24,854	)		(23,290	)
Net cash provided by (used in) financing activities		14,634			13,436			(100,075	)		10,160			36,851
Other Data:
Depreciation and amortization	$	20,875		$	17,997		$	16,854		$	15,653		$	15,087
Capital expenditures		74,815			44,749			50,134			25,208			24,133
	December 31,
	2010			2009			2008			2007			2006
	(In thousands)
Balance Sheet Data:
Working capital	$	576,920		$	511,916		$	400,535		$	454,192		$	347,250
Total assets		948,551			817,246			680,609			699,822			594,935
Total debt		326			1,039			1,532			2,911			3,720
Total stockholders’ equity		828,014			705,085			559,450			592,495			467,497

(1) See discussion on pages 32 and 33 under “Special Items.”

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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.

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

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:

	Average prices during year ended December 31,
	2010		2009		2008
Oil ($/Bbl)	$	79.48	$	62.18	$	99.57
Natural gas ($/per Mcf)		4.52		4.06		9.13

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

27

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.

	Year ended December 31,
	2010		2009		2008
Western Hemisphere		175		165		185
Eastern Hemisphere		144		150		162
Asia-Pacific		236		233		238
Source: ODS – Petrodata RigBase – December 31, 2010, 2009 and 2008

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:

2011	60
2012	33
2013	11
2014	13
	117

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:

	Year ended
	2010		2009		2008
	(In millions)
Revenues:
Products
Subsea equipment	$	111.0	$	114.7	$	82.0
Surface equipment		2.0		2.2		1.9
Offshore rig equipment		79.3		36.9		48.1
Total products		192.3		153.8		132.0
Services		26.2		32.2		38.2
Total U.S. Gulf of Mexico revenues	$	218.5	$	186.0	$	170.2

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:

	Year Ended December 31,
	2010			2009			2008
Revenues:
Products		85.8	%		84.4	%		83.5	%
Services		14.2			15.6			16.5
Total revenues		100.0			100.0			100.0
Cost of sales:
Products:		48.1			48.3			48.0
Services		8.9			9.1			9.5
Total cost of sales		57.0			57.4			57.5
Selling, general and administrative		10.7			10.3			11.5
Engineering and product development		5.2			5.0			4.9
Special items(1)		2.6			1.0			—
Operating income		24.5			26.3			26.1
Interest income		0.1			0.1			0.6
Interest expense		—			—			—
Income before income taxes		24.6			26.4			26.7
Income tax provision		6.5			6.9			7.3
Net income		18.1	%		19.5	%		19.4	%

(1) See discussion on pages 32 and 33 under “Special Items.”

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

	2010		2009		2008
	(In millions)
Revenues:
Products
Subsea equipment	$	369.6	$	361.1	$	322.6
Surface equipment		26.5		31.2		30.6
Offshore rig equipment		90.0		63.7		100.1
Total products		486.1		456.0		453.3
Services		80.2		84.2		89.5
Total revenues	$	566.3	$	540.2	$	542.8

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:

	Year ended December 31,
	2010			2009			2008
	(In thousands)
Operating activities	$	107,160		$	136,412		$	40,677
Investing activities		(72,950	)		(44,325	)		(49,527	)
Financing activities		14,634			13,436			(100,075	)
		48,844			105,523			(108,925	)
Effect of exchange rate changes on cash activities		(786	)		(3,683	)		3,145
Increase (decrease) in cash and cash equivalents	$	48,058		$	101,840		$	(105,780	)

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:

	Payments due by year
Contractual Obligations	2011		2012		2013		2014		2015		After 2015		Total
	(In thousands)
Long-term debt and capital leases	$	268	$	39	$	11	$	5	$	3	$	—	$	326
Operating lease obligations (1)		6,936		4,111		371		288		252		2,542		14,500
Estimated interest payments (2)		1		—		—		—		—		—		1
Total	$	7,205	$	4,150	$	382	$	293	$	255	$	2,542	$	14,827

(1) Includes certain minimum lease obligations for investments in machinery, leasehold improvements and buildings.

(2) Interest rates for leases were calculated using the interest portion of the lease payment. Interest payments for variable rate debt were calculated using the interest rate and exchange rate in effect at 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:

• product revenues recognized under the percentage-of-completion method; and

• product revenues from the sale of products that do not qualify for the percentage-of-completion method.

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:

• The contracts call for products which are designed to customer specifications;

• The structural designs are unique and require significant engineering and manufacturing efforts generally requiring more than one year in duration;

• The contracts contain specific terms as to milestones, progress billings and delivery dates; and

• Product requirements cannot be filled directly from the Company’s standard inventory.

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.

38

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:

• technical advisory assistance;

• rental of running tools; and

• rework and reconditioning of customer owned Dril-Quip products.

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

39

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.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

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

40

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.

Item 8. Financial Statements and Supplementary Data

	Page
Management’s Annual Report on Internal Control over Financial Reporting		42
Reports of Independent Registered Public Accounting Firm		43
Consolidated Statements of Income for the Three Years in the Period Ended December 31, 2010		45
Consolidated Balance Sheets as of December 31, 2010 and 2009		46
Consolidated Statements of Cash Flows for the Three Years in the Period Ended December 31, 2010		47
Consolidated Statements of Stockholders’ Equity for the Three Years in the Period Ended December  31, 2010		48
Notes to Consolidated Financial Statements		49

41

Management’s Annual Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Internal control over financial reporting is defined in Rule 13a-15(f) or 15d-15(f) promulgated under the Securities Exchange Act of 1934 as a process designed by, or under the supervision of, the Company’s principal executive and principal financial officers and effected by the Company’s board of directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America and includes those policies and procedures that:

• pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the transactions and dispositions of the assets of the company;

• provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with accounting principles generally accepted in the United States of America, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and

• provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company’s assets that could have a material effect on the financial statements.

Management has designed its internal control over financial reporting to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with accounting principles generally accepted in the United States of America. Management’s assessment included review and testing of both the design effectiveness and operating effectiveness of controls over all relevant assertions related to all significant accounts and disclosures in the financial statements.

All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Under the supervision and with the participation of our management, including our principal executive officers and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework in Internal Control—Integrated Framework, our management has concluded that our internal control over financial reporting was effective as of December 31, 2010.

BDO USA, LLP, the independent registered public accounting firm, which audited the consolidated financial statements included in the Annual Report on Form 10-K, has also issued an attestation on our internal control over financial reporting, and their report is set forth on page 43.

42

Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders

Dril-Quip, Inc.

Houston, Texas

We have audited Dril-Quip, Inc.’s internal control over financial reporting as of December 31, 2010, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria). Dril-Quip, Inc.’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying “Item 8. Management’s Annual Report on Internal Control Over Financial Reporting”. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, Dril-Quip, Inc. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2010, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Dril-Quip, Inc. as of December 31, 2010 and 2009, and the related consolidated statements of income, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2010 and our report dated February 25, 2011 expressed an unqualified opinion thereon.

/s/    BDO USA, LLP

Houston, Texas

February 25, 2011

43

Report of Independent Registered Public Accounting Firm

Board of Directors and Stockholders

Dril-Quip, Inc.

Houston, Texas

We have audited the accompanying consolidated balance sheets of Dril-Quip, Inc. as of December 31, 2010 and 2009 and the related consolidated statements of income, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2010. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Dril-Quip, Inc. at December 31, 2010 and 2009, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2010, in conformity with accounting principles generally accepted in the United States of America.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Dril-Quip, Inc.’s internal control over financial reporting as of December 31, 2010, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) and our report dated February 25, 2011, expressed an unqualified opinion thereon.

/s/    BDO USA, LLP

Houston, Texas

February 25, 2011

44

DRIL-QUIP, INC.

CONSOLIDATED STATEMENTS OF INCOME

	Year Ended December 31,
	2010			2009			2008
	(In thousands, except per share data)
Revenues:
Products	$	486,050		$	456,022		$	453,315
Services		80,201			84,182			89,456
Total revenues		566,251			540,204			542,771
Cost and expenses:
Cost of sales:
Products		272,619			260,780			260,626
Services		49,988			49,513			51,673
Total cost of sales		322,607			310,293			312,299
Selling, general and administrative		61,069			55,474			62,390
Engineering and product development		29,202			27,173			26,369
Special items		14,660			5,224			—
		427,538			398,164			401,058
Operating income		138,713			142,040			141,713
Interest income		321			507			3,453
Interest expense		(131	)		(156	)		(182	)
Income before income taxes		138,903			142,391			144,984
Income tax provision		36,677			37,250			39,399
Net income	$	102,226		$	105,141		$	105,585
Earnings per common share:
Basic	$	2.57		$	2.68		$	2.65
Diluted	$	2.55		$	2.66		$	2.62
Weighted average common shares outstanding:
Basic		39,828			39,164			39,918
Diluted		40,060			39,538			40,292

The accompanying notes are an integral part of these statements.

45

DRIL-QUIP, INC.

CONSOLIDATED BALANCE SHEETS

	December 31,
	2010			2009
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	245,850		$	197,792
Trade receivables, net		158,894			130,816
Inventories, net		243,432			251,357
Deferred income taxes		21,942			18,103
Prepaids and other current assets		18,131			18,473
Total current assets		688,249			616,541
Property, plant and equipment, net		247,158			194,703
Other assets		13,144			6,002
Total assets	$	948,551		$	817,246
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	31,149		$	24,828
Current maturities of long-term debt		268			723
Accrued income taxes		1,985			8,514
Customer prepayments		48,889			47,214
Accrued compensation		11,899			10,751
Other accrued liabilities		17,139			12,595
Total current liabilities		111,329			104,625
Long-term debt, net of current maturities		58			316
Deferred income taxes		9,150			7,220
Total liabilities		120,537			112,161
Commitments and contingencies (Note 9)
Stockholders’ equity:
Preferred stock: 10,000,000 shares authorized at $0.01 par value (none issued)		—			—
Common stock:
50,000,000 shares authorized at $0.01 par value, 40,041,746 and 39,658,524 issued and outstanding at December 31, 2010 and 2009, respectively		400			396
Additional paid-in capital		151,418			129,528
Retained earnings		685,513			583,287
Foreign currency translation adjustment		(9,317	)		(8,126	)
Total stockholders’ equity		828,014			705,085
Total liabilities and stockholders’ equity	$	948,551		$	817,246

The accompanying notes are an integral part of these statements.

46

DRIL-QUIP, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Year Ended December 31,
	2010			2009			2008
	(In thousands)
Operating activities
Net income	$	102,226		$	105,141		$	105,585
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization		20,875			17,997			16,854
Stock-based compensation expense		4,960			3,975			3,181
Gain on sale of equipment		(214	)		(132	)		(102	)
Deferred income taxes		(1,933	)		(5,540	)		(1,297	)
Special items—non-cash		1,979			1,272			—
Changes in operating assets and liabilities:
Trade receivables, net		(28,746	)		51,461			(46,853	)
Inventories, net		7,257			(19,280	)		(62,139	)
Prepaids and other assets		(6,468	)		(5,909	)		773
Excess tax benefits of stock option exercises		(2,770	)		(7,833	)		(399	)
Trade accounts payable and accrued expenses		9,994			(4,740	)		25,074
Net cash provided by operating activities		107,160			136,412			40,677
Investing activities
Purchase of property, plant, and equipment		(74,815	)		(44,749	)		(50,134	)
Proceeds from sale of equipment		1,865			424			607
Net cash used in investing activities		(72,950	)		(44,325	)		(49,527	)
Financing activities
Repurchase of common stock		—			—			(100,038	)
Principal payments on long-term debt		(679	)		(695	)		(812	)
Proceeds from exercise of stock options		12,543			6,298			376
Excess tax benefits of stock option exercises		2,770			7,833			399
Net cash provided by (used in) financing activities		14,634			13,436			(100,075	)
Effect of exchange rate changes on cash activities		(786	)		(3,683	)		3,145
Increase (decrease) in cash and cash equivalents		48,058			101,840			(105,780	)
Cash and cash equivalents at beginning of year		197,792			95,952			201,732
Cash and cash equivalents at end of year	$	245,850		$	197,792		$	95,952

The accompanying notes are an integral part of these statements.

47

DRIL-QUIP, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

	Common Stock			Additional Paid-In Capital			Retained Earnings		Foreign Currency Translation Adjustment			Total
	(In thousands)
Balance at December 31, 2007	$	408		$	205,835		$	372,561	$	13,691		$	592,495
Translation adjustment		—			—			—		(42,561	)		(42,561	)
Net income		—			—			105,585		—			105,585
Comprehensive income		—			—			—		—			63,024
Options exercised (28,812 shares)		—			376			—		—			376
Stock-based compensation		—			3,181			—		—			3,181
Treasury stock (1,799,928 shares)		(18	)		(100,020	)		—		—			(100,038	)
Excess tax benefits—stock options		—			412			—		—			412
Balance at December 31, 2008		390			109,784			478,146		(28,870	)		559,450
Translation adjustment		—			—			—		20,744			20,744
Net income		—			—			105,141		—			105,141
Comprehensive income		—			—			—		—			125,885
Options exercised (635,927 shares)		6			6,292			—		—			6,298
Stock-based compensation		—			3,975			—		—			3,975
Special items—stock-based compensation		—			1,272			—		—			1,272
Excess tax benefits—stock options		—			8,205			—		—			8,205
Balance at December 31, 2009		396			129,528			583,287		(8,126	)		705,085
Translation adjustment		—			—			—		(1,191	)		(1,191	)
Net income		—			—			102,226		—			102,226
Comprehensive income		—			—			—		—			101,035
Options exercised (383,222 shares)		4			12,539			—		—			12,543
Stock-based compensation		—			4,960			—		—			4,960
Special items—stock-based compensation		—			1,979			—		—			1,979
Excess tax benefits—stock options		—			2,412			—		—			2,412
Balance at December 31, 2010	$	400		$	151,418		$	685,513	$	(9,317	)	$	828,014

The accompanying notes are an integral part of these statements.

48

DRIL-QUIP, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. Organization

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 its products.

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’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.

2. Significant Accounting Policies

Principles of Consolidation

The consolidated financial statements include the accounts of the Company and its subsidiaries, all of which are wholly owned. All material intercompany accounts and transactions have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America under guidance from the Financial Accounting Standards Board Accounting Standards Codification (“ASC”) requires management to make estimates and assumptions that affect reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Some of the Company’s more significant estimates are those affected by critical accounting policies for revenue recognition, inventories and contingent liabilities.

Cash and cash equivalents

Short-term investments that have a maturity of three months or less from the date of purchase are classified as cash equivalents. The Company invests excess cash in 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. The Company’s investment objectives continue to be the preservation of capital and the maintenance of liquidity.

49

Trade Receivables

The Company maintains an allowance for doubtful accounts on trade receivables equal to amounts estimated to be uncollectible. This estimate is based upon historical collection experience combined with a specific review of each customer’s outstanding trade receivable balance. Management believes that the allowance for doubtful accounts is adequate; however, actual write-offs may exceed the recorded allowance. The following is a summary of activity relating to the allowance for doubtful accounts for the years ended December 31, 2008, 2009 and 2010:

	In thousands
Balance at December 31, 2007	$	2,312
Charges to costs and expenses		1,937
Recoveries/write-offs		(742	)
Balance at December 31, 2008		3,507
Charges to costs and expenses		1,333
Recoveries/write-offs		(2,173	)
Balance at December 31, 2009		2,667
Charges to costs and expenses		455
Recoveries/write-offs		(1,671	)
Balance at December 31, 2010	$	1,451

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 were recorded 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.

Property, Plant and Equipment

Property, plant and equipment are carried at cost, with depreciation provided on a straight-line basis over their estimated useful lives.

Impairment of Long-Lived Assets

Long-lived assets, including property, plant and equipment, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the carrying amount of an asset exceeds the estimated undiscounted future cash flows expected to be generated by the asset, an impairment charge is recognized by reflecting the asset at its fair value. No impairment of long-lived assets existed at December 31, 2010.

Income Taxes

The Company accounts for income taxes using the asset and liability method. Current income taxes are provided on income reported for financial statement purposes, adjusted for transactions that do not enter into the computation of income taxes payable in the same year. Deferred tax assets and liabilities are measured using enacted tax rates for the expected future tax consequences of temporary differences between the carrying

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amounts and the tax basis of assets and liabilities. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

Revenue Recognition

Product Revenue

The Company earns product revenues from two sources:

• product revenues recognized under the percentage-of-completion method; and

• product revenues from the sale of products that do not qualify for the percentage-of-completion method.

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:

• The contracts call for products which are designed to customer specifications;

• The structural designs are unique and require significant engineering and manufacturing efforts generally requiring more than one year in duration;

• The contracts contain specific terms as to milestones, progress billings and delivery dates; and

• Product requirements cannot be filled directly from the Company’s standard inventory.

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.

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. As of December 31, 2010 and 2009, receivables included $26.5 million and $24.8 million of unbilled receivables, respectively. For the year ended December 31, 2010, there were 19 projects representing approximately 19% of the Company’s total revenues and approximately 23% of its product revenues that were accounted for using percentage-of-completion accounting, compared to 17 projects during 2009 which represented 13% of the Company’s total revenue and 16% of its product revenues.

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.

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Service revenue

The Company earns service revenues from three sources:

• technical advisory assistance;

• rental of running tools; and

• rework and reconditioning of customer owned Dril-Quip products.

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 relating 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.

Foreign Currency

The financial statements of foreign subsidiaries are translated into U.S. dollars at period-end exchange rates except for revenues and expenses, which are translated at average monthly rates. Translation adjustments are reflected as a separate component of stockholders’ equity and have no current effect on earnings or cash flows. These adjustments amounted to a decrease of $1.2 million in 2010, an increase of $20.7 million in 2009 and a decrease of $42.6 million in 2008. The translation adjustment decrease in 2010 resulted primarily from 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 translation adjustment increase in 2009 resulted primarily from the weakening of the U.S. dollar compared to the British pound sterling and the Brazilian real. The translation adjustment decrease in 2008 resulted primarily from the strengthening of the U.S. dollar compared to the British pound sterling and the Brazilian real during the latter half of 2008.

Foreign currency exchange transactions are recorded using the exchange rate at the date of the settlement. Exchange gains (losses) were approximately $1.0 million in 2010, $3.4 million in 2009, and ($1.5) million in 2008, net of income taxes. These amounts are included in selling, general and administrative costs in the Consolidated Statements of Income on a pre-tax basis.

Fair Value of Financial Instruments

The Company’s financial instruments consist primarily of cash and cash equivalents, receivables, payables, and debt instruments. The carrying values of these financial instruments approximate their respective fair values as they are either short-term in nature or carry interest rates that approximate market rates.

Concentration of Credit Risk

Financial instruments which subject the Company to concentrations of credit risk primarily include trade receivables. The Company grants credit to its customers, which operate primarily in the oil and gas industry. The Company performs periodic credit evaluations of its customers’ financial condition and generally does not require collateral. The Company maintains reserves for potential losses, and such losses have historically been within management’s expectations.

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In addition, the Company invests excess cash in interest bearing accounts, money market mutual funds and funds which invest in obligations of the U.S. Treasury and repurchase agreements backed by U.S. Treasury obligations. Changes in the financial markets and interest rates could affect the interest earned on short-term investments.

Comprehensive Income

ASC Topic 220 establishes the rules for the reporting and display of comprehensive income and its components. The standard requires the Company to include unrealized gains or losses on foreign currency translation adjustments in other comprehensive income. Generally, gains are attributed to a weakening U.S. dollar and losses are the result of a strengthening U.S. dollar.

Earnings Per Share

Basic earnings per share are computed by dividing net income by the weighted average number of shares of common stock outstanding during the year. Diluted earnings per common share are computed considering the dilutive effect of stock options using the treasury stock method.

Reclassifications

Certain reclassifications have been made to prior year amounts and related footnotes to conform to current year presentation.

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.

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.

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3. Inventories

Inventories consist of the following:

	December 31,
	2010			2009
	(In thousands)
Raw materials and supplies	$	46,675		$	50,853
Work in progress		52,556			74,956
Finished goods		169,149			149,749
		268,380			275,558
Less: allowance for obsolete and excess inventory		(24,948	)		(24,201	)
	$	243,432		$	251,357

Summary of allowance for obsolete and excess inventory:

	In thousands
Balance at December 31, 2007	$	19,227
Charges to costs and expenses		2,378
Write-offs of inventory		(776	)
Balance at December 31, 2008		20,829
Charges to costs and expenses		3,942
Write-offs of inventory		(570	)
Balance at December 31, 2009		24,201
Charges to costs and expenses		1,933
Write-offs of inventory		(1,186	)
Balance at December 31, 2010	$	24,948

4. Property, Plant and Equipment

Property, plant and equipment consists of:

	Estimated Useful Lives		December 31,
			2010			2009
			(In thousands)
Land and improvements		10-25 years	$	25,722		$	20,839
Buildings		15-40 years		153,215			103,713
Machinery, equipment and other		3-10 years		239,204			224,956
				418,141			349,508
Less accumulated depreciation				(170,983	)		(154,805	)
			$	247,158		$	194,703

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5. Long-Term Debt

Long-term debt consists of the following:

	December 31,
	2010			2009
	(In thousands)
Bank financing	$	207		$	865
Equipment financing agreements		119			174
		326			1,039
Less current portion		(268	)		(723	)
	$	58		$	316

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 at 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.

Interest paid on long-term debt for the years ended December 31, 2010, 2009 and 2008 was $8,500, $21,700 and $132,000 respectively. Scheduled maturities of long-term debt are as follows: 2011-$268,000; 2012-$39,000; 2013-$11,000; 2014-$5,000; 2015-$3,000; and none thereafter.

6. Income Taxes

In accordance with ASC 740-10, the Company is required to recognize in its financial statements the impact of a tax position that is more likely than not to be sustained upon examination based upon the technical merits of the position, including resolution of any appeals. The standard provides guidance on recognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. Based on the Company’s evaluation, the Company has concluded that there are no significant uncertain tax positions requiring recognition in the Company’s financial statements. The evaluation was performed for the tax years which remain subject to examination by major tax jurisdictions as of December 31, 2010, which are the years ended December 31, 2004 through December 31, 2010. The Company has occasionally been assessed interest or penalties by major tax jurisdictions; these assessments historically have not materially impacted the Company’s financial results. In accordance with the Company’s accounting policy, both before and after adoption of ASC Topic 740-10, interest expense assessed by tax jurisdictions is included with interest expense and assessed penalties are included in selling, general and administrative expenses.

Income before income taxes consisted of the following:

	Year ended December 31,
	2010		2009		2008
	(In thousands)
Domestic	$	70,702	$	52,203	$	72,515
Foreign		68,201		90,188		72,469
Total	$	138,903	$	142,391	$	144,984

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The income tax provision (benefit) consists of the following:

	Year ended December 31,
	2010			2009			2008
	(In thousands)
Current:
Federal	$	25,122		$	22,181		$	25,342
Foreign		13,465			20,750			14,844
Total current		38,587			42,931			40,186
Deferred:
Federal		(3,232	)		(5,371	)		(1,843	)
Foreign		1,322			(310	)		1,056
Total deferred		(1,910	)		(5,681	)		(787	)
	$	36,677		$	37,250		$	39,399

The difference between the effective income tax rate reflected in the provision for income taxes and the U.S. federal statutory rate was as follows:

	Year ended December 31,
	2010			2009			2008
Federal income tax statutory rate		35.0	%		35.0	%		35.0	%
Foreign income tax rate differential		(5.7	)		(5.7	)		(4.5	)
Foreign development tax incentive		(0.8	)		(2.1	)		(2.0	)
Manufacturing benefit		(1.4	)		(0.7	)		(1.1	)
Other		(0.7	)		(0.3	)		(0.2	)
Effective income tax rate		26.4	%		26.2	%		27.2	%

Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Based upon existing market conditions and the Company’s earnings prospects, it is anticipated that all deferred tax assets will be realized in future years. Significant components of the Company’s deferred tax assets and liabilities are as follows:

	December 31,
	2010			2009
	(In thousands)
Deferred tax assets:
Inventory	$	7,120		$	5,489
Inventory reserve		5,701			5,210
Allowance for doubtful accounts		397			656
Reserve for accrued liabilities		690			1,420
Stock options		5,385			3,431
Other		2,649			1,897
Total deferred tax assets		21,942			18,103
Deferred tax liability:
Property, plant and equipment		(9,150	)		(7,220	)
Net deferred tax asset	$	12,792		$	10,883

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Undistributed earnings of the Company’s foreign subsidiaries are considered to be indefinitely reinvested and, accordingly, no provision for U.S. federal income taxes has been provided thereon. The estimate of undistributed earnings of the Company’s foreign subsidiaries amounted to $310 million as of December 31, 2010. Upon distribution of those earnings in the form of dividends or otherwise, the Company may be subject to both U.S. income taxes (subject to an adjustment for foreign tax credits) and withholding taxes payable to the various foreign countries. Determination of the amount of unrecognized deferred U.S. income tax liability is not practicable.

The Company paid $34.1 million, $37.8 million and $40.5 million in income taxes in 2010, 2009 and 2008, respectively.

7. Other Accrued Liabilities

Other accrued liabilities consist of the following:

	December 31,
	2010		2009
	(In thousands)
Payroll taxes	$	2,818	$	2,443
Property, sales and other taxes		4,292		130
Commissions payable		1,142		2,179
Accrued project costs		396		2,614
Accrued vendor costs		5,659		1,965
Other		2,832		3,264
Total	$	17,139	$	12,595

8. Employee Benefit Plans

The Company has a defined-contribution 401(k) plan covering domestic employees and a defined-contribution pension plan covering certain foreign employees. The Company generally makes contributions to the plans equal to each participant’s eligible contributions for the plan year up to a specified percentage of the participant’s annual compensation. The Company’s contribution expense was $2.8 million, $3.1 million and $3.0 million in 2010, 2009 and 2008, respectively.

9. Commitments and Contingencies

The Company leases certain offices, shop and warehouse facilities, automobiles and equipment. The Company expenses all lease payments when incurred. Total lease expense incurred was $3.3 million, $3.1 million and $2.6 million in 2010, 2009 and 2008, respectively. Future annual minimum lease commitments, including required leasehold improvements, at December 31, 2010 are as follows: 2011—$7.2 million; 2012—$4.1 million; 2013—$0.4 million; 2014—$0.3 million; 2015—$0.3 million; and thereafter—$2.5 million.

In November 2007, the Company entered into a lease agreement in Singapore for approximately 11 acres of vacant land. The lease term is 30 years and the Company elected to make a lump sum payment for the entire lease. In addition, under the terms of the lease, the Company is obligated to make certain minimum investments in machinery, leasehold improvements and buildings by November 2012.

In October 2009, the Company entered into an agreement for the construction of a manufacturing facility in Singapore. The agreement is valued at SGD46.5 million (approximately USD36.3 million as of December 31, 2010). The expected construction term is 16 months and is followed by a maintenance term of 12 months. As of the end of 2010, the Company had incurred costs of SGD39.2 million (approximately USD29.2 million).

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In 2006, the Company entered into a contract in the amount of approximately $47 million with MPF Corp. Ltd. (“MPF”), pursuant to which the Company agreed to construct risers and related equipment to be installed on an offshore drillship being constructed for MPF. In September 2008, MPF and its affiliates filed a Chapter 11 bankruptcy case in the United States Bankruptcy Court for the Southern District of Texas, Houston Division (Case No. 08-36084). At the time of the bankruptcy filing, the Company had recognized approximately $20 million in revenues under the contract and had received payments of approximately $16 million. In April 2010, the Company, MPF and a new third-party buyer signed an amendment to the original contract and a novation agreement, pursuant to which the third party, MPF and the Company agreed that the third party would assume the contract. The novation agreement was approved by the bankruptcy court on June 8, 2010 and became effective on July 20, 2010. Under the amended contract, the new third party is required to pay for modifications, unpaid invoices, interest and other incidental costs. As a result, the total value of the contract has increased from approximately $47 million to approximately $50 million. All unpaid invoices and obligations due as of December 31, 2010 have been paid.

On April 22, 2010, a deepwater U.S. Gulf of Mexico drilling rig known as the Deepwater Horizon, 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. A moratorium was placed on offshore deepwater drilling on May 28, 2010 in the U.S. Gulf of Mexico and was lifted on October 12, 2010. During the pendency of the moratorium, the Bureau of Ocean Energy Management, Regulation and Enforcement of the U.S. Department of the Interior (the “BOEM”) issued various new regulations intended to improve offshore safety systems and environmental protection. These new regulations increased the complexity of the drilling permit process and resulted in delays for the receipt of drilling permits relative to past experience. The Company is currently unable to quantify the extent of the impact that the U.S. Gulf of Mexico drilling moratorium and subsequent delay in the issuance of permits will have on its future revenues.

Revenues associated with the U.S. Gulf of Mexico totaled approximately 39% of our worldwide revenues during 2010. Although the Company believes that the drilling moratorium and permitting delays will have little or no impact on revenues related to sales of its 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. The Company believes that the U.S. Gulf of Mexico service revenues (which were approximately 4.6% of the Company’s total revenues during 2010) could be substantially negatively impacted in 2011 by the 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.

The Company does 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, the Company believes 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 to the costs of the Company’s customers could cause some projects to become non-economical, and as a result, reduce demand for the Company’s 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. The Company has been designated as a party-in-interest, received requests for certain information and has provided testimony in connection with the joint investigation being conducted by the Departments of Homeland 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

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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.

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.

At the time of the Deepwater Horizon incident, the Company 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, the Company’s 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. The Company 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.

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

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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.

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 dependency on the condition of the oil and gas industry. Additionally, products of the Company are used in potentially hazardous drilling, completion, and production applications that can cause personal injury, product liability, and environmental claims. Although exposure to such risk has not resulted in any significant problems in the past, there can be no assurance that ongoing and future developments will not adversely impact the Company.

In December 2010 and January 2011, the Company’s Brazilian subsidiary was 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 and therefore, 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. Accordingly, 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.

The Company is also 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 action, in the opinion of management, the ultimate liability with respect thereto will not have a material adverse effect on the Company’s operations, financial position or cash flows.

In the United States, the Company is primarily self-insured for employee health and dental costs, but has stop-loss insurance coverage to limit per-incident and aggregate liability. The accrual for self-insurance is based on claims filed and an estimate of claims incurred but not yet reported. The Company believes that adequate accruals are maintained to cover its potential medical liability. The majority of the Company’s other locations are covered by national health insurance plans.

10. Stockholders’ Equity

Under a Stockholder Rights Plan adopted by the Board of Directors on November 24, 2008, each share of common stock includes one right to purchase from the Company a unit consisting of one one-hundredth of a share (a “Fractional Share”) of Series A Junior Participating Preferred Stock at a specific purchase price per Fractional Share, subject to adjustment in certain event. The rights will cause substantial dilution to any person or group that attempts to acquire the Company without the approval of the Company’s Board of Directors.

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11. Geographic Segments

	Year ended December 31,
	2010			2009			2008
	(In thousands)
Revenues
Western Hemisphere
Products	$	273,747		$	220,171		$	224,816
Services		36,587			37,014			43,065
Intercompany		50,447			67,546			64,418
Total	$	360,781		$	324,731		$	332,299
Eastern Hemisphere
Products	$	130,764		$	166,181		$	154,226
Services		30,435			36,053			34,732
Intercompany		2,489			1,765			1,858
Total	$	163,688		$	203,999		$	190,816
Asia-Pacific
Products	$	81,539		$	69,670		$	74,273
Services		13,179			11,115			11,659
Intercompany		2,488			3,397			7,714
Total	$	97,206		$	84,182		$	93,646
Summary
Products	$	486,050		$	456,022		$	453,315
Services		80,201			84,182			89,456
Intercompany		55,424			72,708			73,990
Eliminations		(55,424	)		(72,708	)		(73,990	)
Total	$	556,251		$	540,204		$	542,771
Income (loss) before income taxes
Western Hemisphere	$	63,987		$	63,839		$	69,319
Eastern Hemisphere		29,773			45,939			35,509
Asia-Pacific		35,071			35,061			33,592
Eliminations		10,072			(2,448	)		6,564
Total	$	138,903		$	142,391		$	144,984
Total Long-Lived Assets
Western Hemisphere	$	179,392		$	158,210		$	147,460
Eastern Hemisphere		36,924			27,214			22,892
Asia-Pacific		46,535			18,029			16,402
Eliminations		(2,549	)		(2,748	)		(20,419	)
Total	$	260,302		$	200,705		$	166,335
Total Assets
Western Hemisphere	$	593,648		$	518,475		$	465,797
Eastern Hemisphere		185,903			158,112			125,497
Asia-Pacific		191,715			147,644			120,943
Eliminations		(22,715	)		(6,985	)		(31,628	)
Total	$	948,551		$	817,246		$	680,609

61

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.

Eliminations of operating profits are related to intercompany inventory transfers that are deferred until shipment is made to third party customers.

In 2010, one customer, Keppel Fels, accounted for approximately 13% of the Company’s revenues. In 2009, one customer, ConocoPhillips, accounted for approximately 10% of the Company’s total revenues. In 2008 no single customer accounted for more than 10% of the Company’s revenues.

12. Employee Stock Option Plan and Awards

On September 19, 1997, the Company adopted the Dril-Quip, Inc. 1997 Incentive Plan (as amended, the “1997 Plan”) and the Company reserved 3,400,000 shares of Common Stock for use in connection with the 1997 Plan. During 2001, the Company reserved an additional 1,400,000 shares for use in connection with the 1997 Plan. Some options remain outstanding under the 1997 Plan; however, no additional grants will be awarded under this plan. On May 13, 2004, the Company’s stockholders approved the 2004 Incentive Plan of Dril-Quip, Inc. (the “2004 Plan”), which reserved up to 2,696,294 shares of Common Stock to be used in connection with the 2004 Plan. Persons eligible for awards under the 1997 Plan and 2004 Plan are employees holding positions of responsibility with the Company or any of its subsidiaries. Options granted under the 1997 Plan and the 2004 Plan have a term of ten years and become exercisable in cumulative annual increments of one-fourth of the total number of shares of Common Stock subject thereto, beginning on the first anniversary of the date of the grant.

The fair value of stock options granted is estimated on the grant date using the Black-Scholes option pricing model. The expected life is based on the Company’s historical trends, and volatility is based on the expected life of the options. The risk-free interest rate is based on U.S. Treasury yield curve at the grant date. The Company does not pay dividends and, therefore, there is no dividend yield.

On October 28, 2010, October 28, 2009 and October 28, 2008, the Company granted options to purchase 237,484; 243,470 and 408,123 shares, respectively, of Common Stock pursuant to the 2004 Plan to certain officers and employees. The following table presents the assumptions used in the option pricing model.

	2010			2009			2008
Expected life (years)		5.8			6.2			6.3
Volatility		50.1	%		48.8	%		46.2	%
Risk-free interest rate		1.23	%		2.37	%		2.75	%
Dividend yield		0.0	%		0.0	%		0.0	%
Fair value of each option	$	31.76		$	24.22		$	10.23

62

Option activity for the year ended December 31, 2010 was as follows:

	Number of Options			Weighted Average Price		Aggregate intrinsic value (in millions)		Weighted Average Remaining Contractual Life (in years)
Outstanding at December 31, 2009		1,202,440		$	35.74
Granted		237,484			66.93
Exercised		(383,222	)		32.72
Forfeited		—			—
Outstanding at December 31, 2010		1,056,702		$	43.87	$	35.8		7.81
Exercisable at December 31, 2010		521,977		$	37.55	$	21.0		6.77

The total intrinsic value of stock options exercised in 2010, 2009 and 2008 was $13.1 million, $24.9 million and $1.3 million, respectively. The income tax benefit realized from stock options exercised was $4.6 million for the year ended December 31, 2010.

Stock-based compensation is recognized as selling, general and administrative expense in the accompanying Consolidated Statements of Income. During the years ended December 31, 2010, 2009 and 2008, stock-based compensation expense totaled $5.0 million, $4.0 million and $3.2 million, respectively. Stock option expense for 2009 excludes $1.3 million for the accelerated vesting of Mr. Smith’s remaining options upon his death. Stock option expense for 2010 excludes $2.0 million for the early vesting of Mr. Reimert’s options, which vested upon the termination of his employment. Both of these expenses are included in Special items on the Consolidated Statements of Income and are discussed in Note 15 of Notes to Consolidated Financial Statements. No stock-based compensation expense was capitalized during 2010, 2009 or 2008.

Options granted to employees vest over four years and the Company recognizes compensation expense on a straight-line basis over the vesting period of the options. At December 31, 2010, there was $12.0 million of total unrecognized compensation expense related to nonvested stock options. This expense is expected to be recognized over a weighted average of 2.0 years.

The following table summarizes information for equity compensation plans in effect as of December 31, 2010:

	Number of securities to be issued upon exercise of outstanding options		Weighted-average exercise price of outstanding options		Number of securities remaining available for future issuance  under equity compensation plan (excluding securities reflected in column (a))
Plan category	(a)		(b)		(c)
Equity compensation plans approved by stockholders		1,056,702	$	43.87		1,286,498
Equity compensation plans not approved by stockholders		0		not applicable		0
Total		1,056,702	$	43.87		1,286,498

63

13. Earnings Per Share

The following is a reconciliation of the basic and diluted earnings per share computation as required by ASC Topic 260.

	Year Ended December 31,
	2010		2009		2008
	(In thousands, except per share amounts)
Net income	$	102,226	$	105,141	$	105,585
Weighted average common shares outstanding		39,828		39,164		39,918
Effect of dilutive securities—stock options		232		374		374
Total shares and dilutive securities		40,060		39,538		40,292
Basic earnings per common share	$	2.57	$	2.68	$	2.65
Diluted earnings per common share	$	2.55	$	2.66	$	2.62
Weighted average number of stock options with an exercise price greater than average market price for the period		284		294		576

14. Common Stock

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 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 by September 30, 2008.

15. 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 the State of Rio de Janeiro, Brazil, to collect a state tax on the importation of goods. Since 2007, the Company has 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 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, BRL13.8. 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

64

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 contract, 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 Company intends to pay the amount owed to Mr. Reimert in July 2011. 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 as of September 30, 2010, of which $434,000 had been previously accrued. The acceleration of the vesting increased pre-tax non-cash expenses by $1.3 million.

16. Quarterly Results of Operations (Unaudited):

	Quarter Ended
	March 31		June 30		Sept. 30		Dec. 31
	(In thousands, except per share data)
	(Unaudited)
2010
Revenues	$	142,533	$	142,000	$	140,123	$	141,595
Cost of sales		81,815		79,549		79,421		81,822
Gross profit		60,718		62,451		60,702		59,773
Operating income(1)		34,598		39,323		37,714		27,078
Net income(1)		25,697		27,998		27,657		20,874
Earnings per share:
Basic(2)	$	0.65	$	0.70	$	0.69	$	0.52
Diluted(2)		0.64		0.70		0.69		0.52
2009
Revenues	$	127,522	$	133,186	$	138,157	$	141,339
Cost of sales		72,017		77,407		78,260		82,609
Gross profit		55,505		55,779		59,897		58,730
Operating income		34,660		36,311		34,434		36,635
Net income		24,671		26,707		25,084		28,679
Earnings per share:
Basic(2)	$	0.63	$	0.68	$	0.64	$	0.73
Diluted(2)		0.63		0.68		0.63		0.72

(1) See discussion of Special Items in Note 15 of Notes to Consolidated Financial Statements.

(2) The sum of the quarterly per share amounts may not equal the annual amount reported, as per share amounts are computed independently for each quarter and for the full year.

Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

None.

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Item 9A. Controls and Procedures

In accordance with Exchange Act Rules 13a-15 and 15d-15, the Company carried out an evaluation, under the supervision and with the participation of management, including the Company’s Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the Company’s disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Company’s Chief Executive Officer and the Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective as of December 31, 2010 to provide reasonable assurance that information required to be disclosed in the Company’s reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and such information is accumulated and communicated to management, including the Company’s Chief Executive Officer and the Chief Financial Officer, as appropriate to allow timely decisions regarding disclosure.

“Management’s Annual Report on Internal Control over Financial Reporting” appears on page 42 of this annual report on Form 10-K.

There has been no change in the Company’s internal controls over financial reporting that occurred during the three months ended December 31, 2010 that has materially affected, or is reasonably likely to materially affect, the Company’s internal controls over financial reporting.

Item 9B. Other Information

None.

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PART III

Item 10. Directors, Executive Officers and Corporate Governance

The information required by this item is set forth under the captions “Election of Directors,” “Corporate Governance Matters” and “Section 16(a) Beneficial Ownership Reporting Compliance” in the Company’s definitive Proxy Statement (the “2011 Proxy Statement”) for its annual meeting of stockholders to be held on May 11, 2011, which sections are incorporated herein by reference.

Pursuant to Item 401(b) of Regulation S-K, the information required by this item with respect to executive officers of the Company is set forth in Part I of this report.

Item 11. Executive Compensation

The information required by this item is set forth in the sections entitled “Director Compensation,” “Executive Compensation” and “Corporate Governance Matters” in the 2011 Proxy Statement, which sections are incorporated herein by reference.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information required by this item is set forth in the sections entitled “Security Ownership of Certain Beneficial Owners and Management” and “Executive Compensation—Equity Compensation Plan Information” in the 2011 Proxy Statement, which sections are incorporated herein by reference.

Item 13. Certain Relationships and Related Transactions, and Director Independence

The information required by this item is set forth in the section entitled “Corporate Governance Matters” in the 2011 Proxy Statement, which section is incorporated herein by reference.

Item 14. Principal Accountant Fees and Services

The information required by this item is set forth in the sections entitled “Approval of Appointment of Independent Public Accounting Firm—Fees” and “—Audit Committee Pre-Approval Policy for Audit and Non-Audit Services” in the 2011 Proxy Statement, which sections are incorporated herein by reference.

67

PART IV

Item 15. Exhibits and Financial Statement Schedules

(a)(1) Financial Statements

All financial statements of the registrant are set forth under Item 8 of this Annual Report on Form 10-K.

(a)(2) Financial Statement Schedules

All schedules and other statements are omitted because of the absence of conditions under which they are required or because the required information is presented in the financial statements or notes thereto.

(a)(3) Exhibits

Dril-Quip will furnish any exhibit to a stockholder upon payment by the stockholder of the Company’s reasonable expenses to furnish the exhibit.

Exhibit No.		Description
	*3.1	—	Restated Certificate of Incorporation of the Company (Incorporated herein by reference to Exhibit 3.2 to the Company’s Registration Statement on Form S-1 (Registration No. 333-33447)).
	*3.2	—	Certificate of Designations of Series A Junior Participating Preferred Stock of the Company (Incorporated herein by reference to Exhibit 3.1 to the Company’s report on Form 8-K dated November 25, 2008).
	*3.3	—	Amended and restated Bylaws of the Company (Incorporated herein by reference to Exhibit 3.1 to the Company’s report on Form 8-K dated December 21, 2007).
	*4.1	—	Form of certificate representing Common Stock (Incorporated herein by reference to Exhibit 4.2 the Company’s Registration Statement on Form S-1 (Registration No. 333-33447)).
	*4.2	—	Registration Rights Agreement among the Company and certain stockholders (Incorporated herein by reference to Exhibit 4.2 to the Company’s Registration Statement Form S-1 (Registration No. 333-33447)).
	*4.3	—	Rights Agreement dated as of November 24, 2008 between Dril-Quip, Inc. and Mellon Investor Services LLC, as Rights Agent (Incorporated herein by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on November 25, 2008).
	*10.1	—	Credit Agreement between Dril-Quip (Europe) Limited and Bank of Scotland dated November 18, 1999 (Incorporated by reference to Exhibit 10.2 to the Company’s Report on Form 10-Q for the Quarter ended March 30, 2000 (SEC File No. 001-13439)).
	*+10.2	—	Form of Employment Agreement between the Company and each of Messrs. Reimert and Walker (Incorporated herein by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on December 17, 2009).
	*10.3	—	2004 Incentive Plan of Dril-Quip, Inc. (Incorporated herein by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on December 19, 2008).
	**+10.4	—	Summary of Executive Officer and Non-employee Director Compensation.
	*+10.5	—	Consulting Agreement by and between Dril-Quip, Inc. and Larry E. Reimert, dated January 20, 2011 (Incorporated herein by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on January 24, 2011).

68

Exhibit No.		Description
	*10.6	—	Agreement between Dril-Quip Asia Pacific PTE Ltd and Lum Chang Building Contractors PTE Ltd. dated October 16, 2009 (Incorporated herein by reference to Exhibit 10.5 to the Company’s Current Report on Form 10-K filed on February 26, 2010).
	**21.1	—	Subsidiaries of the Registrant.
	**23.1	—	Consent of BDO USA, LLP.
	**31.1	—	Rule 13a-14(a)/15d-14(a) Certification of J. Mike Walker.
	**31.2	—	Rule 13a-14(a)/15d-14(a) Certification of Jerry M. Brooks.
	**32.1	—	Section 1350 Certification of J. Mike Walker.
	**32.2	—	Section 1350 Certification of Jerry M. Brooks.
	***101.INS	—	XBRL Instance Document
	***101.SCH	—	XBRL Schema Document
	***101.CAL	—	XBRL Calculation Document
	***101.LAB	—	XBRL Label Linkbase Document
	***101.PRE	—	XBRL Presentation Linkbase Document
	***101.DEF	—	XBRL Definition Linkbase Document

* Incorporated herein by reference as indicated.

+ Management contract or compensatory plan or arrangement required to be filed as an exhibit to this Form 10-K.

** Filed with this Report

*** Furnished with this Form 10-K

69

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on February 25, 2011.

DRIL-QUIP, INC.
By:	/S/    J. MIKE WALKER
	J. Mike Walker
	Chief Executive Officer and Co-Chairman of the Board of Directors

Pursuant to the requirements of the Securities and Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Name	Capacity	Date
/S/    J. MIKE WALKER         J. MIKE WALKER	Chief Executive Officer, Co-Chairman of the Board and Director (Principal Executive Officer)	February 25, 2011
/S/    LARRY E. REIMERT         LARRY E. REIMERT	Co-Chairman of the Board and Director	February 25, 2011
/S/    JERRY M. BROOKS         JERRY M. BROOKS	Chief Financial Officer (Principal Financial and Accounting Officer)	February 25, 2011
/S/    JOHN V. LOVOI         JOHN V. LOVOI	Director	February 25, 2011
/S/    L.H. DICK ROBERTSON         L.H. DICK ROBERTSON	Director	February 25, 2011
/S/    A.P. SHUKIS         A.P. SHUKIS	Director	February 25, 2011

70

EX-10.4

Exhibit 10.4

Summary of Executive Officer and Non-employee Director Compensation

Set forth below is a summary of the compensation paid by Dril-Quip, Inc. (the “Company”) to its executive officers and non-employee directors as of the date of filing of the Company’s Annual Report on Form 10-K. For more information regarding executive officer and director compensation, please read “Director Compensation,” “Executive Compensation,” and “Corporate Governance Matters—Related Person Transactions—Employment Agreements” contained in the Company’s proxy statement for its 2011 Annual Meeting of Stockholders to be filed with the SEC pursuant to Regulation 14A.

Executive Officers

The Company’s Chief Executive Officer (the “CEO”) is compensated in accordance with his employment agreement entered into with the Company prior to the closing of the Company’s initial public offering. The employment agreement was amended in 2008 to comply with the requirements of Section 409A of the Internal Revenue Code of 1986, as amended, and the regulations promulgated thereunder (the “Code”), and was subsequently amended in 2009 to comply with the requirements of Section 162m of the Code. Except for revisions to certain provisions regarding the timing of payments made under the agreement and the calculation of certain bonus amounts upon termination, the benefits and terms of the amended employment agreement are substantially similar in all material respects to the benefits and terms of the prior employment agreement.

The agreement provides for an annual base salary, as well as cash incentive compensation in the form of an annual performance bonus for each 12-month period based on (i) the Company’s performance in the 12-month period ending December 31 against the Company’s annual budget and (ii) the Company’s return on capital compared to that of a peer group of companies for the 12-month period ending September 30. In addition, the agreement provides for long-term stock-based incentive compensation in the form of an annual grant of options under the Company’s incentive plan equal to the CEO’s base salary multiplied by three and divided by the market price of the Company’s Common Stock on the grant date. The employment agreement gives the Nominating, Governance and Compensation Committee the discretion to increase the annual performance bonus and the annual option grant above the amounts determined for such awards pursuant to the terms of the employment agreement. The agreement also requires the Company to maintain a flexible perquisites spending account in the amount of $25,000 each year for the CEO for use in paying for membership dues, costs associated with purchasing or leasing an automobile, financial counseling, tax return preparation and mobile phones. The Company is required to pay the unused and remaining balance of such account annually to the CEO.

Effective December 31, 2010, the CEO currently receives a base salary of $605,000. For additional information regarding the CEO’s annual cash incentive compensation and long-term stock-based incentive compensation, please read the Company’s proxy statement for its 2011 Annual Meeting of Stockholders.

The Company’s Chief Financial Officer (the “CFO”) is compensated with a base salary, annual cash incentive compensation and stock-based incentive compensation as determined by the CEO. Effective March 10, 2010 the CFO currently receives a base salary of $270,000. For additional information regarding the CFO’s annual cash incentive compensation and long-term stock-based incentive compensation, please read the Company’s proxy statement for its 2011 Annual Meeting of Stockholders.

Non-Employee Directors

The Company’s non-employee directors receive an annual fee of $75,000, plus a fee of $1,000 for attendance at each Board of Directors meeting and $1,000 for each committee meeting. All directors are reimbursed for their out-of-pocket expenses and other expenses incurred in attending meetings of the Board or its committees and for other expenses incurred in their capacity as directors.

EX-21.1

EXHIBIT 21.1

SUBSIDIARIES OF DRIL-QUIP, INC.

Name of Entity	Jurisdiction  of Organization
Dril-Quip Angola LTD	Angola
Dril-Quip Holdings Pty. Ltd	Australia
Dril-Quip do Brasil LTDA	Brazil
Dril-Quip (Tianjin) Oilfield Services Ltd	China
Dril-Quip Egypt for Petroleum Services S.A.E.	Egypt
Dril-Quip France SARL	France
Dril-Quip (Ghana) Ltd.	Ghana
Dril-Quip de México, S. de R.L. de C.V.	Mexico
Servicios Dril-Quip de México, S. de R.L. de C.V.	Mexico
Dril-Quip (Nigeria) Ltd	Nigeria
Dril-Quip (Europe) Limited	Scotland
Dril-Quip Asia Pacific PTE Ltd.	Singapore

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

Dril-Quip, Inc.

Houston, Texas

We hereby consent to the incorporation by reference in the Registration Statements on Form S-8 (No. 333-118876), Form S-8 (No. 333-68976), and Form S-8 (No. 333-47453) of Dril-Quip, Inc. of our report dated February 25, 2011, relating to the consolidated financial statements and the effectiveness of Dril-Quip, Inc.’s internal control over financial reporting, which appears in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010.

/s/ BDO USA, LLP

Houston, Texas

February 25, 2011

EX-31.1

Exhibit 31.1

CERTIFICATION

I, J. Mike Walker, certify that:

1. I have reviewed this annual report on Form 10-K of Dril-Quip, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 25, 2011

/S/    J. MIKE WALKER        

J. Mike Walker

Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Jerry M. Brooks, certify that:

1. I have reviewed this annual report on Form 10-K of Dril-Quip, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 25, 2011

/S/    JERRY M. BROOKS        

Jerry M. Brooks

Vice President—Finance,

Chief Financial Officer and Secretary

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report of Dril-Quip, Inc. (the “Company”) on Form 10-K for the period ended December 31, 2010 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, J. Mike Walker, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/S/    J. MIKE WALKER        

J. Mike Walker

Chief Executive Officer

February 25, 2011

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report of Dril-Quip, Inc. (the “Company”) on Form 10-K for the period ended December 31, 2010 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Jerry M. Brooks, Vice President—Finance, Chief Financial Officer and Secretary of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/S/ JERRY M. BROOKS

Jerry M. Brooks

Vice President—Finance,

Chief Financial Officer and Secretary

February 25, 2011