DRIL-QUIP INC - Quarter Report: 2011 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(MARK ONE)

FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2011

OR

Commission file number 001-13439

DRIL-QUIP, INC.

(Exact name of registrant as specified in its charter)

13550 HEMPSTEAD HIGHWAY

HOUSTON, TEXAS

77040

(Address of principal executive offices)

(Zip Code)

(713) 939-7711

(Registrant’s telephone number, including area code)

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

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 Exchange Act Rule 12b-2).    Yes  ¨    No  x

As of August 2, 2011 the number of shares outstanding of the registrant’s common stock, par value $.01 per share, was 40,057,747.

PART I—FINANCIAL INFORMATION

DRIL-QUIP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

The accompanying notes are an integral part of these statements.

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DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)

The accompanying notes are an integral part of these statements.

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DRIL-QUIP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

The accompanying notes are an integral part of these statements.

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DRIL-QUIP, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

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.

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 condensed consolidated financial statements included herein have been prepared by Dril-Quip and are unaudited, except for the balance sheet at December 31, 2010, which has been derived from the audited consolidated financial statements at that date. In the opinion of management, the unaudited condensed consolidated interim financial statements include all normal recurring adjustments necessary for a fair presentation of the financial position as of June 30, 2011, the results of operations for each of the three and six-month periods ended June 30, 2011 and 2010, and the cash flows for each of the six-month periods ended June 30, 2011 and 2010. Although management believes the unaudited interim related disclosures in these condensed consolidated financial statements are adequate to make the information presented not misleading, certain information and footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America under guidance from the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification™ (“ASC”) have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission. The results of operations and the cash flows for the six-month period ended June 30, 2011 are not necessarily indicative of the results to be expected for the full year. The condensed consolidated financial statements included herein should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010.

Principles of Consolidation

The condensed 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 ASC requires management to make estimates and assumptions

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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 as discussed more fully in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010.

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.

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 $25.9 million and $24.9 million were recorded as of June 30, 2011 and December 31, 2010, 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.

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 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:

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Revenues recognized under the percentage-of-completion method

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

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

Under the percentage-of-completion method, billings usually do not 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 Condensed 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 June 30, 2011 and December 31, 2010, receivables included $36.8 million and $26.5 million of unbilled receivables, respectively. During the quarter ended June 30, 2011, there were 12 projects representing approximately 20% of the Company’s total revenue and approximately 24% of its product revenues that were accounted for using percentage-of-completion accounting, compared to 11 projects during the second quarter of 2010 which represented 22% of the Company’s total revenues and 26% of its product revenues. For the six months ended June 30, 2011, there were 12 projects which represented 23% of the Company’s total revenues and 27% of its product revenues, compared to 14 projects which represented 19% of the Company’s total revenues and 22% of its product revenues for the six months ended June 30, 2010, all of which were accounted for using percentage-of-completion accounting.

Revenues not recognized under the percentage-of-completion method

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

Service revenue

The Company earns service revenues from three sources:

The recognition of service revenue is the same for all products, including those accounted for under the percentage-of-completion method. The Company does not install products for its customers, but it provides

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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 effect on current earnings or cash flows.

Foreign currency exchange transactions are recorded using the exchange rate at the date of the settlement. Exchange gains (losses) are included in selling, general and administrative costs in the Condensed Consolidated Statements of Income.

Fair Value of Financial Instruments

The Company’s financial instruments consist primarily of cash and cash equivalents, receivables and payables. 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.

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 standards 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.

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The following table provides comprehensive income for the periods indicated:

Earnings Per Share

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

In each relevant period, the net income used in the basic and dilutive earnings per share calculations is the same. The following table reconciles the number of common shares outstanding at June 30 of each year to the weighted average number of common shares outstanding and the weighted average diluted number of common shares outstanding for the purpose of calculating basic and diluted earnings per share:

Reclassifications

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

New Accounting Standards

In June 2011, the FASB issued Accounting Standards Update (“ASU”) 2011-05, Comprehensive Income (Topic 220). This ASU amends the guidance on the presentation of comprehensive income in financial statements to improve the comparability, consistency and transparency of financial reporting and to increase the prominence of items that are recorded in other comprehensive income. The new accounting guidance requires entities to report components of comprehensive income in either (1) a continuous statement of comprehensive income or (2) two separate but consecutive statements. The provisions of this new guidance are effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The Company is evaluating the impact of adopting this guidance on its consolidated financial statements.

In April 2010, the FASB issued 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

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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 did 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. The adoption of this accounting standard update did not have a material impact on the Company’s consolidated financial statements. In May 2011, the FASB issued ASU 2011-04, Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP (General Accepted Accounting Principles) and IFRSs (International Financial Reporting Standards). This update results in common fair value measurement and disclosure requirements and changes the language describing the requirements in the U.S. GAAP. This amendment is effective for public entities for interim and annual periods beginning after December 15, 2011. The adoption of this amendment will 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 did not have a material impact on the Company’s consolidated financial statements or the Company’s revenue recognition policy.

During each of the three-month periods ended June 30, 2011 and 2010, the Company recognized approximately $1.2 million in stock- based compensation expense. For each of the six-month periods ended June 30, 2011 and 2010, the stock-based compensation expense totaled $2.4 million. Stock-based compensation expense is included in the selling, general and administrative expense line of the Condensed Consolidated Statements of Income. No stock-based compensation expense was capitalized during the three and six months ended June 30, 2011 or 2010. There were no stock options granted in the second quarter of 2011 or 2010. Refer to Note 12 of the Company’s Annual Report on Form 10-K for the year ended December 31, 2010 for additional information regarding stock-based compensation plans.

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Inventories consist of the following:

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Deepwater Horizon Incident

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. Since the Deepwater Horizon incident, the Bureau of Ocean Energy Management, Regulation and Enforcement of the U.S. Department of the Interior (the “BOEM”) has 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. In the first quarter of 2011, the BOEM resumed the issuance of deepwater drilling permits, and drilling activity may begin to recover in the coming quarters although there can be no assurance of whether or when operations in the U.S. Gulf of Mexico will return to pre-moratorium levels. The Company is currently unable to quantify the full 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 and earnings.

Revenues associated with the U.S. Gulf of Mexico totaled approximately 22% and 30% of worldwide revenues for the three and six months ended June 30, 2011, respectively, as compared with 42% and 43% for the three and six month periods ended June 30, 2010, respectively. For the year ended December 31, 2010, U.S. Gulf of Mexico revenues were approximately 39% of worldwide revenues. 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 the second half of 2011. The Company’s U.S. Gulf of Mexico service revenues totaled approximately 5% and 4% of total worldwide revenues for the three and six months ended June 30, 2011, respectively, as compared 5% and 6% for the three and six months ended June 30, 2010, respectively. For the year ended December 31, 2010, U.S. Gulf of Mexico service revenues were approximately 5% of the Company’s total worldwide revenues. The Company believes that the U.S. Gulf of Mexico service revenues 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 in 2010, generally as a result of the drilling moratorium and related permitting delays. Service revenues in the first half of 2011 are increasing as compared to levels in the second half of 2010, but are

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still below the levels experienced during the first half of 2010. 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. BOEM officials have recently stated that they are reviewing the possibility of expanding BOEM’s oversight of offshore drilling beyond the oil and gas companies that hold the drilling permits to cover rig suppliers, oilfield service firms, potentially including the Company, and other contractors now outside the scope of BOEM regulations. 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. In addition, there can be no assurance that the Company’s existing products will meet any additional requirements imposed by the BOEM.

Investigations into the incident are ongoing by the Departments of Homeland Security, Interior and Justice, and the U.S. Chemical Safety and Hazard Investigation Board. The National Commission on the BP Deepwater Horizon Oil Spill and Offshore Drilling released an investigation report in January 2011 setting forth its conclusions of the causes of the Deepwater Horizon incident. 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 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 (“CWA”), which carries civil penalties and fines as well as criminal penalties, The Oil Pollution Act of 1990 (“OPA”), 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 ten other lawsuits arising out of the Deepwater Horizon incident. These actions were filed against the Company between April 28, 2010 and March 11, 2011. As of July 21, 2011, all of these lawsuits remain consolidated, along with hundreds of other lawsuits not directly naming 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 lawsuits generally allege, among other things, violation of state and federal environmental and other laws and regulations, negligence, gross negligence, strict liability, personal injury 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 but related 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 its freight. On February 18, 2011, Transocean filed a Third-Party Complaint, tendering the Company to the plaintiffs/claimants in the Limitation Action. The procedural effect of Transocean’s action is to make the Company a defendant in any of the actions where the plaintiff has filed a claim in the Limitation Action. As of July 21, 2011, over 100,000 claims have been filed in the Limitation Action using a short-form joinder claim process implemented by the court. 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 named party. In April 2011, the Company moved to dismiss Transocean’s Third-Party Complaint and the consolidated complaints alleging economic losses from the oil spill and personal injury or property damage

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arising from efforts to contain and clean up the oil spill. The Company contends that those complaints fail to satisfy federal pleading standards, fail to allege facts necessary to support their theories of recovery and/or allege claims that are preempted by OPA. Also in April 2011, the Company filed its answer to Transocean’s Limitation petition denying all claims and responsibility for the incident and denying Transocean’s right to limit its liability. The Company also filed cross claims against Transocean seeking contribution from Transocean in the event the Company is found liable for damages arising from the incident.

In April and May 2011, Transocean, Cameron International Corporation (“Cameron”), Halliburton Energy Services, Inc. (“Halliburton”), M-I, LLC (“M-I”), and Weatherford U.S. LP and Weatherford International, Inc. (collectively, “Weatherford”) each filed cross claims against the Company in the MDL Proceeding and/or in the Limitation Action, generally seeking subrogation and/or contribution from the Company and alleging negligence, comparative fault and strict liability for manufacturing, design and marketing defects by the Company. In May 2011, the Company filed cross claims against Anadarko Petroleum Corporation, Anadarko E&P Company, LP, BP, BP P.L.C., BP America Production Company, Cameron, Halliburton, M-I, Weatherford, MOEX Offshore 2007 LLC, MOEX USA Corporation and Mitsui Oil Exploration Co., Ltd. in the Limitation Action seeking contribution from the cross claimants and alleging that the cross claimants are or may be liable in whole or in part for the claims asserted against the Company in connection with the Deepwater Horizon incident.

In May 2011, Transocean filed a Third-Party Complaint against the Company, impleading it into an action brought by the United States in connection with the Deepwater Horizon incident against Transocean, BP and certain of its affiliates, Anadarko Petroleum Corporation and certain of its affiliates, and MOEX Offshore 2007, LLC as “Responsible Parties” under OPA and for violations of CWA. Transocean’s Third-Party Complaint alleges comparative fault and strict liability for manufacturing, design and marketing defects by the Company and generally seeks subrogation and/or contribution from the Company.

In June 2011, BP and its affiliate BP America Production Company filed counterclaims against the Company in the MDL Proceeding and in the Limitation Action generally seeking subrogation and/or contribution from the Company.

For every complaint, cross claim, third-party complaint and/or counterclaims alleging fault on the part of the Company for the Deepwater Horizon incident, the Company has moved to dismiss the allegations contained in the complaint, cross claim, third-party complaint, and/or counterclaim because the Company contends that those complaints fail to satisfy federal pleading standards and fail to allege facts necessary to support theories of recovery against the Company.

The Company intends to continue 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 Company has received a “reservation of rights” letter from its insurers. 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.

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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.

Brazilian Tax Issue

In December 2010 and January 2011, the Company’s Brazilian subsidiary was served with assessments collectively valued at approximately BRL24.4 million (approximately USD15.6 million as of June 2011) from the State of Rio de Janiero, Brazil, to cancel credits resulting from the importation of goods and subsequent transfers to the Company’s subsidiary in Brazil. The Company believes that its subsidiary should not be subject to the cancellation of credits 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. While pending, the amount of interest, penalties and monetary restatement fees on the tax assessments continues to accrue. As of June 2011, the total assessment, including interest, penalties and possible monetary restatement fees is approximately BRL25.3 million (approximately USD16.2 million).

General

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.

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.

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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 unaudited condensed consolidated financial statements. This discussion should be read in conjunction with the unaudited condensed consolidated financial statements and the discussion in Part II, Item 1A “Risk Factors,” presented elsewhere in this Form 10-Q, as well as the discussion under “Risk Factors,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the annual consolidated financial statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2010.

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 assistance 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.

Deepwater Horizon Incident

On April 22, 2010, a deepwater Gulf of Mexico drilling rig known as the Deepwater Horizon, operated by BP, sank after an explosion and fire that began on April 20, 2010. The Department of Interior issued an order imposing a moratorium on deepwater drilling in the U.S. Gulf of Mexico that was lifted on October 12, 2010. The Company’s revenues and earnings may be affected by, among other things, new or revised governmental laws or regulations relating to offshore oil and gas exploration and production activities, both in the U.S. Gulf of Mexico and in other areas in which the Company’s customers operate, and the effect of such laws or regulations on the level of demand for the Company’s products and services. For additional information related to the impact of the Deepwater Horizon incident on the Company’s product and service revenues, as well as information related to litigation and additional governmental investigations and regulations arising out of the incident, see “Commitments and Contingencies,” Note 6 of the Notes to Condensed Consolidated Financial Statements and Part II, Item 1, “Legal Proceedings.” In addition, as a result of recent scrutiny of the offshore drilling industry triggered by the Deepwater Horizon incident, the technical specifications for the Company’s existing and future products may change resulting in additional testing of its products to ensure their compliance with such specifications. If the Company’s products are unable to satisfy the requirements of the additional testing, or if the costs of the modifications to such products necessary to satisfy the testing are not acceptable to the Company’s customers, the customers may terminate their contracts with the Company or decide not to purchase 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. Declines in oil and gas prices may adversely affect the willingness of some oil and gas companies to make capital expenditures on exploration, drilling and production operations offshore, which could have an adverse impact on the Company’s operations, financial position or cash flows.

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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 the periods covered by this report:

During the second quarter of 2011, crude oil closing prices ranged between $90.65 and $113.39 per barrel with an average quarterly price of $102.02 per barrel, as compared to a range of $68.01 and $86.84 per barrel with the average quarterly price of $78.05 per barrel for the same period in 2010. For the six months ended June 30, 2011 and 2010, crude oil closing prices averaged $98.08 and $78.46, respectively, and ranged between $83.13 per barrel and $113.39 per barrel, as compared to a range of $68.01 to $86.84 per barrel for the same period in 2010. West Texas Intermediate crude oil prices ended the second quarter of 2011 at $95.30 per barrel and Henry Hub natural gas prices at June 30, 2011 were $4.51 per Mcf.

According to the July 2011 release of the Short-Term Energy Outlook published by the EIA, West Texas Intermediate crude oil prices are projected to average $98.43 per barrel for the full year 2011 and $102.50 per barrel in 2012. The EIA projects that world consumption will grow by 1.4 million barrels per day in 2011 and 1.6 million barrels per day in 2012. In July 2011, the EIA projected Henry Hub natural gas prices to average $4.39 per Mcf over the second half of 2011 and $4.68 per Mcf in 2012. In its July 2011 Oil Market Report, the International Energy Agency (“IEA”) stated that global demand is estimated to be 89.5 million barrels per day for 2011, increasing to 91.0 million barrels per day in 2012. On June 23, 2011, in response to the ongoing Libyan crisis, the IEA announced the coordinated release of 60 million barrels of strategic stocks for an initial 30 day period.

Rig Count

Detailed below is the average contracted rig count for the Company’s geographic regions for the three and six months ended June 30, 2011 and 2010. The rig count data includes floating rigs (semi-submersibles and drillships) and jack-up rigs. The Company has included only these types of rigs as they are the primary end users of the Company’s products.

Source: ODS – Petrodata RigBase – June 30, 2011 and 2010

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 June 30, 2011, there were 58 rigs under contract in the U.S. Gulf of Mexico (33 jack-up rigs and 25 floater rigs). Of the total contracted, 46 were actively drilling (28 jack-up rigs and 18 floating rigs). As of June 30, 2010, there were 64 rigs under contract in the U.S. Gulf of Mexico and 35 of these were actively drilling (26 jack-up rigs and 9 floating rigs). As of April 20, 2010, the day the fire started on the Deepwater Horizon, there were 70 rigs under contract in the U.S. Gulf of Mexico and 68 of these were actively drilling (38 jack-up rigs and 30 floating rigs).

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The Company believes that the number of rigs (semi-submersibles, jack-ups and drillships) under construction impacts its revenue 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 tends to negatively impact the Company’s backlog. According to ODS-Petrodata, at the end of both June 2011 and 2010, there were 144 and 123 rigs, respectively, under construction. The expected delivery dates for the rigs under construction on June 30, 2011 are as follows:

Regulation

The demand for the Company’s products and services is also affected by laws and regulations relating to the oil and gas industry in general, including those specifically directed to offshore operations. The adoption of new laws and regulations, or changes to existing laws or regulations, that curtail exploration and development drilling 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 6 of the Notes to Condensed 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. The civil unrest in Egypt and Libya and the devastation in Japan have contributed to the volatility of crude oil process. 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 believes that its backlog should help mitigate the impact of negative market conditions; however, a prolonged decline in commodity prices, an extended continuation of the downturn in the global economy or future restrictions or declines in offshore oil and gas exploration and production could have a negative impact on the Company and/or its backlog. The Company’s backlog at June 30, 2011 was approximately $727 million compared to approximately $655 million at March 31, 2011, $627 million at December 31, 2010, and $538 million at June 30, 2010. The Company can give no assurance that backlog will remain at current levels. All of the Company’s projects currently included in its backlog are subject to change and/or termination at the option of the customer. If the Company’s existing or future products are unable to satisfy the requirements for any testing required by its customers or additional testing triggered by the Deepwater Horizon incident, or if the costs of the modifications to such products necessary to satisfy the testing are not acceptable to the Company’s customers, the customers may terminate their contracts with the Company. In addition, if the Company is unable to use a third party’s technology or purchase a component from a third party that is required under a contract, the Company may not be able to meet existing contractual commitments. In the

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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.

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. For each of the six months ended June 30, 2011 and 2010, the Company derived 85% and 86%, respectively, of its revenues from the sale of its products and 15% and 14%, respectively, of its revenues from services. 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 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.

The Company accounts for larger and more complex projects that have relatively longer manufacturing time frames on a percentage-of-completion basis. For the first six months of 2011, 12 projects representing approximately 23% of the Company’s total revenues and 27% of its product revenues were accounted for using percentage-of-completion accounting, compared to 14 projects representing approximately 19% of the Company’s total revenue and 22% of its product revenue for the first six months of 2010. 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.

The Company has substantial international operations, with approximately 78% and 58% of its revenues derived from foreign sales for the three months ended June 30, 2011 and 2010, respectively, and 70% and 57% for the six months ended June 30, 2011 and 2010, respectively. Substantially all of the Company’s domestic revenue relates to operations in the U.S. Gulf of Mexico. Domestic revenue approximated 22% and 42% of the Company’s total revenues for the three months ended June 30, 2011 and 2010, respectively, and 30% and 43% of the Company’s total revenues for the six months ended June 30, 2011 and 2010, respectively.

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

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At this time, the Company is unable to quantify the extent of the full 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, in the second half of 2011. The decreases in subsea and surface equipment revenues for the three and six month periods ended June 30, 2011 compared to the same periods ended June 30, 2010 in the U.S. Gulf of Mexico were essentially due to the 2010 drilling moratorium and subsequent permitting delays in the U.S. Gulf of Mexico which resulted in a decrease in the number of rigs actively drilling between the time of the Deepwater Horizon incident and June 2011. The decreases in offshore rig equipment revenues for the three and six month periods ended June 30, 2011 compared to the same periods ended June 30, 2010 in the U.S. Gulf of Mexico were not specifically attributable to the 2010 drilling moratorium. The decreases are primarily related to the timing of the recognition of offshore rig equipment revenues for certain percentage-of-completion projects located in the U.S. Gulf of Mexico.

In addition, the Company believes that the U.S. Gulf of Mexico service revenues could continue to be negatively impacted in the second half of 2011 by permitting delays related to the drilling moratorium. The Company’s U.S. Gulf of Mexico service revenues totaled approximately $6.3 million and $7.4 million, respectively, for the three months ended June 30, 2011 and 2010. For the six months ended June 30, 2011 and 2010, U.S. Gulf of Mexico service revenues totaled approximately $10.7 million and $16.9 million, respectively.

The Company will continue to monitor the effects of the drilling moratorium and permitting delays on its ongoing business operations.

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.

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Results of Operations

The following table sets forth, for the periods indicated, certain statement of operations data expressed as a percentage of revenues:

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

Three Months Ended June 30, 2011 Compared to Three Months Ended June 30, 2010.

Revenues.    Revenues decreased by $5.0 million, or approximately 3.5%, to $137.0 million in the three months ended June 30, 2011 from $142.0 million in the three months ended June 30, 2010. Product revenues decreased by approximately $7.7 million for the three months ended June 30, 2011 compared to the same period in 2010 as a result of decreased revenues of $26.1 million in offshore rig equipment and $1.9 million in surface equipment, partially offset by a $20.3 million increase in subsea equipment. Product revenues decreased in the Western Hemisphere by approximately $27.8 million and in Asia-Pacific by $2.6 million, partially offset by an increase in product revenues of $22.7 million in the Eastern Hemisphere. The decrease in product revenues in the Western Hemisphere was primarily attributable to decreases of $20.9 million in revenues related to offshore rig