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 its 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.
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 headquarter locations as well as Macae, Brazil. The Company maintains additional facilities for fabrication and/or reconditioning in Norway, Denmark, 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. Both are wholly owned subsidiaries of DQE. 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 2008 the Company generated approximately 69% of its revenues from foreign sales compared to 69% and 65% in 2007 and 2006, respectively.
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. Together, Messrs. Reimert, Smith and Walker have over 100 years of combined 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, on average.
The Company makes available free of charge on its website its annual report on Form 10-K, quarterly reports on Form 10-Q, 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 we file with the SEC.
Additionally, the Company makes available free of charge on its internet website:
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its Code of Business Conduct and Ethical Practices,
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its Corporate Governance Guidelines,
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its Nominating, Governance, and Compensation Committee Charter, and
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its 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 within five business days and maintained for at least twelve months.
Industry Overview and Outlook
Both the market for offshore drilling and production equipment and services and the Company’s business are substantially dependent on the financial 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 in which the Company operates. However, in mid-2008, oil and gas prices began to decline. This decline has resulted in reduced capital spending by some oil and gas companies and may result in additional reductions in capital spending. We expect that the need for specialized products will continue and to date, we have not seen a material dropoff in demand for our products during this volatile market period. See “Item 1A.
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.
Our principal stockholders have the ability to significantly influence our management and affairs and matters on which shareholders may vote.
Our principal stockholders, Larry E. Reimert, Gary D. Smith and J. Mike Walker and certain entities they control, beneficially own approximately 25% of our common stock and are able to exert significant control over us. The collective ownership of Messrs. Reimert, Smith 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.
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:
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worldwide economic activity;
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the level of exploration and production activity;
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interest rates and the cost of capital;
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environmental regulation;
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federal, state and foreign policies regarding exploration and development of oil and gas;
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the ability of the Organization of Petroleum Exporting Countries (OPEC) to set and maintain production levels and pricing;
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the cost of exploring and producing oil and gas;
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the cost of developing alternative energy sources;
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the sale and expiration dates of offshore leases in the United States and overseas;
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the discovery rate of new oil and gas reserves in offshore areas;
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technological advances; and
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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. Although hydrocarbon prices improved in recent years until mid-2008 and the level of offshore exploration, drilling and production activity increased during that period, we cannot assure you that such price and activity levels will be sustained and that there will not be continued volatility 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, a significant and prolonged decline in hydrocarbon prices would likely have a material adverse effect on our results of operations.
The global financial crisis may have impacts on our business and financial condition that we currently cannot predict.
The continued credit crisis and related turmoil in the global financial system may have an impact on our business and our financial condition. The current 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 crisis reduces the availability of credit to our customers, 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, the current economic situation 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 65%, 69% and 69% of our revenues derived from foreign sales in each of 2006, 2007 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 to the risks customarily attendant to international operations and investments in foreign countries. Risks associated with our international operations include:
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volatility in general economic, social and political conditions;
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terrorist acts, war and civil disturbances;
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expropriation or nationalization of assets;
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renegotiation or nullification of existing contracts;
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foreign taxation, including changes in law or interpretation of existing law;
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assaults on property or personnel;
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restrictive action by local governments;
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foreign and domestic monetary policies;
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limitations on repatriation of earnings;
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travel limitations or operational problems caused by public health threats; and
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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” for a description of our current dispute regarding a tax assessment 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 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.
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. 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. Such insurance does not, however, 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 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:
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errors in estimates or bidding;
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changes in availability and cost of labor and materials; and
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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 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 method. 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 executive management team, Larry E. Reimert, Gary D. Smith and J. Mike Walker. The loss of any of these officers 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:
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federal, state and local and foreign laws and other regulations relating to the oilfield operations, worker safety and the protection of the environment;
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changes in these laws and regulations; and
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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 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. The modification of existing laws or regulations or the adoption of new laws or regulations imposing more stringent environmental restrictions could adversely affect our operations.
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.
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 2007, our top 15 customers represented approximately 51% of total revenues, with no customer accounting for more than 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.
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.
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, Smith and Walker and certain entities they control. Messrs. Reimert, Smith and Walker and certain entities they control 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:
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limited trading volume in our common stock;
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quarterly variations in operating results;
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general financial market conditions;
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the prices of natural gas and oil;
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announcements by us and our competitors;
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our liquidity;
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changes in government regulations;
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our ability to raise additional funds;
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our involvement in litigation; and
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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.
Item 1B. Unresolved Staff Comments
None.
Item 2.
Item 2. Properties
Major Manufacturing Facilities
Dril-Quip has manufacturing facilities in Houston, Aberdeen, Singapore and Macae, The Houston facility at Eldridge produces in-house a majority of the Company’s forging and heat treatment requirements.
Sales, Service and Reconditioning Facilities
(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 and Singapore.
Item 3.
Item 3. Legal Proceedings
In 2006, the Company entered into a contract in the amount of approximately $47 million with MPF Corp. Ltd. (“MPF”) under which the Company was to construct risers and related equipment to be installed on an offshore drill ship being constructed for MPF. MPF and its affiliates filed a Chapter 11 bankruptcy case in September 2008 in the United States Bankruptcy Court for the Southern District of Texas, Houston Division. Under the Bankruptcy Code, at some point MPF must either assume this contract or reject it. Since MPF is not required to make a decision on the handling of the contract right away, we cannot assure you when our rights under the contract will be clarified. Currently, the Company has possession of all the raw materials purchased to date and work-in-progress under the contract. 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. No further revenue has been recognized since the second quarter of 2008. The Company believes the remaining $4 million of unpaid receivables will be realized through the workings of the contract or through its interest in the partially constructed inventory. While the Company has made filings in the bankruptcy proceedings that it believes are appropriate to protect its rights, there can be no assurance that the Company will be able to receive the expected benefits of the contract with MPF. While the Company does not expect the outcome of this matter to have a material adverse effect on the Company’s operations, financial position or cash flows, the Company may be required to write down or forfeit some portion of the revenues recognized to date if it becomes probable that the Company will not receive such funds.
In August 2007, our Brazilian subsidiary was served with assessments collectively valued at approximately $12.8 million from the State of Rio de Janiero, Brazil, to collect a state tax on the importation of goods. We believe that our subsidiary is not liable for the taxes and are vigorously contesting the assessments in the Brazilian administrative and judicial systems. At this time, the ultimate disposition of this matter cannot presently 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. We do not expect the liability, if any, resulting from these assessments to have a material adverse effect on the Company’s operations, financial position or cash flows.
On December 1, 2006, Cameron International Corporation (“Cameron”) filed a patent infringement suit against the Company in the United States District Court for the District of Delaware. The complaint asserts that the Company has infringed and continues to infringe on certain of Cameron’s patents related to horizontal spool tree technology. The Company denies any liability. To date, the Company has not sold any horizontal spool trees. Cameron seeks injunctive relief and unspecified damages, including attorneys’ fees. Although no assurance can be given with respect to the ultimate outcome of this matter, 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.
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 operations, financial position or cash flows.
Item 4.
Item 4. Submission of Matters to a Vote of Security Holders
No matters were submitted to a vote of security holders of the Company during the quarter ended December 31, 2008.
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, 2009) and positions of the Company’s executive officers:
Larry E. Reimert is Co-Chairman of the Board and Co-Chief Executive Officer with principal responsibility for engineering, product development and finance. He has been the Director-Engineering, Product Development and Finance, as well as a member of the Board of Directors, since the Company’s inception in 1981. Prior to that, he worked for Vetco Offshore, Inc. in various capacities, including Vice President of Technical Operations, Vice President of Engineering and Manager of Engineering. Mr. Reimert holds a BSME degree from the University of Houston and an MBA degree from Pepperdine University.
Gary D. Smith is Co-Chairman of the Board and Co-Chief Executive Officer with principal responsibility for sales, service, training and administration. He has been the Director-Sales, Service, Training and Administration, as well as a member of the Board of Directors, since the Company’s inception in 1981. Prior to that, he worked for Vetco Offshore, Inc. in various capacities, including General Manager and Vice President of Sales and Service.
J. Mike Walker is Co-Chairman of the Board and Co-Chief Executive Officer with principal responsibility for manufacturing, purchasing and facilities. He has been the Director-Manufacturing, Purchasing and
Facilities, as well as a member of the Board of Directors, since the Company’s inception in 1981. Prior to that, 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 has been Chief Financial Officer since March 1999. Prior to that, he served as Chief Accounting Officer since joining the Company in 1992. 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 from the University of Texas at Austin.
PART II
Item 5.
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 2007 and 2008.
There were approximately 38 stockholders of record of the Company’s Common Stock as of February 16, 2009. 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 have been retired.
There were no repurchases of our equity securities during the fourth quarter of 2008.
Item 6.
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.
The Company adopted Statement of Financial Accounting Standards No. 123(R), “Share-Based Payment,” effective January 1, 2006. During the years ended December 31, 2006, 2007 and 2008 stock-based compensation expense on a pre-tax basis totaled $1.8 million, $2.3 million and $3.2 million, respectively. No stock-based
compensation expense was capitalized during these years. Additionally, all share and per share data has been adjusted for all periods presented for the two-for-one stock split effective October 5, 2006.
Item 7.
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 and rental of running and installation tools for use in connection with the installation and retrieval of its products.
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, oil (West Texas Intermediate Cushing Crude Oil) and natural gas (Henry Hub Natural Gas) prices are listed below as averages of the daily closing prices for the years 2006, 2007 and 2008:
In mid July 2008, oil prices spiked to $145.16 per barrel and ended the year in 2008 at $44.60 per barrel. Additionally, by the end of December 2008, gas prices had declined to $5.48 per Mcf. These declines in hydrocarbon prices have adversely affected 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 financial condition and results of operations.
According to the January and February 2009 release of the Short-Term Energy Outlook published by the EIA, West Texas Intermediate crude oil prices are projected to average $43.14 per barrel in 2009 and $54.50 in 2010. In January 2009, the EIA projected Henry Hub gas prices to average $5.78 per Mcf in 2009 and increase to an average of $6.63 per Mcf in 2010. In February 2009 EIA lowered the expectation to $5.01 per Mcf in 2009 and $5.93 per Mcf in 2010. The EIA further predicted OPEC crude oil production to average 30.0 million barrels per day in 2009 and 30.7 million barrels per day in 2010. This estimate was revised downward in February 2009
to 29.4 million barrels per day in 2009 and 30.1 million barrels per day in 2010. In the January 2009 Oil Market Report, the International Energy Agency projected oil demand in 2009 to be 85.3 million barrels per day, compared to an estimated 85.8 million barrels per day in 2008. In February 2009 the International Energy Agency revised the oil demand in 2009 downward to 84.7 million barrels per day.
Detailed below is the average contracted rig count for our geographic regions for the years ended December 31, 2006, 2007 and 2008. The rig count data includes floating rigs (semi-submersibles and drill ships) and jack-ups. We have included only these types of rigs as they are the primary end users of our products.
The table represents rigs under contract and includes rigs currently drilling as well as rigs committed, but not yet drilling. Since mid-2008 the number of active offshore rigs has declined.
We believe that the number of rigs (semi-submersibles, jack-ups and drill ships) under construction impacts our revenue because our customers generally order some of our products during the construction of such rigs. As a result, an increase in rig construction activity tends to favorably impact our backlog. According to ODS-Petrodata, at the end of December 2006 and 2007, there were 112 and 156 rigs under construction, respectively, compared to 172 at the end of December 2008, which represents an increase of 53.5% and 10.3%, respectively.
Due to the significant increase in the oil and gas activity over the past several years, the Company has expanded facilities in all of its major manufacturing locations in Houston, Texas; Aberdeen, Scotland, Macae, Brazil and Singapore. With limited manufacturing capacity in the past, the Company has had to focus on which projects submitted by customers to undertake. In making the decision, the Company takes into consideration such factors as manufacturing time, current projects in progress, delivery requirements, projected gross margins, available personnel and availability of material. Based upon these decisions, it is possible for the Company to have variations between quarters and years based upon product mix.
High 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 has been in the deepwater areas in which the Company operates. However, in mid-2008, oil and gas prices began to decline. This decline has resulted in reduced capital spending by some oil and gas companies and may result in additional reductions in capital spending.
The Company operates its business and markets its products and services in all 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.”
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 service for installation of the Company’s products, reconditioning services and rental of running tools for installation and retrieval of its products. In 2008, the Company derived 84% of its revenues from the sale of its products and 16% of its revenues from services. Service revenues generally correlate to revenues from product sales because increased product sales normally generate increased revenues from technical advisory services during installation and rental of running tools. The Company has substantial international operations, with approximately 65%, 69% and 69% of its revenues derived from foreign sales in 2006, 2007 and 2008, respectively.
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 2006 and 2007, 10 and 16 projects, respectively representing approximately 12% and 19%, of the Company’s total revenues were accounted for using the percentage-of-completion accounting. During 2008, 23 projects representing approximately 25% of the Company’s total revenue and 30% of the Company’s product revenues were accounted for using percentage-of-completion accounting. 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 costs. 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.”
Results of Operations
The following table sets forth, for the periods indicated, certain consolidated statements of income data expressed as a percentage of revenues:
The following table sets forth, for the periods indicated, a breakdown of our products and service revenues:
Year ended December 31, 2008 Compared to Year Ended December 31, 2007
Revenues. Revenues increased by $47.2 million, or approximately 9.5%, to $542.8 million in 2008 from $495.6 million in 2007. Product revenues increased by approximately $35.3 million for the year ended December 31, 2008 compared to the same period in 2007 as a result of increased revenues of $41.3 million in offshore rig equipment and $1.5 million in subsea equipment offset by a $7.5 million decrease in surface equipment. The increase in offshore rig equipment was primarily due to the increase in the number of long-term projects. During 2007 there were 16 projects, compared to 23 projects during 2008 and the majority of these projects related to offshore rig equipment. Of the Company’s total product revenues, product revenues increased in the Western Hemisphere, Eastern Hemisphere and Asia-Pacific by $26.5 million, $6.0 million and $2.8 million, respectively. Service revenues increased by approximately $11.9 million from increased service revenues in the Western Hemisphere of $4.8 million, Eastern Hemisphere of $2.0 million Asia-Pacific of $5.1 million. The majority of the increases in service revenues related to an increase in technical advisory assistance and reconditioning services.
Cost of Sales. Cost of sales increased by $27.0 million, or approximately 9.5%, to $312.3 million for 2008 from $285.3 million for the same period in 2007. As a percentage of revenues, cost of sales were approximately 57.6% in 2007 and 57.5% in 2008. Cost of sales as a percentage of revenue remained relatively consistent between 2007 and 2008. The increase in cost of sales in 2008 as compared to 2007 is basically consistent with the increase in revenue.
Selling, General and Administrative Expenses. For 2008, selling, general and administrative expenses increased by approximately $13.1 million, or 26.6%, to $62.4 million from $49.3 million in 2007. The increase in selling, general and administrative expenses were due to increased labor and overhead expenses resulting from increased staffing levels in the areas of sales and administration, increases in legal and professional fees, stock option expenses and the effect of foreign currency transaction gains and losses. The Company experienced approximately $3.0 million in pre-tax foreign currency transaction gains during 2007 versus approximately $2.1 million in pre-tax foreign currency transaction losses during 2008. 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. Selling, general and administrative expenses as a percentage of revenues were 9.9% in 2007 and 11.5% in 2008.
Engineering and Product Development Expenses. For 2008, engineering and product development expenses increased by $3.8 million, or approximately 16.8%, to approximately $26.4 million from $22.6 million in 2007. This increase was due primarily to an increase in personnel and associated operating expenses. Engineering and product development expenses as a percentage of revenues increased from 4.6% in 2007 to 4.9% in 2008.
Interest Income. Interest income for 2008 was $3.5 million as compared to $8.3 million in 2007. This decrease was due to a reduction in interest earned on short-term investments caused by lower interest rates and reduced balances in short-term investments. Due to the global financial crisis, the Company has transferred the
majority of its short-term investments to funds which invest in U.S. Treasury obligations, which normally earn lower interest rates than money market funds. Short-term investment balances declined primarily as a result of expenditures of $100 million related to the Company’s share repurchase program.
Interest expense. Interest expense for 2008 was $182,000 compared to $370,000 in 2007.
Income tax provision. Income tax expense for 2008 was $39.4 million on income before taxes of $145.0 million, resulting in an effective income tax rate of approximately 27.2%. Income tax expense in 2007 was $38.3 million on income before taxes of $146.3 million, resulting in an effective tax rate of approximately 26.2%. In the fourth quarter of 2007 the Company benefited from a foreign development tax incentive which resulted in a reduction in income taxes of approximately $4.7 million.
Net Income. Net income was approximately $105.6 million in 2008 and $107.9 million in 2007, for the reasons set forth above.
Year ended December 31, 2007 Compared to Year Ended December 31, 2006
Revenues. Revenues increased by $52.9 million, or approximately 11.9%, to $495.6 million in 2007 from $442.7 million in 2006. Product revenues increased by approximately $45.5 million for 2007 as compared to 2006 as a result of increased revenues of $58.9 million in offshore rig equipment and $7.5 million in surface equipment offset by a decrease of $20.9 million in subsea equipment. The increase in offshore rig equipment was primarily due to the increase in the number of long-term projects. During 2006 there were 10 projects, compared to 16 projects during 2007 and the majority of these projects related to offshore rig equipment. On a geographic basis, product revenues increased in the Western Hemisphere, Eastern Hemisphere and Asia-Pacific by $12.7 million, $12.3 million and $20.5 million, respectively. Service revenues increased by approximately $7.4 million from increased service revenues in the Western Hemisphere of $5.0 million and Eastern Hemisphere of $3.7 million and slightly offset by a decrease in Asia-Pacific of $1.3 million. The majority of the increase in service revenues was due to higher technical advisory assistance and reconditioning services.
Cost of Sales. Cost of sales increased by $28.6 million, or approximately 11.1%, to $285.3 million for 2007 from $256.7 million for the same period in 2006. As a percentage of revenues, cost of sales were approximately 57.9% in 2006 and 57.6% in 2007. The reduction in cost of sales as a percentage of revenues resulted primarily from changes in product mix.
Selling, General and Administrative Expenses. For 2007, selling, general and administrative expenses increased by approximately $5.2 million, or 11.8%, to $49.3 million from $44.1 million in 2006. The increase in selling, general and administrative expenses was primarily due to increased labor and overhead expenses resulting from increased staffing levels in the areas of sales and administration and increases in legal and professional fees. The Company experienced approximately $2.2 million in pre-tax foreign currency transaction gains during 2006 versus approximately $3.0 million in pre-tax foreign currency transaction gains during 2007. Selling, general and administrative expenses as a percentage of revenues were 10.0% in 2006 and 9.9% in 2007.
Engineering and Product Development Expenses. For 2007, engineering and product development expenses increased by $3.0 million, or approximately 15.3%, to approximately $22.6 million from $19.6 million in 2006. This increase was due primarily to an increase in personnel and associated operating expenses. Engineering and product development expenses as a percentage of revenues increased from 4.4% in 2006 to 4.6% in 2007.
Interest Income. Interest income for 2007 was $8.3 million as compared to $3.6 million in 2006. The increase was due to interest earned on short-term investments resulting from excess cash flows generated.
Interest expense. Interest expense for 2007 was $370,000 compared to $669,000 in 2006. This decrease was due to the partial pay down of long-term debt and a reduction in commitment fee expenses related to the Company’s unsecured revolving line of credit.
Income tax provision. Income tax expense for 2007 was $38.3 million on income before taxes of $146.3 million, resulting in an effective income tax rate of approximately 26.2%. Income tax expense in 2006 was $38.5 million on income before taxes of $125.4 million, resulting in an effective tax rate of approximately 30.7%. This decrease in the effective tax rate reflects a reduction in foreign tax rates resulting from a foreign development tax incentive and increased tax benefits for manufacturing companies located in the United States of America.
Net Income. Net income was approximately $107.9 million in 2007 and $86.9 million in 2006, for the reasons set forth above.
Liquidity and Capital Resources
Cash flows provided by (used in) operations by type of activity were as follows:
Statements of cash flows for entities with international operations that are local currency functional exclude the effects of the changes in foreign currency exchange rates that occur during any given year, as these are noncash changes. As a result, changes reflected in certain accounts on the consolidated statements of cash flows may not reflect the changes in corresponding accounts on the Consolidated Balance Sheets.
The primary liquidity needs of the Company are (i) to fund capital expenditures to improve and expand facilities and manufacture additional running tools and (ii) to fund working capital. Recently, the Company’s principal sources of funds have been cash flows from operations.
During 2008, the Company generated $40.7 million of cash from operations as compared to $82.7 million for the same period in 2007. The primary reasons for the decrease were the changes in operating assets and liabilities during 2008 as compared to the same period in 2007. Cash totaling approximately $84.5 million was utilized during 2008 to increase operating assets and liabilities, compared to a $42.3 million increase in operating assets and liabilities during the same period in 2007. The increase in operating assets and liabilities during 2008 primarily reflected an increase of $62.1 million in inventories due to a $174 million increase in backlog. Customer prepayments, included in trade accounts payable and other accrued expenses, increased over $25 million in 2008 due to the increase in the number of projects. Also, an increase in accounts receivable of $46.9 million was largely due to increases in unbilled project receivables.
Capital expenditures by the Company were $24.1 million, $25.2 million and $50.1 million in 2006, 2007 and 2008, respectively. Capital expenditures in 2006 and 2007 included expanding manufacturing facilities in the Western Hemisphere and increased expenditures on machinery and equipment and running tools due to expanded operations. The capital expenditures for 2008 were primarily $16.8 million for machinery and equipment, $20.8 million for facilities and $9.3 million running tools and other expenditures of $3.2 million. Principal payments on long-term debt were approximately $800,000, $900,000 and $800,000 in 2006, 2007 and 2008, respectively.
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 have been retired.
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, 2008:
(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, 2008.
The Company has a credit facility with Guaranty Bank, FSB providing an unsecured revolving line of credit of up to $10 million. At the option of the Company, borrowing under this facility bears interest at either a rate equal to LIBOR (London Interbank Offered Rate) plus 1.75% or the Guaranty Bank base rate. The facility calls for quarterly interest payments and terminates on June 1, 2009. The facility also contains certain covenants including maintaining minimum tangible net worth levels, not exceeding specified funded debt amounts and required interest coverage ratios. As of December 31, 2007 and 2008, the Company had no borrowings under this facility and was in compliance with all loan covenants.
Dril-Quip (Europe) Limited has a credit agreement with the Bank of Scotland dated March 21, 2001 in the original amount of U.K. Pounds Sterling 4.0 million (approximately U.S. $5.8 million). Borrowing under this facility bears interest at the Bank of Scotland base rate, which was 2.0% at December 31, 2008, 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, 2007 and 2008 was approximately U.S. $2.7 million and U.S. $1.4 million, 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 and its current line of credit will be sufficient to fund operations, working capital needs and anticipated capital expenditure requirements in 2009. 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 adequate to meet such requirements.
Backlog
Backlog consists of firm customer orders for which a purchase order 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 $336 million and $429 million at December 31, 2006 and 2007, respectively, compared to $603 million at December 31, 2008, an increase of $267 million and $174 million or 79% and 41%, respectively. This increase in backlog is primarily due to the increased oil and gas prices in early 2008. The lead time on many of the projects extends for a year or more and several large projects were started in 2008. The Company expects to fill approximately 65% of the December 31, 2008 backlog by December 31, 2009. The remaining backlog at December 31, 2008 consists of longer-term projects which are being designed and manufactured to customer specifications requiring longer lead times. The backlog amount at December 31, 2008 excludes $27 million related to the MPF contract as discussed in “Item 3 - Legal Proceedings.”
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 fluctuated significantly between 2005 and mid-2008. 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 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 and Mexico; 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 (“BRR”) 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 2006, 2007 and 2008, the Company had, net of income taxes, gains of $1.5 million and $2.2 million, and a loss of $1.5 million, respectively. The gain in 2006 was primarily due to large intercompany receivable balances due to the Company from its U.K. subsidiary, payments on the intercompany loans recorded at the historical rate, as well as the strengthening of the British pound sterling compared to the U.S. dollar. U.K. intercompany balances were converted to an intercompany loan at the end of September 2006. The GBP rose as compared to the U.S. dollar from an average of 1.77 in January 2006 to an average rate of 1.96 in December 2006. The gain in 2007 was principally due to the weakening of the U.S. dollar to the Brazilian real on the intercompany payables between Brazil and the United States. The BRR rose as compared to the U.S. dollar from the average of 0.47 in January 2007 to an average rate of 0.56 in December 2007. The loss in 2008 was primarily due to strengthening of the
U.S. dollar compared to the Brazilian real on the intercompany payables between Brazil and the United States. The BRR fell as compared to the U.S. dollar from an average of 0.59 for the first nine months of 2008 to an average rate of 0.44 for the fourth quarter of 2008.
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 and, to a lesser extent, Singapore, Brazil and 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. 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:
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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 Statement of Position 81-1 “Accounting for Performance of Construction-Type and certain Production Type-Contracts.” Long-term project contracts have the following characteristics:
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The contracts call for products which are designed to customer specifications;
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The structural design is unique and requires significant engineering and manufacturing efforts generally requiring more than one year in duration;
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The contracts contain specific terms as to milestones, progress billings and delivery dates;
•
Product requirement 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. At December 31, 2007 and 2008, trade receivables included $18.1 million and $44.8 million of unbilled receivables, respectively. During 2008, 23 projects representing approximately 25% and 30% of the Company’s total revenue and product revenue, respectively, 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 is complete and ownership is transferred to the customer.
Service revenue
The Company earns service revenues from three sources:
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technical advisory assistance;
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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 our customers, but we provide technical advisory assistance. At the time of delivery of the product, the customer is not obligated to buy or rent our 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 when the product will be installed and if 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. Inventory is valued principally using standard costs, which are calculated based upon direct costs incurred and overhead allocations. 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 $19.2 million and $20.8 million were recorded as of December 31, 2007 and 2008, respectively. If market conditions are less favorable than those projected by management, additional inventory reserves may be required.
Contingent liabilities. We establish reserves for estimated loss contingencies when we believe a loss is probable and the amount of the loss can be reasonably estimated. Revisions to contingent liabilities are reflected
in income in the period in which different facts or information become known or circumstances change that affect our previous assumptions with respect to the likelihood or amount of loss. Reserves for contingent liabilities are based upon our assumptions and estimates regarding the probable outcome of the matter. Should the outcome differ from our 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 or contracts or operations that rely upon credit or similar ratings.
New Accounting Standards
In December 2007, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards (“SFAS”) No. 141 (revised 2007), “Business Combinations” (SFAS 141(R)). SFAS 141(R) replaces Statement No. 141, “Business Combinations.” The statement retains the purchase method of accounting used in business combinations but replaces SFAS 141 by establishing principles and requirements for the recognition and measurement of assets, liabilities and goodwill including the requirement that most transaction costs and restructuring costs be expensed. In addition, the statement requires disclosures to enable users to evaluate the nature and financial effects of the business combination. SFAS 141(R) is effective for business combinations when the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. We will adopt SFAS 141(R) on January 1, 2009 for business combinations on or after this date.
In December 2007, the FASB issued SFAS No. 160, “Noncontrolling Interest in Consolidated Financial Statements-an amendment to ARB No. 51” (SFAS 160) which establishes accounting and reporting standards for noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. The provision of SFAS 160 are effective for fiscal years beginning after December 15, 2008. The Company does not believe the provisions of this statement will materially effect the results of operations.
In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities-Including an amendment of FASB Statement No. 115” (SFAS 159). SFAS 159 permits entities to choose to measure eligible financial assets and liabilities at fair value. Unrealized gains and loses on items for which the fair value option has been elected are reported in earnings. SFAS 159 is effective for years beginning after November 15, 2007. We adopted SFAS 159 on January 1, 2008 and did not elect to apply the fair value method to any eligible assets or liabilities at that time.
The Company adopted the provisions of FASB Interpretation No. 48, “Accounting for Uncertainty in Income Taxes, an interpretation of FASB Statement 109” (“FIN 48”), on January 1, 2007. FIN 48 was issued in June 2006 and prescribes that the Company 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 interpretation provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. Based on our evaluation, we have concluded that there are no significant uncertain tax positions requiring recognition in our financial statements. Our evaluation was performed for the tax years which remain subject to examination by major tax jurisdictions as of December 31, 2008, which are the years ended December 31, 2003 through 2008. We may from time to time be assessed interest or penalties by major tax jurisdictions, although any such assessments historically have been minimal and immaterial to our financial results.
In September 2006, the FASB issued SFAS Statement No. 157, “Fair Value Measurements” (SFAS 157), which defines fair value, establishes a framework for measuring fair value under generally accepted accounting principles, and expands disclosures under fair value measurements. SFAS 157 applies to other accounting pronouncements that require or permit fair value measurements. SFAS 157 is effective for fiscal years beginning after November 15, 2007. However, on February 12, 2008, the FASB issued FSP (FASB Staff Position) FAS 157-2 which would delay the effective date of SFAS 157 for all nonfinancial assets and nonfinancial
liabilities, except those that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). This FSP partially defers the effective date of SFAS 157 to fiscal years beginning after November 15, 2008, and interim periods within those fiscal years for items within the scope of this FSP. Effective January 1, 2008, we adopted SFAS 157 except as it applies to those nonfinancial assets and nonfinancial liabilities as noted in FSP FAS 157-2. In October 2008, the FASB issued FSP FAS 157-3, “Determining the Fair Value of a Financial Asset When the Market for That Asset Is Not Active.” FSP FAS 157-3 clarifies the application of SFAS 157 in a market that is not active and addresses application issues such as use of internal assumptions when relevant observable data does not exist, the use of observable market information when the market is not active and the use of market quotes when assessing the relevance of observable and unobservable data. FSP FAS 157-3 was effective immediately and did not have an impact on the Company upon adoption. The Company did not have any assets or liabilities that would be recognized or disclosed on a fair value basis as of December 31, 2008. Cash and cash equivalents include investments in various financial instruments which are carried at cost.
Item 7A.
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 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 result in a decrease in revenues of approximately $22 million and a decrease in net income of approximately $8 million over this period. 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 two credit facilities or loans that require the Company to pay interest at a floating rate. These floating-rate obligations expose 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, 2008 balance of approximately $1.4 million related to these floating rate obligations, each 1.0% rise in interest rates would result in additional annual interest expense to the Company of approximately $14,000, or $3,500 per quarter.
Item 8.
Item 8. Financial Statements and Supplementary Data
Page
Management’s Annual Report on Internal Control over Financial Reporting
Reports of Independent Registered Public Accounting Firm
Consolidated Statements of Income for the Three Years in the Period Ended December 31, 2008
Consolidated Balance Sheets as of December 31, 2007 and 2008
Consolidated Statements of Cash Flows for the Three Years in the Period Ended December 31, 2008
Consolidated Statements of Stockholders’ Equity for the Three Years in the Period Ended December 31, 2008
Notes to Consolidated Financial Statements
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, 2008.
BDO Seidman, LLP, the independent registered public accounting firm, which audited the consolidated financial statements included in the annual report, has also issued an attestation on our internal control over financial reporting, and their report is set forth on page 35.
Report of Independent Registered Public Accounting Firm
Board of Directors and Shareholders
Dril-Quip, Inc.
Houston, Texas
We have audited Dril-Quip, Inc.’s internal control over financial reporting as of December 31, 2008, 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 9A. 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, 2008, 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, 2008 and 2007, and the related consolidated statements of income, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2008 and our report dated February 26, 2009 expressed an unqualified opinion thereon.
/s/ BDO Seidman, LLP
Houston, Texas
February 26, 2009
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, 2008 and 2007 and the related consolidated statements of income, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2008. 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, 2008 and 2007, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2008, 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), the effectiveness of Dril-Quip, Inc.’s internal control over financial reporting as of December 31, 2008, 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 26, 2009, expressed an unqualified opinion thereon.
/s/ BDO Seidman, LLP
Houston, Texas
February 26, 2009
DRIL-QUIP, INC.
CONSOLIDATED STATEMENTS OF INCOME
The accompanying notes are an integral part of these statements.
DRIL-QUIP, INC.
CONSOLIDATED BALANCE SHEETS
The accompanying notes are an integral part of these statements.
DRIL-QUIP, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
The accompanying notes are an integral part of these statements.
DRIL-QUIP, INC.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
The accompanying notes are an integral part of these statements.
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. Both are wholly owned subsidiaries of DQE.
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 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 Treasury obligations. The Company’s investment objectives include the provision of a high level of current income consistent with the preservation of capital and the maintenance of liquidity.
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, 2006, 2007 and 2008:
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. Inventory is valued principally using standard costs, which are calculated based upon direct costs incurred and overhead allocations. 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 $19.2 million and $20.8 million were recorded as of December 31, 2007 and 2008, 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. No impairment of long-lived assets existed at December 31, 2007 or 2008.
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.
Revenue Recognition
Product Revenue
The Company earns product revenues from two sources:
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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 Statement of Position 81-1 “Accounting for Performance of Construction-Type and certain Production Type-Contracts.” Long-term project contracts have the following characteristics:
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The contracts call for products which are designed to customer specifications;
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The structural design is unique and requires significant engineering and manufacturing efforts generally requiring more than one year in duration;
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The contracts contain specific terms as to milestones, progress billings and delivery dates; and
•
Product requirement 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. At December 31, 2007 and 2008, receivables included $18.1 million and $44.8 million of unbilled receivables, respectively. At the end of 2008, there were 23 projects representing approximately 25% of the Company’s total revenue and approximately 30% of its product revenues 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 is complete and ownership is transferred to the customer.
Service revenue
The Company earns service revenues from three sources:
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technical advisory assistance;
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rental of running tools; and
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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 our customers, but we provide
technical advisory assistance. At the time of delivery of the product, the customer is not obligated to buy or rent our 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 when the product will be installed and if 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 increases of $11.4 million and $3.3 million in 2006 and 2007, respectively and a decrease of $42.6 million in 2008. 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 $1.5 million in 2006, $2.2 million in 2007, 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.
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.
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 Treasury obligations. Changes in the financial markets and interest rates could affect the interest earned on short-term investments.
Comprehensive Income
Statement of Financial Accounting Standards (“SFAS”) No. 130 “Reporting Comprehensive Income” establishes the rules for the reporting and display of comprehensive income and its components. SFAS No. 130 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.
Interest Capitalization
The Company capitalizes interest on significant construction projects for which interest costs are being incurred. These projects principally consist of construction or expansion of the Company’s facilities. No interest was capitalized in 2006, 2007 or 2008.
Earnings Per Share
Basic earnings per share is computed by dividing net income by the weighted average number of shares of common stock outstanding during the year. Diluted earnings per share is computed considering the dilutive effect of stock options using the treasury stock method.
New Accounting Standards
In December 2007, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards (“SFAS”) No. 141 (revised 2007), “Business Combinations” (SFAS 141(R)). SFAS 141(R) replaces Statement No. 141, “Business Combinations.” The statement retains the purchase method of accounting used in business combinations but replaces SFAS 141 by establishing principles and requirements for the recognition and measurement of assets, liabilities and goodwill including the requirement that most transaction costs and restructuring costs be expensed. In addition, the statement requires disclosures to enable users to evaluate the nature and financial effects of the business combination. SFAS 141(R) is effective for business combinations when the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. We will adopt SFAS 141(R) on January 1, 2009 for business combinations we engage in on or after this date.
In December 2007, the FASB issued SFAS No. 160, “Noncontrolling Interest in Consolidated Financial Statements-an amendment to ARB No. 51” (SFAS 160) which establishes accounting and reporting standards for noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. The provision of SFAS 160 are effective for fiscal years beginning after December 15, 2008. The Company does not believe the provisions of this statement will materially effect the results of operations.
In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities-Including an amendment of FASB Statement No. 115” (SFAS 159). SFAS 159 permits entities to choose to measure eligible financial assets and liabilities at fair value. Unrealized gains and loses on items for which the fair value option has been elected are reported in earnings. SFAS 159 is effective for years beginning after November 15, 2007. We adopted SFAS 159 on January 1, 2008 and did not elect to apply the fair value method to any eligible assets or liabilities at that time.
The Company adopted the provisions of FASB Interpretation No. 48, “Accounting for Uncertainty in Income Taxes, an interpretation of FASB Statement 109” (“FIN 48”), on January 1, 2007. FIN 48 was issued in June 2006 and prescribes that the Company 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 interpretation provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. Based on our evaluation, we have concluded that there are no significant uncertain tax positions requiring recognition in our financial statements. Our evaluation was performed for the tax years which remain subject to examination by major tax jurisdictions as of December 31, 2008, which are the years ended December 31, 2003 through 2008. The Company has occasionally been assessed interest or penalties by major tax jurisdictions and these assessments historically have been minimal and immaterial to our financial results. In accordance with our accounting policy, both before and
after adoption of FIN 48, interest expense assessed by tax jurisdictions is included with interest expense and assessed penalties are included in selling, general and administrative expenses.
In September 2006, the FASB issued SFAS Statement No. 157, “Fair Value Measurements” (SFAS 157), which defines fair value, establishes a framework for measuring fair value under generally accepted accounting principles, and expands disclosures under fair value measurements. SFAS 157 applies to other accounting pronouncements that require or permit fair value measurements. SFAS 157 is effective for fiscal years beginning after November 15, 2007. However, on February 12, 2008, the FASB issued FSP (FASB Staff Position) FAS 157-2 which would delay the effective date of SFAS 157 for all nonfinancial assets and nonfinancial liabilities, except those that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). This FSP partially defers the effective date of SFAS 157 to fiscal years beginning after November 15, 2008, and interim periods within those fiscal years for items within the scope of this FSP. Effective January 1, 2008, we adopted SFAS 157 except as it applies to those nonfinancial assets and nonfinancial liabilities as noted in FSP FAS 157-2. In October 2008, the FASB issued FSP FAS 157-3, “Determining the Fair Value of a Financial Asset When the Market for That Asset Is Not Active.” FSP FAS 157-3 clarifies the application of SFAS 157 in a market that is not active and addresses application issues such as use of internal assumptions when relevant observable data does not exist, the use of observable market information when the market is not active and the use of market quotes when assessing the relevance of observable and unobservable data. FSP FAS 157-3 was effective immediately and did not have an impact on the Company upon adoption. The Company did not have any assets or liabilities that would be recognized or disclosed on a fair value basis as of December 31, 2008. Cash and cash equivalents include investments in various financial instruments which are carried at cost.
3. Inventories
Inventories consist of the following:
Summary of allowance for obsolete and excess inventory:
4. Property, Plant and Equipment
Property, plant and equipment consists of:
5. Long-Term Debt
Long-term debt consists of the following:
The Company has a credit facility with Guaranty Bank, FSB providing an unsecured revolving line of credit of up to $10 million. At the option of the Company, borrowing under this facility bears interest at either a rate equal to LIBOR (London Interbank Offered Rate) plus 1.75% or the Guaranty Bank base rate. The facility calls for quarterly interest payments and terminates June 1, 2009. The facility also contains certain covenants including maintaining minimum tangible net worth levels, not exceeding specified funded debt amounts and required interest coverage ratios. As of December 31, 2007 and 2008, the Company had no borrowings under this facility and was in compliance with all loan covenants.
Dril-Quip (Europe) Limited has a credit agreement with the Bank of Scotland dated March 21, 2001 in the original amount of U.K. Pounds Sterling 4.0 million (approximately U.S. $5.8 million). Borrowing under this facility bears interest at the Bank of Scotland base rate, which was 2.0% at December 31, 2008, 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, 2007 and 2008 was approximately U.S. $2.7 million and U.S. $1.4 million, 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, 2006, 2007 and 2008 was $749,000, $253,000 and $132,000 respectively. Scheduled maturities of long-term debt are as follows: 2009-$584,000; 2010-$584,000; 2011-$195,000; and none thereafter.
6. Income Taxes
Income before income taxes consisted of the following:
The income tax provision (benefit) consists of the following:
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:
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 benefits will be realized in future years. Significant components of the Company’s deferred tax assets and liabilities are as follows:
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. 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 American Jobs Creation Act of 2004 provides for a tax deduction for qualified production activities. Under the guidance of FASB Staff Position No 109-1, Application of FASB Statement No. 109, “Accounting for Income Taxes,” to the Tax Deduction on Qualified Production Activities Provided by American Jobs Creation Act of 2004, the deduction will be treated as a “special deduction” as described in FASB No. 109 and not as a reduction in the tax rate. As such, the special deduction has no effect on deferred tax assets and liabilities existing on the date of enactment. The Company’s production activities qualify for the tax deduction and the Company’s 2008 tax provision includes an estimated deduction of approximately $4.5 million.
The Company paid $15.2 million, $41.9 million and $40.5 million in income taxes in 2006, 2007 and 2008, respectively.
7. Other Accrued Liabilities
Other accrued liabilities consist of the following:
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 $1.5 million, $2.7 million and $3.0 million in 2006, 2007 and 2008, respectively.
9. Commitments and Contingencies
The Company leases certain office, shop and warehouse facilities, automobiles, and equipment. The Company expenses all lease payments when incurred. Total lease expense incurred was $3.0 million, $2.7 million and $2.6 million in 2006, 2007 and 2008, respectively. Future annual minimum lease commitments, including required leasehold improvements, at December 31, 2008 are as follows: 2009-$1.7 million; 2010-$0.8 million; 2011-$18.9 million; 2012-$3.0 million; 2013-$0.1 million; and thereafter-$2.3 million.
In 2006, the Company entered into a contract in the amount of approximately $47 million with MPF Corp. Ltd. (“MPF”) under which the Company was to construct risers and related equipment to be installed on an offshore drill ship being constructed for MPF. MPF and its affiliates filed a Chapter 11 bankruptcy case in September 2008 in the United States Bankruptcy Court for the Southern District of Texas, Houston Division. Under the Bankruptcy Code, at some point MPF must either assume this contract or reject it. Since MPF is not required to make a decision on the handling of the contract right away, we cannot assure you when our rights under the contract will be clarified. Currently, the Company has possession of all the raw materials purchased to date and work-in-progress under the contract. 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. No further revenue has been recognized since the second quarter of 2008. The Company believes the remaining $4 million of unpaid receivables will be realized through the workings of the contract or through its interest in the partially constructed inventory. While the Company has made filings in the bankruptcy proceedings that it believes are appropriate to protect its rights, there can be no assurance that the Company will be able to receive the expected benefits of the contract with MPF. While the Company does not expect the outcome of this matter to have a material adverse effect on the Company’s operations, financial position or cash flows, the Company may be required to write down or forfeit some portion of the revenues recognized to date if it becomes probable that the Company will not receive such funds.
In August 2007, our Brazilian subsidiary was served with assessments collectively valued at approximately $12.8 million from the State of Rio de Janiero, Brazil, to collect a state tax on the importation of goods. We believe that our subsidiary is not liable for the taxes and are vigorously contesting the assessments in the Brazilian administrative and judicial systems. At this time, the ultimate disposition of this matter cannot presently 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. We do not expect the liability, if any, resulting from these assessments to have a material adverse effect on the Company’s operations, financial position or cash flows.
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 within the next five years.
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 risk 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 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 affect on the Company’s operations, financial position or cash flows.
10. Stockholders’ Equity
The Rights Agreement between the Company and ChaseMellon Shareholder Services, L.L.C. dated as of October 17, 1997 included one right to purchase one one-hundredth of a share of Series A Junior Participating Preferred Stock for each share of common stock. On October 17, 2007, the Rights Agreement and the rights issued thereunder expired by their terms, at which time no shares of the Series A Preferred Stock were issued or outstanding.
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.
11. 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.
Eliminations of operating profits are related to intercompany inventory transfers that are deferred until shipment is made to third party customers.
In 2006, 2007 and 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 was based on the Company’s historical trends and volatility was 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 27, 2006, October 26, 2007 and October 28, 2008 the Company granted options to purchase 264,435, 256,284 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.
Option activity for the year ended December 31, 2008 was as follows:
The total intrinsic value of stock options exercised in 2006, 2007 and 2008 was $52.8 million, $19.9 million and $1.3 million, respectively. The income tax benefit realized from stock options exercised was $461,000 for the year ended December 31, 2008.
Stock-based compensation is recognized as selling, general and administrative expense in the accompanying Consolidated Statements of Income. During the years ended December 31, 2006, 2007 and 2008 stock-based compensation expense totaled $1.8 million, $2.3 million and $3.2 million, respectively. No stock-based compensation expense was capitalized during those years.
While the options granted to employees vest over four years, the Company recognizes compensation expense on a straight-line basis over the vesting period of the options. At December 31, 2008, there was $11.1 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, 2008:
13. Earnings Per Share
The following is a reconciliation of the basic and diluted earnings per share computation as required by Statement of Financial Accounting Standards No. 128, “Earnings per Share”:
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 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 have been retired.
In September 2006, the Board of Directors of the Company approved a two-for-one common stock split in the form of a stock dividend. As a result, the split was paid in the form of a stock dividend on October 5, 2006 to stockholders of record as of the close of business on September 21, 2006. The Company issued 19.9 million shares of common stock as a result of the stock split. In addition, the number of shares of common stock issuable upon the exercise of outstanding stock options and the number of shares of common stock reserved for issuance under the Company’s employee benefit plans were proportionately increased in accordance with the terms of those respective agreements and plans. The transaction reduced additional paid-in capital by $0.2 million and increased common stock by $0.2 million. All share and per share data (except par value) for all periods presented have been restated to reflect the stock split.
15. Quarterly Results of Operations (Unaudited):
(1) 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.
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None.
Item 9A.
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 Co-Chief Executive Officers and 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 Co-Chief Executive Officers and Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective as of December 31, 2008 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 Co-Chief Executive Officers and Chief Financial Officer, as appropriate to allow timely decisions regarding disclosure.
“Management’s Annual Report on Internal Control over Financial Reporting” appears on page 30 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, 2008 that has materially affected, or is reasonably likely to materially affect, the Company’s internal controls over financial reporting.
Item 9B.
Item 9B. Other Information
None.
PART III
Item 10.
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 “2008 Proxy Statement”) for its annual meeting of stockholders to be held on May 14, 2009, 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.
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 2009 Proxy Statement, which sections are incorporated herein by reference.
Item 12.
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 2009 Proxy Statement, which sections are incorporated herein by reference.
Item 13.
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 2008 Proxy Statement, which section is incorporated herein by reference.
Item 14.
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 2008 Proxy Statement, which sections are incorporated herein by reference.
PART IV
Item 15.
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.
* 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
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 26, 2009.
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.