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FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

(Mark One)

For the quarterly period ended March 31, 2005

OR

For the transition period from              to             

Commission file number 000-31579

HYDRIL COMPANY

(Exact name of registrant as specified in its charter)

Registrant’s telephone number, including area code (281) 449-2000

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

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act).    Yes  x    No  ¨

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

Shares outstanding at April 25, 2005:

Common stock, $.50 par value, 19,410,067 shares outstanding

Class B common stock, $.50 par value, 4,028,270 shares outstanding

HYDRIL COMPANY

INDEX

* * *

Cautionary Statement Regarding Forward-Looking Information

This Quarterly Report on Form 10-Q contains forward-looking statements. These statements relate to future events or our future financial performance, including our business strategy and product development plans, and involve known and unknown risks and uncertainties. These risks and uncertainties and assumptions, which are more fully described under “RISK FACTORS” in Item 2 of this report and in Hydril Company’s Annual Report on Form 10-K for the year ended December 31, 2004 filed with the Securities and Exchange Commission, include, but are not limited to, the impact of changes in oil and natural gas prices and worldwide and domestic economic conditions on drilling activity and demand for and pricing of Hydril’s products, the impact of geo-political and other events affecting international markets and trade, Hydril’s ability to successfully develop technologies and products and maintain and increase its market share, the impact of international and domestic trade laws and other conditions in the steel industry, the loss of or change to distribution methods of premium connections in the U.S. and Canada, overcapacity in the pressure control industry, and high fixed costs that could affect the pricing of Hydril’s products. These factors may cause our company’s or our industry’s actual results, levels of activity, performance or achievements to be materially different from those expressed or implied by the forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “will,” “should,” “could,” “expects,” “intends,” “plans,” “anticipated,” “believes,” “estimated,” “potential,” or the negative of these terms or other comparable terminology.

These statements are only projections, based on anticipated industry activity. Although we believe that the expectations reflected in the forward-looking statements are reasonable, we cannot guarantee future results, levels of activity, performance or achievements.

HYDRIL COMPANY

Part I, Item 1: Consolidated Balance Sheets

(In Thousands, Except Share and Per Share Information)

See notes to unaudited consolidated financial statements

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HYDRIL COMPANY

Part I, Item 1: Consolidated Balance Sheets

(In Thousands, Except Share and Per Share Information)

See notes to unaudited consolidated financial statements

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HYDRIL COMPANY

Part I, Item 1: Unaudited Consolidated Statements of Operations

(In Thousands, Except Share and Per Share Amounts)

See notes to unaudited consolidated financial statements

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HYDRIL COMPANY

Part I, Item 1: Unaudited Consolidated Statements of Cash Flows

(In Thousands)

See notes to unaudited consolidated financial statements

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Hydril Company

Part I, Item 1: Notes to Unaudited Consolidated Financial Statements

Note 1 — BASIS OF PRESENTATION

Principles of Consolidation- The consolidated financial statements include the accounts of Hydril Company and its wholly owned subsidiaries. Intercompany accounts and transactions are eliminated in consolidation.

Use of Estimates- The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.

Reclassifications- Certain prior year amounts within the consolidated financial statements have been reclassified to conform to the current year’s presentation.

Interim Presentation- The accompanying consolidated interim financial statements and disclosures have been prepared by the Company in accordance with accounting principles generally accepted in the United States of America and in the opinion of management reflect all adjustments (consisting solely of normal recurring adjustments) necessary for a fair presentation in all material respects of the financial position and results for the interim periods. The December 31, 2004 consolidated balance sheet was derived from our audited financial statements. These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2004. The results of operations for the three months ended March 31, 2005 are not necessarily indicative of results to be expected for the full year.

Investments — The Company invests excess cash in various securities and money market mutual funds rated as the highest quality by a nationally recognized rating agency.

The Company has investment securities classified as “available for sale” in accordance with Statement of Financial Accounting Standards No. 115 (“SFAS 115”), “Accounting for Certain Investments in Debt and Equity Securities.” At March 31, 2005 and December 31, 2004, the Company held $66,590,000 and $50,664,000 in “available for sale” securities, respectively. The fair value of these securities as of March 31, 2005 and December 31, 2004 approximates the carrying value. The realized and unrealized gains and losses related to these available for sale investments were immaterial to the results of operations. The contractual maturities of these investments vary with $1,850,000 maturing within one year, $400,000 maturing in one to five years and the balance maturing after ten years. While the contractual maturities of these investments can be greater than one year, they are classified as short-term investments because they are redeemable in less than one year and it is management’s intent that they be available for use in current operations.

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Additionally, the Company has investments classified as “held-to-maturity” and measured at amortized cost in accordance with SFAS 115. Management has the positive intent and ability to hold those securities to maturity. As of March 31, 2005 and December 31, 2004, the Company held $20,680,000 and $22,202,000, respectively of corporate investment securities classified as “held to maturity.” Contractual maturities of these securities at March 31, 2005 include $17,179,000 which mature in 2005 and $3,501,000 which mature in 2006.

Stock Based Compensation – The Company accounts for stock-based compensation using the intrinsic value method prescribed by Accounting Principles Board Opinion No. 25, “Accounting for Stock Issued to Employees.” Accordingly, no compensation expense has been recognized for the Company’s stock option plans to the extent that the quoted market price of the stock at the measurement date was equal to or less than the amount the employee is required to pay for the stock. In December 2002, the Financial Accounting Standards Board (“FASB”) issued SFAS No. 148 “Accounting for Stock-Based Compensation-Transition and Disclosure.” The statement requires pro forma disclosures that reflect the difference in stock-based employee compensation cost, if any, included in net income and the total cost measured by the fair value based method per SFAS 123 “Accounting for Stock-Based Compensation”, if any, that would have been recognized in the income statement if the fair value based method had been applied to all awards.

The following table illustrates the effect on net income and earnings per share if the Company had applied the fair value recognition provisions of SFAS 123 for the three months ended March 31, 2005 and 2004:

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Note 2 — Product Warranty Liability

The change in the aggregate product warranty liability is as follows for the three months ended March 31:

Note 3 — LONG-TERM CONTRACTS

The components of long-term contracts as of March 31, 2005 and December 31, 2004 consist of the following:

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Note 4 — CONTINGENCIES

The Company is involved in legal proceedings arising in the ordinary course of business. In the opinion of management these matters are such that their outcome will not have a material adverse effect on the financial position or results of operations of the Company.

The Company has been identified as a potentially responsible party at a waste disposal site near Houston, Texas. Based on the number of other potentially responsible parties, the total estimated site cleanup costs and its estimated share of such costs, the Company continues to believe this matter will not materially affect its results of operation or financial condition.

Note 5 —LINES OF CREDIT

At March 31, 2005, the Company had $20,000,000 in total committed unsecured revolving lines of credit, which extend through June 30, 2005. Of this, $15,000,000 relates to the Company’s U.S. operations and $5,000,000 relates to the Company’s foreign operations. Under both the domestic and foreign lines, the Company may, at its election, borrow at either a prime or LIBOR-based interest rate. Interest rates fluctuate depending on the Company’s leverage ratio and are prime minus a spread ranging from 60 to 115 basis points or LIBOR plus a spread ranging from 85 to 140 basis points. At March 31, 2005, there were no outstanding borrowings under either facility. The U.S. revolving line of credit contains covenants that require the Company to maintain a minimum level of tangible net worth and not exceed a specified level of indebtedness or a maximum leverage ratio. The Company was in compliance with these covenants at March 31, 2005. The foreign line does not contain any separate financial covenants but contains cross-default provisions which would be triggered by a default under the U.S. line of credit.

The terms of the Company’s credit facilities allow for the issuance of letters of credit. The amount of outstanding letters of credit reduces the amount available for borrowing under the credit facilities. The letters of credit are generally short in duration and immaterial in amount. At March 31, 2005 there was approximately $1,829,000 outstanding in letters of credit.

Note 6 — INCOME TAXES

During the quarter ended March 31, 2004, the Company completed a research and experimentation tax study which resulted in a $920,000 credit to the Company’s income tax provision. The research and experimentation tax credit covered qualified spending for the two-year period from 2002 through 2003. Prior to 2003, the Company was an alternative minimum tax payer and accordingly could not benefit from this type of tax credit. Expenses of $125,000 associated with the study were included in general and administrative expenses during that quarter.

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Note 7 — EARNINGS PER SHARE

The Company has presented basic and diluted income per share (“EPS”) on the consolidated statement of operations. Basic EPS excludes dilution and is computed by dividing income available to common stockholders by the weighted average number of common shares outstanding for the period. Dilutive EPS is based on the weighted average number of shares outstanding during each period plus the assumed exercise of dilutive stock options and vesting of unissued restricted stock and restricted stock units, less the number of treasury shares from the assumed exercise proceeds using the average market price for the Company’s common stock for each of the periods presented. When potentially dilutive securities are anti-dilutive, they are not included in dilutive EPS. Basic weighted average shares outstanding for the three months ended March 31, 2005 and 2004 were 23,361,493 and 22,847,662, respectively. Dilutive weighted average shares outstanding for the three months ended March 31, 2005 and 2004 were 23,920,538 and 23,137,955, respectively.

The following table summarizes the computation of basic and diluted net income per share:

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Note 8 — EMPLOYEE BENEFITS

The Company has a defined benefit plan and post-retirement health and life benefits which are described in detail in Note 6 “EMPLOYEE BENEFITS” under Item 8 of our Annual Report on Form 10-K for the year-ended December 31, 2004 filed with the Securities and Exchange Commission. The table below shows the amount of estimated net periodic benefit costs under each plan for the three months ended March 31:

Note 9 — SEGMENT AND RELATED INFORMATION

In accordance with SFAS No. 131, “Disclosures About Segments of an Enterprise and Related Information,” the Company has identified the following reportable segments: Premium Connection and Pressure Control.

Hydril is engaged worldwide in engineering, manufacturing and marketing of premium connection and pressure control products for oil and gas drilling and production. The Company sells its products to steel pipe distributors, major and independent, domestic and international oil and gas companies and drilling contractors. The Company’s products are used in drilling environments where extreme pressure, temperature, corrosion and mechanical stress are encountered, as well as in environmentally sensitive drilling. These harsh conditions are typical for deepwater, deep-formation and horizontal or extended reach oil and gas wells.

The Company’s premium connection segment manufactures premium connections that are used in drilling environments where extreme pressure, temperature, corrosion and mechanical stress are encountered, as well as in environmentally sensitive drilling. These harsh drilling conditions are typical for deepwater, deep-formation and horizontal or extended reach wells. Hydril applies premium threaded connections to tubulars owned by its customers and purchases pipe in certain international markets for threading and resale. Hydril manufactures premium threaded connections and provides services at facilities located in Bakersfield, California; Nisku, Alberta, and Dartmouth, Nova Scotia, Canada; Batam, Indonesia; Westwego, Louisiana; Veracruz, Mexico; Warri, Nigeria; Aberdeen, Scotland and Houston, Texas.

The Company’s pressure control segment manufactures a broad range of pressure control equipment used in oil and gas drilling and well completion typically employed in harsh environments. The Company’s pressure control products are primarily safety devices that control and contain fluid and gas pressure during drilling, completion and maintenance in oil and gas wells. The Company also provides aftermarket replacement parts, repair and field services for its installed base of pressure control equipment. Hydril manufactures pressure control products at two plant locations in Houston, Texas.

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The accounting policies of the segments are the same as those described in Note 1 “SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES” under Item 8 of our Annual Report on Form 10-K for the year-ended December 31, 2004 filed with the Securities and Exchange Commission. The Company evaluates segment performance based on operating income or loss.

Financial data for the business segments for the three months ended March 31, 2005 and 2004 is as follows:

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Part I, Item 2: Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion of Hydril’s historical results of operations and financial condition should be read in conjunction with Hydril’s unaudited consolidated financial statements and notes thereto included elsewhere in this report and the audited consolidated financial statements and notes thereto and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in Hydril’s Annual Report on Form 10-K for the year ended December 31, 2004.

OVERVIEW

Hydril Company is engaged worldwide in engineering, manufacturing and marketing premium connection and pressure control products used for oil and gas drilling and production. Hydril applies premium threaded connections to tubulars owned by its customers and purchases pipe in certain international markets for threading and resale. Our premium connections are used in drilling environments where extreme pressure, temperature, corrosion and mechanical stress are encountered, as well as in environmentally sensitive drilling. These harsh drilling conditions are typical for deep-formation, deepwater and horizontal or extended reach wells. Our pressure control products are primarily safety devices that control and contain fluid and gas pressure during drilling, completion and maintenance of oil and gas wells in these same environments. We also provide aftermarket replacement parts, repair and field services for our installed base of pressure control equipment. These products and services are required on a recurring basis because of the impact on original equipment from the extreme conditions in which pressure control products are used.

Demand for our products and services is cyclical and substantially dependent on the activity levels in the oil and gas industry and our customers’ willingness to spend capital on the exploration and development of oil and gas reserves. The level of these capital expenditures is highly sensitive to current and expected oil and gas prices, which have historically been categorized by significant volatility. Generally, increasing oil and gas prices, usually referred to as “commodity prices”, result in increased oil and gas exploration and production, which translates into greater demand for oilfield products and services. Conversely, falling commodity prices generally result in reduced demand for oilfield products and services. Historically, changes in budgets and activity levels by oil and gas exploration and production companies have lagged significant movements in commodity prices.

Premium Connections

Our premium connection products are marketed primarily to exploration and production company operators, who are the end-users. The premium connection market is driven by the level of worldwide drilling activity, in particular by the number of rigs drilling at target depths greater than 15,000 feet and the number of rigs drilling offshore,

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although the rate of consumption varies widely among markets based on specific geological formations, customer history and preference, and available alternatives. The majority of wells with a target depth greater than 15,000 feet have been drilled in North America. These depths require substantially more premium connections than shallower wells.

Internationally, while the total international rig count is a general indicator of the premium connection market, spending on exploration and production is typically spread unevenly between various regions and can be subject to significant volatility. There are many variables, including political and civil unrest, which may adversely impact the level of drilling activity in particular countries or regions. In addition, our international presence is concentrated in particular geographic regions which may not always correspond to where drilling activity is heaviest. If we are affected by conditions that exist in only specific markets, our premium connections results may differ relative to movements in the international rig count. See RISK FACTORS: “A material or extended decline in expenditures by the oil and gas industry, due to a decline in oil and gas prices or other economic factors, would reduce our revenue.”

The following table shows the average rig count for rigs drilling at target depths greater than 15,000 feet in the United States, the average number of rigs under contract in the Gulf of Mexico and the average international rig count for the last five quarters:

Pressure Control

We sell our pressure control products primarily to drilling contractors for use in oil and gas drilling and to a lesser extent to exploration and production companies for oil and gas production. The main factors that affect sales of pressure control capital equipment

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products are the level of construction of new offshore drilling rigs and the replacement and upgrading of equipment for existing offshore drilling rigs. Demand for our pressure control aftermarket replacement parts, repair and field services primarily depends upon the level of worldwide offshore drilling activity as well as the total U.S. rig count. The following tables illustrate the data for these sectors over the last five quarters:

RESULTS OF OPERATIONS FOR THE THREE MONTHS ENDED MARCH 31, 2005

AND 2004

Revenue

Total revenue increased $21.3 million, to $78.8 million for the three months ended March 31, 2005 compared to $57.5 million for the three months ended March 31, 2004. Our premium connection revenue increased $17.1 million, or 51%, to $50.5 million for the three months ended March 31, 2005 compared to $33.4 million for the prior year period. This increase was primarily the result of higher demand in certain international markets, primarily Latin America, and in North America due to higher levels of deep formation drilling activity. Pressure control revenue increased $4.2 million, or 17%, to $28.3 million for the three months ended March 31, 2005 compared to $24.1 million for the same period in 2004. Pressure control capital equipment revenue increased 43% primarily due to improved industry fundamentals resulting in increased drilling activity and higher demand for our products. Aftermarket pressure control revenue increased 4% primarily due to an increase in the U.S. total rig count and consumption of spare parts in the drilling process.

Gross Profit

Gross profit increased $13.1 million to $35.4 million for the three months ended March 31, 2005 compared to $22.3 million for the prior year period. Gross profit for our

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premium connection segment increased 72% over the prior year due primarily to higher demand for our products worldwide which led to higher plant utilization and lower manufacturing costs per unit and due to a higher level of pricing in select international markets resulting from price increases initiated during 2004. Gross profit for our pressure control segment increased 40% from the prior year due primarily to higher demand for our capital equipment and aftermarket products and lower costs for excess and obsolete inventory due to an improving business environment.

Selling, General and Administrative Expenses

Selling, general, and administrative expenses for the three months ended March 31, 2005 were $13.3 million compared to $11.9 million for the prior year quarter. The increase over the prior year quarter was due to higher administrative costs, agent’s commissions and sales and marketing expenses. As a percentage of revenue, selling, general, and administrative expenses were 17% for the first quarter of 2005 compared to 21% for the prior year quarter.

Operating Income

Operating income increased $11.6 million to $22.1 million for the three months ended March 31, 2005 compared to $10.5 million for the same period in 2004. Operating income for our premium connection segment increased $9.0 million to $18.4 million for the first quarter of 2005 from $9.4 million for the first quarter of 2004. Operating income for our pressure control segment increased $3.0 million to $7.8 million for the quarter ended March 31, 2005 compared to $4.8 million for the same period in 2004. Corporate and administrative expenses were $4.1 million for the three months ended March 31, 2005 compared to $3.7 million for the prior year period.

Provision for Income Taxes

Income tax expense was $7.6 million for the three months ended March 31, 2005, compared to $2.7 million for the three months ended March 31, 2004. The prior year quarter includes a research and experimentation tax credit of $0.9 million. The research and experimentation tax credit covers qualified spending for the two-year period from 2002 to 2003. Prior to 2003, the Company was an alternative minimum tax payer and accordingly could not benefit from this type of tax credit. Expenses of $0.1 million associated with the tax credit study were included in general and administrative expenses for the quarter ended March 31, 2004.

LIQUIDITY AND CAPITAL RESOURCES

Our primary liquidity needs are to fund capital expenditures, fund new product development and provide additional working capital. Our primary source of funds is cash flow from operations. In addition, we had available cash, cash equivalents and investments of $145.9 million at March 31, 2005. We also had the capacity to borrow up to $18.2 million as of that date under our committed revolving credit facilities, which expire on June 30, 2005. At March 31, 2005, we had $1.8 million in outstanding letters of credit and no outstanding indebtedness.

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We believe that cash from operations and existing cash, cash equivalents and investment balances will be sufficient to meet anticipated cash requirements, including working capital needs, contractual obligations and planned capital expenditures, for at least the next 12 months. In the longer term, if we were to need additional cash, we could borrow under our existing or future credit facilities and anticipate that we could also raise additional funds through issuing debt or equity securities.

Operating Activities

For the three months ended March 31, 2005, cash provided by operating activities was $23.8 million primarily due to earnings and contractual cash payments received on long-term capital equipment projects. For the three months ended March 31, 2004, cash provided by operating activities was $9.9 million primarily due to earnings and contractual cash payments received from customers on long-term capital equipment projects.

Investing Activities

Net cash used in investing activities was $20.0 million for the three months ended March 31, 2005 compared to $2.6 million for the three months ended March 31, 2004. The investment of cash in the first quarter of 2005 was primarily for net investments in marketable securities of $14.4 million and capital spending of $4.1 million while the investment of cash in 2004 of $2.6 million was for capital spending of $1.4 million and $1.2 million in net investments in marketable securities.

Capital spending for the three months ended March 31, 2005 of $4.1 million included $3.3 million for our premium connection segment and $0.6 million for our pressure control segment, in both cases primarily to support manufacturing operations, and $0.2 million for general corporate purposes. Capital spending for the three months ended March 31, 2004 of $1.4 million included $0.8 million for our premium connection segment and $0.5 million for our pressure control segment, in both cases primarily to support manufacturing operations, and $0.1 million for general corporate purposes.

Credit Facilities

We have two unsecured revolving lines of credit for working capital requirements that provide up to $20.0 million in total committed revolving credit borrowings through June 30, 2005. Of these, $15.0 million relates to our U.S. operations and $5.0 million relates to our foreign operations. Under these lines, we may borrow, at our election, at either a prime or LIBOR-based interest rate. Interest rates fluctuate depending on our leverage ratio and are prime minus a spread ranging from 60 to 115 basis points or LIBOR plus a spread ranging from 85 to 140 basis points. At March 31, 2005, there were no outstanding borrowings under either facility. The U.S. revolving line of credit contains financial covenants which require us to maintain a minimum level of tangible net worth and not to exceed a specified level of indebtedness or a maximum leverage ratio. At March 31, 2005, we were in compliance with these covenants. Our foreign line of credit does not contain

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any separate financial covenants but contains cross-default provisions which would be triggered by a default under our U.S. line of credit. We are in the process of evaluating whether to renew these credit facilities upon their upcoming maturity. We have not had any borrowings under these credit facilities since 2001.

The terms of the Company’s credit facilities allows for the issuance of letters of credit. The amount of outstanding letters of credit reduces the amount available for borrowing under the credit facilities. The letters of credit are generally short in duration and immaterial in amount. At March 31, 2005 there was approximately $1.8 million outstanding in letters of credit.

Backlog

The pressure control capital equipment backlog, which includes long-term projects and other capital equipment orders, was $29.9 million at March 31, 2005, $14.6 million at December 31, 2004 and $11.9 million at March 31, 2004. The increase in our backlog reflects an $18.6 million long-term project order received during the first quarter of 2005 for blowout prevention and control system equipment. We recognize the revenue and gross profit from pressure control long-term projects using the percentage-of-completion accounting method. As revenue is recognized under the percentage-of-completion method, the order value in backlog is reduced. Revenue for capital equipment that is not part of long-term projects is recognized using the completed contract method. It is possible for orders to be cancelled; however, in the event of cancellations all costs incurred would be billable to the customer. Our backlog of premium connection and pressure control aftermarket parts and service is not a meaningful measure of business prospects due to the quick turnover of such orders.

CRITICAL ACCOUNTING ESTIMATES

Our significant accounting policies are described in Note 1 in the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2004. We prepare our consolidated financial statements in conformity with accounting principles generally accepted in the United States, which require us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expense during the year. Actual results could differ from those estimates. The estimates in the areas we consider to be most critical in understanding the judgments that are involved in preparing our financial statements and the uncertainties that could impact our results of operations, financial condition and cash flows are described under “Management’s Discussion and Analysis of Financial Condition and Results of Operations–Critical Accounting Estimates” in our Annual Report on Form 10-K.

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RISK FACTORS

You should consider carefully the following risk factors and all other information contained in this quarterly report on Form 10-Q and our Annual Report on Form 10-K for the year-ended December 31, 2004. Any of the following risks could impair our business, financial condition and operating results.

A material or extended decline in expenditures by the oil and gas industry, due to a decline in oil and gas prices or other economic factors, would reduce our revenue.

Demand for our products and services is substantially dependent on the level of capital expenditures by the oil and gas industry for the exploration for and development of crude oil and natural gas reserves. In particular, demand for our premium connections and our aftermarket pressure control products and services is driven by the level of worldwide drilling activity, especially drilling in harsh environments. A substantial or extended decline in drilling activity will adversely affect the demand for our products and services. Demand for our pressure control capital equipment is directly affected by the number of drilling rigs being built or refurbished. Drilling rig utilization and day rates though improved, have not experienced sufficiently large or sustained improvements to result in significant refurbishment of drilling rigs or new rig construction. An extended decline in capital equipment orders could adversely affect revenue and operating income for our pressure control segment and could result in additional charges if we are required to take cost reduction measures in light of business conditions.

Worldwide drilling activity is generally highly sensitive to oil and gas prices and can be dependent on the industry’s view of future oil and gas prices, which have been historically characterized by significant volatility. Oil and gas prices are affected by numerous factors, including:

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We expect prices for oil and natural gas to continue to be volatile and affect the demand and pricing of our products and services. A material decline in oil or gas prices could materially adversely affect our business. In addition, recessions and other adverse economic conditions can also cause declines in spending levels by the oil and gas industry, and thereby decrease our revenue and materially adversely affect our business.

We rely on a few distributors for sales of our premium connections in the United States and Canada; a loss of one or more of our distributors or a change in the method of distribution could adversely affect our ability to sell our products.

There are a limited number of distributors who buy steel tubulars, contract with us to thread the tubulars and sell completed tubulars with our premium connections. In 2004, our eight distributors accounted for 64% of our premium connection sales in the United States and Canada.

In the United States, tubular distributors have combined on a rapid basis in recent years resulting in fewer distribution alternatives for our products. In 1999, four distributors, one of which distributed our premium connections, combined to become one of the largest distributors of tubulars in the United States, and the combined company no longer distributes our products. Because of the limited number of distributors, we have few alternatives if we lose a distributor. Identifying and utilizing additional or replacement distributors may not be accomplished quickly and could involve significant additional costs. Even if we find replacement distributors, the terms of new distribution agreements may not be favorable to us. In addition, distributors may not be as well capitalized as our end-users and may present a higher credit risk.

We cannot assure you that the current distribution system for premium connections will continue. For example, products may in the future be sold directly by tubular manufacturers to end-users or through other distribution channels such as the internet. If methods of distribution change, many of our competitors may be better positioned to take advantage of those changes than we are.

The intense competition in our industry could result in reduced profitability and loss of market share for us.

Contracts for our products and services are generally awarded on a competitive basis, and competition is intense. The most important factors considered by our customers in awarding contracts include:

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Many of our major competitors are diversified multinational companies that are larger and have substantially greater financial resources, larger operating staffs and greater budgets for marketing and research and development than we do. They may be better able to compete in making equipment available faster and more efficiently, meeting delivery schedules or reducing prices. In addition, two or more of our major competitors could consolidate producing an even larger company. Also our competitors may acquire product lines or consolidate with another company in the oilfield services and equipment industry, and as a result be able to offer a more complete package of drilling equipment and services rather than providing only individual components. For example, National Oilwell, a manufacturer and supplier of oilfield equipment, systems and services that has historically purchased Hydril pressure control equipment, recently merged with Varco International, a manufacturer of pressure control equipment and one of our primary competitors. As a result of any of the foregoing reasons, we could lose customers and market share to those competitors. These companies may also be in a better position to endure downturns in the oil and gas industry.

We do not do business in as many countries as some of our larger multinational competitors and in some cases even where we do business, we do not have as significant a presence. Our lack of geographic diversity and penetration may have a material adverse affect on our results of operations and competitive position. Spending on exploration and production is typically spread unevenly between various regions with changes in geographic spending patterns arising as discoveries are made, the price of oil and gas changes, political changes take place or other factors occur that make drilling more or less attractive in a given geographic area. As a result, even when international rig counts and drilling activity increase overall, if the increased activity is not in countries in which we have a strong presence, we may not experience any increase in business and may lose market share.

Moreover, some of our competitors with greater financial resources and multinational presence have relocated manufacturing operations to countries where they have substantially lower labor costs and lower general overhead costs. The relocation by competitors of manufacturing operations to low cost environments may continue in the future. As a result, our competitors may have lower costs than we do and be able to sell their products at prices significantly below ours.

Our international operations may experience severe interruptions due to political, economic and other risks.

In 2004, approximately 69% of our total revenue was derived from services or equipment ultimately provided or delivered to end-users outside the United States, and

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approximately 41% of our revenue was derived from products which were produced and used outside of the United States. We are, therefore, significantly exposed to the risks customarily attendant to international operations and investments in foreign countries. These risks include:

An interruption of our international operations could reduce our earnings or adversely affect the value of our foreign assets. The occurrence of any of these risks could also have an adverse effect on demand for our products and services or our ability to provide them. We have manufacturing facilities in Warri, Nigeria and in Batam, Indonesia and a portion of our revenue is from sales to customers in these countries and surrounding areas. In addition, a portion of our revenue is from sales to customers in Venezuela. These countries in recent history have experienced civil disturbances and violence, which have disrupted oil and gas exploration and production operations located there as well as day-to-day operations and oversight of our business from time to time. These disruptions have affected our operations and resulted in lower demand for our premium connection products and services and, accordingly have had an adverse affect on our results of operations in recent periods and may continue to do so.

The level and pricing of tubular goods imported into the United States and Canada could adversely affect demand for our products and our results of operations.

The level of imports of tubular goods, which has varied significantly over time, affects the domestic tubular goods market. High levels of imports reduce the volume sold by domestic producers and tend to reduce their selling prices, both of which could have an adverse impact on our business. We believe that United States import levels are affected by, among other things:

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In many cases, foreign producers of tubular goods have been found to have sold their products, which may include premium connections, for export to the United States at prices that are lower than the cost of production or their prices in their home market or a major third-country market, a practice commonly referred to as “dumping.” If not constrained by antidumping duty orders and countervailing duty orders, which impose duties on imported tubulars to offset dumping and subsidies provided by foreign governments, this practice allows foreign producers to capture sales and market share from domestic producers. Duty orders normally reduce the level of imported goods and result in higher prices in the United States market. Duty orders may be modified or revoked as a result of administrative reviews conducted at the request of a foreign producer or other party.

In addition, antidumping and countervailing duty orders may be revoked as a result of periodic “sunset reviews”. Under the sunset review procedure, an order must be revoked after five years unless the United States Department of Commerce and the International Trade Commission determine that dumping is likely to continue or recur and that material injury to the domestic injury is likely to continue or recur. Antidumping duty orders continue to cover imports of tubulars from Argentina, Italy, Japan, Korea and Mexico, and a countervailing duty order continues to cover imports from Italy. On July 17, 2001, the Department of Commerce ordered the continuation of the countervailing and antidumping duty orders on tubular goods other than drill pipe on Argentina, Italy, Korea and Mexico, and the continuation of the antidumping duty order on tubular goods, inclusive of drill pipe, from Japan. If the orders covering imports from these countries are revoked in full or in part or the duty rates lowered, we could be exposed to increased competition from imports that could reduce our sales and market share or force us to lower prices. Tubulars produced by domestic steel mills and threaded by us may not be able to economically compete with tubulars manufactured and threaded at steel mills outside the U.S. The Department of Commerce intends to initiate the next five-year review of these orders no later that June 2006. The sunset review for tubular products from Argentina, Italy, Japan, Korea and Mexico will take place in 2006, with a decision expected by April 2007.

We may lose premium connection business to international and domestic competitors who produce their own pipe, as well as other new entrants or lose business due to limitations on the availability of pipe for threading.

Our premium connections are applied to steel tubulars produced by steel mills. In the United States and Canada and sometimes internationally, our premium connections are applied to steel tubulars purchased by a distributor from the steel suppliers. In international markets distribution is more varied. We also purchase the tubulars from the steel producers, thread them and sell the complete product, or thread tubulars held by the steel producer, which the producer then sells, or thread tubulars owned by the end-user. In any case, the price paid by the purchaser includes, but does not differentiate between, the costs of the steel pipe and the connection. Pricing of premium connections can be affected by steel prices, as the steel pipe is the largest component of the overall price. We have no control over the availability or the price of the steel pipe. Prices for steel pipe have

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increased in recent periods due to higher worldwide demand for steel, which in turn has contributed to a tight supply of tubulars for oil and gas applications. If these conditions persist and demand for pipe increases, we or our distributors could have difficulty obtaining plain-end pipe for us to thread. If we or our distributors are not able to obtain pipe for threading to satisfy customer demand, our business would be adversely affected.

A number of steel producers, especially internationally, are integrated steel producers, who both produce and thread steel tubulars. For example, several foreign steel mills have formed a corporation that is licensed to produce and sell a competing premium connections product line outside of the United States and Canada. There are also some steel producers which market their own premium connections in North America. Due to the current tight supply of steel and steel tubulars and low levels of inventory of tubular goods for oil and gas applications in the industry generally, integrated producers may attempt to require that all or a greater portion of the pipe they produce bear their premium connections or change distribution methods in a way that is adverse to us. Integrated steel producers also have more pricing flexibility for premium connections since they control the production of both the steel tubulars to which the connections are applied, as well as the premium connections. This inherent pricing and supply control puts us at a competitive disadvantage, and we could lose business to integrated steel producers even if plain end pipe is available and we may have a better product. The recent acquisition or future acquisitions of U.S. tubular steel manufacturing capacity by foreign integrated steel producers could result in a loss of market share for Hydril. In addition, other domestic and foreign steel producers who do not currently manufacture tubulars with premium connections may in the future enter the premium connections business and compete with us.

The occurrence or threat of terrorist attacks could have an adverse affect on our results and growth prospects, as well as on our ability to access capital and obtain adequate insurance.

The occurrence or threat of future terrorist attacks could adversely affect the economies of the United States and other developed countries. A lower level of economic activity could result in a decline in energy consumption, which could cause a decrease in spending by oil and gas companies for exploration and development. In addition, these risks could trigger increased volatility in prices for crude oil and natural gas which could also adversely affect spending by oil and gas companies. A decrease in spending for any reason could adversely affect the markets for our products and thereby adversely affect our revenue and margins and limit our future growth prospects. Moreover, these risks could cause increased instability in the financial and insurance markets and adversely affect our ability to access capital and to obtain insurance coverage that we consider adequate or are otherwise required by our contracts with third parties.

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The consolidation or loss of end-users of our products could adversely affect demand for our products and services and reduce our revenue.

Exploration and production company operators and drilling contractors have undergone substantial consolidation in the last few years. Additional consolidation is probable. In addition, many oil and gas properties will be transferred over time to different potential customers.

Consolidation results in fewer end-users for our products. In addition, merger activity among both major and independent oil and gas companies also affects exploration, development and production activity, as these consolidated companies attempt to increase efficiency and reduce costs. Generally, only the more promising exploration and development projects from each merged entity are likely to be pursued, which may result in overall lower post-merger exploration and development budgets. Moreover, some end-users are not as risk-averse and, as such, do not use as many premium products in drilling deep formation wells.

We are subject to the usual risks associated with having a limited number of customers and end-users. The end-users of our products, who are not always our direct customers, are primarily international and domestic independent, major and state-owned oil and gas companies and drilling contractors. During 2004, we sold products to and services to approximately 1,030 customers. For 2004, Petroleos de Venezuela S.A. (PdVSA) the state-owned oil and gas company of Venezuela, represented 11% of our consolidated revenue; and we estimate that Petroleos Mexicanos (Pemex) indirectly represented 14% of our consolidated revenue. In 2004, our two largest premium connection customers accounted for 23% and 17% of segment sales, and our ten largest premium connection customers accounted for 71% of total segment sales. In 2004, our two largest pressure control customers each accounted for 12% of segment sales and our ten largest pressure control customers accounted for 62% of segment sales.

The loss of one or more of our significant customers or end-users, a reduction in exploration and development budgets as a result of industry consolidation or other reasons or a transfer of deep formation drilling prospects to end-users that do not rely as heavily on premium products could adversely affect demand for our products and services and reduce our revenue.

Overcapacity in the pressure control industry and high fixed costs could exacerbate the level of price competition for our products, adversely affecting our business and revenue.

There currently is and historically has been overcapacity in the pressure control equipment industry. When oil and gas prices fall, cash flows of our customers are reduced, leading to lower levels of expenditures and reduced demand for pressure control equipment. In addition, adverse economic conditions can reduce demand for oil and gas, which in turn could decrease demand for our pressure control products. Under these conditions, the overcapacity causes increased price competition in the sale of pressure control products and aftermarket services as competitors seek to capture the reduced

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business to cover their high fixed costs and avoid the idling of manufacturing facilities. Because we have multiple facilities that produce different types of pressure control products, it is even more difficult for us to reduce our fixed costs since to do so we might have to shut down more than one plant. During and after periods of increasing oil and gas prices when sales of pressure control products may be increasing, the overcapacity in the industry will tend to keep prices for the sale of pressure control products lower than if overcapacity were not a factor. As a result, when oil and gas prices are low, or are increasing from low levels because of increased demand, our business and revenue may be adversely affected because of either reduced sales volume or sales at lower prices or both.

If we do not develop new technologies and products that are commercially successful, our revenue may decline or we may be required to write-off any capitalized investment.

The markets for premium connections and pressure control products and services are characterized by continual technological developments. As a result, substantial improvements in the scope and quality of product function and performance can occur over a short period of time. If we are not able to develop commercially competitive products in a timely manner in response to changes in technology, our business and revenue may be adversely affected. Our future ability to develop new products depends on our ability to:

We may encounter resource constraints or technical or other difficulties that could delay introduction of new products and services in the future. Our competitors may introduce new products before we do and achieve a competitive advantage. Additionally, the time and expense invested in product development may not result in commercial applications and provide revenue.

For example, while we have incurred significant amounts in the development of new technologies, such as subsea mudlift drilling, demand for new products may be limited for various reasons. In the case of subsea mudlift drilling, due in part to the cost to implement the technology, we do not anticipate any customer orders for the product in the near future. In addition, there are other groups of companies in our industry that are also developing competing technologies for deepwater drilling, and they may be ahead of us in completing development of their technology or develop more cost-effective competing products.

If we are unable to successfully implement technological or R&D type activities, our growth prospects may be reduced and the level of our future revenue may be materially and adversely affected. In addition, we would be required to write-off any capitalized investment in a product that is not a commercial success and does not have an alternative use. For example, in the case of advanced composite tubing, we wrote off a portion of our investment in the third quarter of 2004, recording a pre-tax impairment charge of $0.7 million, and then sold the fixed assets, inventory and intellectual property rights at an

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amount approximating the net book value of such assets at the end of 2004. Moreover, we may experience operating losses after new products are introduced and commercialized because of high start-up costs, unexpected manufacturing costs or problems, or lack of demand.

Limitations on our ability to protect our intellectual property rights could cause a loss in revenue and any competitive advantage we hold.

Some of our products and the processes we use to produce them have been granted United States and international patent protection, or have patent applications pending. Nevertheless, patents may not be granted from our applications and, if patents are issued, the claims allowed may not be sufficient to protect our technology. If our patents are not enforceable, our business may be adversely affected. In addition, if any of our products infringe patents held by others, our financial results may be adversely affected. Our competitors may be able to independently develop technology that is similar to ours without infringing on our patents. The latter is especially true internationally where the protection of intellectual property rights may not be as effective. In addition, obtaining and maintaining intellectual property protection internationally may be significantly more expensive than doing so domestically. We may have to spend substantial time and money defending our patents. After our patents expire, our competitors will not be legally constrained from developing products substantially similar to ours.

The loss of any member of our senior management and other key employees may adversely affect our results of operations.

Our success depends heavily on the continued services of our senior management and other key employees. Our senior management consists of a small number of individuals relative to other comparable or larger companies. These individuals are Christopher T. Seaver, our President and Chief Executive Officer, Charles E. Jones, our Executive Vice President and Chief Operating Officer, Neil G. Russell, our Senior Vice President-Premium Connections and Senior Vice President-Business Development, Chuck Chauviere, our Vice President-Pressure Control, and Chris D. North, our Chief Financial Officer. These individuals, as well as other key employees, possess sales and marketing, engineering, manufacturing, financial and administrative skills that are critical to the operation of our business. We generally do not have employment or non-competition agreements with members of our senior management or other key employees. If we lose or suffer an extended interruption in the services of one or more of our senior officers or other key employees, our results of operations may be adversely affected. Moreover, we may not be able to attract and retain qualified personnel to succeed members of our senior management and other key employees.

Our quarterly sales and earnings may vary significantly, which could cause our stock price to fluctuate.

Fluctuations in quarterly revenue and earnings could adversely affect the trading price of our common stock. Our quarterly revenue and earnings may vary significantly from quarter to quarter depending upon:

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In addition, our fixed costs cause our margins to decrease when demand is low and manufacturing capacity is underutilized.

We could be subject to substantial liability claims, which would adversely affect our results and financial condition.

Most of our products are used in hazardous drilling and production applications where an accident or a failure of a product can have catastrophic consequences. For example, if one of our blowout preventers fails, the oil and gases from the well may ignite or the equipment and tubulars in the well may be suddenly propelled out of the well, potentially resulting in injury or death of personnel, destruction of drilling equipment, environmental damage and suspension of operations. Damages arising from an occurrence at a location where our products are used have in the past and may in the future result in the assertion of potentially large claims against us.

While we maintain insurance coverage against these risks, this insurance may not protect us against liability for some kinds of events, including specified events involving pollution, or against losses resulting from business interruption. Our insurance may not be adequate in risk coverage or policy limits to cover all losses or liabilities that we may incur. Moreover, we may not be able in the future to maintain insurance at levels of risk coverage or policy limits that we deem adequate. Any significant claims made under our policies will likely cause our premiums to increase. Any future damages caused by our products or services that are not covered by insurance, are in excess of policy limits or are subject to substantial deductibles, could reduce our earnings and our cash available for operations.

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If we are unable to attract and retain skilled labor, the results of our manufacturing and services activities will be adversely affected.

Our ability to operate profitably and expand our operations depends in part on our ability to attract and retain skilled manufacturing workers, equipment operators, engineers and other technical personnel. Because of the cyclical nature of our industry, many qualified workers choose to work in other industries where they believe lay-offs as a result of cyclical downturns are less likely. As a result, our growth may be limited by the scarcity of skilled labor. Even if we are able to attract and retain employees, the intense competition for them, especially when our industry is in the top of its cycle, may increase our compensation costs. Additionally, a significant increase in the wages paid by competing employers could result in a reduction in our skilled labor force, increases in the rates of wages we must pay or both. If our compensation costs increase or we cannot attract and retain skilled labor, the immediate effect on us would be a reduction in our profits and the extended effect would be diminishment of our production capacity and profitability and impairment of any growth potential.

Changes in regulation or environmental compliance costs and liabilities could have a material adverse effect on our results and financial condition.

Our business is affected by changes in public policy, federal, state and local laws and regulations relating to the energy industry. The adoption of laws and regulations curtailing exploration and development drilling for oil and gas for economic, environmental and other policy reasons may adversely affect our operations by limiting available drilling and other opportunities in the oil and gas exploration and production industry. Our operations and properties are subject to increasingly stringent laws and regulations relating to environmental protection, including laws and regulations governing air emissions, water discharges, waste management and workplace safety. Many of our operations require permits that may be revoked or modified, that we are required to renew from time to time. Failure to comply with such laws, regulations or permits can result in substantial fines and criminal sanctions, or require us to purchase costly pollution control equipment or implement operational changes or improvements. We incur, and expect to continue to incur, substantial capital and operating costs to comply with environmental laws and regulations.

We could become subject to claims related to the release of hazardous substances which could adversely affect our results and financial condition.

We use and generate hazardous substances and wastes in our manufacturing operations. In addition, many of our current and former properties are or have been used for industrial purposes for many years. Accordingly, we could become subject to potentially material liabilities relating to the investigation and cleanup of contaminated properties, including property owned or leased by us now or in the past or third party sites to which we sent waste for disposal. We also could become subject to claims alleging personal injury or property damage as the result of exposures to, or releases of, hazardous substances. In addition, stricter enforcement of existing laws and regulations, the enactment of new laws

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and regulations, the discovery of previously unknown contamination or the imposition of new or increased requirements could require us to incur costs or become the basis of new or increased liabilities that could reduce our earnings and our cash available for operations. See Note 11 to our audited consolidated financial statements included elsewhere in this report for more information regarding environmental contingencies.

Liability to customers under warranties may materially and adversely affect our earnings.

We provide warranties as to the proper operation and conformance to specifications of the equipment we manufacture. Our pressure control equipment and premium connections are often deployed in critical environments including subsea applications. Failure of this equipment or our premium connections to operate properly or to meet specifications may increase our costs by requiring additional engineering resources and services, replacement of parts and equipment or monetary reimbursement to a customer. We have in the past received warranty claims and we expect to continue to receive them in the future. To the extent that we incur substantial warranty claims in any period, our reputation, our ability to obtain future business and our earnings could be materially and adversely affected.

We may lose money on fixed price contracts, and such contracts could cause our quarterly revenue and earnings to fluctuate significantly.

Almost all of our pressure control projects, including all of our larger engineered subsea control systems projects, are performed on a fixed-price basis. This means that we are responsible for all cost overruns, other than any resulting from change orders. Our costs and any gross profit realized on our fixed-price contracts could vary from the estimated amounts on which these contracts were originally based. This may occur for various reasons, including:

The variations and the risks inherent in engineered subsea control systems projects may result in reduced profitability or losses on our projects. Depending on the size of a project, variations from estimated contract performance can have a significant impact on our operating results for any particular fiscal quarter or year. Our significant losses in 1997 through 1999 on fixed-price contracts to provide pressure control equipment and subsea control systems for pressure control equipment are an example of the problems we can experience with fixed-price contracts.

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Excess cash is invested in marketable securities which may subject us to potential losses.

We invest excess cash in various securities and money market mutual funds rated as the highest quality by a nationally recognized rating agency. However, changes in the financial markets, including interest rates, as well as the performance of the issuing companies can affect the market value of our short-term investments.

Part I, Item 3: Quantitative and Qualitative Disclosures About Market Risk

There have been no significant changes since December 31, 2004 in the Company’s exposure to market risk.

Part I, Item 4: Controls and Procedures

Hydril’s Chief Executive Officer and Chief Financial Officer have evaluated the Company’s disclosure controls and procedures as of March 31, 2005 and they have concluded that these controls and procedures are effective. There were no changes in the Company’s internal control over financial reporting that occurred during the Company’s last fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Part II, Item 6: Exhibits

Exhibits:

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SIGNATURE

Pursuant to the requirements 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.

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