OCEANEERING INTERNATIONAL INC - Quarter Report: 2011 June (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

For the quarterly period ended June 30, 2011

OR

For the transition period from              to             

Commission File Number 1-10945

OCEANEERING INTERNATIONAL, INC.

(Exact name of registrant as specified in its charter)

(713) 329-4500

(Registrant’s telephone number, including area code)

Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

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

The number of shares of the registrant’s common stock outstanding as of July 29, 2011 was 108,533,170.

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Oceaneering International, Inc.

Form 10-Q

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PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

OCEANEERING INTERNATIONAL, INC. & SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands)

The accompanying Notes are an integral part of these Consolidated Financial Statements.

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OCEANEERING INTERNATIONAL, INC. & SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

(unaudited)

(in thousands, except per share amounts)

The accompanying Notes are an integral part of these Consolidated Financial Statements.

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OCEANEERING INTERNATIONAL, INC. & SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

(in thousands)

The accompanying Notes are an integral part of these Consolidated Financial Statements.

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OCEANEERING INTERNATIONAL, INC. & SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1. Summary of Major Accounting Policies

Basis of Presentation. We have prepared these unaudited consolidated financial statements pursuant to instructions for quarterly reports on Form 10-Q, which we are required to file with the Securities and Exchange Commission. These financial statements do not include all information and footnotes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States. These financial statements reflect all adjustments that we believe are necessary to present fairly our financial position at June 30, 2011 and our results of operations and cash flows for the periods presented. Except as otherwise disclosed herein, all such adjustments are of a normal and recurring nature. These financial statements should be read in conjunction with the consolidated financial statements and related notes included in our annual report on Form 10-K for the year ended December 31, 2010. The results for interim periods are not necessarily indicative of annual results.

Based on changes in the economic facts and circumstances of our operations in Brazil, we have changed the functional currency of our Brazilian subsidiary from the U.S. dollar to the Brazilian real effective January 1, 2011. This change had no material effect on our financial statements.

Stock Split. On May 6, 2011, our Board of Directors declared a two-for-one stock split to be effected in the form of a stock dividend of our common stock to our shareholders of record at the close of business on May 19, 2011. The stock dividend was distributed on June 10, 2011. All historical share and per share data in this Form 10-Q reflect this stock split. The total number of authorized shares of common stock and par value were unchanged by this stock split. We have restated shareholders’ equity to give retroactive recognition of the stock split for all periods presented by reclassifying an amount equal to the par value of the additional shares issued through the stock dividend from additional paid-in capital to common stock.

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

During the six-month period ended June 30, 2010, we recorded an impairment charge of $5.2 million to reduce the carrying value of our vessel held for sale, The Performer, to its fair value, less estimated costs to sell. This charge is reflected within the cost of services and products of our Subsea Projects segment. The Performer completed its contract in Angola during the first quarter of 2010. We estimated the fair value based on preliminary offers presented to us to purchase the vessel by market participants, which we believed were Level 3 inputs. In July 2010, we sold the vessel for approximately its reduced carrying value.

Reclassifications. Certain amounts from prior periods have been restated to conform to the current presentation.

Business Acquisitions. On March 31, 2011, we purchased, for $56 million net of cash acquired, Norse Cutting & Abandonment AS (“NCA”), a Norwegian oilfield technology company that specializes in providing subsea tooling services used in the plugging, abandonment and decommissioning of offshore oil and gas production platforms and subsea wellheads. In addition, NCA performs specialized maintenance and repair services on production platforms in the North Sea. NCA’s business is split approximately evenly between the North Sea and the U.S. Gulf of Mexico. We have accounted for this acquisition by allocating the purchase price to the net assets acquired based on their estimated fair values at the date of acquisition. This purchase price allocation is preliminary and based on information currently available to us, and is subject to change when we obtain final asset and liability valuations. This acquisition, along with another smaller acquisition we made in the second quarter, are not material. As a result, we have not included historical pro forma information.

Subsequent Events. We evaluated events and transactions through the issuance of these financial statements for possible recognition or disclosure.

New Accounting Standards. In October 2009, the FASB issued a release regarding accounting for revenue involving multiple-deliverable arrangements that will, in certain circumstances, require sellers to account for more products or services (“deliverables”) separately rather than as a combined unit.

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This release establishes a selling price hierarchy for determining the selling price of a deliverable. The selling price used for each deliverable will be based on vendor-specific objective evidence if available, third-party evidence if vendor-specific objective evidence is not available, or estimated selling price if neither vendor-specific objective evidence nor third-party evidence is available. The release also replaces the term fair value in the revenue allocation guidance with selling price to clarify that the allocation of revenue is based on entity-specific assumptions rather than assumptions of a marketplace participant.

The release eliminates the residual method of allocation and requires that arrangement consideration be allocated at the inception of the arrangement to all deliverables using the relative selling price method. The relative selling price method allocates any discount in the arrangement proportionally to each deliverable on the basis of each deliverable’s selling price.

The release requires that a seller determine its best estimated selling price in a manner that is consistent with that used to determine the price to sell the deliverable on a stand-alone basis. The release does not prescribe any specific methods that sellers must use to accomplish this objective, but provides guidance.

For us, the release was effective prospectively for revenue arrangements entered into or materially modified on or after January 1, 2011. The provisions of the release have not had a material effect on our financial position or results of operations.

Note 2. Investment in Medusa Spar LLC

We own a 50% equity interest in Medusa Spar LLC. Medusa Spar LLC owns an interest in a production spar platform in the U.S. Gulf of Mexico. Medusa Spar LLC’s revenue is derived from processing oil and gas production for a fee based on the volumes processed through the platform. Medusa Spar LLC has no debt. We believe our maximum exposure to loss from our investment in Medusa Spar LLC is our investment. Medusa Spar LLC is a variable interest entity. We are not the primary beneficiary of Medusa Spar LLC because we own 50% of its equity and we do not manage the operations of the asset it owns. As we are not the primary beneficiary, we are accounting for our investment in Medusa Spar LLC under the equity method of accounting. Equity earnings from Medusa Spar LLC reflected in our financial statements are after amortization of our initial acquisition costs.

The following are condensed 100% statements of income of Medusa Spar LLC:

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Note 3. Inventory

Our inventory consisted of the following:

We state our inventory at the lower of cost or market. We determine cost using the weighted-average method.

Note 4. Debt

We had no long-term debt at June 30, 2011 and December 31, 2010.

We capitalized $0.1 million of interest in the three- and six-month periods ended June 30, 2010. We have not capitalized any interest in 2011.

Note 5. Commitments and Contingencies

Litigation. Various actions and claims are pending against us, most of which are covered by insurance. Although we cannot predict the ultimate outcome of these matters, we believe the ultimate liability, if any, that may result from these actions and claims will not materially affect our results of operations, cash flow or financial position.

Financial Instruments and Risk Concentration. In the normal course of business, we manage risks associated with foreign exchange rates and interest rates through a variety of strategies, including the use of hedging transactions. As a matter of policy, we do not use derivative instruments unless we have an underlying exposure.

We had an interest rate hedge in place on $100 million of floating rate debt under our revolving credit facility for the period August 2009 to August 2011, designated as a cash flow hedge. We terminated this hedge in May 2010 and charged the cost of $2.9 million to interest expense in the three-month period ended June 30, 2010.

Other financial instruments that potentially subject us to concentrations of credit risk are principally cash and cash equivalents and accounts receivable. The carrying values of cash and cash equivalents and bank borrowings approximate their fair values due to the short maturity of those instruments or the short-term duration of the associated interest rate periods. Accounts receivable are generated from a broad group of customers, primarily from within the energy industry, which is our major source of revenue. Due to their short-term nature, carrying values of our accounts receivable and accounts payable approximate fair market value.

One customer in Angola owed us $51 million at June 30, 2011, all of which is overdue. At December 31, 2010, this customer owed us $56 million. We collected $5 million from this customer during the six months ended June 30, 2011, and we have collected an additional $5 million subsequent to June 30, 2011. We completed the work on the contracts related to this receivable in the first quarter of 2010. Based on our past history with this customer, we believe this receivable will ultimately be collected.

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Note 6. Shareholders’ Equity, Earnings per Share and Stock-Based Compensation

Shareholders’ Equity

Our shareholders’ equity consisted of the following:

During the six-month period ended June 30, 2011, we reissued 302,406 shares of treasury stock to satisfy obligations under our stock-based compensation plans. On June 29, 2011, we paid a cash dividend of $0.15 per share, totaling $16,280,000, to our shareholders of record at the close of business on June 17, 2011. This was the first of a regular quarterly dividend program we announced in May 2011. In July 2011, we announced another quarterly dividend of $0.15 per share to be paid on September 20, 2011 to our shareholders of record at the close of business on September 1, 2011.

Comprehensive Income

Comprehensive income is the total of net income and all nonowner changes in equity. The amounts of comprehensive income for the periods indicated are as follows:

Accumulated other comprehensive Income

Amounts comprising the elements of other comprehensive income in Shareholders’ Equity are as follows:

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Earnings per Share

The following table presents our earnings per share calculations:

Stock-Based Compensation

Stock Options. At June 30, 2011, we had no outstanding stock options, and we had no future stock-based compensation expense to be recognized pursuant to stock option grants.

Restricted Stock Plan Information. We grant restricted units of our common stock to certain of our key executives, key employees and Chairman of the Board. We also grant shares of restricted stock to our other non-employee directors. The restricted units granted to our key executives and key employees generally vest in full on the third anniversary of the award date, conditional on continued employment. The restricted unit grants, including those granted to our Chairman, can vest pro rata over three years, provided the individual meets certain age and years-of-service requirements. The grants to our other non-employee directors vest in full on the first anniversary of the award date, conditional upon continued service as a director.

For each of the restricted stock units granted in 2009 through 2011, at the earlier of three years after grant or at termination of employment or service, the grantee will be issued a share of our common stock for each common stock unit vested. As of June 30, 2011 and December 31, 2010, totals of 1,099,200 and 1,044,150 shares of restricted stock or restricted stock units were outstanding. Each grantee of shares of restricted stock is deemed to be the record owner of those shares during the restriction period, with the right to vote and receive any dividends on those shares. The restricted stock units outstanding have no voting or dividend rights.

We estimate that stock-based compensation cost not yet recognized related to shares of restricted stock or restricted stock units, based on their grant-date fair values, was $18.8 million at June 30, 2011. This expense is being recognized on a staged-vesting basis over three years for awards attributable to individuals meeting certain age and years-of-service requirements, and on a straight-line basis over the applicable vesting period of one or three years for the other awards.

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Note 7. Income Taxes

General

During interim periods, we provide for income taxes based on our current estimated annual effective tax rate using assumptions as to (1) earnings and other factors that would affect the tax provision for the remainder of the year and (2) the operations of foreign branches and subsidiaries that are subject to local income and withholding taxes. The primary difference between our current 2011 estimated effective tax rate of 31.5% and the federal statutory tax rate of 35% reflects our intent to indefinitely reinvest in international operations; therefore, we are no longer providing for U.S. taxes on certain of our foreign earnings.

We conduct our operations in a number of locations that have varying laws and regulations with regard to income and other taxes, some of which are subject to interpretation. Our tax returns are subject to audit by taxing authorities in multiple jurisdictions. These audits often take years to complete and settle. Since December 31, 2010, the changes to the earliest tax years open to examination by tax authorities where we have significant operations are: Norway — to 2001 from 2000, Angola — to 2006 from 2005 and Nigeria — to 2005 from 2004. Our management believes that adequate provisions have been made for all taxes that ultimately will be payable, although final determinations of tax liabilities may differ from our estimates.

Income Tax Positions

The financial statement recognition of the benefit for a tax position depends on the benefit being more likely than not to be sustainable upon audit by the applicable taxing authority. If this threshold is met, the tax benefit is then measured and recognized at the largest amount that is more likely than not of being realized upon ultimate settlement. We account for any applicable interest and penalties on uncertain tax positions as a component of our provision for income taxes in our financial statements. There were no significant changes in the six-month periods ended June 30, 2011 and 2010, respectively, for penalties and interest taken in our financial statements relating to uncertain tax positions. Our total liabilities for penalties and interest on uncertain tax positions were $4.3 million and $4.0 million on our balance sheets at June 30, 2011 and December 31, 2010, respectively. Including penalties and interest, we have accrued a net total of $5.7 million and $5.6 million in the caption “other long-term liabilities” on our balance sheets at June 30, 2011 and December 31, 2010, respectively, for unrecognized tax benefits. All additions or reductions to those liabilities affect our effective income tax rate in the periods of change.

We do not believe that the total of our unrecognized tax benefits will significantly increase or decrease in the next 12 months.

Note 8. Business Segment Information

We are a global oilfield provider of engineered services and products primarily to the offshore oil and gas industry, with a focus on deepwater applications. Through the use of our applied technology expertise, we also serve the defense and aerospace industries. Our Oil and Gas business consists of four business segments: Remotely Operated Vehicles (“ROVs”); Subsea Products; Subsea Projects; and Inspection. Our Advanced Technologies business is a separate segment that provides project management, engineering services, products and equipment for applications outside the oil and gas industry. Unallocated Expenses are those not associated with a specific business segment. These consist of expenses related to our incentive and deferred compensation plans, including restricted stock units, performance units and bonuses, as well as other general expenses.

There are no differences in the basis of segmentation or in the basis of measurement of segment profit or loss from those used in our consolidated financial statements for the year ended December 31, 2010.

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The following summarizes certain financial data by business segment:

We generate a material amount of our consolidated revenue from contracts for services in the U.S. Gulf of Mexico in our Subsea Projects segment, which is usually more active from April through October, as compared to the rest of the year. The European operations of our Inspection segment are also seasonally more active in the second and third quarters. Revenue in our ROV segment is subject to seasonal variations in demand, with our first quarter generally being the low quarter of the year. The level of our ROV seasonality depends on the number of ROVs we have engaged in construction support, which is more seasonal than drilling support. Revenue in each of our Subsea Products and Advanced Technologies segments has generally not been seasonal.

During the six months ended June 30, 2011, we made $168 million of capital expenditures, of which $74 million was invested in our Subsea Products segment and $53 million was invested in our ROV segment. The amount in our Subsea Products segment included $59,558,000 for business acquisitions.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Certain forward-looking statements we make in this quarterly report on Form 10-Q, including, without limitation, statements regarding our expectations about:

are forward-looking statements made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. These forward-looking statements are subject to various risks, uncertainties and assumptions, including those we have referred to under the heading “Risk Factors” in this report and under the headings “Risk Factors” and “Cautionary Statement Concerning Forward-Looking Statements” in Part I of our annual report on Form 10-K for the year ended December 31, 2010. Although we believe that the expectations reflected in such forward-looking statements are reasonable, because of the inherent limitations in the forecasting process, as well as the relatively volatile nature of the industries in which we operate, we can give no assurance that those expectations will prove to be correct. Accordingly, evaluation of our future prospects must be made with caution when relying on forward-looking information.

The following discussion should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in our annual report on Form 10-K for the year ended December 31, 2010.

Executive Overview

We are raising our 2011 diluted earnings per share estimate from the range of $1.83 to $1.95 to the range of $1.90 to $1.98. This compares to our 2010 diluted earnings per share of $1.82. We have lowered our estimated effective tax rate from 34.3% in 2010 to 31.5% in 2011. We believe our ROV, Subsea Products and Inspection operating income will be higher in 2011 than in 2010. We believe Subsea Projects revenue and operating income for 2011 will be less than in 2010. We forecast third quarter 2011 diluted earnings per share of $0.54 to $0.58, with increases in operating income from ROVs, Subsea Products, Subsea Projects and Advanced Technologies over the second quarter of 2011. We expect increased days on hire for ROVs on international drill support work. In Subsea Products, we expect higher subsea field development and valve sales, and more operating income from tooling due to a change in product mix. We expect increased demand for our diving and deepwater vessel services in Subsea Projects, along with a profit contribution from the demobilization of the Ocean Legend. In Advanced Technologies, we expect increased submarine maintenance and installation work for the U.S. Navy.

We generate approximately 90% of our revenue and substantially all of our operating income before Unallocated Expenses from our services and products provided to the oil and gas industry, particularly in the deepwater sector of the offshore market. Consequently, the level of our customers’ capital spending on deepwater exploration and development has a significant impact on the demand for many of our services and products. The usual uncertainties we face associated with our customers’ spending and the timing of projects have been exacerbated by the Deepwater Horizon drilling rig tragedy at the Macondo well in the U.S. Gulf of Mexico in April 2010, the resulting environmental impacts, and the effects of new environmental and safety regulations established by the U.S. Department of the Interior in response to the incident. The moratorium, which was lifted in October 2010, and

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the subsequent regulatory developments and delay in issuing drilling permits began to have an unfavorable effect on our U.S. Gulf of Mexico ROV operations in June 2010. Deepwater well permitting in the U.S. Gulf of Mexico has resumed, and we believe there will be a gradual recovery of deepwater exploration and development activity in the U.S. Gulf of Mexico.

Critical Accounting Policies and Estimates

For information about our Critical Accounting Policies and Estimates, please refer to the discussion in our annual report on Form 10-K for the year ended December 31, 2010 under the heading “Critical Accounting Policies and Estimates” in Item 7 — Management’s Discussion and Analysis of Financial Condition and Results of Operation.

New Accounting Standards

For a discussion of new accounting standards applicable to us, see the discussion in Note 1 to the Consolidated Financial Statements contained in Item 1 of this quarterly report on Form 10-Q.

Liquidity and Capital Resources

We consider our liquidity and capital resources adequate to support our existing operations and capital commitments. At June 30, 2011, we had working capital of $556 million, including $151 million of cash and cash equivalents. Additionally, we had $300 million of borrowing capacity available under our revolving credit facility.

Our capital expenditures, including business acquisitions, were $168 million during the first six months of 2011, as compared to $95 million during the corresponding period of last year. We added eight new ROVs to our fleet during the six months ended June 30, 2011, retired five, and transferred one to our Advanced Technologies segment, resulting in a total of 262 ROVs available for oilfield use. We plan to add seven to 12 more new ROVs during the rest of 2011, and most of these are in the process of being built or installed. Our capital expenditures in the six months ended June 30, 2011 included $56 million for the acquisition of Norse Cutting & Abandonment AS (“NCA”), a Norwegian oilfield technology company, and $53 million in our ROV segment. NCA specializes in providing subsea tooling services used in the plugging, abandonment and decommissioning of offshore production platforms and subsea wellheads in the North Sea and the U.S. Gulf of Mexico. In addition, NCA performs specialized maintenance and repair services on production platforms in the North Sea. NCA is part of our Subsea Products segment. We estimate our capital expenditures for 2011 will be in the range of $250 million to $275 million, with $100 million for upgrading and adding vehicles to our ROV fleet, $56 million for the NCA acquisition, and $55 million in Subsea Projects, including the completion of the Ocean Patriot renovation and the addition of a third saturation diving system.

We have chartered a deepwater vessel, the Ocean Intervention III, for a term that now extends to May 2012, with annual extension options for up to four additional years. We have also chartered an additional deepwater vessel, the Olympic Intervention IV, for an initial five-year term ending in July 2013, with one two-year and three one-year extension options. We have outfitted each of these deepwater vessels with two of our high specification work-class ROVs, and we use these vessels to perform subsea hardware installation and inspection, repair and maintenance projects in the ultra-deep waters of the U.S. Gulf of Mexico.

We had no material contractual commitments for capital expenditures at June 30, 2011.

At June 30, 2011, we had no long-term debt outstanding and an available $300 million revolving credit facility, which is scheduled to expire in January 2012. The revolving credit facility has short-term interest rates that float with market rates, plus applicable spreads. We plan to renew or replace our revolving credit agreement in 2011.

Our principal source of cash from operating activities is our net income, adjusted for the non-cash expenses of depreciation and amortization, deferred income taxes and noncash compensation under our restricted stock plans. Our $85 million and $195 million of cash provided from operating activities in the six-month periods ended June 30, 2011 and 2010, respectively, were affected by cash increases/(decreases) of: ($64 million) and ($1 million), respectively, from changes in accounts receivable; ($23 million) and ($7 million), respectively, from changes in inventory; and ($10 million) and $41 million, respectively, from changes in operating liabilities.

In the six-month period ended June 30, 2011, we used $164 million of cash in investing activities. The cash used in investing activities was used for the capital expenditures, including the business acquisition, described above.

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We have not guaranteed any debt not reflected on our consolidated balance sheet and do not have any off-balance sheet arrangements, as defined by SEC rules.

In February 2010, our Board of Directors approved a plan to repurchase up to 12 million shares of our common stock. The timing and amount of repurchases will be determined by our management. We expect that any shares repurchased under the plan will be held as treasury stock for future use. The plan does not obligate us to repurchase any particular number of shares. We repurchased a total of 2.2 million shares for $49.5 million during 2010, and we have made no additional repurchases during 2011.

In May 2011, our Board of Directors declared a two-for-one common stock split effected by means of a stock dividend, which was distributed on June 10, 2011. In addition, the board initiated a regular quarterly dividend of $0.15 per common share on the split-adjusted shares, with the first such dividend paid on June 29, 2011 to shareholders of record at the close of business on June 17, 2011. In July 2011, we announced another quarterly dividend of $0.15 per share to be paid on September 20, 2011 to our shareholders of record at the close of business on September 1, 2011.

Results of Operations

We operate in five business segments. The segments are contained within two businesses — services and products provided to the oil and gas industry (“Oil and Gas”) and all other services and products (“Advanced Technologies”). Our Unallocated Expenses are those not associated with a specific business segment.

Consolidated revenue and margin information is as follows:

We generate a material amount of our consolidated revenue from contracts for services in the U.S. Gulf of Mexico in our Subsea Projects segment, which is usually more active from April through October, as compared to the rest of the year. The European operations of our Inspection segment are also seasonally more active in the second and third quarters. Revenue in our ROV segment is subject to seasonal variations in demand, with our first quarter generally being the low quarter of the year. The level of our ROV seasonality depends on the number of ROVs we have engaged in construction support, which is more seasonal than drilling support. Revenue in each of our Subsea Products and Advanced Technologies segments has generally not been seasonal.

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Oil and Gas

The following table sets forth the revenues and margins for our Oil and Gas business segments for the periods indicated.