Exhibit 99.1

To the Annual General Meeting of

Transocean Ltd., Zug

Zurich, February 27, 2012

Report of the statutory auditor on the consolidated financial statements

As statutory auditor, we have audited the consolidated financial statements of Transocean Ltd. and subsidiaries, which comprise the consolidated balance sheets as of December 31, 2011 and 2010 and the related consolidated statements of operations, comprehensive income (loss), equity, and cash flows and notes thereto (pages 2 to 61) for each of the three years in the period ended December 31, 2011.

Board of Directors’ responsibility

The Board of Directors is responsible for the preparation and fair presentation of the consolidated financial statements in accordance with accounting principles generally accepted in the United States and the requirements of Swiss law. This responsibility includes designing, implementing and maintaining an internal control system relevant to the preparation and fair presentation of consolidated financial statements that are free from material misstatement, whether due to fraud or error. The Board of Directors is further responsible for selecting and applying appropriate accounting policies and making accounting estimates that are reasonable in the circumstances.

Auditor’s responsibility

Our responsibility is to express an opinion on these consolidated financial statements based on our audit. We conducted our audit in accordance with Swiss law, Swiss Auditing Standards and standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance whether the consolidated financial statements are free from material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the consolidated financial statements. The procedures selected depend on the auditor’s judgment, including the assessment of the risks of material misstatement of the consolidated financial statements, whether due to fraud or error. In making those risk assessments, the auditor considers the internal control system relevant to the entity’s preparation and fair presentation of the consolidated financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control system. An audit also includes evaluating the appropriateness of the accounting policies used and the reasonableness of accounting estimates made, as well as evaluating the overall presentation of the consolidated financial statements. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.

Opinion

In our opinion, the consolidated financial statements for the years ended December 31, 2011 and 2010 present fairly in all material respects, the consolidated financial position of Transocean Ltd. and subsidiaries at December 31, 2011 and 2010, and the consolidated results of operations and cash flows for each of the three years in the period ended December 31, 2011 in accordance with accounting principles generally accepted in the United States and comply with Swiss law.

Without qualifying our opinion we draw attention to Note 15 to the consolidated financial statements describing material uncertainties surrounding the Macondo well incident. The company is unable to estimate the full impact the Macondo well incident will have on them.  The company has recognized a liability for estimated loss contingencies that they believe are probable and for which a reasonable estimate can be made.

Report on other legal requirements

We confirm that we meet the legal requirements on licensing according to the Auditor Oversight Act (AOA) and independence (article 728 CO and article 11 AOA) and that there are no circumstances incompatible with our independence.

In accordance with article 728a paragraph 1 item 3 CO and Swiss Auditing Standard 890, we confirm that an internal control system exists, which has been designed for the preparation of consolidated financial statements according to the instructions of the Board of Directors.

We recommend that the consolidated financial statements submitted to you be approved.

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TRANSOCEAN LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(In millions, except per share data)

See accompanying notes.

2

TRANSOCEAN LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In millions)

See accompanying notes.

3

TRANSOCEAN LTD. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In millions, except share data)

See accompanying notes.

4

TRANSOCEAN LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF EQUITY

(In millions)

See accompanying notes.

5

TRANSOCEAN LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

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TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1—Nature of Business

Transocean Ltd. (together with its subsidiaries and predecessors, unless the context requires otherwise, “Transocean,” the “Company,” “we,” “us” or “our”) is a leading international provider of offshore contract drilling services for oil and gas wells.  We specialize in technically demanding sectors of the offshore drilling business with a particular focus on deepwater and harsh environment drilling services.  Our mobile offshore drilling fleet is considered one of the most versatile fleets in the world.  We contract our drilling rigs, related equipment and work crews predominantly on a dayrate basis to drill oil and gas wells.  At December 31, 2011, we owned or had partial ownership interests in and operated 135 mobile offshore drilling units.  As of this date, our fleet consisted of 50 High-Specification Floaters (Ultra-Deepwater, Deepwater and Harsh Environment semisubmersibles and drillships), 25 Midwater Floaters, nine High-Specification Jackups, 50 Standard Jackups and one swamp barge.  In addition, we had two Ultra-Deepwater Floaters and four High-Specification Jackups under construction (see Note 10—Drilling Fleet).

We also provide oil and gas drilling management services, drilling engineering and drilling project management services through Applied Drilling Technology Inc., our wholly owned subsidiary, and through ADT International, a division of one of our U.K. subsidiaries (together, “ADTI”).  ADTI conducts drilling management services primarily on either a dayrate or a completed-project, fixed-price (or “turnkey”) basis.

In February 2011, we sold the subsidiary that owns the High-Specification Jackup Trident 20, located in the Caspian Sea.  In March 2011, we engaged an unaffiliated advisor to coordinate the sale of the assets of our oil and gas properties reporting unit, a component of our other operations segment, which comprises the exploration, development and production activities performed by Challenger Minerals Inc. and Challenger Minerals (North Sea) Limited (together, “CMI”).  As a result of these actions, we reclassified to discontinued operations the operating results associated with our Caspian Sea operations and our oil and gas operations.  Additionally, we reclassified the assets and liabilities of these components as held for sale.  In October 2011, we completed the sale of Challenger Minerals (North Sea) Limited.  See Note 7—Discontinued Operations and Note 28—Subsequent Events.

In October 2011, we completed our acquisition of Aker Drilling, a Norwegian company formerly listed on the Oslo Stock Exchange.  In connection with the acquisition, we acquired two Harsh Environment, Ultra-Deepwater semisubmersibles currently operating on long-term contracts in Norway.  Additionally, we acquired two Ultra-Deepwater drillships currently under construction at the Daewoo Shipbuilding & Marine Engineering Co. Ltd. shipyard in Korea, which have expected deliveries in 2014.  See Note 4—Business Combination.

Note 2—Significant Accounting Policies

Accounting estimates—The preparation of financial statements in accordance with accounting principles generally accepted in the United States (“U.S.”) requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosures of contingent assets and liabilities.  On an ongoing basis, we evaluate our estimates and assumptions, including those related to our allowance for doubtful accounts, materials and supplies obsolescence, property and equipment, investments, notes receivable, goodwill and other intangible assets, income taxes, share-based compensation, defined benefit pension plans and other postretirement benefits and contingencies.  We base our estimates and assumptions on historical experience and on various other factors we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying amounts of assets and liabilities that are not readily apparent from other sources.  Actual results could differ from such estimates.

Fair value measurements—We estimate fair value at a price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the principal market for the asset or liability.  Our valuation techniques require inputs that we categorize using a three-level hierarchy, from highest to lowest level of observable inputs, as follows: (1) significant observable inputs, including unadjusted quoted prices for identical assets or liabilities in active markets (“Level 1”), (2) significant other observable inputs, including direct or indirect market data for similar assets or liabilities in active markets or identical assets or liabilities in less active markets (“Level 2”) and (3) significant unobservable inputs, including those that require significant judgment for which there is little or no market data (“Level 3”).  When multiple input levels are required for a valuation, we categorize the entire fair value measurement according to the lowest level of input that is significant to the measurement even though we may have also utilized significant inputs that are more readily observable.

Consolidation—We consolidate entities in which we have a majority voting interest and entities that meet the criteria for variable interest entities for which we are deemed to be the primary beneficiary for accounting purposes.  We eliminate intercompany transactions and accounts in consolidation.  We apply the equity method of accounting for investments in entities if we have the ability to exercise significant influence over an entity that (a) does not meet the variable interest entity criteria or (b) meets the variable interest entity criteria, but for which we are not deemed to be the primary beneficiary.  We apply the cost method of accounting for investments in other entities if we do not have the ability to exercise significant influence over the unconsolidated affiliate.  See Note 23—Variable Interest Entities.

We recognized equity in earnings of unconsolidated affiliates, recorded in other, net, on our consolidated statements of operations, in the amount of $18 million, $8 million and $6 million for the years ended December 31, 2011, 2010 and 2009, respectively.  Our investments in and advances to unconsolidated affiliates, recorded in other assets, had carrying amounts of less than $1 million and $19 million at December 31, 2011 and 2010, respectively.

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TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

Business combination—In connection with our acquisition of Aker Drilling, we applied the acquisition method of accounting.  Accordingly, we recorded the acquired assets and assumed liabilities at fair value and recognized goodwill to the extent the fair value of the business acquired exceeded the fair value of the net assets.  We estimated the fair values of the acquired assets and assumed liabilities as of the date of the acquisition, and our estimates are subject to adjustment based on our final assessments of the fair values of property and equipment, intangible assets, liabilities and our evaluation of tax positions and contingencies.  We will complete our final assessments of the fair values of the acquired assets and assumed liabilities and our final evaluations of uncertain tax positions and contingencies within one year of the acquisition date.  See Note 4—Business Combination.

Operating revenues and expenses—We recognize operating revenues as they are earned, based on contractual dayrates or on a fixed-price basis.  In connection with drilling contracts, we may receive revenues for preparation and mobilization of equipment and personnel or for capital improvements to rigs.  In connection with new drilling contracts, revenues earned and incremental costs incurred directly related to contract preparation and mobilization are deferred and recognized over the primary contract term of the drilling project using the straight-line method.  Our policy to amortize the fees related to contract preparation, mobilization and capital upgrades on a straight-line basis over the estimated firm period of drilling is consistent with the general pace of activity, level of services being provided and dayrates being earned over the life of the contract.  For contractual daily rate contracts, we account for loss contracts as the losses are incurred.  Costs of relocating drilling units without contracts to more promising market areas are expensed as incurred.  Upon completion of drilling contracts, any demobilization fees received are reported in income, as are any related expenses.  Capital upgrade revenues received are deferred and recognized over the primary contract term of the drilling project.  The actual cost incurred for the capital upgrade is depreciated over the estimated useful life of the asset.  We incur periodic survey and drydock costs in connection with obtaining regulatory certification to operate our rigs and well control systems on an ongoing basis.  Costs associated with these certifications are deferred and amortized on a straight-line basis over the period until the next survey.

Contract drilling intangible revenues—In connection with our business combination with GlobalSantaFe Corporation in November 2007, we acquired drilling contracts for future contract drilling services.  The terms of these contracts include all fixed dayrates that were above or below the market dayrates that were available for similar contracts as of the date of the business combination.  We recognized the fair value adjustments as contract intangible assets and liabilities, recorded in other assets and other long-term liabilities, respectively.  We amortize the resulting contract drilling intangible revenues on a straight-line basis over the respective contract period.  We recognized contract drilling intangible revenues of $45 million, $98 million and $281 million in the years ended December 31, 2011, 2010 and 2009, respectively.  See Note 11—Goodwill and Other Intangible Assets.

Other revenues—Our other revenues represent those derived from drilling management services, integrated services, and customer reimbursable revenues.  For fixed-price contracts associated with our drilling management services, we recognize revenues and expenses upon well completion and customer acceptance, and we recognize loss provisions on contracts in progress when losses are anticipated.  We refer to integrated services as those services we provide through contractors and our employees under certain contracts that include well and logistics services in addition to our normal drilling services.  We consider customer reimbursable revenues to be billings to our customers for reimbursement of certain equipment, materials and supplies, third-party services, employee bonuses and other expenses that we recognize in operating and maintenance expense, the result of which has little or no effect on operating income.

Share-based compensation—For time-based awards, we recognize compensation expense on a straight-line basis through the date the employee is no longer required to provide service to earn the award (the “service period”).  For market-based awards that vest at the end of the service period, we recognize compensation expense on a straight-line basis through the end of the service period.  For performance-based awards with graded vesting conditions, we recognize compensation expense on a straight-line basis over the service period for each separately vesting portion of the award as if the award was, in substance, multiple awards.  Share-based compensation expense is recognized, net of a forfeiture rate, estimated at the time of grant based on historical experience and adjusted, if necessary, in subsequent periods based on actual forfeitures.

To measure the fair values of time-based restricted shares and deferred units granted or modified, we use the market price of our shares on the grant date or modification date.  To measure the fair values of stock options and stock appreciation rights (“SARs”) granted or modified, we use the Black-Scholes-Merton option-pricing model and apply assumptions for the expected life, risk-free interest rate, dividend yield and expected volatility.  The expected life is based on historical information of past employee behavior regarding exercises and forfeitures of options.  The risk-free interest rate is based upon the published U.S. Treasury yield curve in effect at the time of grant or modification for instruments with a similar life.  The dividend yield is based on our history and expectation of dividend payouts.  The expected volatility is based on a blended rate with an equal weighting of the (a) historical volatility based on historical data for an amount of time approximately equal to the expected life and (b) implied volatility derived from our at-the-money long-dated call options.  To measure the fair values of market-based deferred units granted or modified, we use a Monte Carlo simulation model and, in addition to the assumptions applied for the Black-Scholes-Merton option-pricing model, we apply assumptions using a risk neutral model and an average price at the performance start date.  The risk neutral model assumes that all peer group stocks grow at the risk-free rate.  The average price at the performance start date is based on the average stock price for the preceding 30 trading days.

We recognize share-based compensation expense in the same financial statement line item as cash compensation paid to the respective employees.  Tax deduction benefits for awards in excess of recognized compensation costs are reported as a financing cash flow.  Share-based compensation expense was $95 million, $102 million and $81 million in the years ended December 31, 2011, 2010 and 2009, respectively.  Income tax benefit on share-based compensation expense was $16 million, $13 million, and $11 million in the years ended December 31, 2011, 2010 and 2009, respectively.  See Note 18—Share-Based Compensation Plans.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

Capitalized interest—We capitalize interest costs for qualifying construction and upgrade projects.  We capitalized interest costs on construction work in progress of $39 million, $89 million and $182 million for the years ended December 31, 2011, 2010 and 2009, respectively.

Foreign currency—The majority of our revenues and expenditures are denominated in U.S. dollars to limit our exposure to currency exchange rate fluctuations, resulting in the use of the U.S. dollar as the functional currency for all of our operations.  We recognize foreign currency exchange gains and losses in other income (expense), net.  We recognized net foreign currency exchange gain (losses) of $(99) million, $1 million and $(33) million for the years ended December 31, 2011, 2010 and 2009, respectively.  See Note 13—Derivatives and Hedging.

Income taxes—We provide for income taxes based upon the tax laws and rates in effect in the countries in which operations are conducted and income is earned.  There is little or no expected relationship between the provision for or benefit from income taxes and income or loss before income taxes because the countries in which we operate have taxation regimes that vary not only with respect to nominal rate, but also in terms of the availability of deductions, credits and other benefits.  Variations also arise because income earned and taxed in any particular country or countries may fluctuate from year to year.

We recognize deferred tax assets and liabilities for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of our assets and liabilities using the applicable jurisdictional tax rates in effect at year end.  We record a valuation allowance for deferred tax assets when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized.  We provide a valuation allowance to offset deferred tax assets for net operating losses (“NOL”) incurred during the year in certain jurisdictions and for other deferred tax assets where, in our opinion, it is more likely than not that the financial statement benefit of these losses will not be realized.  We provide a valuation allowance for foreign tax credit carryforwards to reflect the possible expiration of these benefits prior to their utilization.

We maintain liabilities for estimated tax exposures in our jurisdictions of operation, and the provisions and benefits resulting from changes to those liabilities are included in our annual tax provision along with related interest and penalties.  Tax exposure items include potential challenges to permanent establishment positions, intercompany pricing, disposition transactions, and withholding tax rates and their applicability.  These exposures are resolved primarily through the settlement of audits within these tax jurisdictions or by judicial means, but can also be affected by changes in applicable tax law or other factors, which could cause us to revise past estimates.  See Note 6—Income Taxes.

Cash and cash equivalents—Cash equivalents are highly liquid debt instruments with original maturities of three months or less that may include time deposits with commercial banks that have high credit ratings, U.S. Treasury and government securities, Eurodollar time deposits, certificates of deposit and commercial paper.  We may also invest excess funds in no-load, open-end, management investment trusts (“management trusts”).  The management trusts invest exclusively in high-quality money market instruments.

We maintain restricted cash investments that are pledged for debt service, as required under certain bank credit agreements.  We classify such restricted cash investment balances in other current assets if the restriction is expected to expire within one year and in other assets if the restriction is expected to expire in greater than one year.  At December 31, 2011, the aggregate carrying amount of our restricted cash investments was $928 million, of which $182 million and $746 million was classified in other current assets and other assets, respectively.  At December 31, 2010, the aggregate carrying amount of our restricted cash investments was $47 million, classified in other assets.  See Note 12—Debt.

Allowance for doubtful accounts—We establish an allowance for doubtful accounts on a case-by-case basis, considering changes in the financial position of a major customer, when we believe the required payment of specific amounts owed is unlikely to occur.  We derive a majority of our revenues from services to international oil companies and government-owned or government-controlled oil companies.  We evaluate the credit quality of our customers on an ongoing basis, and we do not generally require collateral or other security to support customer receivables.  The allowance for doubtful accounts was $28 million and $38 million at December 31, 2011 and 2010, respectively.

Materials and supplies—Materials and supplies are carried at average cost less an allowance for obsolescence.  The allowance for obsolescence was $73 million and $70 million at December 31, 2011 and 2010, respectively.

Assets held for sale—We classify an asset as held for sale when the facts and circumstances meet the criteria for such classification, including the following: (a) we have committed to a plan to sell the asset, (b) the asset is available for immediate sale, (c) we have initiated actions to complete the sale, including locating a buyer, (d) the sale is expected to be completed within one year, (e) the asset is being actively marketed at a price that is reasonable relative to its fair value, and (f) the plan to sell is unlikely to be subject to significant changes or termination.  Assets held for sale were $26 million and less than $1 million at December 31, 2011 and 2010, respectively.  See Note 7—Discontinued Operations.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

Property and equipment—Property and equipment, consisting primarily of offshore drilling rigs and related equipment, represented approximately 64 percent of our total assets at December 31, 2011.  The carrying amounts of these assets are based on estimates, assumptions and judgments relative to capitalized costs, useful lives and salvage values of our rigs.  These estimates, assumptions and judgments reflect both historical experience and expectations regarding future industry conditions and operations.  We compute depreciation using the straight-line method after allowing for salvage values.  We capitalize expenditures for renewals, replacements and improvements, and we expense maintenance and repair costs as incurred.  Upon sale or other disposition of an asset, we recognize a net gain or loss on disposal of the asset, which is measured as the difference between the net carrying amount of the asset and the net proceeds received.

Estimated original useful lives of our drilling units range from 18 to 35 years, our buildings and improvements range from 10 to 30 years and our machinery and equipment range from four to 12 years.  From time to time, we may review the estimated remaining useful lives of our drilling units, and we may extend the useful life when events and circumstances indicate a drilling unit can operate beyond its remaining useful life.  During 2011, we adjusted the useful lives for two rigs, extending the estimated useful lives from between 20 and 30 years to between 23 and 38 years.  During 2010, we adjusted the useful lives for five rigs, extending the estimated useful lives from between 20 and 36 years to between 25 and 39 years.  During 2009, we adjusted the useful lives for 10 rigs, extending the estimated useful lives from between 30 and 35 years to between 33 and 50 years.  We deemed the life extensions appropriate for each of these rigs based on the respective contracts under which the rigs were operating and the additional life-extending work, upgrades and inspections we performed on the rigs.  For each of the years ended December 31, 2011, 2010 and 2009, the changes in estimated useful lives of these rigs resulted in a reduction in depreciation expense of $2 million ($0.01 per diluted share from continuing operations), $23 million ($0.07 per diluted share from continuing operations) and $23 million ($0.07 per diluted share from continuing operations), respectively, which had no tax effect for any period.

Long-lived assets and definite-lived intangible assets—We review the carrying amounts of long-lived assets and definite-lived intangible assets, principally property and equipment and a drilling management services customer relationships intangible asset, for potential impairment when events occur or circumstances change that indicate that the carrying value of such assets may not be recoverable.

For assets classified as held and used, we determine recoverability by evaluating the undiscounted estimated future net cash flows, based on projected dayrates and utilization, of the asset group under review.  We consider our asset groups to be Ultra-Deepwater Floaters, Deepwater Floaters, Harsh Environment Floaters, Midwater Floaters, High-Specification Jackups, and Standard Jackups.  When an impairment of one or more of our asset groups is indicated, we measure the impairment as the amount by which the asset group’s carrying amount exceeds its fair value.  We measure the fair values of our contract drilling asset groups by applying a combination of income and market approaches, using projected discounted cash flows and estimates of the exchange price that would be received for the assets in the principal or most advantageous market for the assets in an orderly transaction between market participants as of the measurement date.  For our drilling management services customer relationships asset, we estimate fair value using the excess earnings method, which applies the income approach.  For an asset classified as held for sale, we consider the asset to be impaired to the extent its carrying amount exceeds fair value less cost to sell.

In the year ended December 31, 2011, we concluded that our assets held for sale were impaired, and we recognized a loss on impairment of $28 million.  In the year ended December 31, 2010, we concluded that our Standard Jackup asset group was impaired, and we recognized a loss on impairment of $1.0 billion ($3.15 per diluted share from continuing operations), which had no tax effect.  In the year ended December 31, 2009, we determined that our assets held for sale and our customer relationships intangible asset were impaired, and we recognized losses on the impairment of these assets in the amount of $279 million ($0.87 per diluted share from continuing operations), which had no tax effect, and $49 million ($0.15 per diluted share from continuing operations), which had no tax effect.  See Note 5—Impairments and Note 11—Goodwill and Other Intangible Assets.

Goodwill and other indefinite-lived intangible assets—We conduct impairment testing for our goodwill and other indefinite-lived intangible assets annually as of October 1 and more frequently, on an interim basis, when an event occurs or circumstances change that may indicate a reduction in the fair value of a reporting unit or the indefinite-lived intangible asset is below its carrying value.

We test goodwill at the reporting unit level, which is defined as an operating segment or one level below an operating segment that constitutes a business for which financial information is available and is regularly reviewed by management.  We have identified two reporting units for this purpose: (1) contract drilling services and (2) drilling management services.  We test goodwill for impairment by comparing the carrying amount of the reporting unit, including goodwill, to the fair value of the reporting unit.

For our contract drilling services reporting unit, we estimate fair value using projected discounted cash flows, publicly traded company multiples and acquisition multiples.  To develop the projected cash flows associated with our contract drilling services reporting unit, which are based on estimated future dayrates and utilization, we consider key factors that include assumptions regarding future commodity prices, credit market conditions and the effect these factors may have on our contract drilling operations and the capital expenditure budgets of our customers.  We discount the projected cash flows using a long-term, risk-adjusted weighted-average cost of capital, which is based on our estimate of the investment returns that market participants would require for each of our reporting units.  We derive publicly traded company multiples for companies with operations similar to our reporting units using observable information related to shares traded on stock exchanges and, when available, observable information related to recent acquisitions.  If the reporting unit’s

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

carrying amount exceeds its fair value, we consider goodwill impaired and perform a second step to measure the amount of the impairment loss, if any.  As a result of our annual impairment testing on October 1, 2011, we concluded that our goodwill was impaired due to a decline in projected cash flows and market valuations for this reporting unit, and we recognized an estimated loss on impairment of goodwill in the amount of $5.2 billion ($16.15 per diluted share from continuing operations), which had no tax effect.  As a result of our annual impairment testing in each of the years ended December 31, 2010 and 2009, we concluded that goodwill was not impaired.  See Note 5—Impairments and Note 11—Goodwill and Other Intangible Assets.

For our trade name intangible asset, which we have identified as indefinite-lived, we estimate fair value using the relief from royalty method, which applies the income approach.  As a result of our impairment testing in the years ended December 31, 2011 and 2010, we concluded that the trade name intangible asset for our drilling management services reporting unit was not impaired.  As a result of impairment testing in the year ended December 31, 2009, we concluded that the trade name intangible asset for our drilling management services reporting unit was impaired, and we recognized a loss on impairment in the amount of $6 million ($0.02 per diluted share from continuing operations), which had no tax effect.  See Note 5—Impairments and Note 11—Goodwill and Other Intangible Assets.

Derivatives and hedging—From time to time, we may enter into a variety of derivative financial instruments in connection with the management of our exposure to variability in interest rates and currency exchange rates.  We record derivatives on our consolidated balance sheet, measured at fair value.  For derivatives that do not qualify for hedge accounting, we recognize the gains and losses associated with changes in the fair value in current period earnings.

We may enter into cash flow hedges to manage our exposure to variability of the expected future cash flows of recognized assets or liabilities or of unrecognized forecasted transactions.  For a derivative that is designated and qualifies as a cash flow hedge, we initially recognize the effective portion of the gains or losses in other comprehensive income and subsequently recognize the gains and losses in earnings in the period in which the hedged forecasted transaction affects earnings.  We recognize the gains and losses associated with the ineffective portion of the hedges in interest expense in the period in which they are realized.

We may enter into fair value hedges to manage our exposure to changes in fair value of recognized assets or liabilities, such as fixed-rate debt, or of unrecognized firm commitments.  For a derivative that is designated and qualifies as a fair value hedge, we simultaneously recognize in current period earnings the gains or losses on the derivative along with the offsetting losses or gains on the hedged item attributable to the hedged risk.  The resulting ineffective portion, which is measured as the difference between the change in fair value of the derivative and the hedged item, is recognized in current period earnings.  See Note 13—Derivatives and Hedging and Note 22—Financial Instruments and Risk Concentration.

Pension and other postretirement benefits—We use a measurement date of January 1 for determining net periodic benefit costs and December 31 for determining benefit obligations and the fair value of plan assets.  We determine our net periodic benefit costs based on a market-related valuation of assets that reduces year-to-year volatility by recognizing investment gains or losses over a five-year period from the year in which they occur.  Investment gains or losses for this purpose are measured as the difference between the expected return calculated using the market-related value of assets and the actual return based on the market-related value of assets.  If gains or losses exceed 10 percent of the greater of plan assets or plan liabilities, we amortize such gains or losses over the average expected future service period of the employee participants.

The obligations and related costs for our defined benefit pension and other postretirement benefit plans, retiree life insurance and medical benefits, are actuarially determined by applying assumptions, including long-term rate of return on plan assets, discount rates, compensation increases, employee turnover rates and health care cost trend rates.  The two most critical assumptions are the long-term rate of return on plan assets and the discount rate.

For the long-term rate of return, we develop our assumptions regarding the expected rate of return on plan assets based on historical experience and projected long-term investment returns, which are weighted to consider each plan’s target asset allocation.  For the discount rate, we base our assumptions on a yield curve approach using Aa-rated corporate bonds and the expected timing of future benefit payments.  For the projected compensation trend rate, we consider short-term and long-term compensation expectations for participants, including salary increases and performance bonus payments.  For the health care cost trend rate for other postretirement benefits, we establish our assumptions for health care cost trends, applying an initial trend rate that reflects both our recent historical experience and broader national statistics with an ultimate trend rate that assumes that the portion of gross domestic product devoted to health care eventually becomes constant.

Pension and other postretirement benefit plan obligations represented an aggregate liability in the amount of their net underfunded status of $640 million and $469 million, at December 31, 2011 and 2010, respectively.  Net periodic benefit costs were $88 million, $91 million and $87 million for the years ended December 31, 2011, 2010 and 2009, respectively.  See Note 14—Postemployment Benefit Plans.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

Contingent liabilities—We perform assessments of our contingencies on an ongoing basis to evaluate the appropriateness of our liabilities and disclosures for such contingencies.  We establish liabilities for estimated loss contingencies when we believe a loss is probable and the amount of the probable loss can be reasonably estimated.  We recognize corresponding assets for those loss contingencies that we believe are probable of being recovered through insurance.  Once established, we adjust the carrying amount of a contingent liability upon the occurrence of a recognizable event when facts and circumstances change, altering our previous assumptions with respect to the likelihood or amount of loss.  We recognize liabilities for legal costs as they are incurred, and we recognize a corresponding asset for those legal costs that we expect to be recovered through insurance.

Reclassifications—We have made certain reclassifications, which did not have an effect on net income, to prior period amounts to conform with the current year’s presentation, including certain reclassifications to our consolidated statement of financial position, results of operations and cash flows to present our oil and gas operating segment and our Caspian Sea operations as discontinued operations (see Note 7—Discontinued Operations).  These reclassifications did not have a material effect on our consolidated statement of financial position, results of operations or cash flows.

Subsequent events—We evaluate subsequent events through the time of our filing on the date we issue our financial statements.  See Note 28—Subsequent Events.

Note 3—New Accounting Pronouncements

Recently Issued Accounting Standards

Intangibles-goodwill and other—Effective January 1, 2012, we will adopt the accounting standards update that amends the goodwill impairment testing requirements by giving an entity the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount and whether the two-step impairment test is required.  The update is effective for goodwill impairment tests performed for annual and interim periods beginning after December 15, 2011.  We do not expect that our adoption will have a material effect on our consolidated financial statements.

Balance sheet—Effective January 1, 2013, we will adopt the accounting standards update that expands the disclosure requirements for the offsetting of assets and liabilities related to certain financial instruments and derivative instruments.  The update requires disclosures to present both gross information and net information for financial instruments and derivative instruments that are eligible for net presentation due to a right of offset, an enforceable master netting arrangement or similar agreement.  The update is effective for interim and annual periods beginning on or after January 1, 2013.  We do not expect that our adoption will have a material effect on the disclosures contained in our balance sheet or notes to consolidated financial statements.

Note 4—Business Combination

On August 14, 2011, we entered into an irrevocable agreement with Aker Capital AS to acquire its 41 percent interest in Aker Drilling.  After receiving clearance by the Oslo Stock Exchange on August 26, 2011, we launched an all cash offer for 100 percent of the shares of Aker Drilling for NOK 26.50 per share.

As of October 3, 2011, the acquisition date, we held 99 percent of the shares of Aker Drilling, having paid an aggregate amount of NOK 7.9 billion, equivalent to $1.4 billion.  On October 4, 2011, we acquired the remaining noncontrolling interest from holders that were required to tender their shares pursuant to Norwegian law.  We believe the acquisition of Aker Drilling enhances the composition of our High-Specification Floater fleet and strengthens our presence in Norway.  In accounting for the business combination, we applied the acquisition method of accounting, recording the assets and liabilities of Aker Drilling at their estimated fair values as of the acquisition date.  During the year ended December 31, 2011, we incurred acquisition costs of $22 million, recognized in general and administrative expense.

As of October 3, 2011, the acquisition price included the following, measured at estimated fair value: current assets of $323 million, drilling rigs and other property and equipment of $1.8 billion, other assets of $756 million, and the assumption of current liabilities of $272 million and long-term debt of $1.6 billion.  The acquired assets included $901 million of cash investments restricted for the payment of certain assumed debt instruments.  The excess of the purchase price over the estimated fair value of net assets acquired was approximately $273 million, which was recorded as goodwill.  Certain fair value measurements have not been completed, and the purchase price allocation remains preliminary due to the timing of the acquisition and due to the number of acquired assets and assumed liabilities.  We continue to review the estimated fair values of property and equipment, intangible assets, and other assets and liabilities, and to evaluate the assumed tax positions and contingencies.

We have included approximately three months of operating results of Aker Drilling in our consolidated results of operations.  Our operating revenues include approximately $100 million of contract drilling revenues associated with the operations of Aker Drilling for the year ended December 31, 2011.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

Unaudited pro forma combined operating results, assuming the acquisition was completed as of January 1, 2010, were as follows (in millions, except per share data):

The pro forma financial information includes various adjustments, primarily related to additional depreciation resulting from the fair value adjustments to the acquired property and equipment.  The pro forma information is not necessarily indicative of the results of operations had the acquisition of Aker Drilling been completed on the assumed dates or the results of operations for any future periods.

Note 5—Impairments

Assets held for sale—During the year ended December 31, 2011, we recognized an aggregate loss of $28 million ($0.09 per diluted share from continuing operations), which had a tax effect of less than $1 million, associated with the impairment of GSF Britannia, George H. Galloway, GSF Labrador, and Searex IV, which were each classified as an asset held for sale at the time of impairment.  We measured the impairments as the amount by which the carrying amounts of these rigs and related assets exceeded the estimated fair values less costs to sell the rigs and related assets.  We estimated the fair values of the rigs and related assets using significant observable inputs, including binding sale and purchase agreements for the assets.

During the year ended December 31, 2009, we determined that GSF Arctic II and GSF Arctic IV, both classified as assets held for sale, were impaired due to the global economic downturn and pressure on commodity prices, both of which had an adverse effect on our industry.  We estimated the fair values of these rigs based on an exchange price that would be received for the assets in the principal or most advantageous market for the assets in an orderly transaction between market participants as of the measurement date and considering our undertakings to the Office of Fair Trading in the U.K. (“OFT”) that required the sale of the rigs with certain limitations and in a limited amount of time.  We based our estimates on significant unobservable inputs, including non-binding price quotes from unaffiliated parties, considering the then-current market conditions and restrictions imposed by the OFT.  For the year ended December 31, 2009, as a result of our evaluation, we recognized a loss on impairment of $279 million ($0.87 per diluted share), which had no tax effect.  In the year ended December 31, 2010, we completed the sale of these drilling units.  See Note 10—Drilling Fleet.

Assets held and used—During the year ended December 31, 2010, we determined that the Standard Jackup asset group in our contract drilling services reporting unit was impaired due to projected declines in dayrates and utilization.  We measured the fair value of this asset group by applying a combination of income and market approaches, using projected discounted cash flows and estimates of the exchange price that would be received for the assets in the principal or most advantageous market for the assets in an orderly transaction between market participants as of the measurement date.  Our valuation utilized the projection of the future performance of the asset group based on significant unobservable inputs, including assumptions regarding long-term projections for future revenues and costs, dayrates, rig utilization and idle time.  As a result, we determined that the carrying amount of the Standard Jackup asset group exceeded its fair value, and we recognized a loss on impairment of long-lived assets in the amount of $1.0 billion ($3.15 per diluted share from continuing operations), which had no tax effect, during the year ended December 31, 2010.  We did not have an impairment of our assets held and used in either of the years ended December 31, 2011 or 2009.

Goodwill and other indefinite-lived intangible assets—As a result of our annual impairment test, performed as of October 1, 2011, we determined that the goodwill associated with our contract drilling services reporting unit was impaired due to a decline in projected cash flows and market valuations for this reporting unit, and we recognized our best estimate of the loss on impairment in the amount of $5.2 billion ($16.15 per diluted share from continuing operations), which had no tax effect.  We estimated the implied fair value of the goodwill using a variety of valuation methods, including cost, income, and market approaches.  Our valuation required us to project the future performance of the contract drilling services reporting unit based on significant unobservable inputs, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.  We have not completed the measurement of our goodwill impairment due to the complexities involved in determining the implied fair value of goodwill.  Our estimate is, therefore, subject to adjustment.  We expect to complete the measurement of our goodwill impairment in the three months ending March 31, 2012.  As a result of our annual impairment testing for our contract drilling services reporting unit in the year ended December 31, 2010 and 2009, we concluded that goodwill was not impaired.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued

During the year ended December 31, 2009, we determined that the trade name intangible asset associated with our drilling management services reporting unit was impaired due to market conditions resulting from the global economic downturn and continued pressure on commodity prices.  We estimated the fair value of the trade name intangible asset using the relief from royalty method, a valuation methodology that applies the income approach.  Our valuation required us to project the future performance of the drilling management services reporting unit based on significant unobservable inputs, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.  As a result of our valuations in the year ended December 31, 2009, we determined that the carrying amount of the trade name intangible asset exceeded its fair value, and we recognized a loss on impairment of $6 million ($0.02 per diluted share), which had no tax effect.  In the years ended December 31, 2011 and 2010, we determined that we did not have an impairment of our trade name intangible asset.

Definite-lived intangible assets—During the year ended December 31, 2009, we determined that the customer relationships intangible asset associated with our drilling management services reporting unit was impaired due to market conditions resulting from the global economic downturn and continued pressure on commodity prices.  We estimated the fair value of the customer relationships intangible asset using the multiperiod excess earnings method, a valuation methodology that applies the income approach.  Our valuation required us to project the future performance of the drilling management services reporting unit based on significant unobservable inputs, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.  As a result of our valuation in the year ended December 31, 2009, we determined that the carrying amount of the customer relationships intangible asset exceeded its fair value, and we recognized a loss on impairment of $49 million ($0.15 per diluted share from continuing operations), which had no tax effect.  We were not required to test our definite-lived intangible assets for impairment in either of the years ended December 31, 2011 or 2010.

Note 6—Income Taxes

Tax rate—Transocean Ltd., a holding company and Swiss resident, is exempt from cantonal and communal income tax in Switzerland, but is subject to Swiss federal income tax.  At the federal level, qualifying net dividend income and net capital gains on the sale of qualifying investments in subsidiaries are exempt from Swiss federal income tax.  Consequently, Transocean Ltd. expects dividends from its subsidiaries and capital gains from sales of investments in its subsidiaries to be exempt from Swiss federal income tax.

Our provision for income taxes is based on the tax laws and rates applicable in the jurisdictions in which we operate and earn income.  The relationship between our provision for or benefit from income taxes and our income or loss before income taxes can vary significantly from period to period considering, among other factors, (a) the overall level of income before income taxes, (b) changes in the blend of income that is taxed based on gross revenues rather than income before taxes, (c) rig movements between taxing jurisdictions and (d) our rig operating structures.  Generally, our annual marginal tax rate is lower than our annual effective tax rate.

The components of our provision (benefit) for income taxes were as follows (in millions):

The following is a reconciliation of the differences between the income tax expense for our continuing operations computed at the Swiss holding company federal statutory rate of 7.83 percent and our reported provision for income taxes (in millions):

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—Continued