10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_________________________

FORM 10-Q

   (Mark one)

þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2012

OR

 ¨      TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _____ to _____

_________________________

Commission file number 000-53533

TRANSOCEAN LTD.

(Exact name of registrant as specified in its charter)

Zug, Switzerland	98-0599916
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
Chemin de Blandonnet 10 Vernier, Switzerland	1214
(Address of principal executive offices)	(Zip Code)
+41 (22) 930-9000
(Registrant’s telephone number, including area code)

_________________________

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.Yes þ   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 þ   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.

Large accelerated filer þ    Accelerated filer ¨    Non-accelerated filer (do not check if a smaller reporting company) ¨    Smaller reporting company ¨

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

As of April 24, 2012, 350,503,380 shares were outstanding.

TRANSOCEAN LTD. AND SUBSIDIARIES

INDEX TO FORM 10-Q

QUARTER ENDED MARCH31, 2012

		Page
PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Statements of Operations	1
	Condensed Consolidated Statements of Comprehensive Income	2
	Condensed Consolidated Balance Sheets	3
	Condensed Consolidated Statements of Equity	4
	Condensed Consolidated Statements of Cash Flows	5
	Notes to Condensed Consolidated Financial Statements	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	55
Item 4.	Controls and Procedures	56
PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	57
Item 1A.	Risk Factors	57
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	57
Item 6.	Exhibits	58

PART I.                 FINANCIAL INFORMATION

Item 1. Financial Statements

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In millions, except per share data)

(Unaudited)

	Three months ended March 31,
	2012			2011
Operating revenues
Contract drilling revenues	$	2,203		$	1,950
Contract drilling intangible revenues		11			10
Other revenues		117			184
		2,331			2,144
Costs and expenses
Operating and maintenance		1,410			1,359
Depreciation and amortization		351			354
General and administrative		69			67
		1,830			1,780
Loss on impairment		(227	)		—
Gain (loss) on disposal of assets, net		(4	)		8
Operating income		270			372
Other income (expense), net
Interest income		15			15
Interest expense, net of amounts capitalized		(180	)		(145	)
Other, net		(7	)		3
		(172	)		(127	)
Income from continuing operations before income tax expense		98			245
Income tax expense		24			81
Income from continuing operations		74			164
Income (loss) from discontinued operations, net of tax		(15	)		176
Net income		59			340
Net income attributable to noncontrolling interest		17			30
Net income attributable to controlling interest	$	42		$	310
Earnings per share-basic
Earnings from continuing operations	$	0.16		$	0.42
Earnings (loss) from discontinued operations		(0.04	)		0.54
Earnings per share	$	0.12		$	0.96
Earnings per share-diluted
Earnings from continuing operations	$	0.16		$	0.42
Earnings (loss) from discontinued operations		(0.04	)		0.54
Earnings per share	$	0.12		$	0.96
Weighted-average shares outstanding
Basic		350			319
Diluted		350			320

See accompanying notes.

- 1 -

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Inmillions)

(Unaudited)

	Three months ended March 31,
	2012			2011
Net income	$	59		$	340
Other comprehensive income (loss) before income taxes
Unrecognized components of net periodic benefit costs		(28	)		(6	)
Unrecognized gain on derivative instruments		2			1
Recognized components of net periodic benefit costs		13			6
Recognized (gain) loss on derivative instruments		(3	)		2
Other comprehensive income (loss) before income taxes		(16	)		3
Income taxes related to other comprehensive income (loss)		(3	)		(2	)
Other comprehensive income (loss), net of income taxes		(19	)		1
Total comprehensive income		40			341
Total comprehensive income attributable to noncontrolling interest		17			34
Total comprehensive income attributable to controlling interest	$	23		$	307

See accompanying notes.

- 2 -

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Inmillions, except share data)

(Unaudited)

	March 31, 2012			December 31, 2011
Assets
Cash and cash equivalents	$	3,982		$	4,017
Accounts receivable, net of allowance for doubtful accounts of $28 at March 31, 2012 and December 31, 2011		2,238			2,176
Materials and supplies, net of allowance for obsolescence of $76 and $73 at March 31, 2012 and December 31, 2011, respectively		663			627
Deferred income taxes, net		142			142
Assets held for sale		53			26
Other current assets		595			621
Total current assets		7,673			7,609
Property and equipment		28,960			29,037
Property and equipment of consolidated variable interest entities		2,255			2,252
Less accumulated depreciation		8,892			8,760
Property and equipment, net		22,323			22,529
Goodwill		3,087			3,205
Other assets		1,632			1,745
Total assets	$	34,715		$	35,088
Liabilities and equity
Accounts payable	$	841		$	880
Accrued income taxes		70			89
Debt due within one year		2,695			1,942
Debt of consolidated variable interest entities due within one year		97			97
Other current liabilities		2,061			2,350
Total current liabilities		5,764			5,358
Long-term debt		9,940			10,756
Long-term debt of consolidated variable interest entities		724			741
Deferred income taxes, net		512			523
Other long-term liabilities		1,914			1,903
Total long-term liabilities		13,090			13,923
Commitments and contingencies
Redeemable noncontrolling interest		138			116
Shares, CHF 15.00 par value, 402,282,355 authorized, 167,617,649 conditionally authorized, 365,135,298 issued at March 31, 2012 and December 31, 2011;  350,500,518 and 349,805,793 outstanding at March 31, 2012 and December 31, 2011, respectively		4,991			4,982
Additional paid-in capital		7,216			7,211
Treasury shares, at cost, 2,863,267 held at March 31, 2012 and December 31, 2011		(240	)		(240	)
Retained earnings		4,286			4,244
Accumulated other comprehensive loss		(515	)		(496	)
Total controlling interest shareholders’ equity		15,738			15,701
Noncontrolling interest		(15	)		(10	)
Total equity		15,723			15,691
Total liabilities and equity	$	34,715		$	35,088

See accompanying notes.

- 3 -

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(In millions)

(Unaudited)

	Three months ended March 31,
	2012			2011
Shares outstanding
Balance, beginning of period		350			319
Issuance of shares under share-based compensation plans		1			1
Balance, end of period		351			320
Shares
Balance, beginning of period	$	4,982		$	4,482
Issuance of shares under share-based compensation plans		9			6
Balance, end of period	$	4,991		$	4,488
Additional paid-in capital
Balance, beginning of period	$	7,211		$	7,504
Share-based compensation		23			27
Issuance of shares under share-based compensation plans		(17	)		(16	)
Other, net		(1	)		3
Balance, end of period	$	7,216		$	7,518
Treasury shares, at cost
Balance, beginning of period	$	(240	)	$	(240	)
Balance, end of period	$	(240	)	$	(240	)
Retained earnings
Balance, beginning of period	$	4,244		$	9,969
Net income attributable to controlling interest		42			310
Balance, end of period	$	4,286		$	10,279
Accumulated other comprehensive loss
Balance, beginning of period	$	(496	)	$	(332	)
Other comprehensive loss attributable to controlling interest		(19	)		(3	)
Balance, end of period	$	(515	)	$	(335	)
Total controlling interest shareholders’ equity
Balance, beginning of period	$	15,701		$	21,383
Total comprehensive income attributable to controlling interest		23			307
Share-based compensation		23			27
Issuance of shares under share-based compensation plans		(8	)		(10	)
Other, net		(1	)		3
Balance, end of period	$	15,738		$	21,710
Noncontrolling interest
Balance, beginning of period	$	(10	)	$	(8	)
Total comprehensive income (loss) attributable to noncontrolling interest		(5	)		3
Balance, end of period	$	(15	)	$	(5	)
Total equity
Balance, beginning of period	$	15,691		$	21,375
Total comprehensive income		18			310
Share-based compensation		23			27
Issuance of shares under share-based compensation plans		(8	)		(10	)
Other, net		(1	)		3
Balance, end of period	$	15,723		$	21,705

See accompanying notes.

- 4 -

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

(Unaudited)

	Three months ended March 31,
	2012			2011
Cash flows from operating activities
Net income	$	59		$	340
Adjustments to reconcile to net cash provided by operating activities:
Amortization of drilling contract intangibles		(11	)		(10	)
Depreciation and amortization		351			354
Share-based compensation expense		23			27
Loss on impairment		227			—
(Gain) loss on disposal of assets, net		4			(8	)
(Gain) loss on disposal of discontinued operations, net		14			(173	)
Amortization of debt issue costs, discounts and premiums, net		18			26
Deferred income taxes		(30	)		11
Other, net		21			(3	)
Changes in deferred revenue, net		(12	)		46
Changes in deferred expenses, net		(49	)		(36	)
Changes in operating assets and liabilities		(75	)		(184	)
Net cash provided by operating activities		540			390
Cash flows from investing activities
Capital expenditures		(260	)		(240	)
Proceeds from disposal of assets, net		41			13
Proceeds from disposal of discontinued operations, net		—			259
Other, net		12			(6	)
Net cash provided by (used in) investing activities		(207	)		26
Cash flows from financing activities
Changes in short-term borrowings, net		—			51
Proceeds from debt		—			5
Repayments of debt		(147	)		(47	)
Proceeds from restricted cash investments		108			—
Deposits to restricted cash investments		(42	)		—
Distribution of qualifying additional paid-in capital		(278	)		—
Other, net		(9	)		(7	)
Net cash provided by (used in) financing activities		(368	)		2
Net increase (decrease) in cash and cash equivalents		(35	)		418
Cash and cash equivalents at beginning of period		4,017			3,394
Cash and cash equivalents at end of period	$	3,982		$	3,812

See accompanying notes.

- 5 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

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 March 31, 2012, we owned or had partial ownership interests in and operated 130 mobile offshore drilling units.  As of this date, our fleet consisted of 50High-Specification Floaters (Ultra-Deepwater, Deepwater and Harsh Environment semisubmersibles and drillships), 25 Midwater Floaters, nine High-Specification Jackups, 45Standard Jackups and oneswamp barge.  In addition, we had two Ultra-Deepwater drillships 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 TechnologyInc., our wholly owned subsidiary, and through ADTInternational, a division of one of our United Kingdom (“U.K”). subsidiaries (together, “ADTI”).  ADTI conducts drilling management services primarily on either a dayrate or a completed-project, fixed-price (or “turnkey”) basis.

Note 2—Significant Accounting Policies

Basis of presentation—We have prepared our accompanying unaudited condensed consolidated financial statements in accordance with accounting principles generally accepted in the United States (“U.S.”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the U.S. Securities and Exchange Commission (“SEC”).  Pursuant to such rules and regulations, these financial statements do not include all disclosures required by accounting principles generally accepted in the U.S. for complete financial statements.  The condensed consolidated financial statements reflect all adjustments, which are, in the opinion of management, necessary for a fair presentation of financial position, results of operations and cash flows for the interim periods.  Such adjustments are considered to be of a normal recurring nature unless otherwise noted.  Operating results for the three months ended March 31, 2012 are not necessarily indicative of the results that may be expected for the year ending December 31, 2012 or for any future period.  The accompanying condensed consolidated financial statements and notes thereto should be read in conjunction with the audited consolidated financial statements and notes thereto as of December 31, 2011 and 2010 and for each of the three years in the period ended December 31, 2011 included in our annual report on Form 10-K filed on February 27, 2012.

Accounting estimates—To prepare financial statements in accordance with accounting principles generally accepted in the U.S., we are required 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, defined benefit pension plans and other postretirement benefits, contingencies and share-based compensation.  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 considerable 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 entity.  See Note 4—Variable Interest Entities.

Share-based compensation—Share-based compensation expense was $23million and $27million for the three months ended March31, 2012 and 2011, respectively.

- 6 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Capitalized interest—We capitalize interest costs for qualifying construction and upgrade projects.  We capitalized interest costs on construction work in progress of $13 million and $15 million for the three months ended March 31, 2012 and 2011, respectively.

Reclassifications—We have made certain reclassifications, which did not have an effect on net income, to prior period amounts to conform with the current period’s presentation.  These reclassifications did not have a material effect on our condensed 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 19—Subsequent Events.

Note 3—New Accounting Pronouncements

Recently Adopted Accounting Standards

Intangibles-goodwill and other—Effective January 1, 2012, we adopted 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.  Our adoption did not have an effect on our condensed consolidated financial statements.

Fair value measurements—Effective January 1, 2012, we adopted the accounting standards update that requires additional disclosure about fair value measurements that involve significant unobservable inputs, including additional quantitative information about the unobservable inputs, a description of valuation techniques used, and a qualitative evaluation of the sensitivity of these measurements.  Our adoption did not have a material effect on the disclosures contained in our notes to condensed consolidated financial statements.

Recently Issued Accounting Standards

Balance sheet—Effective January1, 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 January1, 2013.  We do not expect that our adoption will have a material effect on our condensed consolidated balance sheet or the disclosures contained in our notes to condensed consolidated financial statements.

Note 4—Variable Interest Entities

Consolidated variable interest entities—We consolidate the operating results, assets and liabilities of Transocean Pacific Drilling Inc. (“TPDI”), a consolidated British Virgin Islands joint venture company, and Angola Deepwater Drilling CompanyLimited (“ADDCL”), a consolidated Cayman Islands joint venture company, which are two variable interest entities for which we are the primary beneficiary.  The carrying amounts associated with our consolidated variable interest entities, after eliminating the effect of intercompany transactions, were as follows (in millions):

	March 31, 2012						December 31, 2011
	Assets		Liabilities		Net carrying amount		Assets		Liabilities		Net carrying amount
Variable interest entity
TPDI	$	1,591	$	660	$	931	$	1,562	$	673	$	889
ADDCL		929		327		602		930		334		596
Total	$	2,520	$	987	$	1,533	$	2,492	$	1,007	$	1,485

See Note 15—Redeemable Noncontrolling Interest.

- 7 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Unconsolidated variable interest entities—As holder of two notes receivable and a lender under a working capital loan, we have a variable interest in AwilcoDrillingplc (“Awilco”), a U.K. company listed on the Oslo Stock Exchange.  In the three months ended March 31, 2012, Awilco encountered operational downtime, both planned and unplanned, and disputed billings.  In the three months ended March 31, 2012, we reevaluated whether Awilco met the definition of a variable interest entity.  Based on our reevaluation, we determined that Awilco now met the definition of a variable interest entity since its equity at risk is insufficient to permit it to carry on its activities without additional subordinated financial support.  We also continue to believe that we were not the primary beneficiary since we did not have the power to direct the activities that most significantly impact the entity’s economic performance.

The notes receivable were originally accepted in exchange for and are secured by two drilling units.  The notes receivable have stated interest rates of nine percent and are payable in scheduled quarterly installments of principal and interest through maturity in January 2015.  The working capital loan, also secured by the two drilling units, has a stated interest rate of 10percent and is payable in scheduled quarterly installments of principal and interest through maturity in January 2013.  We evaluate the credit quality and financial condition of Awilco quarterly.  The aggregate carrying amount of the notes receivable was $109million and $110 million at March 31, 2012 and December 31, 2011, respectively.  The aggregate carrying amount of the working capital loan receivable was $20million and $29million at March 31, 2012 and December 31, 2011, respectively.  At March 31, 2012, our aggregate exposure to loss on these receivable instruments was $129 million.

Note 5—Business Combination

As of October 3, 2011, the acquisition date, we held 99 percent of the shares of Aker Drilling ASA (“Aker Drilling”), a Norwegian company formerly listed on the Oslo Stock Exchange, 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 of Aker Drilling 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.

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 acquisition 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 and other assets and to evaluate the assumed tax positions and contingencies.

In the three months ended March 31, 2012, our operating revenues included approximately $95 million of contract drilling revenues associated with the operations of the two Harsh Environment, Ultra-Deepwater semisubmersibles that we acquired in our acquisition of Aker Drilling.

Unaudited pro forma combined operating results, assuming the acquisition was completed as of January 1, 2011, were as follows (in millions, except per share data):

	Three months ended March 31,
	2011
Operating revenues	$	2,244
Operating income		420
Income from continuing operations		167
Per share earnings from continuing operations
Basic	$	0.43
Diluted	$	0.43

The pro forma financial information includes various adjustments, primarily related to additional depreciation expense 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.

- 8 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 6—Impairments

Assets held for sale—During the threemonths ended March 31, 2012, we recognized a loss of $17 million ($0.05 per diluted share from continuing operations), which had no tax effect, associated with the impairment of GSFRig 136, which was classified as an asset held for sale at the time of impairment.  We measured the impairment of the drilling unit and related equipment as the amount by which the carrying amount exceeded the estimated fair value less costs to sell.  We estimated the fair value of the assets using significant observable inputs, representing a Level 1 fair value measurement, including a binding sale and purchase agreement for the drilling unit and related equipment.

Definite-lived intangible assets—During the three months ended March 31, 2012, we determined that the customer relationships intangible asset associated with our drilling management services reporting unit was impaired due to the declining market outlook for these services in the shallow water of U.S. Gulf of Mexico as well as the increased regulatory environment for obtaining drilling permits and the diminishing demand for our drilling management services.  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, representing a Level 3 fair value measurement, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.  As a result of our valuation, we determined that the carrying amount of the customer relationships intangible asset exceeded its fair value, and we recognized a loss on impairment of $53 million ($37 million, or $0.11 per diluted share from continuing operations, net of tax) in the three months ended March 31, 2012.

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.  In the year ended December 31, 2011, we recognized a loss on impairment, representing our best estimate, in the amount of $5.2billion ($16.15 per diluted share from continuing operations), which had no tax effect.  In the three months ended March 31, 2012, we completed our analysis and recognized an incremental adjustment to our original estimate in the amount of $118 million ($0.34 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 our contract drilling services reporting unit based on significant unobservable inputs, representing a Level 3 fair value measurement, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.

During the three months ended March 31, 2012, we determined that the trade name intangible asset associated with our drilling management services reporting unit was impaired due to the declining market outlook for these services in the shallow water of U.S. Gulf of Mexico as well as the increased regulatory environment for obtaining drilling permits and the diminishing demand for drilling management services.  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, representing a Level 3 fair value measurement, including assumptions for future commodity prices, projected demand for drilling management services, rig availability and dayrates.  As a result of our valuation, we determined that the carrying amount of the trade name intangible asset exceeded its fair value, and we recognized a loss on impairment of $39 million ($25 million, or $0.07 per diluted share from continuing operations, net of tax) in the three months ended March 31, 2012.

- 9 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 7—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.

Our estimated annual effective tax rates were 25.5percent and 19.3 percent for the three months ended March 31, 2012 and 2011, respectively.  These rates were based on estimated annual income before income taxes for each period after adjusting for various discrete items, including certain immaterial adjustments to prior period tax expense.

Deferred taxes—The valuation allowance for our non-current deferred tax assets was as follows (in millions):

	March 31, 2012		December 31, 2011
Valuation allowance for non-current deferred tax assets	$	181	$	183

Unrecognized tax benefits—The liabilities related to our unrecognized tax benefits, including related interest and penalties that we recognize as a component of income tax expense, were as follows (in millions):

	March 31, 2012		December 31, 2011
Unrecognized tax benefits, excluding interest and penalties	$	493	$	509
Interest and penalties		271		272
Unrecognized tax benefits, including interest and penalties	$	764	$	781

Tax returns—We file federal and local tax returns in several jurisdictions throughout the world.  With few exceptions, we are no longer subject to examinations of our U.S. and non-U.S. tax matters for years prior to 2003.  For the three months ended March 31, 2012, the amount of current tax benefit recognized from the settlement of disputes with tax authorities and from the expiration of statutes of limitations was $38 million.

We engage in ongoing discussions with tax authorities regarding the resolution of tax matters in the various jurisdictions in which we operate.  Both the ultimate resolutions of these tax matters and the timing of any resolution or closure of the tax audits are highly uncertain.  It is reasonably possible that the total amount of our existing liabilities for unrecognized tax benefits could decrease by up to 15 percent or increase by up to 10 percent in the next 12 months.

Our tax returns in the major jurisdictions in which we operate, other than the U.S., Norway and Brazil which are mentioned below, are generally subject to examination for periods ranging from three to six years.  We have agreed to extensions beyond the statute of limitations in two major jurisdictions for up to 17years.  Tax authorities in certain jurisdictions are examining our tax returns and in some cases have issued assessments.  We are defending our tax positions in those jurisdictions.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect the ultimate liability to have a material adverse effect on our consolidated statement of financial position or results of operations, although it may have a material adverse effect on our consolidated cash flows.

U.S. tax investigations—With respect to our 2004 U.S. federal income tax return, the U.S. tax authorities withdrew all of their previously proposed tax adjustments, including all claims related to transfer pricing.  In January 2012, a judge in the U.S. Tax Court entered a decision of no deficiency for the 2004 tax year and cancelled the trial previously scheduled to take place in February 2012.  With respect to our 2005 U.S. federal income tax returns, the U.S. tax authorities have withdrawn all of their previously proposed tax adjustments, except a claim regarding transfer pricing for certain charters of drilling rigs between our subsidiaries, resulting in a total proposed adjustment of approximately $50million, excluding interest.  We believe an unfavorable outcome on this assessment with respect to 2005 activities would not result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  Although we believe the transfer pricing for these charters is materially correct, we have been unable to reach a resolution with the tax authorities.

- 10 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

In May 2010, we received an assessment from the U.S. tax authorities related to our 2006 and 2007 U.S. federal income tax returns.  In July 2010, we filed a protest letter with the U.S. tax authorities responding to this assessment.  The significant issues raised in the assessment relate to transfer pricing for certain charters of drilling rigs between our subsidiaries and the creation of intangible assets resulting from the performance of engineering services between our subsidiaries.  These twoitems would result in net adjustments of approximately $278 million of additional taxes, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe our U.S. federal income tax returns are materially correct as filed, and we intend to continue to vigorously defend against all such claims.

In addition, the May 2010 assessment included adjustments related to a series of restructuring transactions that occurred between 2001 and 2004.  These restructuring transactions impacted our basis in our former subsidiary, TODCO, which we disposed of in 2004 and 2005.  The authorities are disputing the amount of capital losses that resulted from the disposition of TODCO.  We utilized a portion of the capital losses to offset capital gains on our U.S federal income tax returns for 2006 through 2009.  The majority of the capital losses were unutilized and expired on December 31, 2009.  The adjustments would also impact the amount of certain net operating losses and other carryovers in 2006 and later years.  The authorities are also contesting the characterization of certain amounts of income received in 2006 and 2007 as capital gain and thus the availability of the capital loss to offset such gains.  These claims with respect to our U.S. federal income tax returns for 2006 through 2009 could result in net tax adjustments of approximately $295million.  An unfavorable outcome on these potential adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe that our U.S federal income tax returns are materially correct as filed, and we intend to vigorously defend against any potential claims.

The May 2010 assessment also included certain claims with respect to withholding taxes and certain other items resulting in net tax adjustments of approximately $160 million, excluding interest.  In addition, the tax authorities assessed penalties associated with the various tax adjustments for the 2006 and 2007 audits in the aggregate amount of approximately $88 million, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  We believe that our U.S. federal income tax returns are materially correct as filed, and we intend to vigorously defend against potential claims.

In February 2012, we received an assessment from the U.S. tax authorities related to our 2008 and 2009 U.S. federal income tax returns.  The significant issues raised in the assessment relate to transfer pricing for certain charters of drilling rigs between our subsidiaries and the creation of intangible assets resulting from the performance of engineering services between our subsidiaries.  These items would result in net adjustments of approximately $473 million of additional taxes, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  Furthermore, if the authorities were to continue to pursue these positions with respect to subsequent years and were successful in such assertions, our effective tax rate on worldwide earnings with respect to years following 2009 could increase substantially, and could have a material adverse effect on our consolidated results of operations and cash flows.  We believe our U.S. federal income tax returns are materially correct as filed, and we intend to continue to vigorously defend against all such claims.

Norway tax investigations—Norwegian civil tax and criminal authorities are investigating various transactions undertaken by our subsidiaries in 2001 and 2002 as well as the actions of certain employees of our former external tax advisors on these transactions.  The authorities issued tax assessments of approximately $274 million, plus interest, related to certain restructuring transactions, approximately $120 million, plus interest, related to the migration of a subsidiary that was previously subject to tax in Norway, approximately $72 million, plus interest, related to a 2001 dividend payment, and approximately $7 million, plus interest, related to certain foreign exchange deductions and dividend withholding tax.  We have filed or expect to file appeals to these tax assessments.  We have provided a parent company guarantee in the amount of approximately $123 million, with respect to one of these tax disputes.  Furthermore, we may be required to provide some form of additional financial security, in an amount up to $754 million, including interest and penalties, for other assessed amounts as these disputes are appealed and addressed by the Norwegian courts.  The authorities have indicated that they plan to seek penalties of 60percent on most but not all matters.  In June 2011, the Norwegian authorities issued criminal indictments against two of our subsidiaries alleging misleading or incomplete disclosures in Norwegian tax returns for the years 1999 through 2002, as well as inaccuracies in Norwegian statutory financial statements for the years ended December 31, 1996 through 2001.  The criminal trial has been scheduled for December 2012.  Two employees of our former external tax advisors were also issued indictments with respect to the disclosures in our tax returns.  In October 2011, the Norwegian authorities issued criminal indictments against a Norwegian tax attorney related to certain of our restructuring transactions and to the 2001 dividend payment.  The indicted Norwegian tax attorney worked for us in an advisory capacity on these transactions.  We believe these charges are without merit and do not alter our technical assessment of the underlying claims.  In January 2012, the Norwegian authorities supplemented the previously issued criminal indictments by issuing a financial claim of approximately $323 million, jointly and severally, against our two subsidiaries, the two external advisors and the external tax attorney.  This compensation claim directly overlaps with an existing civil tax assessment and does not represent an incremental financial exposure to us.  In February 2012, the authorities dropped the previously existing tax assessment related to a certain restructuring transaction.  We believe our Norwegian tax returns are materially correct as filed, and we intend to vigorously contest any assertions by the Norwegian civil and criminal authorities in connection with the various transactions being investigated.  An unfavorable outcome on the Norwegian civil and criminal tax matters could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect the ultimate resolution of these matters to have a material adverse effect on our consolidated statement of financial position or results of operations, although it may have a material adverse effect on our consolidated cash flows.  See Note 19—Subsequent Events.

- 11 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Brazil tax investigations—Certain of our Brazilian income tax returns for the years 2000 through 2004 are currently under examination.  The Brazilian tax authorities have issued tax assessments totaling $114 million, plus a 75percent penalty in the amount of $86 million and interest through December 31, 2011 in the amount of $163 million.  An unfavorable outcome on these proposed assessments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe our returns are materially correct as filed, and we are vigorously contesting these assessments.  On January 25, 2008, we filed a protest letter with the Brazilian tax authorities, and we are currently engaged in the appeals process.

Other tax matters—We conduct operations through our various subsidiaries in a number of countries throughout the world.  Each country has its own tax regimes with varying nominal rates, deductions and tax attributes.  From time to time, we may identify changes to previously evaluated tax positions that could result in adjustments to our recorded assets and liabilities.  Although we are unable to predict the outcome of these changes, we do not expect the effect, if any, resulting from these assessments to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Note8—Discontinued Operations

Oil and gas properties—In March 2011, in connection with our efforts to dispose of non-strategic assets, 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 MineralsInc. and Challenger Minerals (North Sea)Limited, our wholly owned oil and gas subsidiaries.  In October 2011, we completed the sale of Challenger Minerals (North Sea) Limited for net cash proceeds of $24 million, and we recognized a gain on the disposal of the discontinued operations of $12 million.  Additionally, in February 2012, we entered into an agreement to sell the assets of Challenger Minerals Inc.  See Note 19—Subsequent Events.

Caspian Sea operations—In February 2011, in connection with our efforts to dispose of non-strategic assets, we sold the subsidiary that owns the High-Specification Jackup Trident 20, located in the Caspian Sea.  The disposal of this subsidiary, a component of our contract drilling services segment, reflects our decision to discontinue operations in the Caspian Sea.  As a result of the sale, we received net cash proceeds of $259 million and recognized a gain on the disposal of the discontinued operations of $169 million ($0.52per diluted share from discontinued operations), which had no tax effect.  Through June 2011, we continued to operate Trident 20 under a bareboat charter to perform services for the customer and the buyer reimbursed us for the approximate cost of providing these services.  Additionally, we provided certain transition services to the buyer through September 2011.

Summarized results of discontinued operations—The summarized results of operations included in income from discontinued operations were as follows (in millions):

	Threemonths ended March 31,
	2012			2011
Operating revenues	$	3		$	26
Costs and expenses		(2	)		(23	)
Loss on impairment (a)		(6	)		—
Gain (loss) on disposal of discontinued operations, net		(14	)		173
Income (loss) from discontinued operations before income tax expense		(19	)		176
Income tax benefit		4			—
Income (loss) from discontinued operations, net of tax	$	(15	)	$	176

_____________________

(a) During the three months ended March 31, 2012, we recognized a loss on impairment of our oil and gas properties, which were classified as assets held for sale, in the amount of $6 million ($4 million or $0.01 per diluted share from discontinued operations, net of tax) since the carrying amount of the properties exceeded the estimated fair value less costs to sell the properties.  We estimated fair value based on significant observable inputs, representing a Level 1 fair value measurement, including a binding sale and purchase agreement for the properties.

- 12 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Assets and liabilities of discontinued operations— As a result of our decision to discontinue the operations of our oil and gas properties reporting unit and the operations of our Caspian Sea subsidiary, we have classified the related assets and liabilities of these components of our business to other current assets and other current liabilities as of December 31, 2011.  The carrying amounts of the major classes of assets and liabilities associated with these operations were classified as follows (in millions):

	March 31, 2012		December 31, 2011
Assets
Oil and gas properties, net	$	19	$	24
Other related assets		2		2
Assets held for sale	$	21	$	26
Accounts receivable	$	2	$	6
Other assets		11		25
Other current assets	$	13	$	31
Liabilities
Accounts payable	$	1	$	3
Other liabilities		8		14
Other current liabilities	$	9	$	17

Note 9—Earnings Per Share

The numerator and denominator used for the computation of basic and diluted per share earnings from continuing operations were as follows (in millions, except per share data):

	Three months ended March 31,
	2012				2011
	Basic		Diluted		Basic			Diluted
Numerator for earnings per share
Income from continuing operations attributable to controlling interest	$	57	$	57	$	134		$	134
Undistributed earnings allocable to participating securities		—		—		(1	)		(1	)
Income from continuing operations available to shareholders	$	57	$	57	$	133		$	133
Denominator for earnings per share
Weighted-average shares outstanding		350		350		319			319
Effect of stock options and other share-based awards		—		—		—			1
Weighted-average shares for per share calculation		350		350		319			320
Per share earnings from continuing operations	$	0.16	$	0.16	$	0.42		$	0.42

For the threemonths ended March 31, 2012 and 2011, respectively, 1.8million and 1.2million share-based awards were excluded from the calculation since the effect would have been anti-dilutive.

The 1.50% Series B Convertible Senior Notes and 1.50% Series C Convertible Senior Notes did not have an effect on the calculation for the periods presented.  See Note 11—Debt.

- 13 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 10—Drilling Fleet

Expansion—Construction work in progress, recorded in property and equipment, was $1.6billion and $1.4billion at March 31, 2012 and December 31, 2011, respectively.  Capital expenditures and other capital additions, including capitalized interest, for our major construction projects during the threemonths ended March 31, 2012 or during the year ended December 31, 2011 were as follows (in millions):

	Three months ended March 31, 2012		Through December 31, 2011		Total costs
Transocean Andaman (a)	$	19	$	119	$	138
Transocean Siam Driller (a)		19		119		138
Transocean Honor (b)		16		216		232
Ultra-Deepwater Floater TBN1 (c)		14		138		152
Ultra-Deepwater Floater TBN2 (c)		8		137		145
Deepwater Champion (d) (e)		2		776		778
Transocean Ao Thai (f)		1		79		80
Capitalized interest		13		108		121
Mobilization costs		5		26		31
Total	$	97	$	1,718	$	1,815

_____________________

(a) In December 2010, we purchased Transocean Siam Driller and Transocean Andaman, two Keppel FELS Super B class design jackups, which are under construction at Keppel FELS’ yard in Singapore and are expected to commence operations in the first quarter of 2013.

(b) In November 2010, we purchased Transocean Honor, a PPL Pacific Class 400 design jackup, which was offshore Angola undergoing testing and final customer acceptance as of March 31, 2012 and is expected to commence operations in the second quarter of 2012.

(c) The costs for Ultra-Deepwater Floater TBN1 and Ultra-Deepwater Floater TBN2 include our initial investment of $136 million each, representing the estimated fair value of the rigs at the time of our acquisition of Aker Drilling, completed in October 2011.  Currently under construction at the Daewoo Shipbuilding & Marine Engineering Co. Ltd. shipyard in Korea, we expect to take delivery of the two Ultra-Deepwater drillships in the first and second quarter of 2014.

(d) The accumulated construction costs of this rig are no longer included in construction work in progress as of March 31, 2012.

(e) The costs for Deepwater Champion include our initial investment of $109 million, representing the estimated fair value of the rig at the time of our merger with GlobalSantaFe Corporation in November 2007.  Deepwater Champion commenced operations in May 2011.

(f) In June 2011, we purchased Transocean Ao Thai, a Keppel FELS Super B class design jackup, which is under construction at Keppel FELS’ yard in Singapore and is expected to commence operations in the fourth quarter of 2013.

Dispositions—During the three months ended March 31, 2012, in connection with our efforts to dispose of non-strategic assets, we sold the Standard Jackup GSFRig 136 andrelated equipment.  As a result of the sale, we received net cash proceeds of $36 million (See Note 6—Impairments).  For the three months ended March 31, 2012, we recognized a net loss on disposal of unrelated assets of $4 million.

During the three months ended March 31, 2011, in connection with our efforts to dispose of non-strategic assets, we sold the High-Specification Jackup Trident 20 and the Standard Jackup Transocean Mercury.  The sale of Trident 20 reflected our decision to discontinue operations in the Caspian Sea (see Note 8—Discontinued Operations).  In connection with the sale of Transocean Mercury, we received net cash proceeds of $10 million and recognized a net gain on disposal of the drilling unit of $9 million ($0.03 per diluted share from continuing operations), which had no tax effect.  For the three months ended March 31, 2011, we recognized a net loss on disposal of unrelated assets in the amount of $1 million.

Assets held for sale—During the three months ended March 31, 2012, we committed to plans to sell our Standard Jackups, Roger W. Mowell, Transocean Nordic, Transocean Shelf Explorer and Trident 17.  At March 31, 2012, these drilling units and related equipment were classified as assets held for sale with an aggregate net carrying amount of $31 million.  See Note 19—Subsequent Events.

- 14 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 11—Debt

Debt, net of unamortized discounts, premiums and fair value adjustments, was comprised of the following (in millions):

	March 31, 2012						December 31, 2011
	Transocean Ltd. and subsidiaries		Consolidated variable interest entities		Consolidated total		Transocean Ltd. and subsidiaries		Consolidated variable interest entities		Consolidated total
5% Notes due February 2013	$	253	$	—	$	253	$	253	$	—	$	253
5.25% Senior Notes due March 2013 (a)		507		—		507		507		—		507
TPDI Credit Facilities due March 2015		—		455		455		—		473		473
4.95% Senior Notes due November 2015 (a)		1,120		—		1,120		1,120		—		1,120
Aker Revolving Credit and Term Loan Facility due December 2015		572		—		572		594		—		594
5.05% Senior Notes due December 2016 (a)		999		—		999		999		—		999
Callable Bonds due February 2016		278		—		278		267		—		267
ADDCL Credit Facilities due December 2017		—		218		218		—		217		217
Eksportfinans Loans due January 2018		852		—		852		884		—		884
6.00% Senior Notes due March 2018 (a)		998		—		998		998		—		998
7.375% Senior Notes due April 2018 (a)		247		—		247		247		—		247
TPDI Notes due October 2019		—		148		148		—		148		148
6.50% Senior Notes due November 2020 (a)		899		—		899		899		—		899
6.375% Senior Notes due December 2021 (a)		1,199		—		1,199		1,199		—		1,199
7.45% Notes due April 2027 (a)		97		—		97		97		—		97
8% Debentures due April 2027 (a)		57		—		57		57		—		57
7% Notes due June 2028		311		—		311		311		—		311
Capital lease contract due August 2029		671		—		671		676		—		676
7.5% Notes due April 2031 (a)		598		—		598		598		—		598
1.50% Series B Convertible Senior Notes due December 2037 (a)		—		—		—		30		—		30
1.50% Series C Convertible Senior Notes due December 2037 (a)		1,678		—		1,678		1,663		—		1,663
6.80% Senior Notes due March 2038 (a)		999		—		999		999		—		999
7.35% Senior Notes due December 2041 (a)		300		—		300		300		—		300
Total debt		12,635		821		13,456		12,698		838		13,536
Less debt due within one year
5% Notes due February 2013		253		—		253		—		—		—
5.25% Senior Notes due March 2013 (a)		507		—		507		—		—		—
TPDI Credit Facilities due March 2015		—		70		70		—		70		70
Aker Revolving Credit and Term Loan Facility due December 2015		90		—		90		90		—		90
ADDCL Credit Facilities due November 2017		—		27		27		—		27		27
Eksportfinans Loans due January 2018		149		—		149		142		—		142
Capital lease contract due August 2029		18		—		18		17		—		17
1.50% Series B Convertible Senior Notes due December 2037 (a)		—		—		—		30		—		30
1.50% Series C Convertible Senior Notes due December 2037 (a)		1,678		—		1,678		1,663		—		1,663
Total debt due within one year		2,695		97		2,792		1,942		97		2,039
Total long-term debt	$	9,940	$	724	$	10,664	$	10,756	$	741	$	11,497

_____________________

(a) Transocean Inc., a 100 percent owned subsidiary of Transocean Ltd., is the issuer of the notes and debentures, which have been guaranteed by Transocean Ltd.  Transocean Ltd. has also guaranteed borrowings under the Five-Year Revolving Credit Facility.  Transocean Ltd. and Transocean Inc. are not subject to any significant restrictions on their ability to obtain funds from their consolidated subsidiaries by dividends, loans or return of capital distributions.  See Note 18—Condensed Consolidating Financial Information.

- 15 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Scheduled maturities—In preparing the scheduled maturities of our debt, we assume the noteholders will exercise their options to require us to repurchase the 1.50% Series C Convertible Senior Notes in December 2012.  At March 31, 2012, the scheduled maturities of our debt were as follows (inmillions):

	Transocean Ltd. and subsidiaries			Consolidated variable interest entities		Consolidated total
Twelve months ending March 31,
2013	$	2,728		$	97	$	2,825
2014		260			98		358
2015		1,336			373		1,709
2016		1,762			33		1,795
2017		175			35		210
Thereafter		6,377			185		6,562
Total debt, excluding unamortized discounts, premiums and fair value adjustments		12,638			821		13,459
Total unamortized discounts, premiums and fair value adjustments, net		(3	)		—		(3	)
Total debt	$	12,635		$	821	$	13,456

Five-Year Revolving Credit Facility—We have a $2.0 billion revolving credit facility established by the Five-Year Revolving Credit Facility Agreement dated November 1, 2011 (the “Five-Year Revolving Credit Facility”).  Throughout the term of the Five-Year Revolving Credit Facility, we pay a facility fee on the daily unused amount of the underlying commitment, which ranges from 0.13 percent to 0.33 percent, based on our Debt Rating, and was 0.275 percent at March 31, 2012.  At March 31, 2012, we had $24 million in letters of credit issued and outstanding, we had no borrowings outstanding, and we had $2.0 billion available borrowing capacity under the Five-Year Revolving Credit Facility.

TPDI Credit Facilities—TPDI has a bank credit agreement for a $1.265billion secured credit facility (the “TPDI Credit Facilities”), comprised of a $1.0 billion senior term loan, a $190million junior term loan and a $75million revolving credit facility, which was established to finance the construction of and is secured by Dhirubhai Deepwater KG1 and Dhirubhai Deepwater KG2.  Oneof our subsidiaries participates as a lender in the senior and junior term loans with an aggregate commitment of $595million.  At March 31, 2012, $910 million was outstanding under the TPDI Credit Facilities, of which $455 million was due to one of our subsidiaries and was eliminated in consolidation.  On March 31, 2012, the weighted-average interest rate was 2.1 percent.  See Note 12—Derivatives and Hedging.

At March 31, 2012, TPDI had an outstanding letter of credit in the amount of $60 million to satisfy its liquidity requirements under the TPDI Credit Facilities.  The letter of credit was issued under an uncommitted credit facility that has been established by one of our subsidiaries.  Additionally TPDI is required to maintain certain cash balances in accounts restricted for the payment of the scheduled installments on the TPDI Credit Facilities.  TPDI had restricted cash investments of $26 million and $23 million at March 31, 2012 and December 31, 2011, respectively.

Aker Revolving Credit and Term Loan Facility—Aker Drilling has a credit facility established by the Revolving Credit and Term Loan Facility Agreement dated February 21, 2011 (the “Aker Revolving Credit and Term Loan Facility”), comprised of a $500 million revolving credit facility and a $400 million term loan, which is secured by Transocean Spitsbergen and Transocean Barents.  At March 31, 2012, aggregate borrowings of $570 million were outstanding under the Aker Revolving Credit and Term Loan Facility at a weighted-average interest rate of 3.0 percent.

Callable Bonds—Aker Drilling is the obligor on the FRN Aker Drilling ASA Senior Unsecured Callable Bond Issue 2011/2016 (the “FRN Callable Bonds”) and the 11% Aker Drilling ASA Senior Unsecured Callable Bond Issue 2011/2016 (the “11% Callable Bonds,” and together with the FRN Callable Bonds, the “Callable Bonds”), which are publicly traded on the Oslo Stock Exchange.  At March 31, 2012, the total aggregate principal amounts of the FRN Callable Bonds and the 11% Callable Bonds were NOK 940 million and NOK 560 million, equivalent to $165 million and $98 million, respectively, using an exchange rate of NOK 5.69 to US $1.00.  At March 31, 2012, the interest rate on the FRN Callable Bonds was 9.7 percent.  See Note 12—Derivatives and Hedging.

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TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

ADDCL Credit Facilities—ADDCL has a senior secured bank credit agreement for a credit facility (the “ADDCL Primary Loan Facility”) comprised of TrancheA and TrancheC for $215million and $399million, respectively, which was established to finance the construction of and is secured by DiscovererLuanda.  Unaffiliated financial institutions provide the commitment for and borrowings under Tranche A, and one of our subsidiaries provides the commitment for Tranche C.  At March 31, 2012, $190 million was outstanding under Tranche A at a weighted-average interest rate of 1.5 percent.  At March 31, 2012, $399 million was outstanding under Tranche C, which was eliminated in consolidation.

Additionally, ADDCL has a secondary bank credit agreement for a $90million credit facility (the “ADDCL Secondary Loan Facility” and together with the ADDCL Primary Loan Facility, the “ADDCL Credit Facilities”), for which oneof our subsidiaries provides 65percent of the total commitment.  At March 31, 2012, $79 million was outstanding under the ADDCL Secondary Loan Facility, of which $51 million was due to one of our subsidiaries and has been eliminated in consolidation.  On March 31, 2012, the weighted-average interest rate was 3.6 percent.

ADDCL is required to maintain certain cash balances in accounts restricted for the payment of the scheduled installments on the ADDCL Credit Facilities.  ADDCL had restricted cash investments of $30 million and $16 million at March 31, 2012 and December 31, 2011, respectively.

Eksportfinans Loans—The Eksportfinans Loans require cash collateral to remain on deposit at a financial institution (the “Aker Restricted Cash Investments”) through expiration.  The aggregate principal amount of the Aker Restricted Cash Investments was $857 million and $889 million at March 31, 2012 and December 31, 2011, respectively.

TPDI Notes—TPDI has issued promissory notes (the “TPDI Notes”) payable to its two shareholders, Quantum Pacific Management Limited (“Quantum”) and oneof our subsidiaries, which have maturities through October 2019.  At March 31, 2012, the aggregate outstanding principal amount was $296 million, of which $148 million was due to one of our subsidiaries and has been eliminated in consolidation.  On March 31, 2012, the weighted-average interest rate was 2.7 percent.  See Note 15—Redeemable Noncontrolling Interest.

1.50% Series B and 1.50% Series C Convertible Senior Notes—Including amortization of the unamortized discount, the effective interest rates for the Series C Convertible Senior Notes was 5.28 percent.  At March 31, 2012, the remaining period over which the discount will be amortized is less than one year.  Interest expense, excluding amortization of debt issue costs, was as follows (in millions):

	Three months ended March 31,
	2012		2011
Interest expense
Series B Convertible Senior Notes due 2037	$	—	$	20
Series C Convertible Senior Notes due 2037		21		20

The carrying amounts of the liability components of the outstanding Convertible Senior Notes were as follows (in millions):

	March 31, 2012							December 31, 2011
	Principal amount		Unamortized discount			Carrying amount		Principal amount		Unamortized discount			Carrying amount
Carrying amount of liability component
Series B Convertible Senior Notes due 2037	$	—	$	—		$	—	$	30	$	—		$	30
Series C Convertible Senior Notes due 2037		1,722		(44	)		1,678		1,722		(59	)		1,663

The carrying amounts of the equity components of the outstanding Convertible Senior Notes were as follows (in millions):

	March 31, 2012		December 31, 2011
Carrying amount of equity component
Series B Convertible Senior Notes due 2037	$	—	$	4
Series C Convertible Senior Notes due 2037		276		276

In February 2012, we redeemed the remaining $30 million of aggregate principal amount of our Series BConvertible Senior Notes for an aggregate cash payment of $30 million.

- 17 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 12—Derivatives and Hedging

Derivatives designated as hedging instruments—Two of our wholly owned subsidiaries have entered into interest rate swaps, which are designated and have qualified as fair value hedges, to reduce our exposure to changes in the fair values of the 5% Notes due February 2013, the 5.25% Senior Notes due March 2013 and the 4.95% Senior Notes due November 2015.  The interest rate swaps have aggregate notional amounts equal to the corresponding face values of the hedged instruments and have stated maturities that coincide with those of the hedged instruments.  We have determined that the hedging relationships qualify for, and we have applied, the shortcut method of accounting, under which the interest rate swaps are considered to have no ineffectiveness and no ongoing assessment of effectiveness is required.  Accordingly, changes in the fair value of the interest rate swaps recognized in interest expense offset changes in the fair value of the hedged fixed-rate notes.  Through the stated maturities of the interest rate swaps, we receive semi-annual interest at a fixed rate equal to that of the underlying debt instrument and pay variable interest semi-annually at three-month London Interbank Offered Rate plus a margin.

TPDI has entered into interest rate swaps, which have been designated and qualify as a cash flow hedge, to reduce the variability of cash interest payments associated with the variable rate borrowings under the TPDI Credit Facilities through December 31, 2014.  The aggregate notional amount corresponds with the aggregate outstanding amount of the borrowings under the TPDI Credit Facilities.

Aker Drilling has entered into cross-currency interest rate swaps, which have been designated and qualify as a cash flow hedge, to reduce the variability of cash interest payments and the final principal payment, due at maturity in February 2016, associated with the changes in the U.S. dollar to Norwegian kroner exchange rate.  The aggregate notional amount corresponds with the aggregate outstanding amount of the 11% Callable Bonds.

At March 31, 2012, the aggregate notional amounts and the weighted average interest rates associated with our interest rate derivatives designated as hedging instruments were as follows (in millions, except weighted average interest rates):

	Aggregate notional amount		Weighted average variable rate			Weighted average fixed rate
Interest rate swaps, fair value hedges	$	1,400		3.7	%		5.1	%
Interest rate swaps, cash flow hedges		438		0.5	%		2.3	%

At March 31, 2012, the aggregate notional amounts and weighted average interest rates associated with our cross-currency derivatives designated as hedging instruments were as follows (in millions, except weighted average interest rates):

	Pay					Receive
	Notional amount		Weighted average fixed rate			Notional amount		Weighted average fixed rate
Cross-currency swaps, cash flow hedges	$	102		8.9	%	NOK	560		11	%

The effect on our condensed consolidated statements of operations resulting from changes in the fair values of derivatives designated as cash flow hedges was as follows (in millions):

		Three months ended March 31,
	Statement of operations classification	2012			2011
Loss associated with effective portion	Interest expense, net of amounts capitalized	$	2		$	2
Gain associated with ineffective portion	Interest expense, net of amounts capitalized		(1	)		—
Gain associated with effective portion	Other, net		(5	)		—

The balance sheet classification and aggregate carrying amount of our derivatives designated as hedging instruments, measured at fair value, were as follows (in millions):

	Balance sheet classification	March 31, 2012		December 31, 2011
Interest rate swaps, fair value hedges	Other current assets	$	14	$	5
Interest rate swaps, fair value hedges	Other assets		21		31
Interest rate swaps, cash flow hedges	Other current liabilities		1		—
Interest rate swaps, cash flow hedges	Other long-term liabilities		16		16
Cross-currency swaps, cash flow hedges	Other current assets		1		—
Cross-currency swaps, cash flow hedges	Other long-term liabilities		2		7

- 18 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Derivatives not designated as hedging instruments—We have certain derivatives not designated as hedging instruments that we assumed in connection with our acquisition of Aker Drilling for which we receive interest at a fixed rate and we pay interest at a variable rate.  At March 31, 2012, the aggregate notional amounts and the weighted average interest rates associated with our interest rate derivatives not designated as hedging instruments were as follows (in millions, except weighted average interest rates):

	Aggregate notional amount		Weighted average variable rate			Weighted average fixed rate
Interest rate swaps not designated as hedging instruments	$	241		0.5	%		4.2	%

The effect on our condensed consolidated statements of operations resulting from changes in the fair values of derivatives not designated as hedging instruments was as follows (in millions):

		Three months ended March 31,
	Statement of operations classification	2012		2011
Interest rate swaps not designated as hedging instruments	Interest expense, net of amounts capitalized	$	1	$	—

The balance sheet classification and aggregate carrying amount of our derivatives not designated as hedging instruments, measured at fair value, were as follows (in millions):

	Balance sheet classification	March 31, 2012		December 31, 2011
Interest rate swaps not designated as hedging instruments	Other long-term liabilities	$	13	$	15

Note 13—Postemployment Benefit Plans

We have several defined benefit pension plans, both funded and unfunded, covering substantially all of our U.S. employees, including certain frozen plans, assumed in connection with our mergers, that cover certain current employees and certain former employees and directors of our predecessors (the “U.S. Plans”).  We also have various defined benefit plans in the U.K., Norway, Nigeria, Egypt and Indonesia that cover our employees in those areas (the “Non-U.S. Plans”).  Additionally, we offer several unfunded contributory and noncontributory other postretirement employee benefit plans covering substantially all of our U.S. employees (the “OPEB Plans”).

The components of net periodic benefit costs, before tax, and funding contributions for these plans were as follows (in millions):

	Three months ended March 31, 2012											Three months ended March 31, 2011
	U.S. Plans			Non-U.S. Plans			OPEB Plans		Total			U.S. Plans			Non-U.S. Plans			OPEB Plans		Total
Net periodic benefit costs
Service cost	$	12		$	7		$	—	$	19		$	11		$	5		$	—	$	16
Interest cost		14			5			1		20			14			5			1		20
Expected return on plan assets		(15	)		(5	)		—		(20	)		(16	)		(5	)		—		(21	)
Settlements and curtailments		2			—			—		2			—			—			—		—
Actuarial losses, net		10			1			—		11			6			—			—		6
Prior service cost, net		—			—			—		—			—			—			—		—
Transition obligation, net		—			—			—		—			—			—			—		—
Net periodic benefit costs	$	23		$	8		$	1	$	32		$	15		$	5		$	1	$	21
Funding contributions	$	3		$	8		$	1	$	12		$	13		$	7		$	1	$	21

- 19 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 14—Contingencies

Macondo well incident

Overview—On April 22, 2010, the Ultra-Deepwater Floater Deepwater Horizon sank after a blowout of the Macondo well caused a fire and explosion on the rig.  Elevenpersons were declared dead and others were injured as a result of the incident.  At the time of the explosion, Deepwater Horizon was located approximately 41 miles off the coast of Louisiana in Mississippi Canyon Block 252 and was contracted to BP America Production Co. (“BP”).

We are currently unable to estimate the full impact the Macondo well incident will have on us.  We have recognized a liability for estimated loss contingencies that we believe are probable and for which a reasonable estimate can be made.  As of March 31, 2012, we have recognized a liability for such loss contingencies in the amount of $1.2 billion.  This liability takes into account certain events related to the litigation and investigations arising out of the incident.  There are loss contingencies related to the Macondo well incident that we believe are reasonably possible and for which we do not believe a reasonable estimate can be made.  These contingencies could increase the liabilities we ultimately recognize.  As of March 31, 2012, we have also recognized an asset of $222million associated with the portion of our estimated losses that we believe is recoverable from insurance.  Although we have available policy limits that could result in additional amounts recoverable from insurance, we are not currently able to estimate the amount of such additional recoverable amounts.  Our estimates involve a significant amount of judgment.  As a result of new information or future developments, we may adjust our estimated loss contingencies arising out of the Macondo well incident, and the resulting liabilities could have a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  As of December 31, 2011, the amount of the estimated liability was $1.2 billion, and the estimated recoverable amount was $220million.

Many of the Macondo well related claims are pending in the U.S. District Court, Eastern District of Louisiana (the “MDL Court”).  The first phase of a three-phase trial was scheduled to commence on March 5, 2012.  However, on March 2, 2012, BP and the Plaintiff’s Steering Committee (the “PSC”) announced that they had agreed to a partial settlement related primarily to private party environmental and economic loss claims as well as response effort related claims (the “BP/PSC Settlement”).  The BP/PSC Settlement has resulted in the trial being stayed until the court has issued an order outlining a new trial plan.  BP has disclosed that (a) the BP/PSC Settlement is subject to a final written agreement and court approvals, (b) the proposed settlement provides that to the extent provided by law, BP will assign to the PSC certain of its claims, rights and recoveries against us for damages with protections such that the PSC is barred from collecting any amounts from us unless it is finally determined that we cannot recover such amounts from BP, and (c) BP will have the right to approve any settlement between us and the PSC.  We are unable to predict the form of the new trial plan or when trial will commence.  Further, there can be no assurance as to the outcome of the trial, that the trial will proceed according to a new proposed schedule, that we will not enter into a settlement as to some or all of the matters related to the Macondo well incident, including those to be determined at a trial, or the timing or terms of any such settlement.

In April 2011, several defendants in the Macondowell litigation before the Multi-District Litigation Panel (the “MDL”) filed cross-claims or third-party claims against us and certain of our subsidiaries, and other defendants.  BP filed a claim seeking contribution under the Oil Pollution Act of 1990 (“OPA”) and maritime law, subrogation and claimed breach of contract, unseaworthiness, negligence and gross negligence.  BP also sought a declaration that it is not liable in contribution, indemnification, or otherwise to us.  Anadarko Petroleum Corporation (“Anadarko”), which owns a 25 percent non-operating interest in the Macondo well, asserted claims of negligence, gross negligence, and willful misconduct and is seeking indemnity under state and maritime law and contribution under maritime and state law as well as OPA.  MOEX Offshore 2007 LLC (“MOEX”), which owns a 10 percent non-operating interest in the Macondo well, filed claims of negligence under state and maritime law, gross negligence under state law, gross negligence and willful misconduct under maritime law and is seeking indemnity under state and maritime law and contribution under maritime law and OPA.  Cameron International Corporation (“Cameron”), the manufacturer and designer of the blowout preventer, asserted multiple claims for contractual indemnity and declarations regarding contractual obligations under various contracts and quotes and is also seeking non-contractual indemnity and contribution under maritime law and OPA.  As part of the BP/PSC Settlement, one or more of these claims against us and certain of our subsidiaries may be assigned to the PSC.  Halliburton Company (“Halliburton”), which provided cementing and mud-logging services to the operator, filed a claim seeking contribution and indemnity under maritime law, contractual indemnity and alleging negligence and gross negligence.  Additionally, certain other thirdparties filed claims for indemnity and contribution.

On April 20, 2011, we filed cross-claims and counter-claims against BP, Halliburton, Cameron, Anadarko, MOEX, certain of these parties’ affiliates, the U.S. and certain other thirdparties.  We seek indemnity, contribution (including contribution under OPA), and subrogation under OPA, and we have asserted claims for breach of warranty of workmanlike performance, strict liability for manufacturing and design defect, breach of express contract, and damages for the difference between the fair market value of Deepwater Horizon and the amount received from insurance proceeds.  We are not pursuing arbitration on the key contractual issues with BP; instead, we are relying on the court to resolve the disputes.  With regard to the U.S., we are not currently seeking recovery of monetary damages, but rather a declaration regarding relative fault and contribution via credit, setoff, or recoupment.

- 20 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Notices of alleged non-compliance—The final Joint Investigation Team report was issued on September 14, 2011.  Subsequently, the Department of the Interior’s Bureau of Safety and Environmental Enforcement issued fournotices of alleged non-compliance with regulatory requirements to us on October 12, 2011.  While we cannot predict or provide assurance as to the full outcome of these citations, they could result in the assessment of civil penalties.  Our appeal is stayed by mutual agreement with the Department of Interior until a ruling is issued in the MDL.

Insurance coverage—In May 2010, we received notice from BP maintaining that it believes that it is entitled to additional insured status under our excess liability insurance program.  In response, many of our insurers filed declaratory judgment actions in the Houston Division of the U.S. District Court for the Southern District of Texas in May 2010 seeking a judgment declaring that they have limited additional insured obligation to the operator.  Our insurers have also received notices from Anadarko and MOEX advising of their intent to preserve any rights they may have to our insurance policies as an additional insured under the drilling contract.  We, Anadarko and MOEX each have entered into the declaratory judgment actions.  The actions have been transferred to the MDL for discovery purposes in the MDL Court.  On November 15, 2011, the court ruled that coverage rights are limited to the scope of Transocean’s indemnity of BP in the drilling contract.  A final judgment has been entered, and BP has filed a notice of appeal.  While we cannot predict when the appellate court will hear arguments, or the outcome of the appeal, briefs are due by May 7, 2012 and responses are due by June 6, 2012.

At the time of the Macondowell incident, our excess liability insurance program offered aggregate insurance coverage of $950 million, exclusive of a $15 million deductible and a $50 million self-insured layer through our wholly owned captive insurance subsidiary.  This excess liability insurance coverage consisted of a first and a second layer of $150 million each, a third and fourth layer of $200 million each and a fifth layer of $250 million.  The $250 million fifth layer contained different contractual terms, compared to the first four layers, with regard to additional insured status, such that we believe with reasonable certainty that BP, Anadarko and MOEX do not have contractual right to additional insured status under that layer of our insurance program.

Additionally, our first layer of excess insurers filed interpleader actions on June 17, 2011.  The insurers contend that they face multiple, and potentially competing, claims to the relevant insurance proceeds.  In these actions, the insurers effectively ask the court to manage disbursement of the funds to the alleged claimants, as appropriate, and discharge the insurers of any additional liability.  The parties to the suits have executed a protocol, and claims have been submitted to the court for review.  The parties to the interpleaders have agreed to a protocol to facilitate the reimbursement and funding of settlements of personal injury and fatality claims of our crew and vendors using insurance funds.  To date, no payments have yet been received.

Litigation—As of March 31, 2012, 373 actions or claims were pending against us, along with other unaffiliated defendants, in state and federal courts.  Additionally, government agencies have initiated investigations into the Macondo well incident.  We have categorized below the nature of the legal actions or claims.  We are evaluating all claims and intend to vigorously defend any claims and pursue any and all defenses available.  In addition, we believe we are entitled to contractual defense and indemnity for all wrongful death and personal injury claims made by non-employees and third-party subcontractors’ employees as well as all liabilities for pollution or contamination, other than for pollution or contamination originating on or above the surface of the water.  See “—Contractual indemnity.”

Wrongful death and personal injury—As of March 31, 2012, we have been named, along with other unaffiliated defendants, in 19 complaints that were pending in state and federal courts in Louisiana and Texas involving multiple plaintiffs that allege wrongful death and other personal injuries arising out of the Macondowell incident.  Per the order of the MDL, these claims have been centralized for discovery purposes in the MDL Court.  The complaints generally allege negligence and seek awards of unspecified economic damages and punitive damages.  BP, MI-SWACO, Weatherford Ltd. and Cameron and certain of their affiliates, have, based on contractual arrangements, also made indemnity demands upon us with respect to personal injury and wrongful death claims asserted by our employees or representatives of our employees against these entities.  See “—Contractual indemnity.”

Economic loss—As of March 31, 2012, we and certain of our subsidiaries were named, along with other unaffiliated defendants, in 139 individual complaints as well as 185 putative class-action complaints that were pending in the federal and state courts in Louisiana, Texas, Mississippi, Alabama, Georgia, Kentucky, South Carolina, Tennessee, Florida and possibly other courts.  The complaints generally allege, among other things, potential economic losses as a result of environmental pollution arising out of the Macondo well incident and are based primarily on the OPA and state OPA analogues.  The plaintiffs are generally seeking awards of unspecified economic, compensatory and punitive damages, as well as injunctive relief.  These actions have been transferred to the MDL.  See “—Contractual indemnity.”

- 21 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Federal securities claims—Two federal securities law class actions were pending in the U.S. District Court, Southern District of New York, naming us and certain of our officers and directors as defendants.  One of these actions, which was dismissed on March 20, 2012, generally alleged violations of Section 10(b) of the Securities Exchange Act of 1934 (the “Exchange Act”), Rule 10b-5, as promulgated under the Exchange Act, and Section 20(a) of the Exchange Act in connection with the Macondo well incident.  The plaintiffs sought awards of unspecified economic damages, including damages resulting from the decline in our stock price after the Macondo well incident.  The plaintiffs could file an appeal to the dismissal of this action.  The other action, which is still pending, was filed by a former GlobalSantaFe Corporation shareholder, alleging that the proxy statement related to our shareholder meeting in connection with our merger with GlobalSantaFe Corporation violated Section 14(a) of the Exchange Act, Rule 14a-9 promulgated thereunder and Section 20(a) of the Exchange Act.  The plaintiff claims that GlobalSantaFe Corporation shareholders received inadequate consideration for their shares as a result of the alleged violations and seeks rescission and compensatory damages.  The defendants filed a motion to dismiss the claim, but on March 30, 2012, the court denied defendant’s motion.  Defendants have the ability to appeal the ruling but have not yet done so.  A pretrial scheduling conference is set for May 17, 2012, at which time discovery and motion practice deadlines will be established.

Other federal statutes—Several of the claimants have made assertions under the statutes, including the Clean Water Act, the Endangered Species Act, the Migratory Bird Treaty Act, the Clean Air Act, the Comprehensive Environmental Response Compensation and Liability Act and the Emergency Planning and Community Right-to-Know Act.

Shareholder derivative claims—In June 2010, two shareholder derivative suits were filed by our shareholders naming us as a nominal defendant and certain of our officers and directors as defendants in the District Courts of the State of Texas.  The first case generally alleges breach of fiduciary duty, unjust enrichment, abuse of control, gross mismanagement and waste of corporate assets in connection with the Macondo well incident and the other generally alleges breach of fiduciary duty, unjust enrichment and waste of corporate assets in connection with the Macondo well incident.  The plaintiffs are generally seeking, on behalf of us, restitution and disgorgement of all profits, benefits and other compensation from the defendants.  Under current schedule orders, an amended consolidated complaint must be filed by the plaintiffs by June 5, 2012.

Government claims—On December 15, 2010, the U.S. Department of Justice (“DOJ”) filed a civil lawsuit against us and other unaffiliated defendants.  The complaint alleges violations under OPA and the Clean Water Act, including claims for per barrel civil penalties of up to $1,100 per barrel or up to $4,300 per barrel if gross negligence or willful misconduct is established, and the DOJ reserved its rights to amend the complaint to add new claims and defendants.  The U.S. government has estimated that up to 4.1 million barrels of oil were discharged and subject to penalties.  The complaint asserts that all defendants named are jointly and severally liable for all removal costs and damages resulting from the Macondo well incident.  On December 6, 2011, the DOJ filed a motion for partial summary judgment seeking a ruling that we were jointly and severely liable under OPA, and liable for civil penalties under the Clean Water Act, for all of the discharges from the Macondo well on the theory that discharges not only came from the well but also from the blowout preventer and riser, appurtenances of Deepwater Horizon.

On January 9, 2012, we filed our opposition to the motion and filed a cross-motion for partial summary judgment seeking a ruling that we are not liable for the subsurface discharge of hydrocarbons.  On February 22, 2012, the MDL Court ruled that we are not liable as a responsible party for damages under OPA with respect to the below surface discharges from the Macondo well.  The court also ruled that the below surface discharge was discharged from the well facility, and not from the Deepwater Horizon vessel, within the meaning of the Clean Water Act, and that we therefore are not liable for such discharges as an owner of the vessel under the Clean Water Act.  However, the court ruled that the issue of whether we could be held liable for such discharge under the Clean Water Act as an “operator” of the well facility could not be resolved on summary judgment.  The court did not determine whether we could be liable for removal costs under OPA, or the extent of such removal costs.

In addition to the civil complaint, the DOJ served us with civil investigative demands on December 8, 2010.  These demands were part of an investigation by the DOJ to determine if we made false claims, or false statements in support of claims, in connection with the operator’s acquisition of the leasehold interest in the Mississippi Canyon Block 252, Gulf of Mexico and drilling operations on Deepwater Horizon.

The DOJ is also conducting a criminal investigation into the Macondo well incident.  On March 7, 2011, the DOJ announced the formation of a new task force to lead the criminal investigation.  The task force served us with informal requests for documents in March 2011, and a grand jury issued a subpoena requesting documents from us on April 13, 2011.  We have had a number of communications with the task force since that time, and the task force has made informal requests for additional information from us from time to time.  The task force is investigating possible violations by us and certain unaffiliated parties of the Clean Water Act, the Migratory Bird Treaty Act, the Refuse Act, the Endangered Species Act, and the Seaman’s Manslaughter Act, among other federal statutes, and possible criminal liabilities including fines under those statutes and under the Alternative Fines Act.  Under the Alternatives Fines Act, a corporate defendant convicted of a criminal offense may be subject to a fine in the amount of twice the gross pecuniary loss suffered by third parties as a result of the offense.  If we are charged with or convicted of certain criminal environmental offenses, we may be subject to suspension or debarment as a contractor or subcontractor on certain government contracts, including leases.

In June 2010, the Louisiana Department of Environmental Quality (the “LDEQ”) issued a consolidated compliance order and notice of potential penalty to us and certain of our subsidiaries asking us to eliminate and remediate discharges of oil and other pollutants into waters and property located in the State of Louisiana, and to submit a plan and report in response to the order.  In October 2010, the LDEQ rescinded its enforcement actions against us and our subsidiaries but reserved its rights to seek civil penalties for future violations of the Louisiana Environmental Quality Act.

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(Unaudited)

In September 2010, the State of Louisiana filed a declaratory judgment seeking to designate us as a responsible party under OPA and the Louisiana Oil Spill Prevention and Response Act for the discharges emanating from the Macondo well.

Additionally, suits have been filed by the State of Alabama and the cities of Greenville, Evergreen, Georgiana and McKenzie, Alabama in the U.S. District Court, Middle District of Alabama; the Mexican States of Veracruz, Quintana Roo and Tamaulipas in the U.S. District Court, Western District of Texas; and the City of Panama City Beach, Florida in the U.S. District Court, Northern District of Florida.  Suits were also filed by the City of New Orleans, by and on behalf of multiple Parishes, and by or on behalf of the Town of Grand Isle, Grand Isle Independent Levee District, the Town of Jean Lafitte, the Lafitte Area Independent Levee District, the City of Gretna, the City of Westwego, and the City of Harahan in the MDL Court.  Additional suits were filed by or on behalf of other Parishes in the respective Parish courts and were removed to federal court.  A local government master complaint also was filed in which cities, municipalities, and other local government entities can and have joined.  Generally, these governmental entities allege economic losses under OPA and other statutory environmental state claims and also assert various common law state claims.  The claims have been centralized in the MDL and will proceed in accordance with the MDL scheduling order.  The city of Panama City Beach’s claim was voluntarily dismissed.

On August 26, 2011, the MDL Court ruled on the motion to dismiss certain economic loss claims.  The court ruled that state law, both statutory and common law, is preempted by maritime law, notwithstanding OPA’s savings provisions.  Accordingly, all claims brought under state law were dismissed.  Secondly, general maritime law claims that do not allege physical damage to a proprietary interest were dismissed, unless the claim falls into the commercial fisherman exception.  The court ruled that OPA claims for economic loss do not require physical damage to a proprietary interest.  Third, the MDL Court ruled that presentment under OPA is a mandatory condition precedent to filing suit against a responsible party.  Finally, the MDL Court ruled that claims for punitive damages may be available under general maritime law in claims against responsible parties and non-responsible parties.  Certain Louisiana parishes have appealed portions of this ruling, and briefs are due by May 14, 2012 and responses are due by June 13, 2012.

The Mexican States’ OPA claims were dismissed for failure to demonstrate that recovery under OPA was authorized by treaty or executive agreement.  This ruling may be appealed.

By letter dated May 5, 2010, the Attorneys General of the five Gulf Coast states of Alabama, Florida, Louisiana, Mississippi and Texas informed us that they intend to seek recovery of pollution clean-up costs and related damages arising from the Macondo wellincident.  In addition, by letter dated June 21, 2010, the Attorneys General of the 11 Atlantic Coast states of Connecticut, Delaware, Georgia, Maine, Maryland, Massachusetts, New Hampshire, New York, North Carolina, Rhode Island and South Carolina informed us that their states have not sustained any damage from the Macondo well incident but they would like assurances that we will be responsible financially if damages are sustained.  We responded to each letter from the Attorneys General and indicated that we intend to fulfill our obligations as a responsible party for any discharge of oil from Deepwater Horizon on or above the surface of the water, and we assume that the operator will similarly fulfill its obligations under OPA for discharges from the undersea well.

Wreck removal—By letter dated December 6, 2010, the U.S. Coast Guard requested us to formulate and submit a comprehensive oil removal plan to remove any diesel fuel contained in the sponsons and fuel tanks that can be recovered from Deepwater Horizon. We have conducted a survey of the rig wreckage and have confirmed that no diesel fuel remains on the rig.  We have insurance coverage for wreck removal for up to 25 percent of Deepwater Horizon’s insured value, or $140 million, with any excess wreck removal liability generally covered to the extent of our remaining excess liability limits.  The U.S. Coast Guard has not requested that we remove the rig wreckage from the sea floor.

Contractual indemnity—Under our drilling contract for Deepwater Horizon, the operator has agreed, among other things, to assume full responsibility for and defend, release and indemnify us from any loss, expense, claim, fine, penalty or liability for pollution or contamination, including control and removal thereof, arising out of or connected with operations under the contract other than for pollution or contamination originating on or above the surface of the water from hydrocarbons or other specified substances within the control and possession of the contractor, as to which we agreed to assume responsibility and protect, release and indemnify the operator.  Although we do not believe it is applicable to the Macondo well incident, we also agreed to indemnify and defend the operator up to a limit of $15 million for claims for loss or damage to third parties arising from pollution caused by the rig while it is off the drilling location, while the rig is underway or during drive off or drift off of the rig from the drilling location.  The operator has also agreed, among other things, (1) to defend, release and indemnify us against loss or damage to the reservoir, and loss of property rights to oil, gas and minerals below the surface of the earth and (2) to defend, release and indemnify us and bear the cost of bringing the well under control in the event of a blowout or other loss of control.  We agreed to defend, release and indemnify the operator for personal injury and death of our employees, invitees and the employees of our subcontractors while the operator agreed to defend, release and indemnify us for personal injury and death of its employees, invitees and the employees of its other subcontractors, other than us.  We have also agreed to defend, release and indemnify the operator for damages to the rig and equipment, including salvage or removal costs.

Although we believe we are entitled to contractual defense and indemnity, given the potential amounts involved in connection with the Macondo well incident, the operator has sought to avoid its indemnification obligations.  In particular, the operator, in response to our request for indemnification, has generally reserved all of its rights and stated that it could not at this time conclude that it is obligated to indemnify us.  In doing so, the operator has asserted that the facts are not sufficiently developed to determine who is responsible and has cited a variety of possible legal theories based upon the contract and facts still to be developed.  We believe this reservation of rights is without justification and that the operator is required to honor its indemnification obligations contained in our contract and described above.

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(Unaudited)

In April 2011, BP filed a claim seeking a declaration that it is not liable to us in contribution, indemnification, or otherwise.  On November 1, 2011, we filed a motion for partial summary judgment, seeking enforcement of the indemnity obligations for pollution and civil fines and penalties contained in the drilling contract with BP.  On January 26, 2012, the court ruled that the drilling contract requires BP to indemnify us for compensatory damages asserted by third parties against us related to pollution that did not originate on or above the surface of the water, even if the claim is the result of our strict liability, negligence, or gross negligence. The court also held that BP does not owe us indemnity to the extent that we are held liable for civil penalties under the Clean Water Act or for punitive damages.  The court deferred ruling on BP’s argument that we breached the drilling contract or materially increased BP’s risk or prejudiced its rights so as to vitiate BP’s indemnity obligations.  Our motion for partial summary judgment and the court’s ruling did not address the issue of contractual indemnity for criminal fines and penalties.  The law generally considers contractual indemnity for criminal fines and penalties to be against public policy.

Other legal proceedings

Brazil Frade field incident—On or about November 7, 2011, oil was released from fissures in the ocean floor in the vicinity of a development well being drilled by Chevron off the coast of Rio de Janeiro in the Frade field with Sedco 706.  The release was ultimately controlled, the well was plugged, and the released oil is being contained by Chevron.

On March15, 2012, Chevron publicly announced that it had identified a new sheen in Frade field whose source was determined to be seepage from an 800-meter fissure 3kilometers away from the location of the November incident.  Chevron and the Brazilian National Agency of Petroleum have publicly stated that, while further studies are being conducted, the new seepage, which is estimated by Chevron at five liters, appears to be unrelated to the November incident.

On or about December 13, 2011, a federal prosecutor in the town of Campos in Rio de Janeiro State filed a civil public action against Chevron and us seeking BRL 20.0 billion, equivalent to approximately $11.0 billion, and seeking a preliminary and permanent injunction preventing Chevron and us from operating in Brazil.  The prosecutor amended the requested injunction on December 15, 2011, to seek to prevent Chevron and us from conducting extraction or transportation activities in Brazil and to seek to require Chevron to stop the release and remediate its effects.  On January 11, 2012, a judge of the federal court in Campos issued an order finding that the case should be transferred to the federal court in Rio de Janeiro.  The prosecutor has appealed this jurisdictional decision, and that appeal remains pending.  On February24, 2012, the court in Rio de Janeiro issued an order denying the federal prosecutor’s request for a preliminary injunction.  On March27, 2012, the federal prosecutor filed an appeal of that denial, citing the new March2012 seepage as a reason to overrule the decision denying the preliminary injunction.  On March30, 2012, the appellate court issued a decision denying the federal prosecutor’s appeal and upholding the trial court’s decision to deny the preliminary injunction.  On March28, 2012, the original trial court complaint was served on us.  The lawsuit will continue in the trial court, and there remains a risk that Brazilian authorities could temporarily or permanently enjoin us from further operations in Brazil.

On December 21, 2011, a federal police marshal investigating the release filed a report with the federal court in Rio de Janeiro State recommending the indictment of Chevron, us, and 17 individuals, five of whom are our employees.  The report recommended indictment on four counts, three alleging environmental offenses and one alleging false statements by Chevron in connection with its cleanup efforts.  The federal court in Rio de Janeiro State forwarded the report to the federal court in Campos for a decision on the proper jurisdiction for the matter.  On March16, 2012, the Campos federal prosecutor sought and obtained from a special duty judge in Rio de Janeiro injunctions against the 17individuals preventing them from leaving the country without court permission and requiring the Campos court to obtain their passports.  On March21, 2012, the Campos prosecutor issued the recommended indictments against the twocompanies and the 17individuals.  The prosecutor requested that the defendants be enjoined from disposing of property and that bail be set at BRL 10million for the companies and BRL 1million for the individuals.  The indictments must be approved by a court of competent jurisdiction to become effective.  As of March31, 2012, the court has not yet approved the indictments.

On March27, 2012, the union of oil industry workers in Brazil, Federacao Unica dos Petroleiros (“FUP”), filed a civil lawsuit in federal court in Rio de Janeiro against Chevron and us seeking revocation of Chevron's and our contracts and permits in Brazil.  The lawsuit also seeks unspecified damages.  FUP does not represent our workers.  As of March 31, 2012, we had not yet been served with this lawsuit.

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(Unaudited)

The drilling services and charter contracts between Chevron and us provide, among other things, for Chevron to indemnify and defend us for claims based on pollution or contamination originating from below the surface of the water, including claims for control or removal or property loss or damage, including but not limited to third-party claims and liabilities, with an excludable amount of $250,000 per occurrence if the claim arises from our negligence.  We have submitted a claim for indemnity and defense to Chevron under these contracts.  Chevron has responded that our request is premature, and has requested that we confirm our intent to indemnify and defend Chevron regarding alleged violations of safety regulations aboard Sedco 706 that have resulted in the issuance of notices of infractions and any other claims or liabilities that may fall within our legal obligations.  Discussions between Chevron and us are ongoing.

We intend to defend vigorously against any claims that are brought based on the incident.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect it to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  See Note 19—Subsequent Events

Asbestos Litigation–In 2004, several of our subsidiaries were named, along with numerous other unaffiliated defendants, in 21 complaints filed on behalf of 769 plaintiffs in the Circuit Courts of the State of Mississippi and which claimed injuries arising out of exposure to asbestos allegedly contained in drilling mud during these plaintiffs’ employment in drilling activities between 1965 and 1986.  Each individual plaintiff was subsequently required to file a separate lawsuit, and the original 21 multi-plaintiff complaints were then dismissed by the Circuit Courts.  The amended complaints resulted in one of our subsidiaries being named as a direct defendant in seven cases.  As a result of the acquisition of GlobalSantaFeCorporation, we are defending an additional sevencases.  We have or may have an indirect interest in an additional 12cases, for a total of 26 cases of interest.  The complaints generally allege that the defendants used or manufactured asbestos-containing drilling mud additives for use in connection with drilling operations and have included allegations of negligence, products liability, strict liability and claims allowed under the Jones Act and general maritime law.  The plaintiffs generally seek awards of unspecified compensatory and punitive damages.  In each of these cases, the complaints have named other unaffiliated defendant companies, including companies that allegedly manufactured the drilling-related products that contained asbestos.  All of these cases are being governed for discovery and trial setting by a single Case Management Order entered by a Special Master appointed by the court to reside over all the cases, and none of the seven cases in which we are a named defendant have been scheduled for trial or pre-trial discovery.  The preliminary information available on these claims is not sufficient to determine if there is an identifiable period for alleged exposure to asbestos, whether any asbestos exposure in fact occurred, the vessels potentially involved in the claims, or the basis on which the plaintiffs would support claims that their injuries were related to exposure to asbestos.  However, the initial evidence available would suggest that we would have significant defenses to liability and damages.  None of our companies have manufactured or distributed drilling mud or additives for same, and the handling of such additives by one of our employees would be a relatively infrequent occurrence that likely would have involved a non-asbestos product.  In2011, the Special Master issued a ruling that a Jones Act employer defendant, such as us, cannot be sued for punitive damages, and we expect this ruling to apply to each of our seven cases.  To date, seven of the 769 cases have gone to trial against defendants who allegedly manufactured or distributed drilling mud additives.  None of these cases have involved an individual Jones Act employer, and we have not been a defendant in any of these cases.  Two of the cases resulted in defense verdicts, and one case ended with a hung jury.  Four cases resulted in verdicts for the plaintiff.  Because the jury awarded punitive damages, two of these cases resulted in a substantial verdict in favor of the plaintiff; however both of these verdicts have since been vacated by the trial court.  One was vacated on the basis that the plaintiff failed to meet its burden of proof.  While the court’s decision is consistent with our general evaluation of the strength of these cases, it is currently being reviewed on appeal.  The second plaintiff verdict was vacated because the presiding judge was removed from hearing any asbestos cases due to a conflict of interest.  The two remaining plaintiff verdicts are under appeal by the defendants.  We intend to defend these lawsuits vigorously, although there can be no assurance as to the ultimate outcome.  We historically have maintained broad liability insurance, although we are not certain whether insurance will cover the liabilities, if any, arising out of these claims.  Based on our evaluation of the exposure to date, we do not expect the liability, if any, resulting from these claims to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

One of our subsidiaries was involved in lawsuits arising out of the subsidiary’s involvement in the design, construction and refurbishment of major industrial complexes.  The operating assets of the subsidiary were sold and its operations discontinued in 1989, and the subsidiary has no remaining assets other than the insurance policies involved in its litigation, with its insurers and, either directly or indirectly as the beneficiary of a qualified settlement fund, funding from settlements with insurers, assigned rights from insurers and coverage-in-place settlement agreements with insurers, and funds received from the commutation of certain insurance policies.  The subsidiary has been named as a defendant, along with numerous other companies, in lawsuits alleging bodily injury or personal injury as a result of exposure to asbestos.  As of March 31, 2012, the subsidiary was a defendant in approximately 990lawsuits, some of which include multiple plaintiffs, and we estimate that there are approximately 2,158 plaintiffs in these lawsuits.  For many of these lawsuits, we have not been provided with sufficient information from the plaintiffs to determine whether all or some of the plaintiffs have claims against the subsidiary, the basis of any such claims, or the nature of their alleged injuries.  The first of the asbestos-related lawsuits was filed against the subsidiary in 1990.  Through March 31, 2012, the costs incurred to resolve claims, including both defense fees and expenses and settlement costs, have not been material, all known deductibles have been satisfied or are inapplicable, and the subsidiary’s defense fees and expenses and settlement costs have been met by insurance made available to the subsidiary.  The subsidiary continues to be named as a defendant in additional lawsuits, and we cannot predict the number of additional cases in which it may be named a defendant nor can we predict the potential costs to resolve such additional cases or to resolve the pending cases.  However, the subsidiary has in excess of $1.0 billion in insurance limits potentially available to the subsidiary.  Although not all of the policies may be fully available due to the insolvency of certain insurers, we believe that the subsidiary will have sufficient funding from settlements and claims payments from insurers, assigned rights from insurers and coverage-in-place settlement agreements with insurers to respond to these claims.  While we cannot predict or provide assurance as to the final outcome of these matters, we do not believe that the current value of the claims where we have been identified will have a material impact on our consolidated statement of financial position, results of operations or cash flows.

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(Unaudited)

Rio de Janeiro tax assessment—In the thirdquarter of 2006, we received tax assessments of approximately $196 million from the state tax authorities of Rio de Janeiro in Brazil against one of our Brazilian subsidiaries for taxes on equipment imported into the state in connection with our operations.  The assessments resulted from a preliminary finding by these authorities that our subsidiary’s record keeping practices were deficient.  We currently believe that the substantial majority of these assessments are without merit.  We filed an initial response with the Rio de Janeiro tax authorities on September 9, 2006 refuting these additional tax assessments.  In September 2007, we received confirmation from the state tax authorities that they believe the additional tax assessments are valid, and as a result, we filed an appeal on September 27, 2007 to the state Taxpayer’s Council contesting these assessments.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect it to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Brazilian import license assessment—In the fourth quarter of 2010, oneof our Brazilian subsidiaries received an assessment from the Brazilian federal tax authorities in Rio de Janeiro of approximately $235 million based upon the alleged failure to timely apply for import licenses for certain equipment and for allegedly providing improper information on import license applications.  We responded to the assessment on December 22, 2010, and we currently believe that a substantial majority of the assessment is without merit.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect it to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Other matters—We are involved in various tax matters and various regulatory matters.  We are also involved in lawsuits relating to damage claims arising out of hurricanes Katrina and Rita, all of which are insured and which are not material to us.  As of March 31, 2012, we were involved in a number of other lawsuits, including a dispute for municipal tax payments in Brazil and a dispute involving customs procedures in India, neither of which is material to us, and all of which have arisen in the ordinary course of our business.  We do not expect the liability, if any, resulting from these other matters to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We cannot predict with certainty the outcome or effect of any of the litigation matters specifically described above or of any such other pending or threatened litigation.  There can be no assurance that our beliefs or expectations as to the outcome or effect of any lawsuit or other litigation matter will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

Other environmental matters

Hazardous waste disposal sites—We have certain potential liabilities under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and similar state acts regulating cleanup of various hazardous waste disposal sites, including those described below.  CERCLA is intended to expedite the remediation of hazardous substances without regard to fault.  Potentially responsible parties (“PRPs”) for each site include present and former owners and operators of, transporters to and generators of the substances at the site.  Liability is strict and can be joint and several.

We have been named as a PRP in connection with a site located in Santa Fe Springs, California, known as the Waste Disposal,Inc. site.  We and other PRPs have agreed with the U.S. Environmental Protection Agency (“EPA”) and the DOJ to settle our potential liabilities for this site by agreeing to perform the remaining remediation required by the EPA.  The form of the agreement is a consent decree, which has been entered by the court.  The parties to the settlement have entered into a participation agreement, which makes us liable for approximately eight percent of the remediation and related costs.  The remediation is complete, and we believe our share of the future operation and maintenance costs of the site is not material.  There are additional potential liabilities related to the site, but these cannot be quantified, and we have no reason at this time to believe that they will be material.

One of our subsidiaries has been ordered by the California Regional Water Quality Control Board (“CRWQCB”) to develop a testing plan for a site known as Campus 1000 Fremont in Alhambra, California.  This site was formerly owned and operated by certain of our subsidiaries.  It is presently owned by an unrelated party, which has received an order to test the property.  We have also been advised that one or more of our subsidiaries is likely to be named by the EPA as a PRP for the San Gabriel Valley, Area 3, Superfund site, which includes this property.  Testing has been completed at the property but no contaminants of concern were detected.  In discussions with CRWQCB staff, we were advised of their intent to issue us a “no further action” letter but it has not yet been received.  Based on the test results, we would contest any potential liability.  We have no knowledge at this time of the potential cost of any remediation, who else will be named as PRPs, and whether in fact any of our subsidiaries is a responsible party.  The subsidiaries in question do not own any operating assets and have limited ability to respond to any liabilities.

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(Unaudited)

Resolutions of other claims by the EPA, the involved state agency or PRPs are at various stages of investigation.  These investigations involve determinations of:

§   the actual responsibility attributed to us and the other PRPs at the site;

§   appropriate investigatory or remedial actions; and

§   allocation of the costs of such activities among the PRPs and other site users.

Our ultimate financial responsibility in connection with those sites may depend on many factors, including:

§   the volume and nature of material, if any, contributed to the site for which we are responsible;

§   the number of other PRPs and their financial viability; and

§   the remediation methods and technology to be used.

It is difficult to quantify with certainty the potential cost of these environmental matters, particularly in respect of remediation obligations.  Nevertheless, based upon the information currently available, we believe that our ultimate liability arising from all environmental matters, including the liability for all other related pending legal proceedings, asserted legal claims and known potential legal claims which are likely to be asserted, is adequately accrued and should not have a material effect on our statement of financial position or results of operations.  Estimated costs of future expenditures for environmental remediation obligations are not discounted to their present value.

Contamination litigation

On July11, 2005, one of our subsidiaries was served with a lawsuit filed on behalf of threelandowners in Louisiana in the 12th Judicial District Court for the Parish of Avoyelles, State of Louisiana.  The lawsuit named 19other defendants, all of which were alleged to have contaminated the plaintiffs’ property with naturally occurring radioactive material, produced water, drilling fluids, chlorides, hydrocarbons, heavy metals and other contaminants as a result of oil and gas exploration activities.  Experts retained by the plaintiffs issued a report suggesting significant contamination in the area operated by the subsidiary and another codefendant (the “Co-Defendant”), and claimed that over $300million would be required to properly remediate the contamination.  The experts retained by the defendants conducted their own investigation and concluded that the remediation costs would amount to no more than $2.5million.  The Co-Defendant settled the actions with the threelandowners (the “Settlement”).  The Co-Defendant subsequently filed suit in 2008 against the subsidiary and certain of its insurers in the Court of Avoyelles Parish to determine their liability for the Settlement.

On March11, 2010, the Co-Defendant filed a motion for leave to amend the pending litigation in Avoyelles Parish to add GlobalSantaFe Corporation, Transocean Worldwide Inc., its successor, and twoother subsidiaries under the “single business enterprise” doctrine contained in Louisiana law, as well as various additional insurers.  The single business enterprise doctrine is similar to corporate veil piercing doctrines.  A subsequent amendment added a claim for abuse of process under Louisiana law for an earlier bankruptcy filed by the subsidiary in Delaware, which was ultimately dismissed by a bankruptcy court and various other actions undertaken by our subsidiary, GlobalSantaFeCorporation and Transocean WorldwideInc.

A scheduling order has been entered in the Avoyelles Parish lawsuit and a jury trial is set on these matters for September17, 2012.  Discovery is ongoing.  The subsidiary has filed a motion for summary judgment for defense costs against various insurers, and the motion is set for hearing on April23, 2012.

We believe that the legal theories advanced by the Co-Defendant should not be applied against the subsidiary, GlobalSantaFeCorporation or Transocean WorldwideInc. and the two other subsidiaries.  We intend to continue to vigorously defend against any action taken in an attempt to impose liability under the theories discussed above or otherwise and believe there are good and valid defenses thereto.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect them to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

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(Unaudited)

Retained risk

Our hull and machinery and excess liability insurance program consists of commercial market and captive insurance policies.  We periodically evaluate our insurance limits and self-insured retentions.  As of March 31, 2012, the insured value of our drilling rig fleet was approximately $36.0 billion, excluding our rigs under construction.

Under the hull and machinery program, we generally maintain a $125 million per occurrence deductible, limited to a maximum of $250 million per policy period.  Subject to the same shared deductible, we also have coverage for costs incurred to mitigate damage to a rig up to an amount equal to 25 percent of a rig’s insured value.  Also subject to the same shared deductible, we have additional coverage for wreck removal for up to 25 percent of a rig’s insured value, with any excess generally covered to the extent of our remaining excess liability coverage described below.  However, we generally retain the risk for all hull and machinery exposures for our Standard Jackups and swamp barge, which are self-insured through our wholly owned captive insurance company.

We carry $793million of commercial market excess liability coverage, exclusive of the deductibles and self-insured retention, noted below, which generally covers offshore risks such as personal injury, third-party property claims, and third-party non-crew claims, including wreck removal and pollution.  Our excess liability coverage has (1) separate $10 million per occurrence deductibles on crew personal injury liability and on collision liability claims and (2) a separate $5 million per occurrence deductible on other third-party non-crew claims.  Through our wholly owned captive insurance company, we have retained the risk of the primary $50 million excess liability coverage, along with $157 million of the excess liability coverage, of which we have re-insured $25 million in the commercial market.  In addition, we generally retain the risk for any liability losses in excess of $1.0 billion.

We also carry $100 million of additional insurance that generally covers expenses that would otherwise be assumed by the well owner, such as costs to control the well, redrill expenses and pollution from the well.  This additional insurance provides coverage for such expenses in circumstances in which we have legal or contractual liability arising from our gross negligence or willful misconduct.

We have elected to self-insure operators extra expense coverage for ADTI and for the operations of our former oil and gas properties reporting unit (see Note 8—Discontinued Operations).  This coverage provides protection against expenses related to well control, pollution and redrill liability associated with blowouts.  ADTI’s customers assume, and indemnify ADTI for, liability associated with blowouts in excess of a contractually agreed amount, generally $50 million.

We generally do not have commercial market insurance coverage for loss of revenue, unless it is contractually required, or for physical damage losses, including liability for wreck removal expenses, to our fleet caused by named windstorms in the U.S. Gulf of Mexico and war perils worldwide.

Letters of credit and surety bonds

We had letters of credit outstanding totaling $653 million and $650million at March 31, 2012 and December 31, 2011, respectively, issued under various committed and uncommitted credit lines provided by several banks to guarantee various contract bidding, performance activities and customs obligations.  Included in the letters of credit outstanding at March 31, 2012 was a $60 million letter of credit issued under an uncommitted credit facility that has been established by one of our subsidiaries for TPDI to satisfy its liquidity requirements under the TPDI Credit Facilities (see Note 11—Debt).

As is customary in the contract drilling business, we also have various surety bonds in place that secure customs obligations relating to the importation of our rigs and certain performance and other obligations.  We had outstanding surety bonds totaling $12million at March 31, 2012 and December 31, 2011.

- 28 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 15—Redeemable Noncontrolling Interest

Quantum owns the 50 percent interest in TPDI that is not owned by us and has the unilateral right, pursuant to a put option agreement, to exchange its interest in TPDI for our shares or cash, at its election, at an amount based on an appraisal of the fair value of the drillships that are owned by TPDI, subject to certain adjustments.  Accordingly, we present Quantum’s interest as redeemable noncontrolling interest on our condensed consolidated balance sheets.  Changes in redeemable noncontrolling interest were as follows (in millions):

	Threemonths ended March 31,
	2012		2011
Redeemable noncontrolling interest
Balance, beginning of period	$	116	$	25
Net income attributable to noncontrolling interest		22		28
Other comprehensive loss attributable to noncontrolling interest		—		4
Balance, end of period	$	138	$	57

On February 29, 2012, Quantum exercised its rights under the put option agreement, and on March 29, 2012, Quantum elected to exchange its interest in TPDI for our shares, net of Quantum’s share of TPDI’s indebtedness.  Quantum has the right, prior to closing of this exchange, to change its election to cash, net of Quantum’s share of TPDI’s indebtedness.  Therefore, we have continued to present Quantum’s interest as redeemable noncontrolling interest on our condensed consolidated balance sheets.

Note 16—Shareholders’ Equity

Distribution of qualifying additional paid-in capital—In May 2011, at our annual general meeting, our shareholders approved the distribution of additional paid-in capital in the form of a U.S. dollar denominated dividend of $3.16 per outstanding share, payable in four equal installments of $0.79 per outstanding share, subject to certain limitations.  On March 21, 2012, we paid the final installment in the amount of $278 million to shareholders of record as of February 24, 2012.

Shares held by subsidiary—In December 2008, we issued 16 million of our shares to one of our subsidiaries for future use to satisfy our obligations to deliver shares in connection with awards granted under our incentive plans or other rights to acquire our shares.  Our subsidiary held approximately 12 million shares at March 31, 2012 and December 31, 2011.

Accumulated other comprehensive loss—The changes in accumulated other comprehensive loss for the three months ended March 31, 2012 and 2011 were as follows (in millions):

	Three months ended March 31, 2012
	Unrecognized components of net periodic benefit costs			Unrecognized gains (losses) on derivative instruments			Unrecognized gains (losses) on marketable securities			Total
Balance, beginning of period	$	(501	)	$	7		$	(2	)	$	(496	)
Other comprehensive loss attributable to controlling interest		(18	)		(1	)		—			(19	)
Balance, end of period	$	(519	)	$	6		$	(2	)	$	(515	)

	Three months ended March 31, 2011
	Unrecognized components of net periodic benefit costs			Unrecognized gains (losses) on derivative instruments			Unrecognized gains (losses) on marketable securities			Total
Balance, beginning of period	$	(335	)	$	5		$	(2	)	$	(332	)
Other comprehensive loss attributable to controlling interest		(2	)		(1	)		—			(3	)
Balance, end of period	$	(337	)	$	4		$	(2	)	$	(335	)

- 29 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 17—Financial Instruments

The carrying amounts and fair values of our financial instruments were as follows (in millions):

	March 31, 2012				December 31, 2011
	Carrying amount		Fair value		Carrying amount		Fair value
Cash and cash equivalents	$	3,982	$	3,982	$	4,017	$	4,017
Accounts receivable		2,238		2,238		2,176		2,176
Notes receivable and working capital loan receivable		129		129		139		139
Restricted cash investments		913		959		928		975
Long-term debt, including current maturities		12,635		13,800		12,698		13,074
Long-term debt of consolidated variable interest entities, including current maturities		821		821		838		838
Derivative instruments, assets		36		36		36		36
Derivative instruments, liabilities		32		32		38		38

We estimated the fair value of each class of financial instruments, for which estimating fair value is practicable, by applying the following methods and assumptions:

Cash and cash equivalents—The carrying amount of cash and cash equivalents, which are stated at cost plus accrued interest, approximates fair value because of the short maturities of those instruments.

Accounts receivable—The carrying amount, net of valuation allowance, approximates fair value because of the short maturities of those instruments.

Notes receivable and working capital loan receivable—The aggregate carrying amount represents the amortized cost of our investments, which approximates the estimated fair value.  We measured the estimated fair value using significant unobservable inputs, representing a Level 3 fair value measurement, including the credit ratings of the borrowers.  At March 31, 2012, the aggregate carrying amount of our notes receivable and working capital loan receivable was $129 million, including $26 million and $103 million recorded in other current assets and other assets, respectively.  At December 31, 2011, the aggregate carrying amount of our notes receivable and working capital loan receivable was $139 million, including $37 million and $102 million recorded in other current assets and other assets, respectively.

Restricted cash investments—The carrying amount of the Aker Restricted Cash Investments represents the amortized cost of our investment, which was at $857 million and $889 million at March 31, 2012 and December 31, 2011, respectively.  We measured the estimated fair value of the Aker Restricted Investments using significant other observable inputs, representing a Level 2 fair value measurement.  The estimated fair value of the Aker Restricted Cash Investments was $897 million and $930 million at March 31, 2012 and December 31, 2011, respectively.

The aggregate carrying amount of the restricted cash investments for the TPDI Credit Facilities and the ADDCL Credit Facilities approximates fair value due to the short term nature of the instruments in which the restricted cash investments are held.  The aggregate carrying amount of the restricted cash investments for the TPDI Credit Facilities and the ADDCL Credit Facilities was $56 million and $39 million at March 31, 2012 and December 31, 2011, respectively.

Debt—The aggregate carrying amount of our fixed-rate debt was $11.9 billion at March 31, 2012 and December 31, 2011.  We measured the estimated fair value of our fixed-rate debt using significant other observable inputs, representing a Level 2 fair value measurement, including the terms and credit spreads for the instruments.  The aggregate estimated fair value of our fixed-rate debt was $13.1 billion and $12.2 billion at March 31, 2012 and December 31, 2011, respectively.

The aggregate carrying amount of our variable-rate debt approximates fair value because the terms of those debt instruments include short-term interest rates and exclude penalties for prepayment.  We measured the estimated fair value of our variable-rate debt using significant other observable inputs, representing a Level 2 fair value measurement, including the terms and credit spreads for the instruments.  The aggregate carrying amount of our variable-rate debt was $746 million and $761 million at March 31, 2012 and December 31, 2011, respectively.

Debt of consolidated variable interest entities—The aggregate carrying amount of the variable-rate debt of our consolidated variable interest entities approximates fair value because the terms of those debt instruments include short-term interest rates and exclude penalties for prepayments.  We measured the estimated fair value of the debt of our consolidated variable interest entities using significant other observable inputs, representing a Level 2 fair value measurement, including the terms and credit spreads of the instruments.  The aggregate carrying amount of the variable-rate debt of our consolidated variable interest entities was $821 million and $838 million at March 31, 2012 and December 31, 2011, respectively.

- 30 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Derivative instruments—The aggregate carrying amount of our derivative instruments represents the estimated fair value, measured using significant other observable inputs, representing a Level 2 fair value measurement, including the interest rates and terms of the instruments.

Note 18—Condensed Consolidating Financial Information

Transocean Inc., a wholly owned subsidiary of TransoceanLtd., is the issuer of certain notes and debentures, which have been guaranteed by TransoceanLtd.  Transocean Ltd. has also guaranteed borrowings under the Five-Year Revolving Credit Facility.  TransoceanLtd.’s guarantee of debt securities of Transocean Inc. is full and unconditional.  Transocean Ltd. is not subject to any significant restrictions on its ability to obtain funds by dividends, loans or capital distributions from its consolidated subsidiaries.

The following tables present condensed consolidating financial information for (a) TransoceanLtd. (the “Parent Guarantor”), (b) TransoceanInc. (the “Subsidiary Issuer”), and (c) the other direct and indirect wholly owned and partially owned subsidiaries of the Parent Guarantor (the “Other Subsidiaries”), none of which guarantee any indebtedness of the Subsidiary Issuer.  The tables also include the consolidating adjustments necessary to present the condensed financial statements on a consolidated basis.  The following condensed consolidating financial information may not necessarily be indicative of the results of operations, financial position or cash flows had the subsidiaries operated as independent entities (in millions):

	Three months ended March 31, 2012
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Operating revenues	$	—		$	—		$	2,336		$	(5	)	$	2,331
Cost and expenses		11			1			1,823			(5	)		1,830
Loss on impairment		—			—			(227	)		—			(227	)
Loss on disposal of assets, net		—			—			(4	)		—			(4	)
Operating income (loss)		(11	)		(1	)		282			—			270
Other income (expense), net
Interest expense, net		(3	)		(134	)		(28	)		—			(165	)
Equity in earnings		56			202			—			(258	)		—
Other, net		—			(9	)		2			—			(7	)
		53			59			(26	)		(258	)		(172	)
Income from continuing operations before income tax expense		42			58			256			(258	)		98
Income tax expense		—			—			24			—			24
Income from continuing operations		42			58			232			(258	)		74
Loss from discontinued operations, net of tax		—			—			(15	)		—			(15	)
Net Income		42			58			217			(258	)		59
Net income attributable to noncontrolling interest		—			—			17			—			17
Net income attributable to controlling interest		42			58			200			(258	)		42
Other comprehensive loss before income taxes		(4	)		(8	)		(4	)		—			(16	)
Income taxes related to other comprehensive loss		—			—			(3	)		—			(3	)
Other comprehensive loss, net  of income taxes		(4	)		(8	)		(7	)		—			(19	)
Total comprehensive income		38			50			210			(258	)		40
Total comprehensive income attributable to noncontrolling interest		—			—			17			—			17
Total comprehensive income attributable to controlling interest	$	38		$	50		$	193		$	(258	)	$	23

- 31 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

	Three months ended March 31, 2011
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments				Consolidated
Operating revenues	$	—		$	—		$	2,148		$	(4	)	$		2,144
Cost and expenses		10			1			1,773			(4	)			1,780
Gain on disposal of assets, net		—			—			8			—				8
Operating income (loss)		(10	)		(1	)		383			—				372
Other income (expense), net
Interest income (expense), net		—			(131	)		1			—				(130	)
Equity in earnings		320			479			2			(799	)			2
Other, net		—			(23	)		24			—				1
		320			325			27			(799	)			(127	)
Income from continuing operations before income tax expense		310			324			410			(799	)			245
Income tax expense		—			—			81			—				81
Income from continuing operations		310			324			329			(799	)			164
Income from discontinued operations, net of tax		—			—			176			—				176
Net income		310			324			505			(799	)			340
Net income attributable to noncontrolling interest		—			—			30			—				30
Net income attributable to controlling interest		310			324			475			(799	)			310
Other comprehensive income (loss) before income taxes		(3	)		(5	)		11			—				3
Income taxes related to other comprehensive loss		—			—			(2	)		—				(2	)
Other comprehensive income (loss), net  of income taxes		(3	)		(5	)		9			—				1
Total comprehensive income		307			319			514			(799	)			341
Total comprehensive income attributable to noncontrolling interest		—			—			34			—				34
Total comprehensive income attributable to controlling interest	$	307		$	319		$	480		$	(799	)		$	307

- 32 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

	March 31, 2012
	Parent Guarantor		Subsidiary Issuer		Other Subsidiaries		Consolidating adjustments			Consolidated
Assets
Cash and cash equivalents	$	5	$	2,185	$	1,792	$	—		$	3,982
Other current assets		10		877		4,290		(1,486	)		3,691
Total current assets		15		3,062		6,082		(1,486	)		7,673
Property and equipment, net		1		—		22,322		—			22,323
Goodwill		—		—		3,087		—			3,087
Investment in affiliates		16,560		27,782		—		(44,342	)		—
Other assets		—		1,642		17,605		(17,615	)		1,632
Total assets		16,576		32,486		49,096		(63,443	)		34,715
Liabilities and equity
Debt due within one year		—		2,185		607		—			2,792
Other current liabilities		17		428		4,013		(1,486	)		2,972
Total current liabilities		17		2,613		4,620		(1,486	)		5,764
Long-term debt		790		13,626		13,863		(17,615	)		10,664
Other long-term liabilities		31		467		1,928		—			2,426
Total long-term liabilities		821		14,093		15,791		(17,615	)		13,090
Commitments and contingencies		—		—		—		—			—
Redeemable noncontrolling interest		—		—		138		—			138
Total equity		15,738		15,780		28,547		(44,342	)		15,723
Total liabilities and equity	$	16,576	$	32,486	$	49,096	$	(63,443	)	$	34,715

	December 31, 2011
	Parent Guarantor		Subsidiary Issuer		Other Subsidiaries		Consolidating adjustments			Consolidated
Assets
Cash and cash equivalents	$	3	$	2,793	$	1,221	$	—		$	4,017
Other current assets		8		784		4,493		(1,693	)		3,592
Total current assets		11		3,577		5,714		(1,693	)		7,609
Property and equipment, net		1		—		22,528		—			22,529
Goodwill		—		—		3,205		—			3,205
Investment in affiliates		16,503		27,582		—		(44,085	)		—
Other assets		—		1,368		17,908		(17,531	)		1,745
Total assets		16,515		32,527		49,355		(63,309	)		35,088
Liabilities and equity
Debt due within one year		—		1,693		346		—			2,039
Other current liabilities		294		367		4,351		(1,693	)		3,319
Total current liabilities		294		2,060		4,697		(1,693	)		5,358
Long-term debt		495		14,308		14,225		(17,531	)		11,497
Other long-term liabilities		25		439		1,962		—			2,426
Total long-term liabilities		520		14,747		16,187		(17,531	)		13,923
Commitments and contingencies
Redeemable noncontrolling interest		—		—		116		—			116
Total equity		15,701		15,720		28,355		(44,085	)		15,691
Total liabilities and equity	$	16,515	$	32,527	$	49,355	$	(63,309	)	$	35,088

- 33 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

	Three months ended March 31, 2012
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Cash flows from operating activities	$	(15	)	$	(114	)	$	669		$	—		$	540
Cash flows from investing activities
Capital expenditures		—			—			(260	)		—			(260	)
Proceeds from disposal of assets, net		—			—			41			—			41
Investing activities with affiliates, net		—			(283	)		183			100			—
Other, net		—			10			2			—			12
Net cash provided by (used in) investing activities		—			(273	)		(34	)		100			(207	)
Cash flows from financing activities
Repayments of debt		—			(29	)		(118	)		—			(147	)
Proceeds from restricted cash investments		—			—			108			—			108
Deposits to restricted cash investments		—			—			(42	)		—			(42	)
Distribution of qualifying additional paid-in capital		(278	)		—			—			—			(278	)
Financing activities with affiliates, net		295			(183	)		(12	)		(100	)		—
Other, net		—			(9	)		—			—			(9	)
Net cash provided by (used in) financing activities		17			(221	)		(64	)		(100	)		(368	)
Net increase (decrease) in cash and cash equivalents		2			(608	)		571			—			(35	)
Cash and cash equivalents at beginning of period		3			2,793			1,221			—			4,017
Cash and cash equivalents at end of period	$	5		$	2,185		$	1,792		$	—		$	3,982

	Three months ended March 31, 2011
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Cash flows from operating activities	$	(13	)	$	(77	)	$	480		$	—		$	390
Cash flows from investing activities
Capital expenditures		—			—			(240	)		—			(240	)
Proceeds from disposal of assets, net		—			—			13			—			13
Proceeds from disposal of discontinued operations, net		—			—			259			—			259
Investing activities with affiliates, net		—			(21	)		(509	)		530			—
Other, net		—			—			(6	)		—			(6	)
Net cash provided by (used in) investing activities		—			(21	)		(483	)		530			26
Cash flows from financing activities
Changes in short-term borrowings, net		—			51			—			—			51
Proceeds from debt		—			5			—			—			5
Repayments of debt		—			(12	)		(35	)		—			(47	)
Financing activities with affiliates, net		—			509			21			(530	)		—
Other, net		—			(7	)		—			—			(7	)
Net cash provided by (used in) financing activities		—			546			(14	)		(530	)		2
Net increase (decrease) in cash and cash equivalents		(13	)		448			(17	)		—			418
Cash and cash equivalents at beginning of period		38			2,041			1,315			—			3,394
Cash and cash equivalents at end of period	$	25		$	2,489		$	1,298		$	—		$	3,812

- 34 -

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

(Unaudited)

Note 19—Subsequent Events

Norway tax investigations—In April 2012, the Norwegian tax authorities supplemented the previously issued criminal indictments against our two subsidiaries by extending a criminal indictment against a third subsidiary on the same matter, alleging misleading or incomplete disclosures in Norwegian tax returns for the years 2001 and 2002.

Discontinued operations—Subsequent to March 31, 2012, we completed the sale of the assets of Challenger Minerals Inc.

Dispositions—Subsequent to March 31, 2012, we completed the sales of Roger W. Mowell, TransoceanNordic and Transocean Shelf Explorer.

Assets held for sale—Subsequent to March 31, 2012, we entered into an agreement to sell the Standard Jackup GSF Adriatic II, and we reclassified the drilling unit and related equipment, having an aggregate carrying amount of $54 million, to assets held for sale.

Aker Term Loan Facility—Subsequent to March 31, 2012, we prepaid $115 million of borrowings under the Aker Term Loan Facility.

Brazil Frade field incident—On April 3, 2012 the same federal prosecutor who filed the original civil public action filed a new civil lawsuit against Chevron and us in federal court in Campos.  The lawsuit cites the March 2012 seepage and seeks a broad injunction against Chevron and us to prevent them from doing business in Brazil and from removing property or profits from Brazil.  The lawsuit also seeks approximately $11.0 billion in damages from Chevron and us.

On April 16, 2012, the Campos court issued an order stating that it did not have jurisdiction in this matter and transferred the cases to the court in Rio de Janeiro.

- 35 -

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

Forward-Looking Information

The statements included in this annual report regarding future financial performance and results of operations and other statements that are not historical facts are forward-looking statements within the meaning of Section27A of the Securities Act of 1933 and Section21E of the Securities Exchange Act of 1934.  Forward-looking statements in this annual report include, but are not limited to, statements about the following subjects:

§   the impact of the Macondo well incident and related matters,

§   our results of operations and cash flow from operations, including revenues and expenses,

§   the offshore drilling market, including the impact of enhanced regulations in the jurisdictions in which we operate, supply and demand, utilization rates, dayrates, customer drilling programs, commodity prices, stacking of rigs, reactivation of rigs, effects of new rigs on the market and effects of declines in commodity prices and the downturn in the global economy or market outlook for our various geographical operating sectors and classes of rigs,

§   customer contracts, including contract backlog, force majeure provisions, contract commencements, contract extensions, contract terminations, contract option exercises, contract revenues, contract awards and rig mobilizations,

§   liquidity and adequacy of cash flows for our obligations,

§   debt levels, including impacts of the financial and economic downturn,

§   uses of excess cash, including the payment of dividends and other distributions and debt retirement,

§   newbuild, upgrade, shipyard and other capital projects, including completion, delivery and commencement of operation dates, expected downtime and lost revenue, the level of expected capital expenditures and the timing and cost of completion of capital projects,

§   the cost and timing of acquisitions and the proceeds and timing of dispositions,

§   tax matters, including our effective tax rate, changes in tax laws, treaties and regulations, tax assessments and liabilities for tax issues, including those associated with our activities in Brazil, Norway and the United States (“U.S”).,

§   legal and regulatory matters, including results and effects of legal proceedings and governmental audits and assessments, outcomes and effects of internal and governmental investigations, customs and environmental matters,

§   insurance matters, including adequacy of insurance, renewal of insurance, insurance proceeds and cash investments of our wholly owned captive insurance company,

§   effects of accounting changes and adoption of accounting policies, and

§   investments in recruitment, retention and personnel development initiatives, pension plan and other postretirement benefit plan contributions, the timing of severance payments and benefit payments.

Forward-looking statements in this annual report are identifiable by use of the following words and other similar expressions:

§“anticipates”	§“could”	§“forecasts”	§“might”	§“projects”
§“believes”	§“estimates”	§“intends”	§“plans”	§“scheduled”
§“budgets”	§“expects”	§“may”	§“predicts”	§“should”

Such statements are subject to numerous risks, uncertainties and assumptions, including, but not limited to:

§   those described under “Item 1A. Risk Factors” included in our annual report on Form 10-K for the year ended December 31, 2011,  

§   the adequacy of and access to sources of liquidity,

§   our inability to obtain contracts for our rigs that do not have contracts,

§   our inability to renew contracts at comparable dayrates,

§   operational performance,

§   the impact of regulatory changes,

§   the cancellation of contracts currently included in our reported contract backlog,

§   increased political and civil unrest,

§   the effect and results of litigation, regulatory matters, settlements, audits, assessments and contingencies, and

§   other factors discussed in this annual report and in our other filings with the U.S. Securities and Exchange Commission (“SEC”), which are available free of charge on the SEC website at www.sec.gov.

The foregoing risks and uncertainties are beyond our ability to control, and in many cases, we cannot predict the risks and uncertainties that could cause our actual results to differ materially from those indicated by the forward-looking statements.  Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those indicated.

All subsequent written and oral forward-looking statements attributable to us or to persons acting on our behalf are expressly qualified in their entirety by reference to these risks and uncertainties.  You should not place undue reliance on forward-looking statements.  Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statements, except as required by law.

- 36 -

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.  As of April 24, 2012, we owned or had partial ownership interests in and operated 129mobile offshore drilling units.  As of this date, our fleet consisted of 50High-Specification Floaters (Ultra-Deepwater, Deepwater and Harsh Environment semisubmersibles and drillships), 25 Midwater Floaters, nineHigh-Specification Jackups, 44Standard Jackups and oneswamp barge.  In addition, we had two Ultra-Deepwater drillships and fourHigh-Specification Jackups under construction.

We have two reportable segments: (1) contract drilling services and (2) drilling management services, formerly a component of our other operations segment.  Contract drilling services, our primary business, involves contracting our mobile offshore drilling fleet, related equipment and work crews primarily on a dayrate basis to drill oil and gas wells.  We specialize in technically demanding regions of the offshore drilling business with a particular focus on deepwater and harsh environment drilling services.  We believe our drilling fleet is one of the most versatile fleets in the world, consisting of floaters, jackups and other rigs used in support of offshore drilling activities and offshore support services on a worldwide basis.

Our contract drilling operations are geographically dispersed in oil and gas exploration and development areas throughout the world.  Although rigs can be moved from one region to another, the cost of moving rigs and the availability of rig-moving vessels may cause the supply and demand balance to fluctuate somewhat between regions.  Still, significant variations between regions do not tend to persist long term because of rig mobility.  Our fleet operates in a single, global market for the provision of contract drilling services.  The location of our rigs and the allocation of resources to build or upgrade rigs are determined by the activities and needs of our customers.

Our drilling management services segment provides oil and gas drilling management services on either a dayrate basis or a completed-project, fixed-price (or “turnkey”) basis, as well as drilling engineering and drilling project management services.  We provide drilling management services through Applied Drilling TechnologyInc., our wholly owned subsidiary, and through ADT International, a division of one of our United Kingdom (“U.K”). subsidiaries (together, “ADTI”).

Significant Events

TPDI—On February 29, 2012, Quantum Pacific Management Limited (“Quantum”) exercised its right, pursuant to a put option agreement, to exchange its interest in Transocean Pacific Drilling Inc. (“TPDI”) for our shares or cash, and, on March 29, 2012, Quantum elected to exchange its interest in TPDI for our shares, net of Quantum’s share of TPDI’s indebtedness.  Quantum has the right, prior to the closing of this exchange, to change its election to cash, net of Quantum’s share of TPDI’s indebtedness.  See “—Liquidity and Capital Resources—Sources and Uses of Liquidity.”

Dispositions—During the three months ended March 31, 2012, we completed the sale of the Standard Jackup GSFRig 136 andrelated equipment.  In connection with the sale, we received net cash proceeds of $36 million.  See “—Liquidity and Capital Resources—Drilling Fleet.”

Discontinued operations—In the three months ended March 31, 2012, we entered into an agreement to sell the assets of Challenger Minerals Inc., and we completed the sale in April 2012.  See “—Operating Results—Discontinued Operations.”

Distribution of qualifying additional paid-in capital—In May 2011, at our annual general meeting, our shareholders approved the distribution of additional paid-in capital in the form of a U.S. dollar denominated dividend of $3.16 per outstanding share, payable in four equal installments of $0.79 per outstanding share, subject to certain limitations.  On March 21, 2012, we paid to shareholders of record as of February 24, 2012 the final installment in the aggregate amount of $278 million.  See “—Liquidity and Capital Resources—Sources and Uses of Liquidity.”

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Outlook

Drilling market—We expect commodity pricing, underlying the increased exploration and production programs of our customers, to continue to support an increase in contracting opportunities for all asset classes within our drilling fleet for the remainder of this year and into 2013.  Utilization and dayrates continue to improve and have reached levels not experienced since 2009, and we expect this trend to continue into 2013.  As of April 18, 2012, our contract backlog was $20.6 billion compared to $21.4 billion as of February 14, 2012.

Following the Macondo well incident, the U.S. government implemented enhanced regulations related to offshore drilling in the U.S. Gulf of Mexico, which require operators to submit applications for new drilling permits that demonstrate compliance with such enhanced regulations.  The enhanced regulations require independent third-party inspection, certification of well design and well control equipment and emergency response plans in the event of a blowout, among other requirements.  Since their inception in the firstquarter of 2011, the permitting under these enhanced regulations has steadily increased, and as of April 18, 2012, authorities have approved 52 new drilling permits and 47 new exploration plans under these enhanced regulations to customers utilizing our rigs in the U.S. Gulf of Mexico.  The voluntarily application by some of our customers of such third-party inspections and certifications of well control equipment operating outside the U.S. Gulf of Mexico has caused and may continue to cause us to experience additional out of service time and incur additional maintenance costs.  Although the enhanced regulations have affected our revenues, costs and out of service time, we are unable to predict, with certainty, the magnitude with which the enhanced regulations will continue to impact our operations.  The backlog associated with the contracts for our rigs operating in the U.S. Gulf of Mexico was $5.4billion as of April 18, 2012.

Fleet status—As of April 18, 2012, uncommitted fleet rates for the remainder of 2012, 2013, 2014 and 2015 were as follows:

	2012		2013		2014		2015
Uncommitted fleet rate (a)
High-Specification Floaters	17	%	34	%	60	%	78	%
Midwater Floaters	42	%	74	%	84	%	90	%
High-Specification Jackups	24	%	56	%	69	%	75	%
Standard Jackups	35	%	62	%	82	%	96	%

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(a)   The uncommitted fleet rate is the number of uncommitted days as a percentage of the total number of available rig calendar days in the period.

As of April 18, 2012, we had 16 existing contracts with fixed-price or capped options to extend the contract terms that are exercisable, at the customer’s discretion, any time through their expiration dates.  Customers are more likely to exercise fixed-price options when dayrates are higher on new contracts relative to existing contracts, and customers are less likely to exercise fixed-price options when dayrates are lower on new contracts relative to existing contracts.  Given the continued improvement in market conditions, we expect that a number of these options will be exercised by our customers in 2012.  Additionally, well-in-progress or similar provisions of our existing contracts may delay the start of higher or lower dayrates in subsequent contracts, and some of the delays could be significant.

High-Specification Floaters—Our Ultra-Deepwater Floater fleet has three remaining Ultra-Deepwater Floaters with availability in 2012.  During the first quarter 2012, eight Ultra-Deepwater Floaters contracts were entered into worldwide, including the two-year contract that we recently entered into for DeepwaterExpedition.  We expect continued customer demand to support the high utilization of our Ultra-Deepwater Floater fleet for the remainder of 2012 and into 2013 and to result in improved dayrates for this fleet.  Additionally, we expect increased demand for Deepwater Floaters to continue to improve in 2012, recently indicated by one new contract and a contract extension for our Deepwater Floaters.  As of April 18, 2012, we had 36 of our 50High-Specification Floaters contracted through the end of 2012.  We believe continued exploration successes in the major deepwater offshore provinces and the emerging markets will generate additional demand and support our long-term positive outlook for our High-Specification Floater fleet.

Midwater Floaters—Customer demand for our Midwater Floater fleet, which includes 25semisubmersible rigs, has continued to increase with multiple customers interested in available rigs, particularly in the U.K. and West Africa.  We entered into three new contracts for our Midwater Floater fleet in the first quarter 2012.  Based on the robust customer demand, we believe that future demand could offer new opportunities to extend the contracts on our active fleet.  With the improvement in market conditions, we expect that moored Deepwater Floaters previously competing in the midwater market sector will now be contracted for deepwater opportunities.

High-Specification Jackups—Our High-Specification Jackup fleet continues to benefit from the interest of our customers, evidenced by increased tendering and contracting activity that we expect to continue through the remainder of 2012 and into 2013.  We believe that the currently high utilization rates will continue to prevail during this period.  We recently entered into a one-year contract for our last available High-Specification Jackup, which was previously stacked in the U.K. North Sea, and we expect it to commence operations in the third quarter of 2012.  We have also agreed to relocate one High-Specification Jackup to Indonesia for a new three-year program.  As of April 18, 2012, our High-Specification Jackup Transocean Honor was undergoing testing and is expected to commence operations, pending customer acceptance in the second quarter of 2012.  As of April 18, 2012, none of our existing nine High-Specification Jackups were available.

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Standard Jackups—Driven by the high utilization rates of the High-Specification Jackups, customers are showing increased interest in the Standard Jackups, resulting in expected improvements in utilization and opportunities to reactivate some of the idle capacity.  We expect this trend to continue through 2012, resulting in new opportunities for our Standard Jackups.  As of April 18, 2012, we had 14 of our 44 Standard Jackups stacked, excluding five that were held for sale.  In 2012, we expect increasing demand to provide opportunities to extend the contracts on our available fleet and to reactivate a few of our Standard Jackups that require relatively lower reactivation costs.

Operating results— We expect our total revenues for the year ending December 31, 2012 to be higher than our total revenues for the year ended December 31, 2011, primarily due to fewer expected out of service and idle days, increased activity produced by the addition of two Harsh Environment, Ultra-Deepwater semisubmersibles acquired in the Aker Drilling ASA (“Aker Drilling”) acquisition, and the commencement of operations of our newbuild units delivered in 2011 and to be delivered in 2012.  We are unable to predict, with certainty, the full impact that the enhanced regulations, described under “—Drilling market”, will have on our operations for the year ending December 31, 2012 and beyond.

We expect our total operating and maintenance expenses for the year ending December 31, 2012 to be higher than our total operating and maintenance expenses for the year ended December 31, 2011, primarily due to increased operating costs resulting from the additional rigs acquired in the Aker Drilling acquisition and higher personnel costs resulting from increased salaries and increased drilling activity associated with our newbuild units delivered in 2011 and 2012.  Our projected operating and maintenance expenses for the year ending December 31, 2012 are subject to change and could be affected by actual activity levels, rig reactivations, the enhanced regulations described under “—Drilling market”, the Macondo wellincident and related contingencies, exchange rates and cost inflation, as well as other factors.

Although we are unable to estimate the full direct and indirect impact that the Macondo wellincident will have on our business, the incident has had and could continue to have a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  The Deepwater Horizon contract, which terminated at the time of the incident, represented approximately $540 million of contract backlog through the end of the contract term in 2013.  In the two years ended December 31, 2011, we estimate that the Macondo well incident had a direct and indirect effect of greater than $1.0 billion in lost revenues and incremental costs and expenses associated with extended shipyard projects and increased downtime, both as a result of complying with the enhanced regulations and our customers’ requirements.  In December 2011, the increased downtime resulted in the termination of one of our contracts, which represented backlog of approximately $470 million.  In the year ended December 31, 2011, we recognized an estimated loss of $1.0 billion, recorded in operating and maintenance expense, in connection with loss contingencies associated with the Macondo well incident that we believe are probable and for which a reasonable estimate can be made.  Additionally, in the years ended December31, 2011 and 2010, we incurred incremental costs, primarily associated with legal expenses for lawsuits and investigations, net of expected insurance recoveries, in the amount of $71 million and $139million, respectively.  Collectively, the lost contract backlog from the incident and from the termination in December 2011, lost revenues and incremental expenses from extended shipyard projects and increased downtime, loss contingencies associated with the incident and other incremental costs have had an effect of greater than $3.0 billion.  See “—Contingencies—Insurance matters.”

In accordance with our critical accounting policies, we review our property and equipment for impairment when events or changes in circumstances indicate that the carrying amounts of our assets held and used may not be recoverable, and we conduct impairment testing for our goodwill annually and when events and circumstances indicate that the fair value of a reporting unit may have fallen below its carrying amount.  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 upon completion of our measurement, we recognized a total loss on impairment of goodwill in the amount of $5.3 billion (see “—Results of Operations” and “—Critical Accounting Policies and Estimates”).  If we determine that the fair value of our contract drilling services reporting unit has, again, declined below its carrying amount, we may be required to recognize additional losses on impairment of goodwill.  If we are unable to secure new or extended contracts for our active units or the reactivation of any of our stacked units, or if we experience declines in actual or anticipated dayrates or other impairment indicators, especially with respect to our High-Specification Jackup fleet or our Standard Jackup fleet, we may be required to recognize losses in future periods as a result of an impairment of the carrying amount of one or more of our asset groups.  At March 31, 2012, the carrying amount of our property and equipment was $22.3 billion, representing 64 percent of our total assets.  The carrying amount of our goodwill was $3.1 billion, representing nine percent of our total assets after the effect of the impairment noted above.  See “—Critical Accounting Policies and Estimates.”

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Performance and Other Key Indicators

Contract backlog—Our contract backlog for our contract drilling services segment was as follows:

	April 18, 2012		February 14, 2012		October 17, 2011
Contract backlog (a)	(in millions)
High-Specification Floaters
Ultra-Deepwater Floaters	$	11,843	$	12,232	$	14,070
Deepwater Floaters		2,064		2,228		2,574
Harsh Environment Floaters		2,057		2,188		2,545
Total High-Specification Floaters		15,964		16,648		19,189
Midwater Floaters		2,121		2,249		2,140
High-Specification Jackups		1,034		1,051		914
Standard Jackups		1,475		1,434		1,213
Swamp Barge		19		24		30
Total	$	20,613	$	21,406	$	23,486

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(a)   Contract backlog is calculated by multiplying the full contractual operating dayrate by the number of days remaining in the firm contract period, excluding revenues for mobilization, demobilization and contract preparation or other incentive provisions, which are not expected to be significant to our contract drilling revenues.

Our contract backlog includes only firm commitments for our contract drilling services segment, which are represented by signed drilling contracts or, in some cases, by other definitive agreements awaiting contract execution.  Our contract backlog includes amounts associated with our newbuild units that are currently under construction.  The contractual operating dayrate may be higher than the actual dayrate we ultimately receive or an alternative contractual dayrate, such as a waiting-on-weather rate, repair rate, standby rate or force majeure rate, may apply under certain circumstances.  The contractual operating dayrate may also be higher than the actual dayrate we ultimately receive because of a number of factors, including rig downtime or suspension of operations.  In certain contracts, the dayrate may be reduced to zero if, for example, repairs extend beyond a stated period of time.

Fleet average daily revenue—The average daily revenue for our contract drilling services segment was as follows:

	Three months ended
	March 31, 2012		December 31, 2011		March 31, 2011
Average daily revenue (a)
High-Specification Floaters
Ultra-Deepwater Floaters	$	534,900	$	542,900	$	467,700
Deepwater Floaters		348,900		351,600		395,900
Harsh Environment Floaters		478,600		468,300		402,400
Total High-Specification Floaters		486,900		486,600		441,300
Midwater Floaters		275,600		274,300		313,000
High-Specification Jackups		116,900		111,900		106,200
Standard Jackups		91,200		93,400		109,200
Swamp Barge		73,300		73,800		73,400
Total fleet average daily revenue		300,300		295,400		292,600

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(b)   Average daily revenue is defined as contract drilling revenue earned per revenue earning day.  A revenue earning day is defined as a day for which a rig is contracted to earn a dayrate during the firm contract period after commencement of operations.

Our total fleet average daily revenue rises as we stack Midwater Floaters, High-Specification Jackups and Standard Jackups, since these rig types are typically contracted at lower dayrates compared to the High-Specification Floaters.  We include newbuilds in the calculation when the rigs commence operations upon acceptance by the customer.

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Utilization—The utilization rates for our contract drilling services segment were as follows:

	Three months ended
	March 31, 2012			December 31, 2011			March 31, 2011
Utilization (a)
High-Specification Floaters
Ultra-Deepwater Floaters		83	%		79	%		77	%
Deepwater Floaters		47	%		50	%		51	%
Harsh Environment Floaters		84	%		95	%		83	%
Total High-Specification Floaters		71	%		72	%		69	%
Midwater Floaters		56	%		55	%		60	%
High-Specification Jackups		81	%		74	%		40	%
Standard Jackups		47	%		51	%		43	%
Swamp Barge		98	%		99	%		49	%
Total fleet average utilization		61	%		61	%		55	%

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(a)   Utilization is the total actual number of revenue earning days as a percentage of the total number of calendar days in the period.

Our utilization declines as a result of idle and stacked rigs to the extent these rigs are not earning revenues. We include newbuilds in the calculation when the rigs commence operations upon acceptance by the customer.

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Operating Results

Three months ended March 31, 2012 compared to three months ended March 31, 2011

Following is an analysis of our operating results.  See “—Performance and Other Key Indicators—Fleet average daily revenue” for a definition of revenue earning days and average daily revenue.  See “—Performance and Other Key Indicators—Utilization” for a definition of utilization.

	Three months ended March 31,
	2012			2011			Change			% Change
	(In millions, except day amounts and percentages)
Revenue earning days		7,335			6,664			671		10	%
Utilization		61	%		55	%
Average daily revenue	$	300,300		$	292,600		$	7,700		3	%
Contract drilling revenues	$	2,203		$	1,950		$	253		13	%
Contract drilling intangible revenues		11			10			1		10	%
Other revenues		117			184			(67	)	(36)	%
		2,331			2,144			187		9	%
Operating and maintenance expense		(1,410	)		(1,359	)		(51	)	4	%
Depreciation and amortization		(351	)		(354	)		3		(1	)%
General and administrative expense		(69	)		(67	)		(2	)	3	%
Loss on impairment		(227	)		—			(227	)	n/m
Gain on disposal of assets, net		(4	)		8			(12	)	n/m
Operating income		270			372			(102	)	(27)	%
Other income (expense), net
Interest income		15			15			—		n/m
Interest expense, net of amounts capitalized		(180	)		(145	)		(35	)	24	%
Other, net		(7	)		3			(10	)	n/m
Income from continuing operations before income tax expense		98			245			(147	)	(60)	%
Income tax expense		(24	)		(81	)		57		(70)	%
Income from continuing operations		74			164			(90	)	(55)	%
Income (loss) from discontinued operations, net of tax		(15	)		176			(191	)	n/m
Net income		59			340			(281	)	(83)	%
Net income attributable to noncontrolling interest		17			30			(13	)	(43)	%
Net income attributable to controlling interest	$	42		$	310		$	(268	)	(86)	%

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“n/a” means not applicable

“n/m” means not meaningful

Operating revenues—Contract drilling revenues increased for the three months ended March 31, 2012 compared to the threemonths ended March 31, 2011 primarily due to the following: (a) approximately $95million of contract drilling revenues earned from the operations of our two Harsh Environment, Ultra-Deepwater semisubmersibles, acquired in our acquisition of Aker Drilling, (b) approximately $75 million of increased contract drilling revenues associated with our newbuild unit that commenced operations in May 2011, and (c)approximately $70million of increased contract drilling revenues resulting from fewer rigs operating under lower special standby rates in effect during and subsequent to the U.S. Gulf of Mexico drilling moratorium.

Other revenues decreased for the threemonths ended March 31, 2012 compared to the threemonths ended March 31, 2011, primarily due to decreased revenues of approximately $65 million associated with our drilling management services.

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Costs and expenses—Operating and maintenance expenses increased for the threemonths ended March 31, 2012 compared to the threemonths ended March 31, 2011 primarily due to the following: (a)approximately $35 million of increased costs and expenses due to increased activities resulting from the operations of our two Harsh Environment, Ultra-Deepwater semisubmersibles acquired in our acquisition of Aker Drilling, (b) approximately $35 million of increased costs and expenses associated with rigs undergoing shipyard, maintenance, repair and equipment recertification projects, a significant portion of which was associated with the post-Macondo regulatory and operating environment, and (c) approximately $15 million of increased costs and expenses associated with our newbuild units that commenced operations during 2011.  These increases were partially offset by the following: (a) approximately $20 million of decreased costs and expenses associated with the reduced activity of our drilling management services and (b)approximately $20 million of decreased costs and expenses related to increased expectations for insurance recoveries of costs and expenses associated with the Macondowell incident.

During the three months ended March 31, 2012, we recognized a loss of $118 million associated with completing our measurement of the impairment of goodwill associated with our contract drilling services reporting unit.  We had previously recognized an estimated loss of $5.2 billion, in the year ended December 31, 2011, due to a decline in projected cash flows and market valuations for this reporting unit.  Additionally, we recognized a loss of $92 million on impairment of the trade name and customer relationship intangible assets associated with our drilling management services reporting unit due to a declining market outlook for these services in the U.S. Gulf of Mexico as well as the increased regulatory environment for obtaining drilling permits and the diminishing demand for our drilling management services, all of which have led to our decision to exit the region to pursue opportunities in other markets, including Africa and the Far East.  We also recognized a loss of $17million on impairment of GSF Rig 136, which was formerly classified as an asset held for sale and was sold in March 2012.

Other income and expense—Interest expense increased in the three months ended March 31, 2012 compared to the three months ended March 31, 2011, primarily due to $58million of increased interest expense associated with debt issued in November 2011 and debt assumed in our acquisition of Aker Drilling in October 2011.  Partially offsetting these increases was $23million associated with debt repaid or repurchased in the year ended December 31, 2011.

Income tax expense—We operate internationally and provide for income taxes based on the tax laws and rates in the countries in which we operate and earn income.  The annual effective tax rates were 25.5 percent and 19.3 percent at March 31, 2012 and 2011, respectively, based on income from continuing operations before income taxes, after excluding certain items, such as losses on impairment, and gains and losses on certain asset disposals.  The tax effect, if any, of the excluded items as well as settlements of prior year tax liabilities and changes in prior year tax estimates are all treated as discrete period tax expenses or benefits.  For the three months ended March 31, 2012 and 2011, the effect of the various discrete period tax items was a net tax benefit of $29million and a net tax expense of $33million, respectively.  These discrete tax items, coupled with the excluded income and expense items noted above, resulted in effective tax rates of 24.7percent and 33.1 percent on income from continuing operations before income tax expense for the three months ended March 31, 2012 and 2011, respectively.

The relationship between our provision for or benefit from income taxes and our income 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 versus 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.  Consequently, our income tax expense does not change proportionally with our income before income taxes.  Significant decreases in our income before income taxes typically lead to higher effective tax rates, while significant increases in income before income taxes can lead to lower effective tax rates, subject to the other factors impacting income tax expense noted above.  With respect to the annual effective tax rate calculation for the three months ended March 31, 2012, a significant portion of our income tax expense was generated in countries in which income taxes are imposed on gross revenues, with the most significant of these countries being Angola, India, Nigeria, Indonesia, and Ghana.  Conversely, the most significant countries in which we operated during this period that impose income taxes based on income before income tax include the U.K., Switzerland, Norway, Brazil and the U.S.

Our rig operating structures further complicate our tax calculations, especially in instances where we have more than one operating structure for the particular taxing jurisdiction and, thus, more than one method of calculating taxes depending on the operating structure utilized by the rig under the contract.  For example, two rigs operating in the same country could generate significantly different provisions for income taxes if they are owned by two different subsidiaries that are subject to differing tax laws and regulations in the respective country of incorporation.

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Discontinued Operations

Oil and gas properties—During the three months ended March 31, 2011, in connection with our efforts to dispose of non-strategic assets, 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 MineralsInc. and Challenger Minerals (North Sea) Limited.  In October 2011, we completed the sale of Challenger Minerals (North Sea) Limited.  In February 2012, we entered into an agreement to sell the assets of Challenger Minerals Inc., and in April 2012, we completed the sale.

Caspian Sea operations—During the three months ended March 31, 2011, in connection with our efforts to dispose of non-strategic assets, we sold the subsidiary that owns the High-Specification Jackup Trident 20, located in the Caspian Sea.  The disposal of this subsidiary, a component of our contract drilling services segment, reflects our decision to discontinue operations in the Caspian Sea.  As a result of the sale, we received net cash proceeds of $259 million and recognized a gain on the disposal of the discontinued operations of $169 million.  Through June 2011, we continued to operate Trident 20 under a bareboat charter to perform services for the customer and the buyer reimbursed us for the approximate cost of providing these services.  Additionally, we provided certain transition services to the buyer through September 2011.

See Notes to Condensed Consolidated Financial Statements—Note 8—Discontinued Operations.

Liquidity and Capital Resources

Sources and uses of cash

At March 31, 2012, we had $4 billion in cash and cash equivalents.  At any given time, we may require a significant portion of our cash on hand for working capital and other needs related to the operation of our business.  We currently estimate this amount to be approximately $1.0 billion.  As a result, this portion of cash is not generally available to us for other uses.

For the three months ended March 31, 2012, our primary sources of cash were our cash flows from operating activities and proceeds from disposals of assets.  Our primary uses of cash were capital expenditures, primarily associated with our newbuild projects, and the final installment of our distribution of qualifying additional paid-in capital to shareholders and scheduled repayments of debt.

	Three months ended March 31,
	2012			2011			Change
	(In millions)
Cash flows from operating activities
Net income	$	59		$	340		$	(281	)
Amortization of drilling contract intangibles		(11)			(10	)		(1	)
Depreciation and amortization		351			354			(3	)
Loss on impairment		227			—			227
(Gain) loss on disposal of assets, net		4			(8	)		12
(Gain) loss on disposal of discontinued operations, net		14			(173	)		187
Other non-cash items		(29	)		71			(100	)
Changes in operating assets and liabilities, net		(75	)		(184	)		109
	$	540		$	390		$	150

Net cash provided by operating activities increased primarily due to an increase in net income, after adjusting for non-cash items as well as a decrease in cash used in working capital.

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	Three months ended March 31,
	2012			2011			Change
	(In millions)
Cash flows from investing activities
Capital expenditures	$	(260	)	$	(240	)	$	(20	)
Proceeds from disposal of assets, net		41			13			28
Proceeds from disposal of discontinued operations, net		—			259			(259	)
Other, net		12			(6	)		18
	$	(207	)	$	26		$	(233	)

Net cash used in investing activities increased primarily due to proceeds from the disposal of our Caspian Sea operations received in the three months ended March 31, 2011, with no comparable proceeds in the current year period.

	Three months ended March 31,
	2012			2011			Change
	(In millions)
Cash flows from financing activities
Change in short-term borrowings, net	$	—		$	51		$	(51	)
Proceeds from debt		—			5			(5	)
Repayments of debt		(147	)		(47	)		(100	)
Proceeds from restricted cash investments		108			—			108
Deposits to restricted cash investments		(42	)		—			(42	)
Distribution of qualifying additional paid-in capital		(278	)		—			(278	)
Other, net		(9	)		(7	)		(2	)
	$	(368	)	$	2		$	(370	)

Net cash used in financing activities increased primarily due to increased cash used to repay or repurchase debt during the three months ended March 31, 2012 compared to the three months ended March 31, 2011 and the payment of the final installment of our distribution of qualifying additional paid-in capital to shareholders in the three months ended March 31, 2012 with no comparable activity during the three months ended March 31, 2011.

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Drilling fleet

Expansion—From time to time, we review possible acquisitions of businesses and drilling rigs and may make significant future capital commitments for such purposes.  We may also consider investments related to major rig upgrades or new rig construction.  Any such acquisition, upgrade or new rig construction could involve the payment by us of a substantial amount of cash or the issuance of a substantial number of additional shares or other securities.

Capital expenditures, including capitalized interest of $13 million, totaled $260 million during the three months ended March 31, 2012, substantially all of which related to our contract drilling services segment.  The following table presents the historical and projected capital expenditures and other capital additions, including capitalized interest, for our ongoing major construction projects conducted during the three months ended March 31, 2012 (inmillions):

	Total costs through March 31, 2012		Expected costs for the remainder of 2012		Estimated costs thereafter		Total estimated costs at completion
Deepwater Champion (a) (b)	$	778	$	—	$	—	$	778
Transocean Honor (c)		232		3		—		235
Ultra-Deepwater Floater TBN1 (d)		152		49		479		680
Ultra-Deepwater Floater TBN2 (d)		145		36		499		680
Transocean Andaman (e)		138		4		68		210
Transocean Siam Driller (e)		138		11		61		210
Transocean Ao Thai (f)		80		62		73		215
Capitalized interest		121		32		64		217
Mobilization costs		31		8		—		39
Total	$	1,815	$	205	$	1,244	$	3,264

_________________________

(a) The accumulated construction costs of this rig are no longer included in construction work in progress, as the construction project has been completed as of March 31, 2012.

(b) The costs for Deepwater Champion include our initial investment of $109 million, representing the estimated fair value of the rig at the time of our merger with GlobalSantaFe Corporation in November 2007.  Deepwater Champion commenced operations in May 2011.

(c) In November 2010, we purchased Transocean Honor, a PPL Pacific Class 400 design jackup, which is expected to commence operations in the second quarter of 2012.

(d) The costs for Ultra-Deepwater Floater TBN1 and Ultra-Deepwater Floater TBN2 include our initial investment of $136 million each, representing the estimated fair value of the rigs at the time of our acquisition of Aker Drilling, completed in October 2011.  Currently under construction at the Daewoo Shipbuilding & Marine Engineering Co. Ltd. shipyard in Korea, we expect to take delivery of the two Ultra-Deepwater drillships in the first and second quarter of 2014.

(e) In December 2010, we purchased Transocean Siam Driller and Transocean Andaman, two Keppel FELS Super B class design jackups, which are under construction at Keppel FELS’ yard in Singapore and are expected to commence operations in the first quarter of 2013.

(f) In June 2011, we purchased Transocean Ao Thai, a Keppel FELS Super B class design jackup, which is under construction at Keppel FELS’ yard in Singapore and is expected to commence operations in the fourth quarter of 2013.

For the year ending December 31, 2012, we expect capital expenditures to be approximately $1.2billion, approximately $205million of which is associated with our major construction projects.  The ultimate amount of our capital expenditures is partly dependent upon financial market conditions, the actual level of operational and contracting activity, the costs associated with the new regulatory environment and customer requested capital improvements and equipment for which the customer agrees to reimburse us.

As with any major shipyard project that takes place over an extended period of time, the actual costs, the timing of expenditures and the project completion date may vary from estimates based on numerous factors, including actual contract terms, weather, exchange rates, shipyard labor conditions, availability of suppliers to recertify equipment and the market demand for components and resources required for drilling unit construction.

We intend to fund the cash requirements relating to our capital expenditures through available cash balances, cash generated from operations and asset sales.  We also have available credit under the Five-Year Revolving Credit Facility (see “—Sources and Uses of Liquidity”) and may utilize other commercial bank or capital market financings.  Economic conditions could impact the availability of these sources of funding.

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Dispositions—From time to time, we review the possible disposition of drilling units.  During the three months ended March 31, 2012, in connection with our efforts to dispose of non-strategic assets, we sold the Standard Jackup GSFRig 136 andrelated equipment, and we received net proceeds of $36 million.  In April 2012, we completed the sales of the Standard Jackups Roger W. Mowell, Transocean Nordic and Transocean Shelf Explorer.

Assets held for sale—At April 24, 2012, our Standard Jackups GSF AdriaticII and Trident17 were classified as assets held for sale with an aggregate net carrying amount of $57 million.

Sources and uses of liquidity

Overview—We expect to use existing cash balances, internally generated cash flows, borrowings under bank credit agreements and proceeds from the disposal of assets and discontinued operations to fulfill anticipated obligations, such as scheduled debt maturities or other payments, repayment of debt due within one year, including the expected repurchase of any Series C Convertible Senior Notes that the noteholders may require us to repurchase in December 2012, capital expenditures and working capital and other needs in our operations.  Subject in each case to then existing market conditions and to our then expected liquidity needs, among other factors, we may continue to use a portion of our internally generated cash flows and proceeds from asset sales to reduce debt prior to scheduled maturities through debt repurchases, either in the open market or in privately negotiated transactions, through debt redemptions or tender offers, or through repayments of bank borrowings.  At any given time, we may require a significant portion of our cash on hand for working capital and other needs related to the operation of our business.  We currently estimate this amount to be approximately $1.0 billion.  As a result, this portion of cash is not generally available to us for other uses.  From time to time, we may also use borrowings under bank credit agreements to maintain liquidity for short-term cash needs.

In May 2011, at our annual general meeting, our shareholders approved the distribution of additional paid-in capital in the form of a U.S. dollar denominated dividend of $3.16 per outstanding share, payable in fourequal installments of $0.79 per outstanding share, subject to certain limitations.  On March 21, 2012, we paid the final installment to shareholders of record as of February 24, 2012 in the amount of $278 million.  See “—Distribution of qualifying additional paid-in capital.”  The Board of Directors is not proposing a distribution at the 2012 annual general meeting.

On June 28, 2010, we received a letter from the U.S. Department of Justice (“DOJ”) asking us to meet with them to discuss our financial responsibilities in connection with the Macondo well incident and requesting that we provide them certain financial and organizational information.  The letter also requested that we provide the DOJ advance notice of certain corporate actions involving the transfer of cash or other assets outside the ordinary course of business.  We have engaged in discussions with the DOJ and have responded to their document requests, and we expect these discussions to continue.  We can give no assurance that the DOJ investigation and other matters arising out of the Macondo well incident will not adversely affect our liquidity in the future.

Our access to debt and equity markets may be limited due to a variety of events, including, among others, credit rating agency downgrades of our debt, potential liability related to the Macondo well incident, industry conditions, general economic conditions, market conditions and market perceptions of us and our industry.  The economic downturn and related financial market instability, as well as uncertainty related to our potential liabilities from the Macondo well incident, have had, and could continue to have, an impact on our business and our financial condition.  Our ability to access such markets may be severely restricted at a time when we would like, or need, to access such markets, which could have an impact on our flexibility to react to changing economic and business conditions.  The economic downturn could have an impact on the lenders participating in our credit facilities or on our customers, causing them to fail to meet their obligations to us.  Uncertainty related to our potential liabilities from the Macondo well incident has impacted our share price and could impact our ability to access capital markets in the future.

Our internally generated cash flow is directly related to our business and the market sectors in which we operate.  Should the drilling market deteriorate, or should we experience poor results in our operations, cash flow from operations may be reduced.  We have, however, continued to generate positive cash flow from operating activities over recent years and expect that such cash flow will continue to be positive over the next year.

Bank credit agreement—In November2011, we entered into the Five-Year Revolving Credit Facility Agreement dated November 1, 2011, as amended, which established a $2.0 billion five-year revolving credit facility that is scheduled to expire on November 1, 2016 (the “Five-Year Revolving Credit Facility”).  In connection with entering into the Five-Year Revolving Credit Facility, we terminated our former five-year credit facility under the Five-Year Revolving Credit Agreement dated November 27, 2007.  The Five-Year Revolving Credit Facility includes a $1.0billion sublimit for the issuance of letters of credit, and all borrowings under the Five-Year Revolving Credit Facility are guaranteed by Transocean Ltd.  Among other things, the Five-Year Revolving Credit Facility includes limitations on creating liens, incurring subsidiary debt, transactions with affiliates, sale/leaseback transactions, mergers and the sale of substantially all assets.  The Five-Year Revolving Credit Facility also includes a covenant imposing a maximum debt to tangible capitalization ratio of 0.6 to 1.0.  As of March 31, 2012, our debt to tangible capitalization ratio, as defined, was 0.5 to 1.0.  In order to borrow or have letters of credit issued under the Five-Year Revolving Credit Facility, we must, at the time of the borrowing request, not be in default under the bank credit agreement and make certain representations and warranties, including with respect to compliance with laws and solvency, to the lenders, but we are not required to make any representation to the lenders as to the absence of a material adverse effect.  Borrowings under the Five-Year Revolving Credit Facility are subject to acceleration upon the occurrence of an event of default.  We are also subject to various covenants under the indentures pursuant to which our public debt was issued, including restrictions on creating liens, engaging in sale/leaseback transactions and engaging in certain merger, consolidation or reorganization transactions.  Our commitment fee and lending margin under the Five-Year Revolving Credit Facility are subject to change based on our credit rating.  If our credit rating falls below investment grade, the commitment fee will increase from 0.275 percent to 0.325 percent and the lending margin will increase from 1.625 percent to 2.0 percent.  A default under our public debt indentures could trigger a default under the Five-Year Revolving Credit Facility Agreement and, if not waived by the lenders, could cause us to lose access to the Five-Year Revolving Credit Facility.  At April 24, 2012, we had $24 million in letters of credit issued, we had $2.0billion available borrowing capacity and we had no borrowings outstanding under the Five-Year Revolving Credit Facility.

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 Aker Revolving Credit and Term Loan Facility—Aker Drilling has a bank credit facility established by the Revolving Credit and Term Loan Facility Agreement dated February 21, 2011 (the “Aker Revolving Credit and Term Loan Facility”), comprised of a $500 million revolving credit facility and a $400 million term loan, which is secured by Transocean Spitsbergen and Transocean Barents.  The Aker Revolving Credit and Term Loan Facility bears interest at the London Interbank Offered Rate (“LIBOR”) plus a margin of 2.50 percent and mandatory costs, as defined, and requires scheduled quarterly installments on the term loan.  The Aker Revolving Credit and Term Loan Facility expires in December 2015 and may be prepaid in whole or in part without premium or penalty.  The Aker Revolving Credit and Term Loan Facility includes covenants requiring Aker Drilling, our wholly owned subsidiary, to maintain minimum liquidity, a maximum leverage ratio, a minimum interest coverage ratio, a minimum current ratio, and a minimum equity ratio, as defined.  At April 24, 2012, $570 million was outstanding under the Aker Revolving Credit and Term Loan Facility at a weighted-average interest rate of 3.0 percent.  Subsequent to March 31, 2012, we prepaid $115 million of borrowings under the Aker Term Loan Facility.

TPDI Credit Facilities—TPDI has a bank credit agreement for a $1.265billion secured credit facility (the “TPDI Credit Facilities”), comprised of a $1.0 billion senior term loan, a $190million junior term loan and a $75million revolving credit facility, which was established to finance the construction of and is secured by Dhirubhai Deepwater KG1 and Dhirubhai Deepwater KG2.  Oneof our subsidiaries participates in the term loan with an aggregate commitment of $595million.  The senior term loan bears interest at a rate of 1.45 percent and requires quarterly payments with a final payment in March 2015.  The junior term loan and the revolving credit facility bear interest at 2.25 percent and 1.45 percent, respectively, and are due in full in March 2015.  The TPDI Credit Facilities may be prepaid in whole or in part without premium or penalty.  The TPDI Credit Facilities have covenants that require TPDI to maintain a minimum cash balance and available liquidity, a minimum debt service ratio and a maximum leverage ratio.  If Transocean Inc.’s long-term unsecured, unguaranteed and unsubordinated indebtedness is assigned a credit rating less than Baa3 or BBB- by Moody’s Investor Service or Standard & Poor’s Ratings Service, respectively, TPDI would be required to obtain insurance from a source other than our wholly owned captive insurance company within 10 business days.  At April 24, 2012, $910 million was outstanding under the TPDI Credit Facilities, of which $455 million was due to one of our subsidiaries and was eliminated in consolidation.  The weighted-average interest rate on April 24, 2012 was 2.1 percent.

TPDI has an outstanding letter of credit in the amount of $60 million to satisfy its liquidity requirements under the TPDI Credit Facilities.  The letter of credit was issued under an uncommitted credit facility that has been established by one of our subsidiaries.  Additionally, TPDI is required to maintain certain cash balances in restricted accounts for the payment of the scheduled installments on the TPDI Credit Facilities.  At April 24, 2012, TPDI had restricted cash investments of $23 million.

ADDCL Credit Facilities—ADDCL has a senior secured bank credit agreement for a credit facility (the “ADDCL Primary Loan Facility”) comprised of TrancheA and TrancheC for $215million and $399million, respectively, which was established to finance the construction of and is secured by DiscovererLuanda.  Unaffiliated financial institutions provide the commitment for and borrowings under Tranche A and one of our subsidiaries provides the commitment for Tranche C.  The ADDCL Primary Loan Facility contains covenants that require ADDCL to maintain certain cash balances to service the debt and also limits ADDCL’s ability to incur additional indebtedness, to acquire assets, or to make distributions or other payments.  At April 24, 2012, $190 million was outstanding under Tranche A at a weighted-average interest rate of 1.5 percent.  At April 24, 2012, $399 million was outstanding under Tranche C, which was eliminated in consolidation.

Additionally, ADDCL has a secondary bank credit agreement for a $90million credit facility (the “ADDCL Secondary Loan Facility”), for which oneof our subsidiaries provides 65percent of the total commitment.  The facility bears interest at LIBOR plus the applicable margin, ranging from 3.125percent to 5.125percent, depending on certain milestones.  The ADDCL Secondary Loan Facility is payable in full in December 2015, and it may be prepaid in whole or in part without premium or penalty.  Borrowings under the ADDCL Secondary Loan Facility are subject to acceleration by the unaffiliated financial institution upon the occurrence of certain events of default, including the occurrence of a credit rating assignment of less than Baa3 or BBB- by Moody’s Investors Service or Standard & Poor’s Ratings Services, respectively, for Transocean Inc.’s long-term, unsecured, unguaranteed and unsubordinated indebtedness.  In addition, upon such credit rating assignment, ADDCL would be required to obtain insurance from a source other than our wholly owned captive insurance company within 10 business days.  At April 24, 2012, $79 million was outstanding under the ADDCL Secondary Loan Facility, of which $51 million was provided by one of our subsidiaries and was eliminated in consolidation.  The weighted-average interest rate on April 24, 2012 was 3.6 percent.

ADDCL is required to maintain certain cash balances in restricted accounts for the payment of the scheduled installments on the ADDCL Credit Facilities.  At April 24, 2012, ADDCL had restricted cash investments of $34 million.

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Capital lease contract—Petrobras 10000 is held by one of our subsidiaries under a capital lease contract that requires scheduled monthly payments of $6 million through its stated maturity on August 4, 2029, at which time our subsidiary will have the right and obligation to acquire Petrobras 10000 from the lessor for one dollar.  Upon the occurrence of certain termination events, our subsidiary is also required to purchase Petrobras 10000 and pay a termination amount determined by a formula based upon the total cost of the drillship.  The capital lease contract includes limitations on creating liens on Petrobras 10000 and requires our subsidiary to make certain representations in connection with each monthly payment, including with respect to the absence of pending or threatened litigation or other proceedings against our subsidiary or any of its affiliates, which, if determined adversely, could have a material adverse effect on our subsidiary’s ability to perform its obligations under the capital lease contract.  Additionally, Transocean Inc. has guaranteed the obligations under the capital lease contract, and Transocean Inc. is required to maintain an adjusted net worth, as defined, of at least $5.0 billion as of the end of each fiscal quarter.  In the event Transocean Inc. does not satisfy this covenant at the end of any fiscal quarter, it is required to deposit the deficit amount, determined as the difference between $5.0 billion and the adjusted net worth for such fiscal quarter, into an escrow account for the benefit of the lessor.  At April 24, 2012, $671 million was outstanding under the capital lease contract.

Convertible Senior Notes—Holders of our Series C Convertible Senior Notes may elect to convert their notes under certain circumstances.  Upon conversion, we will deliver, in lieu of shares, cash up to the aggregate principal amount of notes to be converted and shares in respect of the remainder, if any, of our conversion obligation in excess of the aggregate principal amount of the notes being converted.  The conversion rate is subject to increase upon the occurrence of certain fundamental changes and adjustment upon certain other corporate events, such as the distribution of cash to our shareholders.  At April 24, 2012, the rate at which the Series C Convertible Senior Notes may be converted was 6.2905 shares per $1,000 note, equivalent to a conversion price of $158.97 per share.  At April 24, 2012, none of the circumstances giving rise to potential conversion were present.

Holders of the Series C Convertible Senior Notes have the right to require us to repurchase their notes on December 14, 2012, December 15, 2017, December 15, 2022, December 15, 2027 and December 15, 2032, and upon the occurrence of a fundamental change, at a repurchase price in cash equal to 100percent of the principal amount of the notes to be repurchased plus accrued and unpaid interest, if any.  At April 24, 2012, the aggregate principal amount of Convertible Senior Notes outstanding was $1.7 billion.

Redeemable noncontrolling interest—On October 18, 2007, one of our subsidiaries acquired a 50 percent interest in TPDI, a joint venture formed to operate two Ultra-Deepwater Floaters, Dhirubhai Deepwater KG1 and Dhirubhai Deepwater KG2 (the “TPDI Rigs”).  Quantum holds the remaining 50 percent interest in TPDI.  We present its interest in TPDI as redeemable noncontrolling interest on our condensed consolidated balance sheets since Quantum has the unilateral right to exchange its interest in TPDI for our shares or cash, at its election, measured at an amount based on an appraisal of the fair value of the drillships that are owned by TPDI, subject to certain adjustments.

Pursuant to a put option and registration rights agreement among Quantum, TPDI and us, entered into a connection with the formation of TPDI, Quantum has the right to exchange its interest in TPDI for our shares or cash, at Quantum’s election (the “Put Option”).  On February 29, 2012, Quantum exercised the Put Option, and on March 29, 2012, Quantum elected to exchange its interest in TPDI for our shares, net of Quantum’s share of TPDI's indebtedness.  However, Quantum has the right, prior to the closing of the exchange, to change its election to cash, net of Quantum’s share of TPDI's indebtedness.  As defined in the Put Option agreement, TPDI's indebtedness excludes the TPDI Notes, which are considered shareholders' equity for purposes of the exchange. At April 24, 2012, TPDI's outstanding indebtedness, as defined, was approximately $940 million.

The number of shares or the amount of cash to be exchanged for Quantum’s interest in TPDI will be determined based on appraisals of the fair value of the TPDI Rigs.  In the event that Quantum maintains its original election to complete the exchange of its interest in TPDI for our shares, the fair value of the TPDI Rigs will be increased by a valuation multiple of 1.08 and the number of shares issued will be determined based on a share price of $49.69.  The Put Option agreement, among other things, restricts Quantum’s sale of our shares until the earlier of the first anniversary of the date of issuance or May 29, 2013.  In the event Quantum elects, instead, to complete the exchange of its interest in TPDI for cash, such exchange will be made based on the fair value of the TPDI Rigs with no valuation multiple.

Distribution of qualifying additional paid-in capital—In May 2011, at our annual general meeting, our shareholders approved the distribution of additional paid-in capital in the form of a U.S. dollar denominated dividend of $3.16 per outstanding share, payable in four equal installments of $0.79 per outstanding share, subject to certain limitations.  On March 21, 2012, we paid to shareholders of record as of February 24, 2012 the final installment in the aggregate amount of $278 million.

Share repurchase program—In May 2009, at our annual general meeting, our shareholders approved and authorized our board of directors, at its discretion, to repurchase an amount of our shares for cancellation with an aggregate purchase price of up to CHF 3.5 billion, which is equivalent to approximately $3.8 billion at an exchange rate as of the close of trading on April 24, 2012 of $1.00 to CHF 0.91.  On February 12, 2010, our board of directors authorized our management to implement the share repurchase program.  We intend to fund any repurchases using available cash balances and cash from operating activities.  In the three months ended March 31, 2012, we did not purchase shares under our share repurchase program.

We may decide, based upon our ongoing capital requirements, the price of our shares, matters relating to the Macondo well incident, regulatory and tax considerations, cash flow generation, the amount and duration of our contract backlog, general market conditions and other factors, that we should retain cash, reduce debt, make capital investments or acquisitions or otherwise use cash for general corporate purposes, and consequently, repurchase fewer or no additional shares under this program.  Decisions regarding the amount, if any, and timing of any share repurchases would be made from time to time based upon these factors.

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Any shares repurchased under this program are expected to be purchased from time to time either, with respect to the U.S. market, from market participants that have acquired those shares on the open market and that can fully recover Swiss withholding tax resulting from the share repurchase or, with respect to the Swiss market, on the secondtrading line for our shares on the SIX Swiss Exchange (“SIX”).  Repurchases could also be made by tender offer, in privately negotiated transactions or by any other share repurchase method.  Any repurchased shares would be held by us for cancellation by the shareholders at a future annual general meeting.  The share repurchase program could be suspended or discontinued by our board of directors or company management, as applicable, at any time.

Under Swiss corporate law, the right of a company and its subsidiaries to repurchase and hold its own shares is limited.  A company may repurchase such company’s shares to the extent it has freely distributable reserves as shown on its Swiss statutory balance sheet in the amount of the purchase price and the aggregate par value of all shares held by the company as treasury shares does not exceed 10 percent of the company’s share capital recorded in the Swiss Commercial Register, whereby for purposes of determining whether the 10 percent threshold has been reached, shares repurchased under a share repurchase program for cancellation purposes authorized by the company’s shareholders are disregarded.  As of April 24, 2012, Transocean Inc., our wholly owned subsidiary, held as treasury shares approximately three percent of our issued shares.  At the annual general meeting in May 2009, the shareholders approved the release of CHF 3.5 billion of additional paid-in capital to other reserves, or freely available reserves as presented on our Swiss statutory balance sheet, to create the freely available reserve necessary for the CHF 3.5 billion share repurchase program for the purpose of the cancellation of shares (the “Currently Approved Program”).  At the May 2011 annual general meeting, our shareholders approved the reallocation of 3.2 billion shares, which is the remaining amount authorized under the share repurchase program, from free reserve to legal reserve, reserve from capital contributions.  This amount will continue to be available for Swiss federal withholding tax-free share repurchases.  We may only repurchase shares to the extent freely distributable reserves are available.  Our board of directors could, to the extent freely distributable reserves are available, authorize the repurchase of additional shares for purposes other than cancellation, such as to retain treasury shares for use in satisfying our obligations in connection with incentive plans or other rights to acquire our shares.  Based on the current amount of shares held as treasury shares, approximately seven percent of our issued shares could be repurchased for purposes of retention as additional treasury shares.  Although our board of directors has not approved such a share repurchase program for the purpose of retaining repurchased shares as treasury shares, if it did so, any such shares repurchased would be in addition to any shares repurchased under the Currently Approved Program.

Contractual obligations—As of March 31, 2012, there have been no material changes from the contractual obligations as previously disclosed in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our annual report on Form 10-K for the year ended December 31, 2011, except as noted below.

For the year ending December 31, 2012, the minimum funding requirement for our U.S. defined benefit pension plans is approximately $99million.  In April 2012, we contributed $99million in satisfaction of this funding requirement.  For the year ending December 31, 2012, the minimum funding requirement for our non-U.S. defined benefit plans is approximately $31million.

As of March 31, 2012, the total liability for unrecognized tax benefit related to uncertain tax positions was $764million.  Due to the high degree of uncertainty regarding the timing of future cash outflows associated with the liabilities recognized in this balance, we are unable to make reasonably reliable estimates of the period of cash settlement with the respective taxing authorities.

Commercial commitments—As of March 31, 2012, there have been no material changes from the commercial commitments as previously disclosed in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our annual report on Form 10-K for the year ended December 31, 2011.

Derivative instruments

Our board of directors has approved policies and procedures for derivative instruments that require the approval of our Chief Financial Officer prior to entering into any derivative instruments.  From time to time, we may enter into a variety of derivative instruments in connection with the management of our exposure to fluctuations in interest rates and currency exchange rates.  We do not enter into derivative transactions for speculative purposes; however, we may enter into certain transactions that do not meet the criteria for hedge accounting.  At April 24, 2012, we have certain derivative instruments that we assumed in our acquisition of Aker Drilling, which are not designated as hedging instruments.  See Notes to Condensed Consolidated Financial Statements—Note 12—Derivatives and Hedging.

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Contingencies

Except as noted in this report, including in Note 14—Contingencies and in Note 7—Income Taxes, there have been no material changes to those actions, claims and other matters pending as discussed in Notes to Consolidated Financial Statements—Note 15—Commitments and Contingencies and “Item 7.  Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contingencies—Macondo well incident” in our annual report on Form 10-K for the year ended December 31, 2011.  As of March 31, 2012, we were also involved in a number of lawsuits which have arisen in the ordinary course of our business and for which we do not expect the liability, if any, resulting from these lawsuits to have a material adverse effect on our current consolidated financial position, results of operations or cash flows.  There can be no assurance that our expectations as to the outcome or effect of any lawsuit or other matters will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

Macondo well incident

On April 22, 2010, the Ultra-Deepwater Floater Deepwater Horizon sank after a blowout of the Macondo well caused a fire and explosion on the rig.  Elevenpersons were declared dead and others were injured as a result of the incident.  At the time of the explosion, Deepwater Horizon was located approximately 41 miles off the coast of Louisiana in Mississippi Canyon Block 252 and was contracted to BP America Production Co.  The rig has been declared a total loss.

Although we are unable to estimate the full direct and indirect effect that the Macondo well incident will have on our business, the incident has had and could continue to have a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  Our business has been negatively impacted by the loss of revenue from Deepwater Horizon.  The backlog associated with the Deepwater Horizon drilling contract was approximately $590 million through the end of the contract term, and we did not carry insurance for business interruption or loss of hire.  In the two years ended December 31, 2011, we estimated that the Macondo well incident had a direct and indirect effect of greater than $1.0 billion in lost revenues and incremental costs and expenses associated with extended shipyard projects and increased downtime, both as a result of complying with the enhanced regulations and our customers’ requirements.  In one case, the increased downtime has resulted in the recent termination of one of our contracts, which represented backlog of approximately $470 million.  In the three months ended December 31, 2011, we recognized an estimated loss of $1.0 billion, recorded in operating and maintenance expense, in connection with loss contingencies associated with the Macondo well incident that we believe are probable and for which a reasonable estimate can be made.  Additionally, in the period since the Macondo well incident, we have incurred incremental costs, primarily associated with legal expenses for lawsuits and investigations, net of expected insurance recoveries, in the amount of $203million.  Collectively, the lost contract backlog from the incident and from the recent termination, lost revenues and incremental expenses from extended shipyard projects and increased downtime, loss contingencies associated with the incident and other incremental costs have had an effect of greater than $3.0 billion.

We are currently unable to estimate the full impact the Macondo well incident will have on us.  We have recognized a liability for estimated loss contingencies that we believe are probable and for which a reasonable estimate can be made.  As of March 31, 2012, we have recognized a liability for such loss contingencies in the amount of $1.2 billion.  This liability takes into account certain events related to the litigation and investigations arising out of the incident.  There are loss contingencies related to the Macondo well incident that we believe are reasonably possible and for which not believe a reasonable estimate can be made.  These contingencies could increase the liabilities we ultimately recognize.  As of March 31, 2012, we have also recognized an asset of $222million associated with the portion of our estimated losses that we believe is recoverable from insurance.  Although we have available policy limits that could result in additional amounts recoverable from insurance, we are not currently able to estimate the amount of such additional recoverable amounts.  Our estimates involve a significant amount of judgment.  As a result of new information or future developments, we may adjust our estimated loss contingencies arising out of the Macondo well incident, and the resulting liabilities could have a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  As of December 31, 2011, the amount of the estimated liability was $1.2 billion, and the estimated recoverable amount was $220 million.

Many of the Macondo well related claims are pending in the U.S. District Court, Eastern District of Louisiana (the “MDL Court”).  The first phase of a three-phase trial was scheduled to commence on March 5, 2012.  However, on March 2, 2012, BP and the Plaintiff’s Steering Committee (the “PSC”) announced that they had agreed to a partial settlement relating primarily to private party environmental and economic loss claims as well as response effort related claims (the “BP/PSC Settlement”).  The BP/PSC Settlement has resulted in the trial being stayed until the court has issued an order outlining a new trial plan.  BP has disclosed that (a) the BP/PSC Settlement is subject to a final written agreement and court approvals, (b) the proposed settlement provides that to the extent provided by law, BP will assign to the PSC certain of its claims, rights and recoveries against us for damages with protections such that the PSC is barred from collecting any amounts from us unless it is finally determined that we cannot recover such amounts from BP, and (c) BP will have the right to approve any settlement between us and the PSC.  We are unable to predict the form of the new trial plan or when trial will commence.  Further, there can be no assurance as to the outcome of the trial, that the trial will proceed according to a new proposed schedule, that we will not enter into a settlement as to some or all of the matters related to the Macondo well incident, including those to be determined at a trial, or the timing or terms of any such settlement.

See Notes to Condensed Consolidated Financial Statements Note14—Contingencies.

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Insurance matters

Our hull and machinery and excess liability insurance program is comprised of commercial market and captive insurance policies.  We periodically evaluate our insurance limits and self-insured retentions.  As of May 1, 2012, the insured value of our drilling rig fleet was approximately $31.7 billion, excluding our rigs under construction.

Hull and machinery—We completed the renewal of our hull and machinery insurance coverage and insurance for worldwide war perils, effective May 1, 2012, with updated rig insured values, primarily based on fair market value appraisals, and with similar terms as previous policies.  Under the hull and machinery program, we generally maintain a $125 million per occurrence deductible, limited to a maximum of $200 million per policy period.  Subject to the same shared deductible, we also have coverage for costs incurred to mitigate damage to a rig up to an amount equal to 25 percent of a rig’s insured value.  Also subject to the same shared deductible, we have additional coverage for wreck removal for up to 25 percent of a rig’s insured value, with any excess generally covered to the extent of our remaining excess liability coverage.  However, we generally retain the risk for all hull and machinery exposures for our Standard Jackups and swamp barge, which are self-insured through our wholly owned captive insurance company.

Excess liability coverage—We completed the renewal of our excess liability insurance coverage with some policies effective May 1, 2012.  We carry $775 million of commercial market excess liability coverage, exclusive of deductibles and self-insured retention, noted below, which generally covers offshore risks such as personal injury, third-party property claims, and third-party non-crew claims, including wreck removal and pollution.  Our excess liability coverage has (1)separate $10 million per occurrence deductibles on collision liability claims and (2)separate $5 million per occurrence deductibles on crew personal injury claims and on other third-party non-crew claims.  Through our wholly owned captive insurance company, we have retained the risk of the primary $50 million excess liability coverage.  In addition, we generally retain the risk for any liability losses in excess of $825 million.

Other insurance—We also carry $100 million of additional insurance that generally covers expenses that would otherwise be assumed by the well owner, such as costs to control the well, redrill expenses and pollution from the well.  This additional insurance provides coverage for such expenses in circumstances in which we have legal or contractual liability arising from our gross negligence or willful misconduct.

We have elected to self-insure operators extra expense coverage for ADTI.  This coverage provides protection against expenses related to well control, pollution and redrill liability associated with blowouts.  ADTI’s customers assume, and indemnify ADTI for, liability associated with blowouts in excess of a contractually agreed amount, generally $50 million.

We generally do not have commercial market insurance coverage for loss of revenues, unless it is contractually required, or for losses for physical damage to our fleet, including liability for wreck removal expenses, and caused by named windstorms in the U.S. Gulf of Mexico.

See Notes to Condensed Consolidated Financial Statements Note14—Contingencies.

Tax matters

We are a Swiss corporation and we operate through our various subsidiaries in a number of countries throughout the world.  Our tax provision is based upon and subject to changes in the tax laws, regulations and treaties in effect in and between the countries in which our operations are conducted and income is earned.  Our effective tax rate for financial reporting purposes fluctuates from year to year considering, among other factors, (a) changes in the blend of income that is taxed based on gross revenues versus income before taxes, (b) rig movements between taxing jurisdictions and (c) our rig operating structures.  A change in the tax laws, treaties or regulations in any of the countries in which we operate, or in which we are incorporated or resident, could result in a higher or lower effective tax rate on our worldwide earnings and, as a result, could have a material effect on our financial results.

U.S. tax investigations—With respect to our 2004 U.S. federal income tax return, the U.S. tax authorities withdrew all of their previously proposed tax adjustments, including all claims related to transfer pricing.  On January 12, 2012, a judge in the U.S. Tax Court entered a decision of no deficiency for tax year 2004 and cancelled the trial previously scheduled to take place in February 2012.  With respect to our 2005 U.S. federal income tax returns, the U.S. tax authorities have withdrawn all of their previously proposed tax adjustments, except a claim regarding transfer pricing from certain charters of drilling rigs between our subsidiaries, reducing the total proposed adjustment to approximately $50 million, exclusive of interest.  We believe an unfavorable outcome on this assessment with respect to 2005 activities would not result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  If the authorities were to continue to pursue this transfer pricing position with respect to subsequent years and were successful in such assertion, our effective tax rate on worldwide earnings with respect to the years following 2005 could increase substantially, and our earnings and cash flows from operations could be materially and adversely affected.  As discussed below, the authorities have raised this transfer pricing issue with respect to our U.S. federal income tax returns for the years 2006 through 2009.  Although we believe the transfer pricing for these charters is materially correct, we have been unable to reach a resolution with the tax authorities.

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In May 2010, we received an assessment from the U.S. tax authorities related to our 2006 and 2007 U.S. federal income tax returns.  In July 2010, we filed a protest letter with the U.S. tax authorities responding to this assessment.  The significant issues raised in the assessment relate to transfer pricing for certain charters of drilling rigs between our subsidiaries and the creation of intangible assets resulting from the performance of engineering services between our subsidiaries.  These twoitems would result in net adjustments of approximately $278 million of additional taxes, exclusive of interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  Furthermore, if the authorities were to continue to pursue these positions with respect to subsequent years and were successful in such assertions, our effective tax rate on worldwide earnings with respect to years following 2007 could increase substantially, and our earnings and cash flows from operations could be materially and adversely affected.  We believe our U.S. federal income tax returns are materially correct as filed, and we intend to continue to vigorously defend against all such claims.

In addition, the May 2010 assessment included adjustments related to a series of restructuring transactions that occurred between 2001 and 2004.  These restructuring transactions affected our basis in our former subsidiary TODCO, which we disposed of in 2004 and 2005.  The authorities are disputing the amount of capital losses resulting from the disposition of TODCO.  We utilized a portion of the capital losses to offset capital gains on our U.S. federal income tax returns for the years 2006 through 2009.  The majority of the capital losses were unutilized and expired on December 31, 2009.  The adjustments would also impact the amount of certain net operating losses and other carryovers into 2006 and later years.  The authorities are also contesting the characterization of certain amounts of income received in 2006 and 2007 as capital gain and thus the availability of the capital loss to offset such gain.  These claims, with respect to our U.S. federal income tax returns for the years 2006 through 2009, could result in net tax adjustments of approximately $295million.  An unfavorable outcome on these potential adjustments could result in a material adverse effect on our consolidated financial position, results of operations or cash flows.  We believe that our U.S. federal income tax returns are materially correct as filed, and we intend to vigorously defend against any potential claims.

The May 2010 assessment also included certain claims with respect to withholding taxes and certain other items resulting in net tax adjustments of approximately $160 million, exclusive of interest.  In addition, the tax authorities assessed penalties associated with the various tax adjustments in the aggregate amount of approximately $88 million, exclusive of interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  We believe that our U.S. federal income tax returns are materially correct as filed, and we intend to vigorously defend against any potential claims.

In February 2012, we received an assessment from the U.S. tax authorities related to our 2008 and 2009 U.S. federal income tax returns.  The significant issues raised in the assessment relate to transfer pricing for certain charters of drilling rigs between our subsidiaries and the creation of intangible assets resulting from the performance of engineering services between our subsidiaries.  These items would result in net adjustments of approximately $473 million of additional taxes, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  Furthermore, if the authorities were to continue to pursue these positions with respect to subsequent years and were successful in such assertions, our effective tax rate on worldwide earnings with respect to years following 2009 could increase substantially, and could have a material adverse effect on our consolidated results of operations and cash flows.  We believe our U.S. federal income tax returns are materially correct as filed, and we intend to continue to vigorously defend against all such claims.

Norway tax investigations—Norwegian civil tax and criminal authorities are investigating various transactions undertaken by our subsidiaries in 2001 and 2002 as well as the actions of certain employees of our former external tax advisors on these transactions.  The authorities issued tax assessments of approximately $274 million, plus interest, related to certain restructuring transactions, approximately $120 million, plus interest, related to the migration of a subsidiary that was previously subject to tax in Norway, approximately $72 million, plus interest, related to a 2001 dividend payment, and approximately $7 million, plus interest, related to certain foreign exchange deductions and dividend withholding tax.  We have filed or expect to file appeals to these tax assessments.  We have provided a parent company guarantee in the amount of approximately $123 million with respect to these tax disputes.  Furthermore, we may be required to provide some form of additional financial security, in an amount up to $846 million, including interest and penalties, for other assessed amounts as these disputes are appealed and addressed by the Norwegian courts.  The authorities have indicated that they plan to seek penalties of 60percent on most but not all matters.  In June 2011, the Norwegian authorities issued criminal indictments against two of our subsidiaries alleging misleading or incomplete disclosures in Norwegian tax returns for the years 1999 through 2002, as well as inaccuracies in Norwegian statutory financial statements for the years ended December 31, 1996 through 2001.  The criminal trial has been scheduled for December 2012.  Two employees of our former external advisors were also issued indictments with respect to the disclosures in our tax returns.  In October 2011, the Norwegian authorities issued criminal indictments against a Norwegian tax attorney related to certain of our restructuring transactions and to the 2001 dividend payment.  The indicted Norwegian tax attorney worked for us in an advisory capacity on these transactions.  We believe the charges brought against us are without merit and do not alter our technical assessment of the underlying claims.  We believe our tax returns are materially correct as filed, and we intend to vigorously contest any assertions by the Norwegian civil and criminal authorities in connection with the various transactions being investigated.  An unfavorable outcome on the Norwegian civil and criminal tax matters could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect the ultimate resolution of these matters to have a material adverse effect on our consolidated statement of financial position or results of operations, although it may have a material adverse effect on our consolidated cash flows.  In January 2012, the Norwegian authorities supplemented the previously issued criminal indictments by issuing a financial claim of approximately $323 million, jointly and severally, against our two subsidiaries, the two external advisors and the external tax attorney.  This compensation claim directly overlaps with an existing civil tax assessment and does not represent an incremental financial exposure to us.  In February 2012, the authorities dropped the previously existing tax assessment related to a certain restructuring transaction.  In April 2012, the Norwegian tax authorities supplemented the previously issued criminal indictments against our two subsidiaries by extending a criminal indictment against a third subsidiary on the same matter, alleging misleading or incomplete disclosures in Norwegian tax returns for the years 2001 and 2002.

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Brazil tax investigations—Certain of our Brazilian income tax returns for the years 2000 through 2004 are currently under examination.  The Brazil tax authorities have issued tax assessments totaling $114 million, plus a 75 percent penalty in the amount of $86 million and interest through December 31, 2011 in the amount of $163 million.  An unfavorable outcome on these assessments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe our returns are materially correct as filed, and we are vigorously contesting these assessments.  On January 25, 2008, we filed a protest letter with the Brazilian tax authorities, and we are currently engaged in the appeals process.

See Notes to Condensed Consolidated Financial Statements—Note 7—Income Taxes.

Regulatory matters

For a discussion of regulatory matters, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our annual report on Form 10-K for the year ended December 31, 2011.

Other matters

In addition, from time to time, we receive inquiries from governmental regulatory agencies regarding our operations around the world, including inquiries with respect to various tax, environmental, regulatory and compliance matters.  To the extent appropriate under the circumstances, we investigate such matters, respond to such inquiries and cooperate with the regulatory agencies.  We have received and responded to an administrative subpoena from the U.S. Treasury Department’s Office of Foreign Assets Control (“OFAC”) concerning our previous operations in Myanmar and a follow-up administrative subpoena from OFAC with questions relating to the previous Myanmar operations subpoena response and the self-reported shipment through Iran matter.  We are cooperating with OFAC and believe that all of our operations fully comply with applicable laws.  Although we are unable to predict the outcome of any of these matters, we do not expect the liability, if any, resulting from these inquiries to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Critical Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operations are based upon our condensed consolidated financial statements.  This discussion should be read in conjunction with disclosures included in the notes to our condensed consolidated financial statements related to estimates, contingencies, and other accounting policies.  Significant accounting policies are discussed in Note 2 to our condensed consolidated financial statements in this quarterly report on Form 10-Q and in Note 2 to our consolidated financial statements for the year ended December 31, 2011.

To prepare financial statements, we are required to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosures of contingent assets and liabilities.  On an ongoing basis, we evaluate our estimates, including those related to our allowance for doubtful accounts, materials and supplies obsolescence, investments, property and equipment, goodwill and other intangible assets, income taxes, defined benefit pension plans and other postretirement employee benefits, contingent liabilities, and share-based compensation.  These estimates require significant judgments, assumptions and estimates.  We base our estimates on historical experience and on various other assumptions that 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 may differ from these estimates.

For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our annual report on Form 10-K for the year ended December 31, 2011.  We have discussed the development, selection and disclosure of these critical accounting policies and estimates with the audit committee of our board of directors.  During the three months ended March 31, 2012, there have been no material changes to the types of judgments, assumptions and estimates, upon which our critical accounting estimates are based.

New Accounting Pronouncements

For a discussion of the new accounting pronouncements, see Notes to Condensed Consolidated Financial Statements—Note 3—New Accounting Pronouncements in this quarterly report on Form 10-Q and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our annual report on Form 10-K for the year ended December 31, 2011.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Overview

We are exposed to interest rate risk and currency exchange rate risk, primarily associated with our restricted cash investments, our long-term and short-term debt, and our derivative instruments.  For our restricted cash investments and debt instruments, the following table presents the principal cash flows and related weighted-average interest rates by contractual maturity date.  For our derivative instruments, including interest rate swaps and cross-currency swaps, the following table presents the notional amounts and weighted-average interest rates by contractual maturity dates.  The information is stated in U.S dollar equivalents.  The instruments are denominated in either U.S. dollars or Norwegian kroner, as indicated.  The following table presents information for the twelve-month periods ending March 31 (inmillions, except interest ratepercentages):

	Scheduled Maturity Date (a)																				Fair Value
	2013			2014			2015			2016			2017			Thereafter			Total		(b)
Restricted cash investments
Fixed rate (NOK)	$	149		$	149		$	149		$	149		$	149		$	112		$	857	$	897
Average interest rate		4.15	%		4.15	%		4.15	%		4.15	%		4.15	%		4.15	%
Debt
Fixed rate (USD)	$	2,489		$	21		$	1,122		$	1,024		$	26		$	6,265		$	10,947	$	(12,052	)
Average interest rate		2.65	%		7.76	%		5.01	%		5.11	%		7.76	%		6.78	%
Fixed rate (NOK)	$	149		$	149		$	149		$	248		$	149		$	112		$	956	$	(1,002	)
Average interest rate		4.15	%		4.15	%		4.15	%		6.87	%		4.15	%		4.15	%
Variable rate (USD)	$	90		$	90		$	65		$	325		$	—		$	—		$	570	$	(570	)
Average interest rate		2.99	%		2.99	%		2.99	%		2.99	%		—	%		—	%
Variable rate (NOK)	$	—		$	—		$	—		$	165		$	—		$	—		$	165	$	(176	)
Average interest rate		—	%		—	%		—	%		9.67	%		—	%		—	%
Debt of consolidated variable interest entities
Variable rate (USD)	$	97		$	98		$	373		$	33		$	35		$	185		$	821	$	(821	)
Average interest rate		1.79	%		1.79	%		2.21	%		1.49	%		1.49	%		2.48	%
Interest rate swaps
Fixed to variable (USD)	$	750		$	—		$	650		$	—		$	—		$	—		$	1,400	$	31
Average pay rate		3.66	%		—	%		3.67	%		—	%		—	%		—	%
Average receive rate		5.17	%		—	%		3.81	%		—	%		—	%		—	%
Interest rate swaps of consolidated variable interest entities
Variable to fixed (USD)	$	70		$	66		$	302		$	—		$	—		$	—		$	438	$	(16	)
Average pay rate		2.34	%		2.32	%		2.35	%		—	%		—	%		—	%
Average receive rate		0.47	%		0.47	%		0.47	%		—	%		—	%		—	%
Cross-currency swaps
Receive NOK / pay USD (c)	$	—		$	—		$	—		$	102		$	—		$	—		$	102	$	(2	)
Average pay rate		—	%		—	%		—	%		8.93	%		—	%		—	%
Average receive rate		—	%		—	%		—	%		11.00	%		—	%		—	%

_________________________

(a)   Expected maturity amounts are based on the face value of debt.

In preparing the scheduled maturities of our debt, we assumed the noteholders will exercise their option to require us to repurchase the 1.50% Series C Convertible Senior Notes in December 2012.

We have engaged in certain hedging activities designed to reduce our exposure to interest rate risk and currency exchange rate risk.  We also hold certain derivative instruments that are not designated as hedges.  See Notes to Consolidated Financial Statements—Note 12—Derivatives and Hedging.

(b)   Amounts represent the fair value of the asset (liability) as of March 31, 2012.

(c)   The cross-currency swaps have fixed rates on both the pay and the receive sides of the derivative instruments.

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Interest Rate Risk

At March 31, 2012 and December 31, 2011, the face value of our variable-rate debt was approximately $2.5 billion, which represented 19 percent of the face value of our total debt, including the effect of our hedging activities.  At March 31, 2012 and December 31, 2011, our variable-rate debt, excluding the effect of our hedging activities, primarily consisted of borrowings under the Aker Revolving Credit and Term Loan Facility, the ADDCL Credit Facilities, the TPDI Credit Facilities, and the FRN Callable Bonds.  Based upon variable-rate debt amounts outstanding as of March 31, 2012 and December 31, 2011, a hypothetical onepercentage point change in annual interest rates would result in a corresponding change in annual interest expense of approximately $25 million.

A large portion of our cash investments is subject to variable interest rates and would earn commensurately higher rates of return if interest rates increase.  Based upon the amounts of our cash investments as of March 31, 2012 and December 31, 2011, a hypothetical onepercentage point change in interest rates would result in a corresponding change in annual interest income of approximately $40 million.

Currency Exchange Rate Risk

We are exposed to currency exchange rate risk associated with our international operations and with some of our long-term and short-term debt.  We may engage in hedging activities to mitigate our exposure to currency exchange risk in certain instances through the use of foreign exchange derivative instruments, including forward exchange contracts, or spot purchases.  A forward exchange contract obligates us to exchange predetermined amounts of specified currencies at a stated exchange rate on a stated date or to make a U.S. dollar payment equal to the value of such exchange.

For our international operations, our primary currency exchange rate risk management strategy involves structuring customer contracts to provide for payment in both U.S. dollars, which is our functional currency, and local currency.  The payment portion denominated in local currency is based on our anticipated local currency needs over the contract term.  Due to various factors, including customer acceptance, local banking laws, other statutory requirements, local currency convertibility and the impact of inflation on local costs, actual local currency needs may vary from those anticipated in the customer contracts, resulting in partial exposure to currency exchange rate risk.  The effect of fluctuations in currency exchange rates caused by our international operations generally have not had a material impact on our overall operating results.  In situations where local currency receipts do not equal local currency requirements, we may use foreign exchange derivative instruments, including forward exchange contracts, or spot purchases, to mitigate currency exchange rate risk.

At March 31, 2012, we had NOK 6.4 billion aggregate principal amount of debt obligations, all of which were assumed in connection with our acquisition of Aker Drilling.  Certain of these kroner-denominated debt instruments are secured by a corresponding amount of restricted cash investments that are also denominated in Norwegian kroner.  Additionally, we have assumed certain cross-currency swaps, which have been designated as a cash flow hedge of certain bonds denominated in Norwegian kroner.  After consideration of these currency exchange rate risk management strategies, we have approximately NOK 940 million aggregate principal amount of debt obligations that are not hedged.  Based on kroner-denominated debt instruments outstanding as of March 31, 2012, a hypothetical one percentage point change in the currency exchange rates would result in a corresponding change in annual interest expense of less than $1 million.

For a discussion of our foreign exchange risk, see “Item 7A. Quantitative and Qualitative Disclosures About Market Risk” in our annual report on Form 10-K for the year ended December 31, 2011.  With the exception of the foregoing, there have been no material changes to these previously reported matters during the threemonths ended March 31, 2012.

Item 4. Controls and Procedures

Disclosure controls and procedures—We carried out an evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report.  Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures, as defined in the Exchange Act Rules 13a-15 and 15d-15, were effective, as of March 31, 2012, to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is (1) accumulated and communicated to our management, including our Chief Executive Officer and our Chief Financial Officer, to allow timely decisions regarding required disclosure and (2) recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms.

Internal controls over financial reporting—There were no changes to our internal controls during the quarter ended March 31, 2012 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

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PART II.                 OTHER INFORMATION

Item 1. Legal Proceedings

We have certain actions, claims and other matters pending as discussed and reported in Notes to Condensed Consolidated Financial Statements Note 14—Contingencies and “Part I. Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contingencies—Macondo well incident” in this quarterly report on Form 10-Q and Notes to Consolidated Financial Statements Note 15—Commitments and Contingencies and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contingencies—Macondo well incident” and “Item 3. Legal Proceedings” in our annual report on Form 10-K for the year ended December 31, 2011.  We are also involved in various tax matters as described in Notes to Condensed Consolidated Financial Statements Note 7—Income Taxes, in “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contingencies—Tax matters” in this quarterly report on Form 10-Q and in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contingencies—Tax matters” in our annual report Form 10-K for the year ended December 31, 2011.  As of March 31, 2012, we were also involved in a number of lawsuits which have arisen in the ordinary course of our business and for which we do not expect the liability, if any, resulting from these lawsuits to have a material adverse effect on our current consolidated financial position, results of operations or cash flows.  We cannot predict with certainty the outcome or effect of any of the matters referred to above or of any such other pending or threatened litigation or legal proceedings.  There can be no assurance that our beliefs or expectations as to the outcome or effect of any lawsuit or other matters will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

Item 1A. Risk Factors

There have been no material changes from the risk factors as previously disclosed in “Item 1A Risk Factors” in our annual report on Form 10-K for the year ended December 31, 2011.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities

Period	(a) Total Number of Shares Purchased (1)	(b) Average Price Paid Per Share		(c) Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (2)		(d) Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs (2) (in millions)
January 2012	1,103	$	40.66		—	$	3,660
February 2012	214,520	$	50.34		—	$	3,660
March 2012	4,310	$	56.00		—	$	3,660
Total	219,933	$	50.40		—	$	3,660

_________________________

(1) Total number of shares purchased in the first quarter of 2012 consists of 219,933 shares withheld by us through a broker arrangement and limited to statutory tax in satisfaction of withholding taxes due upon the vesting of restricted shares granted to our employees under our Long-Term Incentive Plan.

(2) In May 2009, at the annual general meeting of Transocean Ltd., our shareholders approved and authorized our board of directors, at its discretion, to repurchase an amount of our shares for cancellation with an aggregate purchase price of up to CHF 3.5 billion, which is equivalent to approximately $3.9 billion at an exchange rate as of March 31, 2012 of USD 1.00 to CHF 0.90.  On February 12, 2010, our board of directors authorized our management to implement the share repurchase program.  We may decide, based upon our ongoing capital requirements, the price of our shares, matters relating to the Macondo wellincident, regulatory and tax considerations, cash flow generation, the relationship between our contract backlog and our debt, general market conditions and other factors, that we should retain cash, reduce debt, make capital investments or acquisitions or otherwise use cash for general corporate purposes, and consequently, repurchase fewer or no shares under this program.  Decisions regarding the amount, if any, and timing of any share repurchases would be made from time to time based upon these factors.  Through March 31, 2012, we have repurchased a total of 2,863,267 of our shares under this share repurchase program at a total cost of $240 million ($83.74 per share).  See—Sources and Uses of Liquidity—Overview.”

Item 4. Mine Safety Disclosures

Not applicable.

- 57 -

Item 6. Exhibits

(a)           Exhibits

The following exhibits are filed in connection with this Report:

Number Description

† 3.1 Articles of Association of Transocean Ltd.

3.2 Organizational Regulations dated February 17, 2012 (incorporated by reference to Exhibit 3.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 000-53533) filed on February 23, 2012)

10.1 First Amendment to Credit Agreement dated effective as of March 23, 2012 among Transocean Inc., the lenders parties thereto, JPMorgan Chase Bank, N.A., as administrative agent, Crédit Agricole Corporate and Investment Bank and Citibank, N.A., as co-syndication agents, and The Bank of Tokyo-Mitsubishi UFJ, Ltd. and Wells Fargo Bank, National Association, as co-documentation agents (incorporated by reference to Exhibit 10.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 000-53533) filed on March 30, 2012)

10.2 Executive Severance Benefit Policy (incorporated by reference to Exhibit 10.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 000-53533) filed on February 23, 2012)

10.3 Agreement with Gregory L. Cauthen (incorporated by reference to Exhibit 10.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 000-53533) filed on January 10, 2012)

10.4 Agreement with Ricardo H. Rosa (incorporated by reference to Exhibit 10.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 000-53533) filed on January 23, 2012)

† 10.5 Agreement with Robert Shaw.

† 31.1 CEO Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

† 31.2 CFO Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

† 32.1 CEO Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

† 32.2 CFO Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

† 101.ins XBRL Instance Document

† 101.sch XBRL Taxonomy Extension Schema

† 101.cal XBRL Taxonomy Extension Calculation Linkbase

† 101.def XBRL Taxonomy Extension Definition Linkbase

† 101.lab XBRL Taxonomy Extension Label Linkbase

† 101.pre XBRL Taxonomy Extension Presentation Linkbase

_________________________

† Filed herewith.

- 58 -

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on May 2, 2012.

TRANSOCEAN LTD.

By:   /s/ Gregory L. Cauthen                                                                                                                            

Gregory L. Cauthen

Executive Vice President and Chief Financial Officer

(Principle Financial Officer)

By:   /s/ David A. Tonnel                                                                                                                                  

David A. Tonnel

Senior Vice President and Controller

(Principal Accounting Officer)

- 59 -

EX-3.1

 Statuten

 von Transocean Ltd.

 vom4. Dezember 2011

 Articles of Association of

 Transocean Ltd.

 as ofDecember 4, 2011

- 2 -

		Abschnitt 1: Firma, Sitz, Zweck und Dauer der Gesellschaft			Section 1: Name, Place of Incorporation, Purpose and Duration of the Company
		Artikel 1			Article 1
Firma, Sitz		Unter der Firma Transocean Ltd. (die Gesellschaft) besteht eine Aktiengesellschaft mit Sitz in Steinhausen, Kanton Zug, Schweiz.	Name, Place of Incorporation		Under the name Transocean Ltd. (the Company) there exists a corporation with its place of incorporation in Steinhausen, Canton of Zug, Switzerland.
Zweck		Artikel 2	Purpose		Article 2
	1	Zweck der Gesellschaft ist der Erwerb, das Halten, die Verwaltung, die Verwertung und die Veräusserung von Beteiligungen an Unternehmen im In- und Ausland, ob direkt oder indirekt, insbesondere an Unternehmen, die im Bereich der Erbringung von Dienstleistungen für Offshore Öl-und Gasbohrungen, einschliesslich Management Dienstleistungen, Bohringenieurs- und Bohr-Projekt Management-Dienstleistungen für Öl-und Gasbohrungen, sowie von Öl- und Gas-Exploration und -Produktions­aktivitäten tätig sind, sowie die Finanzierung dieser Aktivitäten. Die Gesellschaft kann Grundstücke und gewerbliche Schutzrechte im In- und Ausland erwerben, halten, verwalten, belasten und verkaufen.		1	The purpose of the Company is to acquire, hold, manage, exploit and sell, whether directly or indirectly, participations in businesses in Switzerland and abroad, in particular in businesses that are involved in offshore contract drilling services for oil and gas wells, oil and gas drilling management services, drilling engineering services and drilling project management services and oil and gas exploration and production activities, and to provide financing for this purpose. The Company may acquire, hold, manage, mortgage and sell real estate and intellectual property rights in Switzerland and abroad.

- 3 -

	2	Die Gesellschaft kann alle Tätigkeiten ausüben und Massnahmen ergreifen, die geeignet erscheinen, den Zweck der Gesellschaft zu fördern, oder die mit diesem zusammenhängen.		2	The Company may engage in all types of transactions and may take all measures that appear appropriate to promote the purpose of the Company or that are related thereto.
		Artikel 3			Article 3
Dauer		Die Dauer der Gesellschaft ist unbeschränkt.	Duration		The duration of the Company is unlimited.
		Abschnitt 2: Aktienkapital			Section 2: Share Capital
		Artikel 4			Article 4
Aktienkapital		Das Aktienkapital der Gesellschaft beträgt CHF 5'477'029'470, eingeteilt in 365'135'298 voll liberierte Namenaktien. Jede Namenaktie hat einen Nennwert von CHF 15 (jede Namenaktie nachfolgend bezeichnet als Aktie bzw. die Aktien).	Share Capital		The share capital of the Company is CHF 5,477,029,470 and is divided into 365,135,298 fully paid registered shares. Each registered share has a par value of CHF 15 (each such registered share hereinafter a Share and collectively the Shares).
		Artikel 5			Article 5
Genehmigtes Kapital	1	Der Verwaltungsrat ist ermächtigt, das Aktienkapital jederzeit bis zum 13. Mai 2013 im Maximalbetrag von CHF 557'205'855 durch Ausgabe von höchstens 37'147'057 vollständig zu liberierenden Aktien mit einem Nennwert von je CHF 15 zu erhöhen. Eine Erhöhung (i) auf dem Weg einer Festübernahme durch eine Bank, ein Bankenkonsortium oder Dritte und eines anschliessenden Angebots an die bisherigen Aktionäre sowie (ii) in Teilbeträgen ist zulässig.	Authorized Share Capital	1	The Board of Directors is authorized to increase the share capital, at any time until May 13, 2013, by a maximum amount of CHF 557,205,855 by issuing a maximum of 37,147,057 fully paid up Shares with a par value of CHF 15 each. An increase of the share capital (i) by means of an offering underwritten by a financial institution, a syndicate of financial institutions or another third party or third parties, followed by an offer to the then-existing shareholders of the Company, and (ii) in partial amounts shall be permissible.

- 4 -

2	Der Verwaltungsrat legt den Zeitpunkt der Ausgabe, den Ausgabebetrag, die Art, wie die neuen Aktien zu liberieren sind, den Beginn der Dividendenberechtigung, die Bedingungen für die Ausübung der Bezugsrechte sowie die Zuteilung der Bezugsrechte, welche nicht ausgeübt wurden, fest. Nicht-ausgeübte Bezugsrechte kann der Verwaltungsrat verfallen lassen, oder er kann diese bzw. Aktien, für welche Bezugsrechte eingeräumt, aber nicht ausgeübt werden, zu Marktkonditionen platzieren oder anderweitig im Interesse der Gesellschaft verwenden.	2	The Board of Directors shall determine the time of the issuance, the issue price, the manner in which the new Shares have to be paid up, the date from which the Shares carry the right to dividends, the conditions for the exercise of the preemptive rights and the allotment of preemptive rights that have not been exercised.  The Board of Directors may allow the preemptive rights that have not been exercised to expire, or it may place such rights or Shares, the preemptive rights of which have not been exercised, at market conditions or use them otherwise in the interest of the Company.
3	Der Verwaltungsrat ist ermächtigt, die Bezugsrechte der Aktionäre zu entziehen oder zu beschränken und einzelnen Aktionären oder Dritten zuzuweisen: (a)wenn der Ausgabebetrag der neuen Aktien unter Berücksichtigung des Marktpreises festgesetzt wird; oder (b)für die Übernahme von Unternehmen, Unternehmensteilen oder Beteiligungen oder für die Finanzierung oder Refinanzierung solcher Transaktionen oder die Finanzierung von neuen Investitionsvorhaben der Gesellschaft; oder (c)zum Zwecke der Erweiterung des Aktionärskreises in bestimmten Finanz- oder Investoren-Märkten, zur Beteiligung von strategischen Partnern, oder im Zusammenhang mit der Kotierung von neuen Aktien an inländischen oder ausländischen Börsen; oder (d)für die Einräumung einer Mehrzuteilungsoption (Greenshoe) von bis zu 20% der zu platzierenden oder zu verkaufenden Aktien an die betreffenden Erstkäufer oder Festübernehmer im Rahmen einer Aktienplatzierung oder eines Aktienverkaufs; oder (e)für die Beteiligung von Mitgliedern des Verwaltungsrates, Mitglieder der Geschäftsleitung, Mitarbeitern, Beauftragten, Beratern oder anderen Personen, die für die Gesellschaft oder eine ihrer Tochtergesellschaften Leistungen erbringen; oder (f)wenn ein Aktionär oder eine Gruppe von in gemeinsamer Absprache handelnden Aktionären mehr als 15% des im Handelsregister eingetragenen  Aktienkapitals der Gesellschaft auf sich vereinigt hat, ohne den übrigen Aktionären ein vom Verwaltungsrat empfohlenes Übernahmeangebot zu unterbreiten; oder zur Abwehr eines unterbreiteten, angedrohten oder potentiellen Übernahmeangebotes, welches der Verwaltungsrat, nach Konsultation mit einem von ihm beigezogenen unabhängigen Finanzberater, den Aktionären nicht zur Annahme empfohlen hat, weil der Verwaltungsrat das Übernahmeangebot in finanzieller Hinsicht gegenüber den Aktionären nicht als fair beurteilt hat.	3	The Board of Directors is authorized to withdraw or limit the preemptive rights of the shareholders and to allot them to individual shareholders or third parties: (a)if the issue price of the new Shares is determined by reference to the market price; or (b)for the acquisition of an enterprise, part(s) of an enterprise or participations, or for the financing or refinancing of any of such transactions, or for the financing of new investment plans of the Company; or (c)for purposes of broadening the shareholder constituency of the Company in certain financial or investor markets, for purposes of the participation of strategic partners, or in connection with the listing of new Shares on domestic or foreign stock exchanges; or (d)for purposes of granting an over-allotment option (Greenshoe) of up to 20% of the total number of Shares in a placement or sale of Shares to the respective initial purchaser(s) or underwriter(s); or (e)for the participation of members of the Board of Directors, members of the executive management, employees, contractors, consultants or other persons performing services for the benefit of the Company or any of its subsidiaries; or (f)following a shareholder or a group of shareholders acting in concert having accumulated shareholdings in excess of 15% of the share capital registered in the commercial register without having submitted to the other shareholders a takeover offer recommended by the Board of Directors,orfor the defense of an actual, threatened or potential takeover bid, in relation to which the Board of Directors, upon consultation with an independent financial adviser retained by it, has not recommended to the shareholders acceptance on the basis that the Board of Directors has not found the takeover bid to be financially fair to the shareholders.
4	Die neuen Aktien unterliegen den Eintragungs­beschränkungen in das Aktienbuch von Artikel 7 und 9 dieser Statuten.	4	The new Shares shall be subject to the limitations for registration in the share register pursuant to Articles 7 and 9 of these Articles of Association.

- 5 -

		Artikel 6			Article 6
Bedingtes Aktienkapital	1	Das Aktienkapital kann sich durch Ausgabe von höchstens 167’617’649 voll zu liberierenden Aktien im Nennwert von je CHF 15 um höchstens CHF 2’514’264’735 erhöhen durch: (a)die Ausübung von Wandel-, Tausch-, Options-, Bezugs- oder ähnlichen Rechten auf den Bezug von Aktien (nachfolgend die Rechte), welche Dritten oder Aktionären in Verbindung mit auf nationalen oder internationalen Kapitalmärkten neu oder bereits begebenen Anleihensobligationen, Optionen, Warrants oder anderen Finanzmarktinstrumenten oder neuen oder bereits bestehenden vertraglichen Verpflichtungen der Gesellschaft, einer ihrer Gruppengesellschaften oder einer deren Rechtsvorgänger eingeräumt werden (nachfolgend zusammen die mit Rechten verbundenen Obligationen); und/oder (b)die Ausgabe von Aktien oder mit Rechten verbundenen Obligationen an Mitglieder des Verwaltungsrates, Mitglieder der Geschäftsleitung, Arbeitnehmer, Beauftragte, Berater oder anderen Personen, welche Dienstleistungen für die Gesellschaft oder ihre Tochtergesellschaften erbringen.	Conditional Share Capital	1	The share capital may be increased in an amount not to exceed CHF 2,514,264,735 through the issuance of up to 167,617,649 fully paid-up Shares with a par value of CHF 15 per Share through: (a)the exercise of conversion, exchange, option, warrant or similar rights for the subscription of Shares (hereinafter the Rights) granted to third parties or shareholders in connection with bonds, options, warrants or other securities newly or already issued in national or international capital markets or new or already existing contractual obligations by or of the Company, one of its group companies, or any of their respective predecessors (hereinafter collectively, the Rights-Bearing Obligations); and/or (b)the issuance of Shares or Rights-Bearing Obligations granted to members of the Board of Directors, members of the executive management, employees, contractors, consultants or other persons providing services to the Company or its subsidiaries.

- 6 -

2	Bei der Ausgabe von mit Rechten verbundenen Obligationen durch die Gesellschaft, eine ihrer Gruppengesellschaften oder eine deren Rechtsvorgänger ist das Bezugsrecht der Aktionäre ausgeschlossen. Zum Bezug der neuen Aktien, die bei Ausübung von mit Rechten verbundenen Obligationen ausgegeben werden, sind die jeweiligen Inhaber der mit Rechten verbundenen Obligationen berechtigt. Die Bedingungen der mit Rechten verbundenen Obligationen sind durch den Verwaltungsrat festzulegen.	2	The preemptive rights of the shareholders shall be excluded in connection with the issuance of any Rights-Bearing Obligations by the Company, one of its group companies, or any of their respective predecessors.  The then-current owners of such Rights-Bearing Obligations shall be entitled to subscribe for the new Shares issued upon conversion, exchange or exercise of any Rights-Bearing Obligations.  The conditions of the Rights-Bearing Obligations shall be determined by the Board of Directors.
3	Der Verwaltungsrat ist ermächtigt, die Vorwegzeichnungsrechte der Aktionäre im Zusammenhang mit der Ausgabe von mit Rechten verbundenen Obligationen durch die Gesellschaft oder eine ihrer Gruppengesellschaften zu beschränken oder aufzuheben, falls (1) die Ausgabe zum Zwecke der Finanzierung oder Refinanzierung der Übernahme von Unternehmen, Unternehmensteilen, Beteiligungen oder Investitionen, oder (2) die Ausgabe auf nationalen oder internationalen Finanzmärkten oder im Rahmen einer Privatplatzierung erfolgt. Wird das Vorwegzeichnungsrecht weder direkt noch indirekt durch den Verwaltungsrat gewährt, gilt Folgendes: (a)Die mit Rechten verbundenen Obligationen sind zu den jeweils marktüblichen Bedingungen auszugeben oder einzugehen; und (b)der Umwandlungs-, Tausch- oder sonstige Ausübungspreis der mit Rechten verbundenen Obligationen ist unter Berücksichtigung des Marktpreises im Zeitpunkt der Ausgabe der mit Rechten verbundenen Obligationen festzusetzen; und (c)die mit Rechten verbundenen Obligationen sind höchstens während 30 Jahren ab dem jeweiligen Zeitpunkt der betreffenden Ausgabe oder des betreffenden Abschlusses wandel-, tausch- oder ausübbar.	3	The Board of Directors shall be authorized to withdraw or limit the advance subscription rights of the shareholders in connection with the issuance by the Company or one of its group companies of Rights-Bearing Obligations if (1) the issuance is for purposes of financing or refinancing the acquisition of an enterprise, parts of an enterprise, participations or investments or (2) the issuance occurs in national or international capital markets or through a private placement. If the advance subscription rights are neither granted directly nor indirectly by the Board of Directors, the following shall apply: (a)The Rights-Bearing Obligations shall be issued or entered into at market conditions; and (b)the conversion, exchange or exercise price of the Rights-Bearing Obligations shall be set with reference to the market conditions prevailing at the date on which the Rights-Bearing Obligations are issued; and (c)the Rights-Bearing Obligations may be converted, exchanged or exercised during a maximum period of 30 years from the date of the relevant issuance or entry.
4	Bei der Ausgabe von Aktien oder mit Rechten verbundenen Obligationen gemäss Artikel 6 Absatz 1(b) dieser Statuten sind das Bezugsrecht wie auch das Vorwegzeichnungsrecht der Aktionäre der Gesellschaft ausgeschlossen. Die Ausgabe von Aktien oder mit Rechten verbundenen Obligationenan die in Artikel 6 Absatz 1(b) dieser Statuten genannten Personen erfolgt gemäss einem oder mehreren Beteiligungsplänen der Gesellschaft. Die Ausgabe von Aktien an die Artikel 6 Absatz 1(b) dieser Statuten genannten Personen kann zu einem Preis erfolgen, der unter dem Kurs der Börse liegt, an der die Aktien gehandelt werden, muss aber mindestens zum Nennwert erfolgen.	4	The preemptive rights and advance subscription rights of the shareholders shall be excluded in connection with the issuance of any Shares or Rights-Bearing Obligations pursuant to Article 6 para 1(b) of these Articles of Association.  Shares or Rights-Bearing Obligations shall be issued to any of the persons referred to in Article 6 para 1(b) of these Articles of Association in accordance with one or more benefit or incentive plans of the Company.  Shares may be issued to any of the persons referred to in Article 6 para 1(b) of these Articles of Association at a price lower than the current market price quoted on the stock exchange on which the Shares are traded, but at least at par value.
5	Die neuen Aktien, welche über die Ausübung von mit Rechten verbundenen Obligationen erworben werden, unterliegen den Eintragungs­beschränkungen in das Aktienbuch gemäss Artikel 7 und 9 dieser Statuten.	5	The new Shares acquired through the exercise of Rights-Bearing Obligations shall be subject to the limitations for registration in the share register pursuant to Articles 7 and 9 of these Articles of Association.

- 7 -

		Artikel 7			Article 7
Aktienbuch, Rechtsausübung, Eintragungsbe-schränkungen, Nominees	1	Die Gesellschaft oder von ihr beauftragte Dritte führen ein Aktienbuch. Darin werden die Eigentümer und Nutzniesser der Aktien sowie Nominees mit Namen und Vornamen, Wohnort, Adresse und Staatsangehörigkeit (bei juristischen Personen mit Firma und Sitz) eingetragen. Die Gesellschaft oder der von ihr mit der Aktienbuchführung beauftragte Dritte ist berechtigt, bei Eintragung im Aktienbuch von der antragstellenden Person einen angemessenen Nachweis seiner Berechtigung an den Aktien zu verlangen. Ändert eine im Aktienbuch eingetragene Person ihre Adresse, so hat sie dies dem Aktienbuchführer mitzuteilen. Solange dies nicht geschehen ist, gelten alle brieflichen Mitteilungen der Gesellschaft an die im Aktienbuch eingetragenen Personen als rechtsgültig an die bisher im Aktienbuch eingetragene Adresse erfolgt.	Share Register, Exercise of Rights, Restrictions on Registration, Nominees	1	The Company shall maintain, itself or through a third party, a share register that lists the surname, first name, address and citizenship (in the case of legal entities, the company name and company seat) of the holders and usufructuaries of the Shares as well as the nominees.  The Company or the third party maintaining the share register on behalf of the Company shall be entitled to request at the time of the entry into the share register from the Person requesting such entry appropriate evidence of that Person's title to the Shares.A person recorded in the share register shall notify the share registrar of any change in address.  Until such notification shall have occurred, all written communication from the Company to persons of record shall be deemed to have validly been made if sent to the address recorded in the share register.
	2	Ein Erwerber von Aktien wird auf Gesuch als Aktionär mit Stimmrecht im Aktienbuch eingetragen, vorausgesetzt, dass ein solcher Erwerber ausdrücklich erklärt, die Aktien im eigenen Namen und auf eigene Rechnung erworben zu haben. Der Verwaltungsrat kann Nominees, welche Aktien im eigenen Namen aber auf fremde Rechnung halten, als Aktionäre mit Stimmrecht im Aktienbuch der Gesellschaft eintragen. Die an den Aktien wirtschaftlich Berechtigten, welche die Aktien über einen Nominee halten, üben Aktionärsrechte mittelbar über den Nominee aus.		2	An acquirer of Shares shall be recorded upon request in the share register as a shareholder with voting rights; provided, however, that any such acquirer expressly declares to have acquired the Shares in its own name and for its own account, save that the Board of Directors may record nominees who hold Shares in their own name, but for the account of third parties, as shareholders of record with voting rights in the share register of the Company.  Beneficial owners of Shares who hold Shares through a nominee exercise the shareholders' rights through the intermediation of such nominee.

- 8 -

	3	Der Verwaltungsrat kann nach Anhörung des eingetragenen Aktionärs dessen Eintragung im Aktienbuch als Aktionär mit Stimmrecht mit Rückwirkung auf das Datum der Eintragung streichen, wenn diese durch falsche oder irreführende Angaben zustande gekommen ist. Der Betroffene muss über die Streichung sofort informiert werden.		3	After hearing the registered shareholder concerned, the Board of Directors may cancel the registration of such shareholder as a shareholder with voting rights in the share register with retroactive effect as of the date of registration, if such registration was made based on false or misleading information.  The relevant shareholder shall be informed promptly of the cancellation.
		Artikel 8			Article 8
Form der Aktien	1	Die Gesellschaft gibt Aktien in Form von Einzelurkunden, Globalurkunden oder Wertrechten aus. Der Gesellschaft steht es im Rahmen der gesetzlichen Vorgaben frei, ihre in einer dieser Formen ausgegebenen Aktien jederzeit und ohne Zustimmung der Aktionäre in eine andere Form umzuwandeln. Die Gesellschaft trägt die Kosten, die bei einer solchen Umwandlung anfallen.	Form of Shares	1	The Company may issue Shares in the form of individual certificates, global certificates or uncertificated securities. Subject to applicable law, the Company may convert the Shares from one form into another form at any time and without the approval of the shareholders. The Company shall bear all cost associated with any such conversion.
	2	Ein Aktionär hat keinen Anspruch auf Umwandlung von in bestimmter Form ausgegebenen Aktien in eine andere Form. Jeder Aktionär kann jedoch jederzeit die Ausstellung einer Bescheinigung über die von ihm gemäss Aktienbuch gehaltenen Namenaktien verlangen.		2	A shareholder has no right to request a conversion of the Shares from one form into another form. Each shareholder may, however, at any time request a written attestation of the number of Shares held by it as reflected in the share register.

- 9 -

	3	Werden Bucheffekten im Auftrag der Gesellschaftoder des Aktionärs von einer Verwahrungsstelle, einem Registrar, Transfer Agenten, einer Trust Gesellschaft, Bank oder einer ähnlichen Gesellschaft verwaltet (die Verwahrungsstelle), so setzt Wirksamkeit gegenüber der Gesellschaft voraus, dass diese Bucheffekten und die damit verbundenen Rechte unter Mitwirkung der Verwahrungsstelle übertragen oder daran Sicherheiten bestellt werden.		3	If intermediated securities are administered on behalf of the Company or a shareholder by an intermediary, registrar, transfer agent, trust company, bank or similar entity (the Intermediary), any transfer or grant of a security interest in such intermediated securities and the appurtenant rights associated therewith, in order for such transfer or grant of a security interest to be valid against the Company, requires the cooperation of the Intermediary.
	4	Für den Fall, dass die Gesellschaft beschliesst, Aktienzertifikate zu drucken und auszugeben, müssen die Aktienzertifikate die Unterschrift von zwei zeichnungsberechtigten Personen tragen. Mindestens eine dieser Personen muss ein Mitglied des Verwaltungsrates sein. Faksimile-Unterschriften sind erlaubt.		4	If the Company decides to print and deliver share certificates, the share certificates shall bear the signatures of two duly authorized signatories of the Company, at least one of which shall be a member of the Board of Directors.  These signatures may be facsimile signatures.
		Artikel 9			Article 9
Rechtsausübung	1	Die Gesellschaft anerkennt nur einen Vertreter pro Aktie.	Exercise of Rights	1	The Company shall only accept one representative per Share.
	2	Stimmrechte und die damit verbundenen Rechte können der Gesellschaft gegenüber von einem Aktionär, Nutzniesser der Aktien oder Nominee jeweils nur im Umfang ausgeübt werden, wie dieser mit Stimmrecht im Aktienbuch eingetragen ist.		2	Voting rights and appurtenant rights associated therewith may be exercised in relation to the Company by a shareholder, usufructuary of Shares or nominee only to the extent that such person is recorded in the share register with the right to exercise his voting rights.
		Abschnitt 3: Gesellschaftsorgane A. Generalversammlung			Section 3: Corporate Bodies A. General Meeting of Shareholders

- 10 -

	Artikel 10		Article 10
Zuständigkeit	Die Generalversammlung ist das oberste Organ der Gesellschaft.	Authority	The General Meeting of Shareholders is the supreme corporate body of the Company.

- 11 -

		Artikel 11			Article 11
Ordentliche Generalver-sammlung		Die ordentliche Generalversammlung findet alljährlich innerhalb von sechs Monaten nach Schluss des Geschäftsjahres statt. Spätestens zwanzig Kalendertage vor der Versammlung sind der Geschäftsbericht und der Revisionsbericht den Aktionären am Gesellschaftssitz zur Einsicht aufzulegen. Jeder Aktionär kann verlangen, dass ihm unverzüglich eine Ausfertigung des Geschäftsberichts und des Revisionsberichts ohne Kostenfolge zugesandt wird. Die im Aktienbuch eingetragenen Aktionäre werden über die Verfügbarkeit des Geschäftsberichts und des Revisionsberichts durch schriftliche Mitteilung unterrichtet.	Annual General Meeting		The Annual General Meeting shall be held each year within six months after the close of the fiscal year of the Company. The Annual Report and the Auditor's Report shall be made available for inspection by the shareholders at the registered office of the Company no later than twenty calendar days prior to the Annual General Meeting.  Each shareholder is entitled to request prompt delivery of a copy of the Annual Report and the Auditor's Report free of charge.  Shareholders of record will be notified of the availability of the Annual Report and the Auditor's Report in writing.
		Artikel 12			Article 12
Ausser-ordentliche Generalver­sammlung	1	Ausserordentliche Generalversammlungen finden in den vom Gesetz vorgesehenen Fällen statt, insbesondere, wenn der Verwaltungsrat es für notwendig oder angezeigt erachtet oder die Revisionsstelle dies verlangt.	Extraordinary General Meetings	1	Extraordinary General Meetings shall be held in the circumstances provided by law, in particular when deemed necessary or appropriate by the Board of Directors or if so requested by the Auditor.

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2 Ausserdem muss der Verwaltungsrat eine ausserordentliche Generalversammlung einberufen, wenn es eine Generalversammlung so beschliesst oder wenn ein oder mehrere Aktionäre, welche zusammen mindestens den zehnten Teil des im Handelsregister eingetragenen Aktienkapitals vertreten, dies verlangen, unter der Voraussetzung, dass folgende Angaben gemacht werden: (a)(1) die Verhandlungsgegenstände, schriftlich unterzeichnet von dem/den antragstellenden Aktionär(en), (2) die Anträge sowie (3) der Nachweis der erforderlichen Anzahl der im Aktienbuch eingetragenen Aktien; und (b) die weiteren Informationen, die von der Gesellschaft nach den Regeln der U.S. Securities and Exchange Commission (SEC) in einem sog. Proxy Statementaufgenommen und veröffentlicht werden müssen. 2 An Extraordinary General Meeting shall further be convened by the Board of Directors upon resolution of a General Meeting of Shareholders or if so requested by one or more shareholders who, in the aggregate, represent at least one-tenth of the share capital recorded in the Commercial Register and who submit (a)(1) a request signed by such shareholder(s) that specifies the item(s) to be included on the agenda, (2) the respective proposals of the shareholders and (3) evidence of the required shareholdings recorded in the share register and (b) such other information as would be required to be included in a proxy statement pursuant to the rules of the U.S. Securities and Exchange Commission (SEC).

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		Artikel 13			Article 13
Einberufung	1	Die Generalversammlung wird durch den Verwaltungsrat, nötigenfalls die Revisionsstelle, spätestens 20 Kalendertage vor dem Tag der Generalversammlung einberufen. Die Einberufung erfolgt durch einmalige Bekanntmachung im Publikationsorgan der Gesellschaft gemäss Artikel 32 dieser Statuten. Für die Einhaltung der Einberufungsfrist ist der Tag der Veröffentlichung der Einberufung im Publikationsorgan massgeblich, wobei der Tag der Veröffentlichung nicht mitzuzählen ist. Die im Aktienbuch eingetragenen Aktionäre können zudem auf dem ordentlichen Postweg über die Generalversammlung informiert werden.	Notice of Shareholders' Meetings	1	Notice of a General Meeting of Shareholders shall be given by the Board of Directors or, if necessary, by the Auditor, no later than twenty calendar days prior to the date of the General Meeting of Shareholders.  Notice of the General Meeting of Shareholders shall be given by way of a one-time announcement in the official means of publication of the Company pursuant to Article 32 of these Articles of Association.  The notice period shall be deemed to have been observed if notice of the General Meeting of Shareholders is published in such official means of publication, it being understood that the date of publication is not to be included for purposes of computing the notice period.  Shareholders of record may in addition be informed of the General Meeting of Shareholders by ordinary mail.
	2	Die Einberufung muss die Verhandlungsgegenstände sowie die Anträge des Verwaltungsrates und des oder der Aktionäre, welche die Durchführung einer Generalversammlung oder die Traktandierung eines Verhandlungsgegenstandes verlangt haben, und bei Wahlgeschäften die Namen des oder der zur Wahl vorgeschlagenen Kandidaten enthalten.		2	The notice of a General Meeting of Shareholders shall specify the items on the agenda and the proposals of the Board of Directors and the shareholder(s) who requested that a General Meeting of Shareholders be held or an item be included on the agenda, and, in the event of elections, the name(s) of the candidate(s) that has or have been put on the ballot for election.

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		Artikel 14			Article 14
Traktandierung	1	Jeder Aktionär kann die Traktandierung eines Verhandlungsgegenstandes verlangen. Das Traktandierungsbegehren muss mindestens 30 Kalendertage vor dem Jahrestag des sog. Proxy Statementsder Gesellschaft, das im Zusammenhang mit der Generalversammlung im jeweiligen Vorjahr veröffentlicht und gemäss den anwendbaren SEC Regeln bei der SEC eingereicht wurde, schriftlich unter Angabe des Verhandlungsgegenstandes und der Anträge sowie unter Nachweis der erforderlichen Anzahl im Aktienbuch eingetragenen Aktien eingereicht werden. Falls das Datum der anstehenden Generalversammlung mehr als 30 Kalendertage vor oder nach dem Jahrestag der vorangegangenen Generalversammlung angesetzt worden ist, ist das Traktandierungsbegehren stattdessen spätestens 10 Kalendertage nach dem Tag einzureichen, an dem die Gesellschaft das Datum der Generalversammlung öffentlich bekannt gemacht hat.	Agenda	1	Any shareholder may request that an item be included on the agenda of a General Meeting of Shareholders.  An inclusion of an item on the agenda must be requested in writing at least 30 calendar days prior to the anniversary date of the Company's proxy statement in connection with the previous year's General Meeting of Shareholders, as filed with the SEC pursuant to the applicable rules of the SEC, and shall specify in writing the relevant agenda items and proposals, together with evidence of the required shareholdings recorded in the share register; provided, however, that if the date of the General Meeting of Shareholders is more than 30 calendar days before or after such anniversary date, such request must instead be made at least by the 10th calendar day following the date on which the Company has made public disclosure of the date of the General Meeting of Shareholders.
	2	Zu nicht gehörig angekündigten Verhandlungsgegenständen können keine Beschlüsse gefasst werden. Hiervon ausgenommen sind jedoch der Beschluss über den in einer Generalversammlung gestellten Antrag auf (i) Einberufung einer ausserordentlichen Generalversammlung sowie (ii) Durchführung einer Sonderprüfung gemäss Artikel 697a des Schweizerischen Obligationenrechts (OR).		2	No resolution may be passed at a General Meeting of Shareholders concerning an agenda item in relation to which due notice was not given.  Proposals made during a General Meeting of Shareholders to (i) convene an Extraordinary General Meeting or (ii) initiate a special investigation in accordance with article 697a of the Swiss Code of Obligations (CO) are not subject to the due notice requirement set forth herein.

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	3	Zur Stellung von Anträgen im Rahmen der Verhandlungsgegenstände und zu Verhandlungen ohne Beschlussfassung bedarf es keiner vorgängigen Ankündigung.		3	No prior notice is required to bring motions related to items already on the agenda or for the discussion of matters on which no resolution is to be taken.
		Artikel 15			Article 15
Vorsitz der Generalver-sammlung, Protokoll, Stimmenzähler	1	An der Generalversammlung führt der Präsident des Verwaltungsrates oder, bei dessen Verhinderung, der Vizepräsident oder eine andere vom Verwaltungsrat bezeichnete Person den Vorsitz.	Acting Chair, Minutes, Vote Counters	1	At the General Meeting of Shareholders the Chairman of the Board of Directors or, in his absence, the Vice-Chairman or any other person designated by the Board of Directors, shall take the chair.
	2	Der Vorsitzende der Generalversammlung bestimmt den Protokollführer und die Stimmenzähler, die alle nicht Aktionäre sein müssen. Das Protokoll ist vom Vorsitzenden und vom Protokollführer zu unterzeichnen.		2	The acting chair of the General Meeting of Shareholders shall appoint the secretary and the vote counters, none of whom need be shareholders.  The minutes of the General Meeting of Shareholders shall be signed by the acting chair and the secretary.
	3	Der Vorsitzende der Generalversammlung hat sämtliche Leitungsbefugnisse, die für die ordnungsgemässe Durchführung der Generalversammlung nötig und angemessen sind.		3	The acting chair of the General Meeting of Shareholders shall have all powers and authority necessary and appropriate to ensure the orderly conduct of the General Meeting of Shareholders.
		Artikel 16			Article 16
Recht auf Teilnahme, Vertretung der Aktionäre		Jeder im Aktienbuch eingetragene Aktionär ist berechtigt, an der Generalversammlung und deren Beschlüssen teilzunehmen. Ein Aktionär kann sich an der Generalversammlung vertreten lassen, wobei der Vertreter nicht Aktionär sein muss. Der Verwaltungsrat regelt die Einzelheiten über die Vertretung und Teilnahme an der Generalversammlung in Verfahrensvorschriften.	Right to Participation and Representation		Each shareholder recorded in the share register is entitled to participate at the General Meeting of Shareholders and in any vote taken.  The shareholders may be represented by proxies who need not be shareholders.  The Board of Directors shall issue the particulars of the right to representation and participation at the General Meeting of Shareholders in procedural rules.

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		Artikel 17			Article 17
Stimmrecht		Jede Aktie berechtigt zu einer Stimme. Das Stimmrecht untersteht den Bedingungen von Artikel 7 und 9 dieser Statuten.	Voting Rights		Each Share shall convey the right to one vote.  The right to vote is subject to the conditions of Articles 7and 9 of these Articles of Association.
		Artikel 18			Article 18
Beschlüsse und Wahlen	1	Die Generalversammlung fasst Beschlüsse und entscheidet Wahlen, soweit das Gesetz oder diese Statuten es nicht anders bestimmen, mit der relativen Mehrheit der abgegebenen Aktienstimmen (wobei Enthaltungen, sog. Broker Nonvotes, leere oder ungültige Stimmen für die Bestimmung des Mehrs nicht berücksichtigt werden).	Resolutions and Elections	1	Unless otherwise required by law or these Articles of Association, the General Meeting of Shareholders shall take resolutions and decide elections upon a relative majority of the votes cast at the General Meeting of Shareholders (whereby abstentions, broker nonvotes, blank or invalid ballots shall be disregarded for purposes of establishing the majority).
	2	Die Generalversammlung entscheidet über die Wahl von Mitgliedern des Verwaltungsrates nach dem proportionalen Wahlverfahren, wonach diejenige Person, welche die grösste Zahl der abgegebenen Aktienstimmen für einen Verwaltungsratssitz erhält, als für den betreffenden Verwaltungsratssitz gewählt gilt. Aktienstimmen gegen einen Kandidaten, Stimmenthaltungen, sog. Broker Nonvotes, ungültige oder leere Stimmen haben für die Zwecke dieses Artikels 18 Abs. 2 keine Auswirkungen auf die Wahl von Mitgliedern des Verwaltungsrates.		2	The General Meeting of Shareholders shall decide elections of members of the Board of Directors upon a plurality of the votes cast at the General Meeting of Shareholders. A plurality means that the individual who receives the largest number of votes for a board seat is elected to that board seat.  Votes against any candidate, abstentions, broker nonvotes, blank or invalid ballots shall have no impact on the election of members of the Board of Directors under this Article 18 para. 2.

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3	Für die Abwahl von amtierenden Mitgliedern des Verwaltungsrates gilt das Mehrheitserfordernis gemäss Artikel 20 Abs. 2(e) sowie das Präsenzquorum von Artikel 21 Abs. 1(a).	3	For the removal of a serving member of the Board of Directors, the voting requirement set forth in Article 20 para. 2(e) and the presence quorum set forth in Article 21 para. 1(a) shall apply.
4	Die Abstimmungen und Wahlen erfolgen offen, es sei denn, dass die Generalversammlung schriftliche Abstimmung respektive Wahl beschliesst oder der Vorsitzende dies anordnet. Der Vorsitzende kann Abstimmungen und Wahlen auch mittels elektronischem Verfahren durchführen lassen.  Elektronische Abstimmungen und Wahlen sind schriftlichen Abstimmen und Wahlen gleichgestellt.	4	Resolutions and elections shall be decided by a show of hands, unless a written ballot is resolved by the General Meeting of Shareholders or is ordered by the acting chair of the General Meeting of Shareholders.  The acting chair may also hold resolutions and elections by use of an electronic voting system.  Electronic resolutions and elections shall be considered equal to resolutions and elections taken by way of a written ballot.
5	Der Vorsitzende kann eine offene Wahl oder Abstimmung immer durch eine schriftliche oder elektronische wiederholen lassen, sofern nach seiner Meinung Zweifel am Abstimmungsergebnis bestehen. In diesem Fall gilt die vorausgegangene offene Wahl oder Abstimmung als nicht geschehen.	5	The chair of the General Meeting of Shareholders may at any time order that an election or resolution decided by a show of hands be repeated by way of a written or electronic ballot if he considers the vote to be in doubt.  The resolution or election previously held by a show of hands shall then be deemed to have not taken place.

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		Artikel 19			Article 19
Befugnisse der Generalver-sammlung		Der Generalversammlung sind folgende Geschäfte vorbehalten: (a)Die Festsetzung und Änderung dieser Statuten; (b)die Wahl der Mitglieder des Verwaltungsrates und der Revisionsstelle; (c)die Genehmigung des Jahresberichtes und der Konzernrechnung; (d)die Genehmigung der Jahresrechnung sowie die Beschlussfassung über die Verwendung des Bilanzgewinnes, insbesondere die Festsetzung der Dividende; (e)die Entlastung der Mitglieder des Verwaltungsrates; (f)die Genehmigung eines Zusammenschlusses mit einem Nahestehenden Aktionär (gemäss der Definition dieser Begriffe in Artikel 35 dieser Statuten); und (g)die Beschlussfassung über die Gegenstände, die der Generalversammlung durch das Gesetz oder die Statuten vorbehalten sind oder ihr, vorbehältlich Artikel 716a OR, durch den Verwaltungsrat vorgelegt werden.	Powers of the General Meeting of Shareholders		The following powers shall be vested exclusively in the General Meeting of Shareholders: (a)The adoption and amendment of these Articles of Association; (b)the election of the members of the Board of Directors and the Auditor; (c)the approval of the Annual Report and the Consolidated Financial Statements; (d)the approval of the Annual Statutory Financial Statements of the Company and the resolution on the allocation of profit shown on the Annual Statutory Balance Sheet, in particular the determination of any dividend; (e)the discharge from liability of the members of the Board of Directors; (f)the approval of a Business Combination with an Interested Shareholder (as each such term is defined in Article 35 of these Articles of Association); and (g)the adoption of resolutions on matters that are reserved to the General Meeting of Shareholders by law, these Articles of Association or, subject to article 716a CO, that are submitted to the General Meeting of Shareholders by the Board of Directors.
		Artikel 20			Article 20
Besonderes Quorum	1	Ein Beschluss der Generalversammlung, der mindestens zwei Drittel der an der Generalversammlung vertretenen Stimmen und die absolute Mehrheit der an der Generalversammlung vertretenen Aktiennennwerte auf sich vereinigt, ist erforderlich für: (a)Die Ergänzung oder Änderung des Gesellschaftszweckes gemäss Artikel 2 dieser Statuten; (b)die Einführung und Abschaffung von Stimmrechtsaktien; (c)die Beschränkung der Übertragbarkeit der Aktien und die Aufhebung einer solche Beschränkung; (d)die Beschränkung der Ausübung des Stimmrechts und die Aufhebung einer solchen Beschränkung; (e)eine genehmigte oder bedingte Kapitalerhöhung; (f)die Kapitalerhöhung (i) aus Eigenkapital, (ii) gegen Sacheinlage oder zwecks Sachübernahme oder (iii) die Gewährung von besonderen Vorteilen; (g)die Einschränkung oder Aufhebung des Bezugsrechts; (h)die Verlegung des Sitzes der Gesellschaft; (i)die Umwandlung von Namen- in Inhaberaktien und umgekehrt; und (j)die Auflösung der Gesellschaft.	Special Vote	1	The approval of at least two-thirds of the votes and the absolute majority of the par value of Shares, each as represented at a General Meeting of Shareholders, shall be required for resolutions with respect to: (a)The amendment or modification of the purpose of the Company as described in Article 2 of these Articles of Association; (b)the creation and the cancelation of shares with privileged voting rights; (c)the restriction on the transferability of Shares and the cancelation of such restriction; (d)the restriction on the exercise of the right to vote and the cancelation of such restriction; (e)an authorized or conditional increase in share capital; (f)an increase in share capital (i) through the conversion of capital surplus, (ii) through contribution in kind or for purposes of an acquisition of assets, or (iii) the granting of special privileges; (g)the limitation on or withdrawal of preemptive rights; (h)the relocation of the registered office of the Company; (i)the conversion of registered shares into bearer shares and vice versa; and (j)the dissolution of the Company.

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2	Ein Beschluss der Generalversammlung, der mindestens zwei Drittel aller stimmberechtigten Aktien auf sich vereinigt, ist erforderlich für:	2	The approval of at least two-thirds of the Shares entitled to vote shall be required for:
	(a)Jede Änderung von Artikel 14 Abs. 1 dieser Statuten;		(a)Any change to Article 14 para. 1 of these Articles of Association;
	(b)jede Änderung von Artikel 18 dieser Statuten;		(b)any change to Article 18 of these Articles of Association;
	(c)jede Änderung dieses Artikels 20 Abs. 2;		(c)any change to this Article 20 para. 2;
	(d)jede Änderung von Artikel 21, 22, 23 oder 24 dieser Statuten; und		(d)any change to Article 21, 22, 23 or 24 of these Articles of Association; and
	(e)die Abwahl eines amtierenden Mitglieds des Verwaltungsrates.		(e)a resolution with respect to the removal of a serving member of the Board of Directors.

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3	Zusätzlich zu etwaigen gesetzlich bestehenden Zustimmungserfordernissen ist ein Beschluss der Generalversammlung mit einer Mehrheit, die mindestens die Summe von: (i) zwei Drittel aller stimmberechtigten Aktien; zuzüglich (ii) einer Zahl von stimmberechtigten Aktien, die einem Drittel der von Nahestehenden Aktionären (wie in Artikel 35 dieser Statuten definiert) gehaltenen Aktienstimmen entspricht, auf sich vereinigt, erforderlich für (1) jeden Zusammenschluss der Gesellschaft mit einem Nahestehenden Aktionär innerhalb eines Zeitraumes von drei Jahren, seitdem diese Person zu einem Nahestehenden Aktionär wurde, (2) jede Änderung von Artikel 19(f) dieser Statuten oder (3) jede Änderung von Artikel 20 Abs. 3 dieser Statuten (einschliesslich der dazugehörigen Definitionen in Artikel 35 dieser Statuten). Das im vorangehenden Satz aufgestellte Zustimmungserfordernis ist jedoch nicht anwendbar falls:	3	In addition to any approval that may be required under applicable law, the approval of a majority at least equal to the sum of: (i) two-thirds of the Shares entitled to vote; plus (ii) a number of Shares entitled to vote that is equal to one-third of the number of Shares held by Interested Shareholders (as defined in Article 35 of these Articles of Association), shall be required for the Company to (1) engage in any Business Combination with an Interested Shareholder for a period of three years following the time that such Person became an Interested Shareholder, (2) amend Article 19(f) of these Articles of Association or (3) amend this Article 20 para. 3 of these Articles of Association (including any of the definitions pertaining thereto as set forth in Article 35 of these Articles of Association); provided, however, that the approval requirement in the preceding sentence shall not apply if:
	(a)der Verwaltungsrat, bevor diese Person zu einem Nahestehenden Aktionär wurde, entweder den Zusammenschluss oder eine andere Transaktion genehmigte, als Folge derer diese Person zu einem Nahestehenden Aktionär wurde;		(a)Prior to such time that such Person became an Interested Shareholder, the Board of Directors approved either the Business Combination or the transaction which resulted in such Person becoming an Interested Shareholder;
	(b)nach Vollzug der Transaktion, als Folge derer diese Person zu einem Nahestehenden Aktionär wurde, der Nahestehende Aktionär mindestens 85% der unmittelbar vor Beginn der betreffenden Transaktion allgemein stimmberechtigten Aktien hält, wobei zur Bestimmung der Anzahl der allgemein stimmberechtigten Aktien (nicht jedoch zur Bestimmung der durch den Nahestehenden Aktionär gehaltenen Aktien) folgende Aktien nicht zu berücksichtigen sind: Aktien, (x) welche von Personen gehalten werden, die sowohl Verwaltungsrats- wie Geschäftsleitungsmitglieder sind, und (y) welche für Mitarbeiteraktienpläne reserviert sind, soweit die diesen Plänen unterworfenen Mitarbeiter nicht das Recht haben, unter Wahrung der Vertraulichkeit darüber zu entscheiden, ob Aktien, die dem betreffenden Mitarbeiteraktienplan unterstehen, in einem Übernahme- oder Austauschangebot angedient werden sollen oder nicht;		(b)upon consummation of the transaction which resulted in such Person becoming an Interested Shareholder, the Interested Shareholder Owned at least 85% of the Shares generally entitled to vote at the time the transaction commenced, excluding for purposes of determining such number of Shares then in issue (but not for purposes of determining the Shares Owned by the Interested Shareholder), those Shares Owned (x) by Persons who are both members of the Board of Directors and officers of the Company and (y) by employee share plans in which employee participants do not have the right to determine confidentially whether Shares held subject to the plan will be tendered in a tender or exchange offer;
	(c)eine Person unbeabsichtigterweise zu einem Nahestehenden Aktionär wird und (x) das Eigentum an einer genügenden Anzahl Aktien sobald als möglich veräussert, so dass sie nicht mehr länger als Nahestehender Aktionär qualifiziert und (y) zu keinem Zeitpunkt während der drei dem Zusammenschluss zwischen der Gesellschaft und dieser Person unmittelbar vorangehenden Jahren als Nahestehender Aktionär gegolten hätte, ausgenommen aufgrund des unbeabsichtigten Erwerbs der Eigentümerschaft.		(c)a Person becomes an Interested Shareholder inadvertently and (x) as soon as practicable divests itself of Ownership of sufficient Shares so that such Person ceases to be an Interested Shareholder and (y) would not, at any time within the three-year period immediately prior to a Business Combination between the Company and such Person, have been an Interested Shareholder but for the inadvertent acquisition of Ownership;
	(d)der Zusammenschluss vor Vollzug oder Verzicht auf und nach öffentlicher Bekanntgabe oder der nach diesem Abschnitt erforderlichen Mitteilung (was auch immer früher erfolgt) eine(r) beabsichtigten Transaktion vorgeschlagen wird, welche (i) eine der Transaktionen im Sinne des zweiten Satzes dieses Artikels 20 Abs. 3(d) darstellt; (ii) mit oder von einer Person abgeschlossen wird, die entweder während den letzten drei Jahren kein Nahestehender Aktionär war oder zu einem Nahestehenden Aktionär mit der Genehmigung des Verwaltungsrates wurde; und (iii) von einer Mehrheit der dannzumal amtierenden Mitglieder des Verwaltungsrates (aber mindestens einem) genehmigt oder nicht abgelehnt wird, die entweder bereits Verwaltungsratsmitglieder waren, bevor in den drei vorangehenden Jahren irgendeine Person zu einem Nahestehenden Aktionär wurde, oder die auf Empfehlung einer Mehrheit solcher Verwaltungsratsmitglieder als deren Nachfolger zur Wahl vorgeschlagen wurden. Die im vorangehenden Satz erwähnten beabsichtigen Transaktionen sind auf folgende beschränkt: (x) eine Fusion oder andere Form des Zusammenschlusses der Gesellschaft (mit Ausnahme einer Fusion, welche keine Genehmigung durch die Generalversammlung der Gesellschaft voraussetzt); (y) ein Verkauf, eine Vermietung oder Verpachtung, hypothekarische Belastung oder andere Verpfändung, Übertragung oder andere Verfügung (ob in einer oder mehreren Transaktionen), einschliesslich im Rahmen eines Tauschs, von Vermögenswerten der Gesellschaft oder einer direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird (jedoch nicht an eine direkt oder indirekt zu 100% gehaltene Konzerngesellschaft oder an die Gesellschaft), soweit diese Vermögenswerte einen Marktwert von 50% oder mehr entweder des auf konsolidierter Basis aggregierten Marktwertes aller Vermögenswerte der Gesellschaft oder des aggregierten Marktwertes aller dann ausgegebenen Aktien haben, unabhängig davon, ob eine dieser Transaktionen Teil einer Auflösung der Gesellschaft ist oder nicht; oder (z) ein vorgeschlagenes Übernahme- oder Umtauschangebot für 50% oder mehr der ausstehenden Stimmrechte der Gesellschaft. Die Gesellschaft muss Nahestehenden Aktionären sowie den übrigen Aktionären den Vollzug einer der unter (x) oder (y) des zweiten Satzes dieses Artikels 20 Abs. 3(d) erwähnten Transaktionen mindestens 20 Kalendertage vorher mitteilen.		(d)the Business Combination is proposed prior to the consummation or abandonment of and subsequent to the earlier of the public announcement or the notice required hereunder of a proposed transaction which (i) constitutes one of the transactions described in the second sentence of this Article 20 para. 3(d); (ii) is with or by a person who either was not an Interested Shareholder during the previous three years or who became an Interested Shareholder with the approval of the Board of Directors; and (iii) is approved or not opposed by a majority of the members of the Board of Directors then in office (but not less than one) who were Directors prior to any person becoming an Interested Shareholder during the previous three years or were recommended for election to succeed such Directors by a majority of such Directors.  The proposed transactions referred to in the preceding sentence are limited to (x) a merger or consolidation of the Company (except for a merger in respect of which no vote of the Company’s shareholders is required); (y) a sale, lease, exchange, mortgage, pledge, transfer or other disposition (in one transaction or a series of transactions), whether as part of a dissolution or otherwise, of assets of the Company or of any direct or indirect majority-Owned subsidiary of the Company (other than to any direct or indirect wholly Owned subsidiary or to the Company) having an aggregate market value equal to 50% or more of either that aggregate market value of all of the assets of the Company determined on a consolidated basis or the aggregate market value of all the issued shares; or (z) a proposed tender or exchange offer for 50% or more of the voting shares then in issue.  The Company shall give not less than 20 days' notice to all Interested Shareholders as well as to the other shareholders prior to the consummation of any of the transactions described in clause (x) or (y) of the second sentence of this Article 20 para. 3(d).

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		Artikel 21			Article 21
Präsenzquorum	1	Die nachfolgend aufgeführten Angelegenheiten erfordern zum Zeitpunkt der Konstituierung der Generalversammlung ein Präsenzquorum von Aktionären oder deren Vertretern, welche mindestens zwei Drittel des im Handelsregister eingetragenen Aktienkapitals vertreten, damit die Generalversammlung beschlussfähig ist: (a)Die Beschlussfassung über die Abwahl eines amtierenden Verwaltungsrats­mitglieds; und (b)die Beschlussfassung, diesen Artikel 21 oder Artikel 18, 19(f), 20, 22, 23 oder 24 dieser Statuten zu ergänzen, zu ändern, nicht anzuwenden oder ausser Kraft zu setzen.	Presence Quorum	1	The matters set forth below require that a quorum of shareholders of record holding in person or by proxy at least two-thirds of the share capital recorded in the Commercial Register are present at the time when the General Meeting of Shareholders proceeds to business: (a)the adoption of a resolution to remove a serving Director; and (b)the adoption of a resolution to amend, vary, suspend the operation of, disapply or cancel this Article 21 or Articles 18, 19(f), 20, 22, 23 or 24 of these Articles of Association.
	2	Jede andere Beschlussfassung oder Wahl setzt zu ihrer Gültigkeit voraus, dass zum Zeitpunkt der Konstituierung der Generalversammlung zumindest die Mehrheit aller stimmberechtigten Aktien anwesend ist. Die Aktionäre können mit der Behandlung der Traktanden fortfahren, selbst wenn Aktionäre nach Bekanntgabe des Quorums durch den Vorsitzenden die Generalversammlung verlassen und damit weniger als das geforderte Präsenzquorum an der Generalversammlung verbleibt.		2	The adoption of any other resolution or election requires that at least a majority of all the Shares entitled to vote be represented at the time when the General Meeting of Shareholders proceeds to business.  The shareholders present at a General Meeting of Shareholders may continue to transact business, despite the withdrawal of shareholders from such General Meeting of Shareholders following announcement of the presence quorum at that meeting.

- 22 -

		B. Verwaltungsrat			B. Board of Directors
		Artikel 22			Article 22
Anzahl der Verwaltungs-räte		Der Verwaltungsrat besteht aus mindestens zwei und höchstens 14 Mitgliedern.	Number of Directors		The Board of Directors shall consist of no less than two and no more than 14 members.
		Artikel 23			Article 23
Amtsdauer	1	Die Verwaltungsräte werden vom Verwaltungsrat in drei Klassen aufgeteilt, welche als Klasse I, Klasse II und Klasse III bezeichnet werden. An jeder ordentlichen Generalversammlung soll jede Klasse Verwaltungsräte, deren Amtsdauer abläuft, für eine Amtsdauer von drei Jahren bzw. bis zur Wahl eines Nachfolgers in sein Amt gewählt werden. Der Verwaltungsrat legt die Reihenfolge der Wiederwahl fest, wobei die erste Amtszeit einer Klasse von Verwaltungsräten auch weniger als drei Jahre betragen kann. Für die Zwecke dieser Bestimmung ist unter einem Jahr der Zeitabschnitt zwischen zwei ordentlichen Generalversammlungen zu verstehen.	Term of Office	1	The Board of Directors shall divide its members into three classes, designated Class I, Class II and Class III.  At each Annual General Meeting, each class of the members of the Board of Directors whose term shall then expire shall be elected to hold office for a three-year term or until the election of their respective successor in office. The Board of Directors shall establish the order of rotation, whereby the first term of office of members of a particular Class may be less than three years. For purposes of this provision, one year shall mean the period between two Annual General Meetings of Shareholders.
	2	Wenn ein Verwaltungsratsmitglied vor Ablauf seiner Amtsdauer aus welchen Gründen auch immer ersetzt wird, endet die Amtsdauer des an seiner Stelle gewählten neuen Verwaltungsratsmitgliedes mit dem Ende der Amtsdauer seines Vorgängers.		2	If, before the expiration of his term of office, a Director should be replaced for whatever reason, the term of office of the newly elected member of the Board of Directors shall expire at the end of the term of office of his predecessor.

- 23 -

		Artikel 24			Article 24
Organisation des Verwaltungs-rates, Entschädigung	1	Der Verwaltungsrat wählt aus seiner Mitte einen Vorsitzenden. Er kann einen oder mehrere Vizepräsidenten wählen. Er bestellt weiter einen Sekretär, welcher nicht Mitglied des Verwaltungsrates sein muss. Der Verwaltungsrat regelt unter Vorbehalt der Bestimmungen des Gesetzes und dieser Statuten die Einzelheiten seiner Organisation in einem Organisationsreglement.	Organization of the Board, Remuneration	1	The Board of Directors shall elect from among its members a Chairman.  It may elect one or more Vice-Chairmen.  It shall further appoint a Secretary, who need not be a member of the Board of Directors.  Subject to applicable law and these Articles of Association, the Board of Directors shall establish the particulars of its organization in organizational regulations.
	2	Die Mitglieder des Verwaltungsrates haben Anspruch auf Ersatz ihrer im Interesse der Gesellschaft aufgewendeten Auslagen sowie auf eine ihrer Tätigkeit und Verantwortung entsprechende Entschädigung, die der Verwaltungsrat auf Antrag eines Ausschusses des Verwaltungsrates festlegt.		2	The members of the Board of Directors shall be entitled to reimbursement of all expenses incurred in the interest of the Company, as well as remuneration for their services that is appropriate in view of their functions and responsibilities.  The amount of the remuneration shall be determined by the Board of Directors upon recommendation by a committee of the Board of Directors.

- 24 -

3	Soweit gesetzlich zulässig, hält die Gesellschaft aktuelle und ehemalige Mitglieder des Verwaltungsrates und der Geschäftsleitung sowie deren Erben, Konkurs- oder Nachlassmassen aus Gesellschaftsmitteln für Schäden, Verluste und Kosten aus drohenden, hängigen oder abgeschlossenen Klagen, Verfahren oder Untersuchungen zivil-, straf- oder verwaltungsrechtlicher oder anderer Natur schadlos, welche ihnen oder ihren Erben, Konkurs- oder Nachlassmassen entstehen aufgrund von tatsächlichen oder behaupteten Handlungen, Zustimmungen oder Unterlassungen im Zusammenhang mit der Ausübung ihrer Pflichten oder behaupteten Pflichten oder aufgrund der Tatsache, dass sie Mitglied des Verwaltungsrates oder der Geschäftsleitung der Gesellschaft sind oder waren oder auf Aufforderung der Gesellschaft als Mitglied des Verwaltungsrates, der Geschäftsleitung oder als Arbeitnehmer oder Agent eines anderen Unternehmens, einer anderen Gesellschaft, einer nicht-rechtsfähigen Personengesellschaft oder eines Trusts sind oder waren. Diese Pflicht zur Schadloshaltung besteht nicht, soweit in einem endgültigen, nicht weiterziehbaren Entscheid eines zuständigen Gerichts bzw. einer zuständigen Verwaltungsbehörde entschieden worden ist, dass eine der genannten Personen ihre Pflichten als Mitglied des Verwaltungsrates oder der Geschäftsleitung absichtlich oder grobfahrlässig verletzt hat.	3	The Company shall indemnify and hold harmless, to the fullest extent permitted by law, the existing and former members of the Board of Directors and officers, and their heirs, executors and administrators, out of the assets of the Company from and against all threatened, pending or completed actions, suits or proceedings – whether civil, criminal, administrative or investigative – and all costs, charges, losses, damages and expenses which they or any of them, their heirs, executors or administrators, shall or may incur or sustain by or by reason of any act done or alleged to be done, concurred or alleged to be concurred in or omitted or alleged to be omitted in or about the execution of their duty, or alleged duty, or by reason of the fact that he is or was a member of the Board of Director or officer of the Company, or while serving as a member of the Board of Director or officer of the Company is or was serving at the request of the Company as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise; provided, however, that this indemnity shall not extend to any matter in which any of said persons is found, in a final judgment or decree of a court or governmental or administrative authority of competent jurisdiction not subject to appeal, to have committed an intentional or grossly negligent breach of his statutory duties as a member of the Board of Director or officer.
4	Ohne den vorangehenden Absatz 3 dieses Artikels 24 einzuschränken, bevorschusst die Gesellschaft Mitgliedern des Verwaltungsrates und der Geschäftsleitung Gerichts- und Anwaltskosten. Die Gesellschaft kann solche Vorschüsse zurückfordern, wenn ein zuständiges Gericht oder eine zuständige Verwaltungsbehörde in einem endgültigen, nicht weiterziehbaren Urteil bzw. Entscheid zum Schluss kommt, dass eine der genannten Personen ihre Pflichten als Mitglied des Verwaltungsrates oder der Geschäftsleitung absichtlich oder grobfahrlässig verletzt hat.	4	Without limiting the foregoing paragraph 3 of this Article 24, the Company shall advance court costs and attorneys' fees to the existing and former members of the Board of Directors and officers.  The Company may however recover such advanced costs if any of said persons is found, in a final judgment or decree of a court or governmental or administrative authority of competent jurisdiction not subject to appeal, to have committed an intentional or grossly negligent breach of his statutory duties as a Director of officer.

		Artikel 25			Article 25
Befugnisse des Verwaltungs-rates	1	Der Verwaltungsrat hat die in Artikel 716a OR statuierten unübertragbaren und unentziehbaren Aufgaben, insbesondere: (a)die Oberleitung der Gesellschaft und die Erteilung der nötigen Weisungen; (b)die Festlegung der Organisation; und (c)die Oberaufsicht über die mit der Geschäftsführung betrauten Personen, namentlich im Hinblick auf die Befolgung der Gesetze, Statuten, Reglemente und Weisungen.	Specific Powers of the Board	1	The Board of Directors has the non-delegable and inalienable duties as specified in Article 716a CO, in particular: (a)the ultimate direction of the business of the Company and the issuance of the required directives; (b)the determination of the organization of the Company; and (c)the ultimate supervision of the persons entrusted with management duties, in particular with regard to compliance with law, these Articles of Association, regulations and directives.
	2	Der Verwaltungsrat kann überdies in allen Angelegenheiten Beschluss fassen, die nicht nach Gesetz oder Statuten der Generalversammlung zugeteilt sind.		2	In addition, the Board of Directors may pass resolutions with respect to all matters that are not reserved to the General Meeting of Shareholders by law or under these Articles of Association.
	3	Der Verwaltungsrat kann Beteiligungspläne der Gesellschaft der Generalversammlung zur Genehmigung vorlegen.		3	The Board of Directors may submit benefit or incentive plans of the Company to the General Meeting of Shareholders for approval.
		Artikel 26			Article 26
Übertragung von Befugnissen		Der Verwaltungsrat kann unter Vorbehalt von Artikel 25 Abs. 1 dieser Statuten sowie der Vorschriften des OR die Geschäftsführung nach Massgabe eines Organisationsreglements ganz oder teilweise an eines oder mehrere seiner Mitglieder, an einen oder mehrere Ausschüsse des Verwaltungsrates oder an Dritte übertragen.	Delegation of Powers		Subject to Article 25 para. 1 of these Articles of Association and the applicable provisions of the CO, the Board of Directors may delegate the management of the Company in whole or in part to individual directors, one or more committees of the Board of Directors or to persons other than Directors pursuant to organizational regulations.

- 25 -

		Artikel 27			Article 27
Sitzungen des Verwaltungsrats	1	Sofern das vom Verwaltungsrat erlassene Organisationsreglement nichts anderes festlegt, ist zur gültigen Beschlussfassung über Geschäfte des Verwaltungsrates die Anwesenheit einer Mehrheit der Mitglieder des gesamten Verwaltungsrates notwendig. Kein Präsenzquorum ist erforderlich für die Statutenanpassungs- und Feststellungsbeschlüsse des Verwaltungsrates im Zusammenhang mit Kapitalerhöhungen.	Meeting of the Board of Directors	1	Except as otherwise set forth in organizational regulations of the Board of Directors, the attendance quorum necessary for the transaction of the business of the Board of Directors shall be a majority of the whole Board of Directors.  No attendance quorum shall be required for resolutions of the Board of Directors providing for the confirmation of a capital increase or for the amendment of the Articles of Association in connection therewith.
	2	Der Verwaltungsrat fasst seine Beschlüsse mit einer Mehrheit der von den anwesenden Verwaltungsräten abgegebenen Stimmen, vorausgesetzt, das Präsenzquorum von Absatz 1 dieses Artikels 27 ist erfüllt. Der Vorsitzende hat bei Stimmengleichheit keinen Stichentscheid.		2	The Board of Directors shall pass its resolutions with the majority of the votes cast by the Directors present at a meeting at which the attendance quorum of para. 1 of this Article 27 is satisfied.  The Chairman shall have no casting vote.
		Artikel 28			Article 28
Zeichnungs-berechtigung		Die rechtsverbindliche Vertretung der Gesellschaft durch Mitglieder des Verwaltungsrates und durch Dritte wird in einem Organisationsreglement festgelegt.	Signature Power		The due and valid representation of the Company by members of the Board of Directors and other persons shall be set forth in organizational regulations.

- 26 -

		C. Revisionsstelle			C. Auditor
		Artikel 29			Article 29
Amtsdauer, Befugnisse und Pflichten	1	Die Revisionsstelle wird von der Generalversammlung gewählt und es obliegen ihr die vom Gesetz zugewiesenen Befugnisse und Pflichten.	Term, Powers and Duties	1	The Auditor shall be elected by the General Meeting of Shareholders and shall have the powers and duties vested in it by law.
	2	Die Amtsdauer der Revisionsstelle beträgt ein Jahr, beginnend am Tage der Wahl an einer ordentlichen Generalversammlung und endend am Tage der nächsten ordentlichen Generalversammlung.		2	The term of office of the Auditor shall be one year, commencing on the day of election at an Annual General Meeting of Shareholders and terminating on the day of the next Annual General Meeting of Shareholders.
		Abschnitt 4: Jahresrechnung, Konzernrechnung und Gewinnverteilung			Section 4: Annual Statutory Financial Statements, Consolidated Financial Statements and Profit Allocation
		Artikel 30			Article 30
Geschäftsjahr		Der Verwaltungsrat legt das Geschäftsjahr fest.	Fiscal Year		The Board of Directors determines the fiscal year.
		Artikel 31			Article 31
Verteilung des Bilanzgewinns, Reserven	1	Über den Bilanzgewinn verfügt die Generalversammlung im Rahmen der anwendbaren gesetzlichen Vorschriften. Der Verwaltungsrat unterbreitet ihr seine Vorschläge.	Allocation of Profit Shown on the Annual Statutory Balance Sheet, Reserves	1	The profit shown on the Annual Statutory Balance Sheet shall be allocated by the General Meeting of Shareholders in accordance with applicable law.  The Board of Directors shall submit its proposals to the General Meeting of Shareholders.
	2	Neben der gesetzlichen Reserve können weitere Reserven geschaffen werden.		2	Further reserves may be taken in addition to the reserves required by law.

- 27 -

	3	Dividenden, welche nicht innerhalb von fünf Jahren nach ihrem Auszahlungsdatum bezogen werden, fallen an die Gesellschaft und werden in die allgemeinen gesetzlichen Reserven verbucht.		3	Dividends that have not been collected within five years after their payment date shall enure to the Company and be allocated to the general statutory reserves.
		Abschnitt 5: Auflösung und Liquidation			Section 5: Winding-up and Liquidation
		Artikel 32			Article 32
Auflösung und Liquidation	1	Die Generalversammlung kann jederzeit die Auflösung und Liquidation der Gesellschaft nach Massgabe der gesetzlichen und statutarischen Vorschriften beschliessen.	Winding-up and Liquidation	1	The General Meeting of Shareholders may at any time resolve on the winding-up and liquidation of the Company pursuant to applicable law and the provisions set forth in these Articles of Association.
	2	Die Liquidation wird durch den Verwaltungsrat durchgeführt, sofern sie nicht durch die Generalversammlung anderen Personen übertragen wird.		2	The liquidation shall be effected by the Board of Directors, unless the General Meeting of Shareholders shall appoint other persons as liquidators.
	3	Die Liquidation der Gesellschaft erfolgt nach Massgabe der gesetzlichen Vorschriften.		3	The liquidation of the Company shall be effectuated pursuant to the statutory provisions.
	4	Nach erfolgter Tilgung der Schulden wird das Vermögen unter die Aktionäre nach Massgabe der eingezahlten Beträge verteilt, soweit diese Statuten nichts anderes vorsehen.		4	Upon discharge of all liabilities, the assets of the Company shall be distributed to the shareholders pursuant to the amounts paid in, unless these Articles of Association provide otherwise.
		Abschnitt 6: Bekanntmachungen, Mitteilungen			Section 6: Announcements, Communications
		Artikel 33			Article 33
Bekannt-machungen, Mitteilungen	1	Publikationsorgan der Gesellschaft ist das Schweizerische Handelsamtsblatt.	Announcements, Communications	1	The official means of publication of the Company shall be the Swiss Official Gazette of Commerce.

- 28 -

	2	Soweit keine individuelle Benachrichtigung durch das Gesetz, börsengesetzliche Bestimmungen oder diese Statuten verlangt wird, gelten sämtliche Mitteilungen an die Aktionäre als gültig erfolgt, wenn sie im Schweizerischen Handelsamtsblatt veröffentlicht worden sind. Schriftliche Bekanntmachungen der Gesellschaft an die Aktionäre werden auf dem ordentlichen Postweg an die letzte im Aktienbuch verzeichnete Adresse des Aktionärs oder des bevollmächtigten Empfängers geschickt. Finanzinstitute, welche Aktien für wirtschaftlich Berechtigte halten und als solches im Aktienbuch eingetragen sind, gelten als bevollmächtigte Empfänger.		2	To the extent that individual notification is not required by law, stock exchange regulations or these Articles of Association, all communications to the shareholders shall be deemed valid if published in the Swiss Official Gazette of Commerce.  Written communications by the Company to its shareholders shall be sent by ordinary mail to the last address of the shareholder or authorized recipient recorded in the share register.  Financial institutions holding Shares for beneficial owners and recorded in such capacity in the share register shall be deemed to be authorized recipients.
		Abschnitt 7: Verbindlicher Originaltext			Section 7: Original Language
		Artikel 34			Article 34
Verbindlicher Originaltext		Falls sich zwischen der deutschen und englischen Fassung dieser Statuten Differenzen ergeben, hat die deutsche Fassung Vorrang.	Original Language		In the event of deviations between the German and English version of these Articles of Association, the German text shall prevail.
		Abschnitt 8: Definitionen			Section 8: Definitions

- 29 -

		Artikel 35			Article 35
Aktie(n)	1	Der Begriff Aktie(n) hat die in Artikel 4 dieser Statuten aufgeführte Bedeutung.	Share(s)	1	The term Share(s) has the meaning assigned to it in Article 4 of these Articles of Association.
Eigentümer	2	Eigentümer(in), unter Einschluss der Begriffe Eigentum, halten, gehalten, Eigentümerschaft oder ähnlicher Begriffe, bedeutet, wenn verwendet mit Bezug auf Aktien, jede Person, welche allein oder zusammen mit oder über Nahestehende Gesellschaften oder Nahestehende Personen:	Owner	2	Owner, including the terms Own, Owned and Ownership when used with respect to any Shares means a Person that individually or with or through any of its Affiliates or Associates:
		(a)wirtschaftliche Eigentümerin dieser Aktien ist, ob direkt oder indirekt;			(a)beneficially Owns such Shares, directly or indirectly;
		(b)(1) das Recht hat, aufgrund eines Vertrags, einer Absprache oder einer anderen Vereinbarung, oder aufgrund der Ausübung eines Wandel-, Tausch-, Bezugs- oder Optionsrechts oder anderweitig Aktien zu erwerben (unabhängig davon, ob dieses Recht sofort ausübbar ist oder nur nach einer gewissen Zeit); vorausgesetzt, dass eine Person nicht als Eigentümerin derjenigen Aktien gelten soll, die im Rahmen eines Übernahme- oder Umtauschangebots, das diese Person oder eine dieser Person Nahestehende Gesellschaft oder Nahestehende Person eingeleitet hat, angedient werden, bis diese Aktien zum Kauf oder Tausch akzeptiert werden; oder (2) das Recht hat, die Stimmrechte dieser Aktien aufgrund eines Vertrags, einer Absprache oder einer anderen Vereinbarung auszuüben; vorausgesetzt, dass eine Person nicht als Eigentümerin von Aktien gilt infolge des Rechts, das Stimmrecht auszuüben, soweit der diesbezügliche Vertrag, die diesbezügliche Absprache oder die diesbezügliche andere Vereinbarung nur aufgrund einer widerruflichen Vollmacht (proxy) oder Zustimmung zustande gekommen ist, und diese Vollmacht (proxy) oder Zustimmung in Erwiderung auf eine an 10 oder mehr Personen gemachte diesbezügliche Aufforderung ergangen ist; oder			(b)has (1) the right to acquire such Shares (whether such right is exercisable immediately or only after the passage of time) pursuant to any agreement, arrangement or understanding, or upon the exercise of conversion rights, exchange rights, warrants or options, or otherwise; provided, however, that a Person shall not be deemed the Owner of Shares tendered pursuant to a tender or exchange offer made by such Person or any of such Person's Affiliates or Associates until such tendered Shares are accepted for purchase or exchange; or (2) the right to vote such Shares pursuant to any agreement, arrangement or understanding; provided, however, that a Person shall not be deemed the Owner of any Shares because of such Person's right to vote such Shares if the agreement, arrangement or understanding to vote such Shares arises solely from a revocable proxy or consent given in response to a proxy or consent solicitation made to 10 or more Persons; or
		(c)zwecks Erwerbs, Haltens, Stimmrechtsausübung (mit Ausnahme der Stimmrechtsausübung aufgrund einer widerruflichen Vollmacht (proxy) oder Zustimmung wie in Artikel 35 Abs. 2(b)(ii)(2) umschrieben) oder Veräusserung dieser Aktien mit einer anderen Person in einen Vertrag, eine Absprache oder eine andere Vereinbarung getreten ist, die direkt oder indirekt entweder selbst oder über ihr Nahestehende Gesellschaften oder Nahestehende Personen wirtschaftlich Eigentümerin dieser Aktien ist.			(c)has any agreement, arrangement or understanding for the purpose of acquiring, holding, voting (except voting pursuant to a revocable proxy or consent as described in Article 35 para. 2(b)(ii)(2)), or disposing of such Shares with any other Person that beneficially Owns, or whose Affiliates or Associates beneficially Own, directly or indirectly, such Shares.
Gesellschaft	3	Der Begriff Gesellschaft hat die in Artikel 1 dieser Statuten aufgeführte Bedeutung.	Company	3	The term Company has the meaning assigned to it in Article 1 of these Articles of Association.

- 30 -

Kontrolle 4 Kontrolle, einschliesslich die Begriffe kontrollierend, kontrolliert von und unter gemeinsamer Kontrolle mit, bedeutet die Möglichkeit, direkt oder indirekt auf die Geschäftsführung und die Geschäftspolitik einer Person Einfluss zu nehmen, sei es aufgrund des Haltens von Stimmrechten, eines Vertrags oder auf andere Weise. Eine Person, welche 20% oder mehr der ausgegebenen oder ausstehenden Stimmrechte einer Kapitalgesellschaft, rechts- oder nicht-rechtsfähigen Personengesellschaft oder eines anderen Rechtsträgers hält, hat mangels Nachweises des Gegenteils unter Anwendung des Beweismasses der überwiegenden Wahrscheinlichkeit der Beweismittel vermutungsweise Kontrolle über einen solchen Rechtsträger. Ungeachtet des Voranstehenden gilt diese Vermutung der Kontrolle nicht, wenn eine Person in Treu und Glauben und nicht zur Umgehung dieser Bestimmung Stimmrechte als Stellvertreter (agent), Bank, Börsenmakler (broker), Nominee, Depotbank (custodian)oder Treuhänder (trustee) für einen oder mehrere Eigentümer hält, die für sich allein oder zusammen als Gruppe keine Kontrolle über den betreffenden Rechtsträger haben. Control 4 Control, including the terms controlling, controlled by and under common control with, means the possession, direct or indirect, of the power to direct or cause the direction of the management and policies of a Person, whether through the Ownership of voting shares, by contract, or otherwise.  A Person who is the Owner of 20% or more of the issued or outstanding voting shares of any corporation, partnership, unincorporated association or other entity shall be presumed to have control of such entity, in the absence of proof by a preponderance of the evidence to the contrary. Notwithstanding the foregoing, a presumption of control shall not apply where such Person holds voting shares, in good faith and not for the purpose of circumventing this provision, as an agent, bank, broker, nominee, custodian or trustee for one or more Owners who do not individually or as a group have control of such entity.

- 31 -

Nahestehender Aktionär	5	Nahestehender Aktionär bedeutet jede Person (unter Ausschluss der Gesellschaft oder jeder direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird), (i) die Eigentümerin von 15% oder mehr der ausgegebenen Aktien ist, oder (ii) die als Nahestehende Gesellschaft oder Nahestehende Person anzusehen ist und irgendwann in den drei unmittelbar vorangehenden Jahren vor dem Zeitpunkt, zu dem bestimmt werden muss, ob diese Person ein Nahestehender Aktionär ist, Eigentümerin von 15% oder mehr der ausgegebenen Stimmrechte gewesen ist, ebenso wie jede Nahestehende Gesellschaft und Nahestehende Person dieser Person; vorausgesetzt, dass eine Person nicht als Nahestehender Aktionär gilt, die aufgrund von Handlungen, die ausschliesslich der Gesellschaft zuzurechnen sind, Eigentümerin von Aktien in Überschreitung der 15%-Beschränkung ist; wobei jedoch jede solche Person dann als Nahestehender Aktionär gilt, falls sie später zusätzliche Aktien erwirbt, ausser dieser Erwerb erfolgt aufgrund von weiteren Gesellschaftshandlungen, die weder direkt noch indirekt von dieser Person beeinflusst werden. Zur Bestimmung, ob eine Person ein Nahestehender Aktionär ist, sind die als ausgegeben geltenden Aktien unter Einschluss der von dieser Person gehaltenen Aktien (unter Anwendung des Begriffs "gehalten" wie in Artikel 35 Abs. 2 dieser Statuten definiert) zu berechnen, jedoch unter Ausschluss von nichtausgegebenen Aktien, die aufgrund eines Vertrags, einer Absprache oder einer anderen Vereinbarung, oder aufgrund der Ausübung eines Wandel-, Bezugs- oder Optionsrechts oder anderweitig ausgegeben werden können;	Interested Shareholder	5	Interested Shareholder means any Person (other than the Company or any direct or indirect majority-Owned subsidiary of the Company) (i) that is the Owner of 15% or more of the issued Shares of the Company or (ii) that is an Affiliate or Associate of the Company and was the Owner of 15% or more of the issued Shares at any time within the three-year period immediately prior to the date on which it is sought to be determined whether such Person is an Interested Shareholder, and also the Affiliates and Associates of such Person; provided, however, that the term Interested Shareholder shall not include any Person whose Ownership of Shares in excess of the 15% limitation is the result of action taken solely by the Company; provided that such Person shall be an Interested Shareholder if thereafter such Person acquires additional Shares, except as a result of further corporate action not caused, directly or indirectly, by such Person.  For the purpose of determining whether a Person is an Interested Shareholder, the Shares deemed to be in issue shall include Shares deemed to be Owned by the Person (through the application of the definition of Owner in Article 35 para. 2 of these Articles of Association) but shall not include any other unissued Shares which may be issuable pursuant to any agreement, arrangement or understanding, or upon exercise of conversion rights, warrants or options, or otherwise.
Nahestehende Gesellschaft	6	Nahestehende Gesellschaft bedeutet jede Person, die direkt oder indirekt über eine oder mehrere Mittelspersonen eine andere Person kontrolliert, von einer anderen Person kontrolliert wird, oder unter gemeineinsamer Kontrolle mit einer anderen Person steht.	Affiliate	6	Affiliate means a Person that directly, or indirectly through one or more intermediaries, controls, or is controlled by, or is under common control with, another Person.
Nahestehende Person	7	Nahestehende Person bedeutet, wenn verwendet zur Bezeichnung einer Beziehung zu einer Person, (i) jede Kapitalgesellschaft, rechts- oder nicht-rechtsfähige Personengesellschaft oder ein anderer Rechtsträger, von welcher diese Person Mitglied des Leitungs- oder Verwaltungsorgans, der Geschäftsleitung oder Gesellschafter ist oder von welcher diese Person, direkt oder indirekt, Eigentümerin von 20% oder mehr einer Kategorie von Aktien oder anderer Anteilsrechte ist, die ein Stimmrecht vermitteln, (ii) jedes Treuhandvermögen (Trust) oder jede andere Vermögenseinheit, an der diese Person wirtschaftlich einen Anteil von 20% oder mehr hält oder in Bezug auf welche diese Person als Verwalter (trustee) oder in ähnlich treuhändischer Funktion tätig ist, und (iii) jeder Verwandte, Ehe- oder Lebenspartner dieser Person, oder jede Verwandte des Ehe- oder Lebenspartners, jeweils soweit diese den gleichen Wohnsitz haben wie diese Person.	Associate	7	Associate, when used to indicate a relationship with any Person, means (i) any corporation, partnership, unincorporated association or other entity of which such Person is a director, officer or partner or is, directly or indirectly, the Owner of 20% or more of any class of voting shares, (ii) any trust or other estate in which such Person has at least a 20% beneficial interest or as to which such Person serves as trustee or in a similar fiduciary capacity, and (iii) any relative or spouse of such Person, or any relative of such spouse, who has the same residence as such Person.
OR	8	Der Begriff OR hat die in Artikel 14 Abs. 2 dieser Statuten aufgeführte Bedeutung.	CO	8	The term CO has the meaning assigned to it in Article 14 para. 2 of these Articles of Association.

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Person	9	Person bedeutet jede natürliche Person, Kapitalgesellschaft, rechts- oder nicht-rechtsfähige Personengesellschaft oder jeder andere Rechtsträger;	Person	9	Person means any individual, corporation, partnership, unincorporated association or other entity.
Rechte	10	Der Begriff Rechte hat die in Artikel 6 Abs. 1 dieser Statuten aufgeführte Bedeutung.	Rights	10	The term Rights has the meaning assigned to it in Article 6 para. 1 of these Articles of Association.
Mit Rechten verbundenen Obligationen	11	Der Begriff mit Rechten verbundenen Obligationen hat die in Artikel 6 Abs. 1 dieser Statuten aufgeführte Bedeutung.	Rights-Bearing Obligations	11	The term Rights-Bearing Obligations has the meaning assigned to it in Article 6 para. 1 of these Articles of Association.
SEC	12	Der Begriff SEC hat die in Artikel 12 Abs. 2 dieser Statuten aufgeführte Bedeutung.	SEC	12	The term SEC has the meaning assigned to it in Article 12 para. 2 of these Articles of Association.
Transfer Agent	13	Der Begriff Transfer Agent hat die in Artikel 8 Abs. 3 dieser Statuten aufgeführte Bedeutung.	Transfer Agent	13	The term Transfer Agent has the meaning assigned to it in Article 8 para. 3 of these Articles of Association.

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Zusammen­schluss	14	Zusammenschluss bedeutet, wenn im Rahmen dieser Statuten in Bezug auf die Gesellschaft oder einen Nahestehenden Aktionär der Gesellschaft verwendet:	Business Combination	14	Business Combination, when used in these Articles of Association in reference to the Company and any Interested Shareholder of the Company, means:
		(a)Jede Fusion oder andere Form des Zusammenschlusses der Gesellschaft oder einer direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, mit (1) dem Nahestehenden Aktionär oder (2) einer anderen Kapitalgesellschaft, rechts- oder nicht-rechtsfähigen Personengesellschaft oder einem anderen Rechtsträger, soweit diese Fusion oder andere Form des Zusammenschlusses durch den Nahestehenden Aktionär verursacht worden ist und als Folge dieser Fusion oder anderen Form des Zusammenschlusses Artikel 19(f) und Artikel 20 Abs. 3 dieser Statuten (sowie jede der dazu gehörigen Definition in Artikel 35 dieser Statuten) oder im Wesentlichen gleiche Bestimmungen wie Artikel 19(f), Artikel 20 Abs. 3 (und die dazugehörigen Definitionen in Artikel 35 dieser Statuten auf den überlebenden Rechtsträger) nicht anwendbar sind;			(a)Any merger or consolidation of the Company or any direct or indirect majority-Owned subsidiary of the Company with (1) the Interested Shareholder or (2) with any other corporation, partnership, unincorporated association or other entity if the merger or consolidation is caused by the Interested Shareholder and as a result of such merger or consolidation Article 19(f) and Article 20 para. 3 of these Articles of Association (including the relevant definitions in Article 35 of these Articles of Association pertaining thereto) or a provision substantially the same as such Article 19(f) and Article 20 para. 3 (including the relevant definitions in Article 35) are not applicable to the surviving entity;
		(b)jeder Verkauf, Vermietung oder Verpachtung, hypothekarische Belastung oder andere Verpfändung, Übertragung oder andere Verfügung (ob in einer oder mehreren Transaktionen), einschliesslich im Rahmen eines Tauschs, von Vermögenswerten der Gesellschaft oder einer direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, an einen Nahestehenden Aktionär (ausser soweit der Zuerwerb unter einer der genannten Transaktionen proportional als Aktionär erfolgt), soweit diese Vermögenswerte einen Marktwert von 10% oder mehr entweder des auf konsolidierter Basis aggregierten Marktwertes aller Vermögenswerte der Gesellschaft oder des aggregierten Marktwertes aller dann ausgegebenen Aktien haben, unabhängig davon, ob eine dieser Transaktionen Teil einer Auflösung der Gesellschaft ist oder nicht;			(b)any sale, lease, exchange, mortgage, pledge, transfer or other disposition (in one transaction or a series of transactions), except proportionately as a shareholder, to or with the Interested Shareholder, whether as part of a dissolution or otherwise, of assets of the Company or of any direct or indirect majority-Owned subsidiary of the Company which assets have an aggregate market value equal to 10% or more of either the aggregate market value of all the assets of the Company determined on a consolidated basis or the aggregate market value of all the Shares then in issue;
		(c)jede Transaktion, die dazu führt, dass die Gesellschaft oder eine direkte oder indirekte Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, Aktien oder Tochtergesellschafts-Aktien an den Nahestehenden Aktionär ausgibt oder überträgt, es sei denn (1) aufgrund der Ausübung, des Tauschs oder der Wandlung von Finanzmarktinstrumenten, die in Aktien oder Aktien einer direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, ausgeübt, getauscht oder gewandelt werden können, vorausgesetzt, die betreffenden Finanzmarktinstrumente waren zum Zeitpunkt, in dem der Nahestehende Aktionär zu einem solchem wurde, bereits ausgegeben; (2) als Dividende oder Ausschüttung an alle Aktionäre, oder aufgrund der Ausübung, des Tauschs oder der Wandlung von Finanzmarktinstrumenten, die in Aktien oder Aktien einer direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, ausgeübt, getauscht oder gewandelt werden können, vorausgesetzt, diese Finanzinstrumente werden allen Aktionäre anteilsmässig ausgegeben, nachdem der Nahestehende Aktionär zu einem solchem wurde; (3) gemäss einem Umtauschangebot der Gesellschaft, Aktien von allen Aktionären zu den gleichen Bedingungen zu erwerben; oder (4) aufgrund der Ausgabe oder der Übertragung von Aktien durch die Gesellschaft; vorausgesetzt, dass in keinem der unter (2) bis (4) genannten Fällen der proportionale Anteil des Nahestehenden Aktionärs an den Aktien erhöht werden darf;			(c)any transaction which results in the issuance or transfer by the Company or by any direct or indirect majority-Owned subsidiary of the Company of any Shares or shares of such subsidiary to the Interested Shareholder, except (1) pursuant to the exercise, exchange or conversion of securities exercisable for, exchangeable for or convertible into Shares or the shares of a direct or indirect majority-Owned subsidiary of the Company which securities were in issue prior to the time that the Interested Shareholder became such; (2) pursuant to a dividend or distribution paid or made, or the exercise, exchange or conversion of securities exercisable for, exchangeable for or convertible into Shares or the shares of a direct or indirect majority-Owned subsidiary of the Company which security is distributed, pro rata, to all shareholders subsequent to the time the Interested Shareholder became such; (3) pursuant to an exchange offer by the Company to purchase Shares made on the same terms to all holders of said Shares; or (4) any issuance or transfer of Shares by the Company; provided, however, that in no case under (2)–(4) above shall there be an increase in the Interested Shareholder's proportionate interest in the Shares;
		(d)jede Transaktion, in welche die Gesellschaft oder eine direkte oder indirekte Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, involviert ist, und die direkt oder indirekt dazu führt, dass der proportionale Anteil der vom Nahestehenden Aktionär gehaltenen Aktien, in Aktien wandelbare Obligationen oder Tochtergesellschafts-Aktien erhöht wird, ausser eine solche Erhöhung ist nur unwesentlich und die Folge eines Spitzenausgleichs für Fraktionen oder eines Rückkaufs oder einer Rücknahme von Aktien, soweit diese(r) weder direkt noch indirekt durch den Nahestehenden Aktionär verursacht wurde; oder			(d)any transaction involving the Company or any direct or indirect majority-Owned subsidiary of the Company which has the effect, directly or indirectly, of increasing the proportionate interest in the Shares, or securities convertible into the Shares, or in the shares of any such subsidiary which is Owned by the Interested Shareholder, except as a result of immaterial changes due to fractional share adjustments or as a result of any purchase or redemption of any Shares not caused, directly or indirectly, by the Interested Shareholder; or
		(e)jede direkte oder indirekte Gewährung von Darlehen, Vorschüssen, Garantien, Bürgschaften, oder garantieähnlicher Verpflichtungen, Pfändern oder anderen finanziellen Begünstigungen (mit Ausnahme einer solchen, die gemäss den Unterabschnitten (a) – (d) dieses Artikels 35 Abs. 14 ausdrücklich erlaubt ist sowie einer solchen, die proportional an alle Aktionäre erfolgt) durch die oder über die Gesellschaft oder eine direkte oder indirekte Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird, an den Nahestehenden Aktionär.			(e)any receipt by the Interested Shareholder of the benefit, directly or indirectly (except proportionately as a shareholder), of any loans, advances, guarantees, pledges or other financial benefits (other than those expressly permitted in subsections (a)–(d) of this Article 35 para. 14) provided by or through the Company or any direct or indirect majority-Owned subsidiary of the Company.

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	Abschnitt 9: Übergangsbestimmungen		Section 9: Transitional Provisions
	Artikel 36		Article 36
Sacheinlage	Die Gesellschaft übernimmt bei der Kapi­talerhöhung vom 19. Dezember 2008 von der Transocean Inc. in Grand Cayman, Cayman Islands (Transocean Inc.), gemäss Sacheinlagevertrag per 18. Dezember 2008 (Sacheinlagevertrag) 319’228’632 Aktien (ordinary shares) der Transocean Inc. Diese Aktien werden zu einem Übernahmewert von insgesamt CHF 16'476'107'961.80 übernommen. Als Gegenlei­stung für diese Sacheinlage gibt die Gesellschaft einem Umtauschagenten, handelnd auf Rechnung der Aktionäre der Transocean Inc. im Zeitpunkt unmittelbar vor Vollzug des Sacheinlagevertrages und im Namen und auf Rechnung der Transocean Inc., insgesamt 335'228’632 voll einbezahlte Aktien mit einem Nennwert von insgesamt CHF 5'028'429’480 aus. Die Gesell­schaft weist die Diffe­renz zwischen dem totalen Nennwert der aus­gegebenen Aktien und dem Übernahmewert der Sacheinlage im Gesamtbetrag von CHF 11'447'678'481.80 den Reserven der Gesellschaft zu.	Contribution in Kind	In connection with the capital increase of December 19, 2008, and in accordance with the contribution in kind agreement as of December 18, 2008 (the Contribution in Kind Agreement), the Company acquires 319,228,632 ordinary shares of Transocean Inc., Grand Cayman, Cayman Islands (Transocean Inc.).  The shares of Transocean Inc. are acquired for a total value of CHF 16,476,107,961.80.  As consideration for this contribution, the Company issues to an exchange agent, acting for the account of the holders of ordinary shares of Transocean Inc. outstanding immediately prior to the completion of the Contribution in Kind Agreement and in the name and the account of Transocean Inc, a total of 335,228,632 fully paid Shares with a total par value of CHF 5,028,429,480.  The difference between the aggregate par value of the issued Shares and the total value of CHF 11,447,678,481.80 is allocated to the reserves of the Company.

 ____________________

Zug, 4. Dezember 2011 Zug, December 4, 2011  

EX-10.5

March 2, 2012

Mr. Robert Shaw

Dear Rob:

This letter agreement (the “Agreement”) states the terms and conditions applicable to the termination of your employment with Transocean.  All references in this Agreement to “Transocean” shall mean Transocean Offshore Deepwater Drilling, Inc. (“TODDI”), its parent, subsidiaries, affiliates and related entities.

1.   Resignation and Termination.  You previously resigned as Vice President, Controller & Principal Accounting Officer, and from any and all other officer or director positions with Transocean, effective January 25, 2012.  Your employment with Transocean shall terminate on March 15, 2012 (the “Termination Date”).

2.   Severance Pay.  You shall receive a lump sum cash payment equal to $350,000, less applicable withholding (the “Compensation”), subject to and contingent upon your timely execution without revocation of the supplemental waiver and release agreement attached hereto as Annex I (the “Waiver and Release”).  In order to be considered as timely and valid for purposes of this Agreement, the Waiver and Release must be signed by you and delivered to Transocean no earlier than the Termination Date and no later than 21 days after the Termination Date, without revocation.  The Compensation shall be payable in a lump sum thirty (30) days after the Termination Date.  Any right you may have to payment arising in connection with earned but unused vacation time will be fully satisfied by the payment of the Compensation.

3.   Bonus.  Subject to and contingent upon your timely execution without revocation of the Waiver and Release, you will also receive a cash payment (the “2012 Bonus”) in an amount equal to $35,960.Payment of your 2012 Bonus, less applicable withholding, will be made simultaneously with the payment of Compensation thirty (30) days after the Termination Date and will be in lieu of your participation in the Cash Bonus Plan for the 2012 calendar year.

4.   Long-Term Incentive Plan Awards.  You will not receive any additional awards under the LTIP.  You should refer to the applicable award letters as to the specific treatment of any awards previously granted to you under the LTIP.  In addition, the following terms shall apply to any awards under the LTIP that remain outstanding as of the Termination Date:

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(A)Restricted Stock Units.  All Restricted Stock Units (“RSUs”) previously granted to you under the LTIP will be treated as if Transocean terminated your employment for the Convenience of the Company (as defined by and determined in accordance with the terms of the LTIP and the applicable award agreement) on the Termination Date, provided that, such treatment is subject to and contingent upon your timely execution without revocation of the Waiver and Release.  For the avoidance of doubt, the following provides details regarding the status of your outstanding RSU awards if you continue to be employed by Transocean until March 15, 2012:

Grant Date	RSUs Granted	Vested Per Schedule as of March 15, 2012	Accelerated Vesting on March 15, 2012*
11/17/2010	6,275	2,091	4,184
2/10/2011	1,997	665	1,332
12/1/2011	9,869	0	9,869

*Your accelerated RSUs will be settled 30 days following your Termination Date, contingent on execution without revocation of the Waiver and Release.

(B)Non-qualified Stock Options.  All non-qualified stock options (“NQ Options”) previously granted to you under the LTIP will be treated as if Transocean terminated your employment for the Convenience of the Company (as defined by and determined in accordance with the terms of the LTIP and the applicable award agreement) on the Termination Date, provided that, such treatment is subject to and contingent upon your timely execution without revocation of the Waiver and Release.For the avoidance of doubt, the following provides details regarding the status of your NQ Options if you continue to be employed by Transocean until March 15, 2012:

Grant Date	Exercise Price  (in U.S. dollars)	Number Awarded	Vested on March 15, 2012	Forfeited as of March 15, 2012	Exercise Period Ends
2/10/2011	$ 78.76	3,929	1,309	2,620	March 14, 2013

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(C)Contingent Deferred Units.  All contingent deferred units (“CDUs”) previously granted to you under the LTIP will be treated as if Transocean terminated your employment for the Convenience of the Company (as defined by and determined in accordance with the terms of the LTIP and the applicable award agreement) on the Termination Date, provided that, such treatment is subject to and contingent upon your timely execution without revocation of the Waiver and Release.  You will receive a pro-rata portion of the CDUs that are outstanding as of your Termination Date, which will remain subject to the applicable performance contingency.  For the avoidance of doubt, the following provides details regarding the status of your outstanding CDUs if you continue to be employed by Transocean until March 15, 2012:

Grant Date	CDUs Held	Forfeited as of Termination Date	Outstanding as of Termination Date	Earned
2/10/2011	1,997	1,242	755	TBD*

*In the event of a termination of employment for the Convenience of the Company, you receive a pro-rata portion of outstanding CDUs.  The pro-rata portion of the CDUs determined above is calculated by multiplying the number of CDUs held by a fraction, the numerator of which is the number of calendar days of employment during the performance cycle after the grant date (399) and the denominator of which is the total number of calendar days in the performance cycle after the grant date (1055).  The determination of the vested awards will be made within the first 60 days of 2014, and the distribution of the vested portion of the award will be made on March 15, 2014.

5.   Benefits.

(A)Retirement Plans.  Following the Termination Date, you will no longer be able to participate in the Transocean retirement plans, including the U.S. Savings Plan, U.S. Retirement Plan and the Transocean Management, Ltd. Pension Plan (the “Plans”).  The payment of your benefit under the Plans will be made in accordance with the applicable terms of that plan.

(B)Welfare Benefits.  You shall continue to receive coverage under Transocean’s expatriate group medical insurance program at Transocean’s expense until July 31, 2012 and Transocean will make available to you an opportunity to elect COBRA health continuation coverage.

(C)Cash Relocation Allowance.  Transocean waives it right to the repayment of the one-time cash relocation allowance of $175,000 that was previously paid to you on or about November 30, 2011.

(D)Repatriation.  You willbereimbursed for reasonable and documented repatriation costs incurred on or before December 31, 2012, in accordance with the repatriation section of Transocean’s Global Relocation policy.

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(E)Severance.  You will not be eligible to participate in any severance plan or arrangement established by Transocean, including but not limited to the Transocean Executive Severance Policy, and you agree that you will have no right to claim a benefit under any severance plan or arrangement.

(F)Outplacement Services.  You will be eligible to receive outplacement services in accordance with the current Human Resources’ practice at a cost not to exceed $17,500 in equivalent currency using exchange rates as of the Termination Date.

(G)Other Benefits and Perquisites.  Except as otherwise provided in this Agreement, the terms and conditions of each Transocean benefit plan or program in which you participate as of the Termination Date shall continue to apply to any payments due and owing to you under the terms of such plan or program as they would apply to other similarly situated executives of Transocean.  Without limiting the foregoing, you will remain covered under the terms of Transocean’s Swiss tax protection program, which includes, at Company expense, the preparation or assistance in preparation by PricewaterhouseCoopers LLP of your Swiss and United States tax returns.  Nothing in this Agreement shall limit or constrain in any way Transocean’s ability to amend the terms and/or conditions of any such plan or program.

(H)Financial Planning.  Executive shall be entitled to the full executive financial planning benefit for calendar year 2012 in an amount not to exceed $3,000, to be paid in accordance with the terms of Transocean’s executive financial planning policy.

6.   Indemnification. You will be indemnified for any direct expenses that (i) you may incur in Switzerland that are triggered by the premature termination of agreements you entered into related to your establishment of a residency in Switzerland and that you have to terminate due to the early termination of your residency in Switzerland and (ii) are payable to the party with whom you have contracted for the service or property, provided that such direct expenses could not be reasonably prevented or abated by you.

7.   Waiver And Release.  In exchange for this Agreement you agree, on behalf of yourself, your heirs, relations, successors, executors, administrators, assigns, agents, representatives, attorneys, and anyone acting on your behalf as follows:

You irrevocably and unconditionally release, acquit, and forever discharge Transocean, and any predecessors or successors (collectively, the “Transocean Group”), and its and their past and present officers, directors, attorneys, insurers, agents, servants, suppliers, representatives, employees, affiliates, subsidiaries, parent companies, partners, predecessors and successors in interest, assigns and benefit plans (except with respect to vested benefits under such plans), and any other persons or firms for whom the Transocean Group could be legally responsible (collectively, “Released Parties”), from any and all claims, liabilities or causes of action, whether known or now unknown to you, arising from or related in any way to your employment or termination of your employment with the Transocean Group and/or any of the Released Parties and occurring through the date you sign and return this Agreement, other than claims arising under the Age Discrimination in Employment Act, as amended, and the Older Workers Benefit Protection Act, which are addressed only in the Waiver and Release.

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You acknowledge that this Agreement is your knowing and voluntary waiver of all rights or claims arising before you accept and return this Agreement, as indicated below.  You understand and agree that your waiver includes, but is not limited to, all waivable charges, complaints, claims, liabilities, actions, suits, rights, demands, costs, losses, damages or debts of any nature except as specifically set forth above.  You further acknowledge and agree that your waiver of rights or claims is in exchange for valuable payments and other promises in addition to anything of value to which you are already entitled.

You further acknowledge and agree that the Transocean Group has no obligation to reemploy, rehire or recall you, and promise that you shall not apply for re-employment with the Transocean Group.

8.   Miscellaneous.

(A)You warrant, acknowledge and agree that:

(B)Your acceptance of this Agreement is completely voluntary;

(C)You are hereby being advised in writing by Transocean to consult with an attorney regarding the terms of this Agreement before accepting;

(D)You are receiving under this Agreement consideration of value in addition to anything to which you are already entitled;

(E)You are fully competent to execute this Agreement, which you understand to be a binding contract;

(F)You accept this Agreement including the Waiver and Release of your own free will, after having a reasonable period of time to review, study and deliberate regarding its meaning and effect, and without reliance on any representation of any kind or character not specifically included in writing in the Agreement;

(G)You understand that TODDI is relying upon the truthfulness of the statements you make in the Agreement and you understand that TODDI would not enter into this Agreement if you did not make each of the representations and promises contained in the Agreement.

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9.   Cooperation.  Following the termination of your employment with Transocean, you agree to reasonably cooperate with and make yourself available on a continuing basis to  Transocean and its representatives and legal advisors in connection with any matters in which you are or were involved during your employment with Transocean or any existing or future claims, investigations, administrative proceedings, lawsuits and other legal and business matters as reasonably requested by Transocean.If Transocean’s request for your cooperation as described in the previous sentence results in your spending more than six hours per month engaged in Transocean matters, Transocean shall pay you a fee per hour of services performed (in excess of six hours per month) at a rate of $175.00/hour, prorated for partial hours.  You also agree to promptly send the General Counsel, Transocean Ltd. copies of all correspondence (for example, but not limited to, subpoenas) received by you in connection with any such matters involving or relating to Transocean, unless you are expressly prohibited by law from so doing.  You agree not to cooperate voluntarily in any third party claims against Transocean.  You agree that nothing in this Agreement restricts your ability to appropriately respond to a subpoena or other request from the government or regulators.  Transocean agrees to reimburse you for your reasonable out-of-pocket expenses incurred in connection with the performance of your obligations under this section.

10.   Confidentiality.  You acknowledge that, in the course of your employment with Transocean, you have acquired Confidential Information which is and remains the exclusive property of Transocean. You agree not to divulge to any other person, firm, corporation or legal entity, any Confidential Information or trade secret of Transocean, except as required by law.   “Confidential Information” shall mean information:  (A) disclosed to or known by executive as a consequence of or through executive’s employment with Transocean; (B) not generally known outside the Transocean; and (C) which relates to any aspect of Transocean or their business, finances, operation plans, budgets, research, or strategic development.  “Confidential Information” includes, but is not limited to, Transocean’s trade secrets, proprietary information, financial documents, long range plans, customer information, employee compensation, marketing strategy, data bases, pricing and costing data, patent information, computer software developed by Transocean, investments made by Transocean, and any information provided to Transocean by a third party under restrictions against disclosure or use by Transocean or others.  You additionally represent and agree that the existence, terms and conditions of this Agreement shall be and remain confidential and that you will not disclose them to any third party other than your attorney or legal advisor.

11.   Return of Transocean’s Property.  You acknowledge and agree that you will promptly return to Transocean all property pertaining to its business activities that is in your possession, as well as any other property of Transocean that you are expressly requested to return, including computers, files, documents, and other materials which were given to you by Transocean for your use during your employment or which are otherwise in your possession, custody or control.

HOU01:1211745.11

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12.   Non-Disparagement.  You agree that, in acting alone or in concert with others, you will not (A) publicly criticize or disparage Transocean or any of its officers, employees, directors or agents, or privately criticize or disparage Transocean or any of its officers, employees, directors or agents in a manner intended or reasonably calculated to result in public embarrassment to, or injury to the reputation of, Transocean or any of its officers, employees, directors or agents; (B) directly or indirectly, acting alone or acting in concert with others, institute or prosecute, or assist any person in any manner in instituting or prosecuting, any legal proceedings of any nature against Transocean; (C) commit damage to the property of Transocean or otherwise engage in any misconduct which is injurious to the business or reputation of Transocean; or (D) take any other action, or assist any person in taking any other action, that is adverse to the interests of the Transocean or inconsistent with fostering the goodwill of Transocean; provided, however, that nothing in this Section 12 shall apply to or restrict in any way the communication of information by the executive to any state or federal law enforcement agency or require notice to Transocean, and you  will not be in breach of the covenant contained in (B) above solely by reason of your testimony which is compelled by process of law.

13.   Non-Solicitation of Customers.  You agree that, during the one year period beginning on the Termination Date, you will not directly or indirectly, on your own behalf or on behalf of others, solicit or accept any business producing or providing products or services which Transocean produces or provides from any person that was a customer or client or prospective customer or client of Transocean during the period during which you were employed by Transocean.

14.   Non-Solicitation of Employees.  You agree that during the term of your employment under this Agreement and for a period of two years following the Termination Date, you will not either directly or indirectly solicit, induce, recruit or encourage any of Transocean’s employees to leave their employment, or take away such employees, or attempt to solicit, induce, recruit, encourage, take away or hire Transocean’s employees, either for yourself or any other person or entity.

15.   Indemnification Agreement.   Nothing in this Agreement shall act as a release or waiver by you of any rights of defense or indemnification which would otherwise be afforded to you under the Articles of Association of Transocean Ltd. or the similar governing documents of any affiliate of Transocean Ltd., or any rights of defense or indemnification afforded to you under the indemnification agreement previously entered into between you and Transocean, or any rights of defense or indemnification which would be afforded to you under any officer liability or other insurance policy maintained by Transocean.

16.   Enforcement of Agreement.                                                      No waiver or nonaction with respect to any breach by the other party of any provision of this Agreement, nor the waiver or nonaction with respect to any breach of the provisions of similar agreements with other employees or consultants shall be construed to be a waiver of any succeeding breach of such provision, or as a waiver of the provision itself.  Should any provisions hereof be held to be invalid or wholly or partially unenforceable, such holdings shall not invalidate or void the remainder of this Agreement.  Portions held to be invalid or unenforceable shall be revised and reduced in scope so as to be valid and enforceable, or, if such is not possible, then such portion shall be deemed to have been wholly excluded with the same force and effect as if they had never been included herein.

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17.   Choice of Law.  This Agreement shall be interpreted and construed in accordance with and shall be governed by the laws of the State of Texas, notwithstanding any conflicts of law principles which may refer to the laws of any other jurisdiction.

18.   Taxes.

Transocean will have the right to deduct from all benefits and payment made under this Agreement any and all taxes required by law to be paid or withheld with respect to such benefits or payments.

19.   Section 409A.

The Agreement is intended to comply with the provisions of Section 409A and applicable Treasury authorities and, wherever possible, shall be construed and interpreted to ensure that any payments that may be paid, distributed provided, reimbursed, deferred or settled under this Agreement will not be subject to any additional taxation under Section 409A.  This Section 19 does not create an obligation on the part of Transocean to modify the Agreement in the future and does not guarantee that the amounts or benefits owed under the Agreement will not be subject to interest and penalties under Code Section 409A.  Notwithstanding any provision of the Agreement to the contrary, the following provisions shall apply for purposes of complying with Section 409A:

(i)           Pursuant to the applicable standards regarding termination from employment for purposes of Section 409A and the applicable Treasury Regulations under 1.409A-1(h)(1)(ii), you and Transocean acknowledge that you will have a separation from service for purposes of determining the timing of payment of deferred compensation to which you are entitled as of the Termination Date.

(ii)           The provisions of Section 409A of the Internal Revenue Code of 1986, as amended, do not apply to the Compensation or the 2012 Bonus since this amount qualifies for the short-term deferral exception described in Treasury Regulation §1.409A-1(b)(4), in addition to the separation pay exemption as it does not exceed the separation pay plan limits described in Treasury Regulation §1.409A-1(b)(9).

(iii)           Continued medical benefits are intended to satisfy the exemption for medical expense reimbursements under Treasury Regulation Section 1.409A-1(b)(9)(v)(B).

20.  Notices.  Notices provided for in this Agreement shall be in writing and shall either be personally delivered by hand or sent by:  (i) mail service, postage prepaid, properly packaged, addressed and deposited with the mail service system; (ii) via facsimile transmission or electronic mail if the receiver acknowledges receipt; or (iii) via Federal Express or other expedited delivery service provided that acknowledgment of receipt is received and retained by the deliverer and furnished to the sender.  Notices to you by Transocean shall be delivered to the last address you have filed, in writing, with Transocean, and notices by you to Transoceanshall be delivered to Transocean Management Ltd., c/o Mr. Ian Clark, Vice President, Human Resources, Chemin de Blandonnet 10, CH-1214 Vernier, Switzerland.

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21.   Assignment.  This Agreement shall be binding upon and inure to the benefit of and be enforceable by the parties hereto and any successors or assigns of Transocean.

TRANSOCEAN OFFSHORE DEEPWATER DRILLING, INC.

Robert L. Herrin                                                                                                                                              March 2, 2012

Date

ACCEPTANCE OF AGREEMENT BY EMPLOYEE

I hereby accept this Agreement and agree to be bound by the terms and conditions stated in it.

Accepted this 2nd day of March, 2012.

/s/ Robert Shaw                                

Robert Shaw

HOU01:1211745.11

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ANNEX 1

SUPPLEMENTAL WAIVER AND RELEASE AGREEMENT

In exchange for the payment and the other promises made by Transocean Offshore Deepwater Drilling Inc. in the letter agreement entered into among TODDI and myself dated March 2, 2012 (the “Letter Agreement”), I, Robert Shaw, on behalf of myself, my heirs, relations, successors, executors, administrators, assigns, agents, representatives, attorneys, and anyone acting on my behalf, promise and agree as follows:

I irrevocably and unconditionally release, acquit, and forever discharge Transocean Ltd. and its predecessors, successors, parent and affiliated companies (collectively, the “Transocean Group”), and its and their past and present officers, directors, attorneys, insurers, agents, servants, suppliers, representatives, employees, affiliates, subsidiaries, parent companies, partners, predecessors and successors in interest, assigns and benefit plans (except with respect to vested benefits under such plans), and any other persons or firms for whom Transocean could be legally responsible (collectively, “Released Parties”), from any and all claims, liabilities or causes of action, whether known or now unknown to me, arising from or related in any way to my employment and termination of my employment with Transocean and/or any of the Released Parties and occurring through the date I sign and return this Supplemental Waiver And Release Agreement (the“Agreement”).

I acknowledge that this Agreement is my knowing and voluntary waiver of all rights or claims arising before I accept and return this Agreement, as indicated below.  I understand and agreed that my waiver includes, but is not limited to, all waivable charges, complaints, claims, liabilities, actions, suits, rights, demands, costs, losses, damages or debts of any nature, including, but not limited to, claims arising under Title VII of the Civil Rights Act of 1964, as amended; the Civil Rights Act of 1991; the Texas Commission on Human Rights Acts; the Americans with Disabilities Act; the Age Discrimination in Employment Act, as amended; the Older Workers Benefit Protection Act; the Family and Medical Leave Act of 1993; the Texas Workers’ Compensation Act; the Texas Labor Code; the Employee Retirement Income Security Act of 1974, as amended; all state and federal statutes and regulations; and the common law, whether based in law or equity, in tort or contract.  I further acknowledge and agree that my waiver of rights or claims is in exchange for valuable payments and other promises in addition to anything of value to which I already am entitled.

I acknowledge and agree that Transocean has no obligation to reemploy, rehire or recall me, and promise that I shall not apply for re-employment with the Transocean Group.

For this Supplemental Waiver and Release Agreement, Transocean agrees to provide me the consideration set forth in Sections 2, 3, and 4 of my Letter Agreement  (the “Consideration”).  This Supplemental Waiver and Release Agreement becomes effective after I sign and return the signed Agreement per the instructions below.

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I acknowledge and understand that I am not entitled to the Consideration except in exchange for this Agreement.  Therefore, I will receive the Consideration unless I execute, date and return this Agreement to Transocean and do not revoke this Agreement within the next seven days after execution.

I warrant, acknowledge and agree that:

a.           My acceptance of this Agreement is completely voluntary;

b. I have had the opportunity to consider this Agreement for twenty-one (21) days, though I understand I may accept sooner than 21 days if I choose;

c. I am hereby being advised in writing by Transocean to consult with an attorney regarding the terms of this Agreement before accepting;

d. if I accept this Agreement, I have 7 days following the execution of this Agreement to revoke my acceptance;

e. this Agreement shall not become effective or enforceable until the 7-day revocation period has expired;

f. I am receiving under this Agreement consideration of value in addition to anything to which I already am entitled;

g. I do not waive any claims or rights that may arise after the date I sign and return this Agreement.

I acknowledge and agree that I have carefully read this Agreement and I represent, warrant and promise as follows:

a. I understand this Agreement is my release and waiver of all claims, known and unknown, past or present;

b. I have entered into this Agreement in exchange for Transocean’s promises in this Agreement, including to provide the Consideration;

c. I am fully competent to execute this Agreement, which I understand is a binding contract;

d. I accept this Agreement of my own free will, after having a reasonable period of time to review, study and deliberate regarding its meaning and effect, and without reliance on any representation of any kind or character not specifically included in writing this Agreement;

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e.           I execute this Agreement fully knowing its effect and voluntarily;

f. I understand that Transocean is relying upon the truthfulness of the statements I make in this Agreement, and I understand that Transocean would not enter into this Agreement with me or provide me the Consideration if I did not make each of the representations and promises contained in this Agreement.

This Agreement shall be interpreted and construed in accordance with and shall be governed by the laws of the State of Texas, notwithstanding any conflicts of law principles which may refer to the laws of any other jurisdiction.

To accept this Agreement, I understand that I must sign the Acceptance of Agreement (below) and have the related Notarial Acknowledgement executed by a notary public.  The fully executed Supplemental Waiver and Release Agreement should be delivered by hand to the Human Resources Department marked to the attention of Janis Peterson or mailed to the following address:

Transocean Offshore Deepwater Drilling Inc.

Attention:  Janis Peterson

P.O. Box 2765

Houston, Texas 77252-2765

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This Agreement will not be effective and no payment will be made unless the above procedure is strictly followed.  I understand that if I have any questions concerning the procedure, I may call Janis Peterson at(713) 232-7377.

ACCEPTANCE OF AGREEMENT BY EMPLOYEE

After having the opportunity to consider this Supplemental Waiver and Release Agreement, I knowingly and voluntarily choose to accept this Supplemental Waiver and Release Agreement and agree to be bound by it.

Accepted this ____ day of _____________________.

Robert Shaw

NOTARIAL ACKNOWLEDGEMENT

STATE OF            §

COUNTY OF            §

BEFORE ME, the undersigned, on this day personally appeared Robert Shaw, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that such person executed the same for the purposes and consideration therein expressed.

GIVEN UNDER MY HAND AND SEAL OF OFFICE this ____ day of _________________.

Notary Public in and for the State of

____________________________________

     HOU01:1211745.11                                                             

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EX-31.1

Exhibit 31.1

CEO CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven L. Newman, certify that:

1. I have reviewed this report on Form 10-Q of Transocean Ltd.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and we have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; and

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; and

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent function):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated:           May2, 2012 /s/ Steven L. Newman                                                               Name: Steven L. Newman President and Chief Executive Officer

EX-31.2

Exhibit 31.2

CFO CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Gregory L. Cauthen, certify that:

1. I have reviewed this report on Form 10-Q of Transocean Ltd.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and we have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; and

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; and

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent function):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated:           May 2, 2012 /s/ Gregory L. Cauthen Name: Gregory L. Cauthen Executive Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002 (SUBSECTIONS (a) AND (b)

OF SECTION 1350, CHAPTER 63 OF TITLE 18, UNITED STATES CODE)

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), I, Steven L. Newman, Chief Executive Officer of Transocean Ltd., a Swiss corporation (the “Company”), hereby certify, to my knowledge, that:

(1) the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated:           May 2, 2012 /s/ Steven L. Newman                                                                                                                                                Name: Steven L. Newman President and Chief Executive Officer

The foregoing certification is being furnished solely pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and is not being filed as part of the Report or as a separate disclosure document.

A signed original of this written statement required by Section 906 has been provided to Transocean Ltd. and will be retained by Transocean Ltd. and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO SECTION 906 OF

THE SARBANES-OXLEY ACT OF 2002 (SUBSECTIONS (a) AND (b)

OF SECTION 1350, CHAPTER 63 OF TITLE 18, UNITED STATES CODE)

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), I, Gregory L. Cauthen, Executive Vice President and Chief Financial Officer of Transocean Ltd., a Swiss corporation (the “Company”), hereby certify, to my knowledge, that:

(1) the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2012 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated:           May 2, 2012 /s/ Gregory L. Cauthen Name: Gregory L. Cauthen Executive Vice President and Chief Financial Officer

The foregoing certification is being furnished solely pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and is not being filed as part of the Report or as a separate disclosure document.

A signed original of this written statement required by Section 906 has been provided to Transocean Ltd. and will be retained by Transocean Ltd. and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2012

Financial Instruments

Carrying amounts and fair values of the financial instruments

The carrying amounts and fair values of our financial instruments were as follows (in millions):

	March 31, 2012				December 31, 2011
	Carrying amount		Fair value		Carrying amount		Fair value
Cash and cash equivalents	$	3,982	$	3,982	$	4,017	$	4,017
Accounts receivable	2,238		2,238		2,176		2,176
Notes receivable and working capital loan receivable	129		129		139		139
Restricted cash investments	913		959		928		975
Long-term debt, including current maturities	12,635		13,800		12,698		13,074
Long-term debt of consolidated variable interest entities, including current maturities	821		821		838		838
Derivative instruments, assets	36		36		36		36
Derivative instruments, liabilities	32		32		38		38

XML

Derivatives and Hedging (Details 2) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Other current assets | Derivatives designated as hedging instruments
Aggregate carrying amount of derivatives
Interest rate swaps, fair value hedges	$ 14	$ 5
Cross-currency swaps, cash flow hedges	1.0
Other assets | Derivatives designated as hedging instruments
Aggregate carrying amount of derivatives
Interest rate swaps, fair value hedges	21	31
Other current liabilities | Derivatives designated as hedging instruments
Aggregate carrying amount of derivatives
Interest rate swaps, cash flow hedges	1
Other long-term liabilities | Derivatives designated as hedging instruments
Aggregate carrying amount of derivatives
Interest rate swaps, cash flow hedges	16	16
Cross-currency swaps, cash flow hedges	2.0	7.0
Other long-term liabilities | Nondesignated
Aggregate carrying amount of derivatives
Interest rate swaps not designated as hedging instruments	$ 13	$ 15

XML

Earnings Per Share (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Numerator for earnings per share, basic
Income from continuing operations attributable to controlling interest	$ 57	$ 134
Undistributed earnings allocable to participating securities		(1)
Income from continuing operations available to shareholders	57	133
Denominator for earnings per share, basic
Weighted-average shares outstanding	350	319
Weighted-average shares for per share calculation, basic	350	319
Per share earnings from continuing operations, basic	$ 0.16	$ 0.42
Numerator for earnings per share, diluted
Income from continuing operations attributable to controlling interest	57	134
Undistributed earnings allocable to participating securities		(1)
Income from continuing operations available to shareholders	$ 57	$ 133
Denominator for earnings per share, diluted
Weighted-average shares outstanding	350	319
Effect of dilutive securities:
Stock options and other share based awards (in shares)		1
Weighted-average shares for per share calculation, diluted	350	320
Per share earnings from continuing operations, basic	$ 0.16	$ 0.42
1.50% Series B Convertible Senior Notes due December 2037
Anti-dilutive securities
Interest rate on convertible debt not having effect on earning per share calculation (as a percent)	1.50%
1.50% Series C Convertible Senior Notes due December 2037
Anti-dilutive securities
Interest rate on convertible debt not having effect on earning per share calculation (as a percent)	1.50%
Share-based awards
Anti-dilutive securities
Share-based awards excluded from earnings per share calculation	1.8	1.2

XML

Derivatives and Hedging (Details 3) (Interest rate swaps, USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Interest expense, net of amounts capitalized | Derivatives designated as hedging instruments
Effect on statement of operations resulting from changes in the fair values of derivatives designated as cash flow hedges
Loss associated with effective portion	$ 2	$ 2
Gain associated with ineffective portion	(1)
Interest expense, net of amounts capitalized | Nondesignated
Effect on statement of operations resulting from changes in the fair values of derivatives designated as cash flow hedges
Interest rate swaps not designated as hedging instruments	1
Other, net | Derivatives designated as hedging instruments
Effect on statement of operations resulting from changes in the fair values of derivatives designated as cash flow hedges
Gain associated with effective portion	$ (5)

XML

Income Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012 jurisdiction Y issue	Mar. 31, 2011	Dec. 31, 2011
Components of provision (benefit) for income taxes
Annual effective tax rate (as a percent)	25.50%	19.30%
Deferred taxes
Valuation allowance for non-current deferred tax assets	$ 181		$ 183
Unrecognized tax benefits
Unrecognized tax benefits, excluding interest and penalties	493		509
Interest and penalties	271		272
Unrecognized tax benefits, including interest and penalties	764		781
Current Tax Benefits Recognized Resulting from Settlements with Taxing Authorities and Lapse of Applicable Statute of Limitations	38
Reasonably possible percentage that unrecognized tax benefits could decrease within next twelve months, Maximum	15.00%
Reasonably possible percentage that unrecognized tax benefits could increase within next twelve months, Minimum	10.00%
Tax returns
Minimum range tax returns are subject to examination (in years)	3
Maximum range tax returns are subject to examination (in years)	6
Number of jurisdictions with extensions beyond statute of limitations	2
Maximum number of years agreed to extensions beyond the statute of limitations	17
2005 transfer pricing adjustment, exclusive of interest	50
Number of tax issues relating to assessment	2
2006 and 2007 income tax adjustments, excluding interest	278
2006 through 2009 restructuring transactions tax adjustments	295
2006 through 2009 withholding and other tax adjustments	160
Assessed penalties associated with the various adjustments for 2006 and 2007 audits	88
Net adjustments of additional taxes, excluding interest, related to assessments on 2008 and 2009 U.S. federal income tax returns	473
Brazil tax assessment for income tax returns 2000 to 2004	114
Percentage of penalties to be assessed by Brazil tax authorities	75.00%
Brazil tax assessment penalty	86
Brazil tax assessment interest	163
Norway Tax Assessments Prior to 2012
Tax returns
Norway tax assessment due to restructuring transactions	274
Norway tax assessment due to migration of subsidiary	120
Norway tax assessment due to 2001 dividend payment	72
Norway tax assessment due to foreign exchange deductions and dividend withholding taxes	7
Guarantee amount for tax assessment related to the migration of subsidiary	123
Norway tax additional financial security	754
Percentage of penalties to be assessed by Norway tax authorities	60.00%
Number of subsidiaries against which notification of criminal charges are issued	2
Number of employees of former external advisors indicted	2
Norway Tax Assessments 2012
Tax returns
Number of subsidiaries against which notification of criminal charges are issued	2
Number of employees of former external advisors indicted	2
Financial claim issued by the Norweigian authorities supplementing the criminal indictments	$ 323

XML

Drilling Fleet (Tables)

3 Months Ended

Mar. 31, 2012

Drilling Fleet

Actual capital expenditures and other capital additions, including capitalized interest

	Three months ended March 31, 2012		Through December 31, 2011		Total costs
Transocean Andaman (a)	$	19	$	119	$	138
Transocean Siam Driller (a)	19		119		138
Transocean Honor (b)	16		216		232
Ultra-Deepwater Floater TBN1 (c)	14		138		152
Ultra-Deepwater Floater TBN2 (c)	8		137		145
Deepwater Champion (d) (e)	2		776		778
Transocean Ao Thai (f)	1		79		80
Capitalized interest	13		108		121
Mobilization costs	5		26		31
Total	$	97	$	1,718	$	1,815

(a)In December 2010, we purchased Transocean Siam Driller and Transocean Andaman, two Keppel FELS Super B class design jackups, which are under construction at Keppel FELS’ yard in Singapore and are expected to commence operations in the first quarter of 2013.

(b)In November 2010, we purchased Transocean Honor, a PPL Pacific Class 400 design jackup, which was offshore Angola undergoing testing and final customer acceptance as of March 31, 2012 and is expected to commence operations in the second quarter of 2012.

(c)The costs for Ultra-Deepwater Floater TBN1 and Ultra-Deepwater Floater TBN2 include our initial investment of $136 million each, representing the estimated fair value of the rigs at the time of our acquisition of Aker Drilling, completed in October 2011.  Currently under construction at the Daewoo Shipbuilding & Marine Engineering Co. Ltd. shipyard in Korea, we expect to take delivery of the two Ultra-Deepwater drillships in the first and second quarter of 2014.

(d)The accumulated construction costs of this rig are no longer included in construction work in progress as of March 31, 2012.

(e)The costs for Deepwater Champion include our initial investment of $109 million, representing the estimated fair value of the rig at the time of our merger with GlobalSantaFe Corporation in November 2007.  Deepwater Champion commenced operations in May 2011.

(f)In June 2011, we purchased Transocean Ao Thai, a Keppel FELS Super B class design jackup, which is under construction at Keppel FELS’ yard in Singapore and is expected to commence operations in the fourth quarter of 2013.

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Contingencies (Details)	1 Months Ended			3 Months Ended
	Mar. 31, 2012 BRL	Dec. 31, 2011 USD ($)	Dec. 31, 2011 BRL	Mar. 31, 2012 USD ($) note lawsuit subsidiary plaintiff claim	Mar. 21, 2012 entity employee	Mar. 15, 2012 liters meter kilometers	Dec. 21, 2011 count employee individual	Dec. 31, 2010 USD ($) subsidiary	Dec. 15, 2010 USD ($) bbl	Jun. 30, 2010 lawsuit	Apr. 22, 2010 USD ($) mile person	Sep. 30, 2006 USD ($) subsidiary	Jul. 11, 2005 defendant landowner subsidiary
Macondo well incident
Number of persons declared dead											11
Number of miles Deepwater Horizon was off coast of Louisiana											41
Estimated liability recorded based on probable losses related to the rig explosion and fire incident		$ 1,200,000,000		$ 1,200,000,000
Portion of liability related to the rig explosion and fire incident recoverable from insurance		220,000,000		222,000,000
Percentage of non-operating interest of Anadarko in the Macondo well				25.00%
Percentage of non-operating interest of MOEX in the Macondo well				10.00%
Notices of alleged non-compliance
Number of notices issued by the Department of the Interior's Bureau of Safety and Environmental Enforcement				4
Insurance coverage
Insured status under excess liability insurance program											950,000,000
Deductible amount under excess liability insurance program											15,000,000
Amount covered by fifth layer of excess liability insurance program											250,000,000
Amount covered by third layer of excess liability insurance program											200,000,000
Amount covered by fourth layer of excess liability insurance program											200,000,000
Amount covered by second layer of excess liability insurance program											150,000,000
Amount covered by first layer of excess liability insurance program											150,000,000
Amount covered by self insured layer of excess liability insurance program											50,000,000
Number of actions or claims that were pending				373
Number of complaints filed in state and federal courts in Louisiana and Texas involving multiple plaintiffs that allege wrongful death and other personal injuries arising out of the Macondo well incident (in lawsuits)				19
Number of individual complaints filed alleging, among other things, economic losses as a result of environmental pollution arising out of the Macondo well incident (in lawsuits)				139
Number of putative class action complaints filed alleging, among other things, economic losses as a result of environmental pollution arising out of the Macondo well incident (in lawsuits)				185
Number of federal securities law class actions filed (in lawsuits)				2
Number of federal securities law class actions filed which generally allege violations of Section 10(b) of the Securities Exchange Act of 1934 (in counts)				1
Number of shareholder derivative suits filed (in lawsuits)										2
Civil penalties per barrel, Maximum (in dollars per barrel)									1,100
Civil penalties per barrel for gross negligence or willful misconduct, Maximum (in dollars per barrel)									4,300
U.S. government's maximum estimate of barrels of oil discharged and subject to penalties									4,100,000
Percentage of asset value covered by wreck removal insurance				25.00%
Asset value covered by wreck removal insurance				140,000,000
Amount agreed to indemnify and defend operator of rig				15,000,000
Brazil Frade field incident
Area of fissure of which seepage is noted						800
Distance from the November incident						3
Volume of seepage						5
Amount sought under civil public action by a federal prosecutor in Brazilian town of Campos in Rio de Janeiro State		11,000,000,000	20,000,000,000
Number of individuals for whom indictment recommended under investigation report filed							17
Number of the entity's employees for whom indictment recommended under investigation report filed							5
Number of counts on which indictment recommended under investigation report filed							4
Number of counts alleging environmental offenses on which indictment recommended under investigation report filed							3
Number of counts alleging false statements by Chevron, on which indictment recommended under investigation report filed							1
Number of employees for whom premission granted to leave the Country					2
Number of companies for whom indictment recommended under investigation report filed					2
Bail amount requested by federal prosecutor in Brazilian town of Campos In Rio De Janerio State from companies	10,000,000
Bail amount requested by federal prosecutor in Brazilian town of Campos In Rio De Janerio State from individuals	1,000,000
Amount excludable per occurrence, claim arising from negligence		250,000
Asbestos litigation
Number of complaints filed in 2004 in Mississippi regarding asbestos litigation (in lawsuits)				21
Number of plaintiffs covered by complaints filed in 2004 in Mississippi regarding asbestos litigation				769
Number of subsidiaries named as a direct defendant in amended asbestos complaints				1
Number of cases filed under amended complaint in Mississippi regarding asbestos litigation (in lawsuits)				7
Number of additional cases in which there may be an indirect interest regarding asbestos litigation (in lawsuits)				12
Number of total cases in which there may be an indirect interest regarding asbestos litigation (in lawsuits)				26
Number of cases gone to trial against defendants who allegedly manufactured or distributed drilling mud additives				7
Number of cases gone to trial against defendants, resulting in defense verdict				2
Number of cases gone to trial against defendants, ended with hung jury				1
Number of cases gone to trial against defendants, resulting in verdict for the plaintiff				4
Number of cases resulting in substantial verdict in favor of the plaintiff				2
Number of cases resulting in substantial verdict in favor of the plaintiff vacated on basis failure to meet burden of proof				1
Number of remaining plaintiff verdicts are under appeal by the defendants				2
Number of subsidiaries involved in lawsuits arising from design, construction and refurbishment of major industrial complexes				1
Number of lawsuits alleging personal injury from asbestos exposure for subsidiary involved in design, construction and refurbishment of major industrial complexes				990
Estimated number of plaintiffs in lawsuits alleging personal injury from asbestos exposure for subsidiary involved in design, construction and refurbishment of major industrial complexes				2,158
Insurance limits potentially available for damages in lawsuits regarding personal injury from asbestos exposure for subsidiary involved in design, construction and refurbishment of major industrial				1,000,000,000
Rio de Janeiro Tax Assessment
Tax assessment from state tax authorities of Rio de Janeiro in Brazil												196,000,000
Number of subsidiaries involved in Rio de Janeiro federal tax assessment relating to import license												1
Brazilian import license assessment
Number of subsidiaries involved in Rio de Janeiro federal tax assessment relating to import license								1
Tax assessment from federal tax authorities of Rio de Janeiro in Brazil relating to import license								235,000,000
Hazardous waste disposal sites
Percentage of liability for remediation and related costs from hazardous waste disposal site				8.00%
Number of subsidiaries ordered by California Regional Water Quality Control Board to develop testing plan for Alhambra, California site				1
Minimum number of subsidiaries likely to be named potentially responsible party by US Environmental Protection Agency for superfund site (in counts)				1
Contamination litigation
Number of subsidiaries served with a lawsuit alleging property contamination in Louisiana													1
Number of landowners who filed a lawsuit alleging property contamination in Louisiana													3
Number of other defendants involved in lawsuit alleging property contamination in Louisiana													19
Amount claimed by plaintiffs' experts as required remediation costs for property contamination in Louisiana				300,000,000
Amount claimed by defendants' experts as required remediation costs for property contamination in Louisiana				2,500,000
Number of additional subsidiaries plaintiff attempted to add as defendant for lawsuit alleging property contamination in Louisiana				2
Retained risk
Aggregate value of drilling rig fleet				36,000,000,000
Per occurrence insurance deductible on hull and machinery				125,000,000
Maximum aggregate insurance deductible on hull and machinery per year				250,000,000
Percentage of asset value covered by damage mitigation insurance				25.00%
Commercial market excess liability coverage				793,000,000
Per occurrence deductible on crew personal injury liability and collision liability claims				10,000,000
Per occurrence deductible on other third-party non-crew claims				5,000,000
Aggregate per occurrence deductible on other third party non-crew claims				50,000,000
Excess liability coverage through wholly-owned captive insurance company				157,000,000
Re-insured portion of excess liability coverage through wholly-owned captive insurance company				25,000,000
Liability loss limit for commercial market excess liability coverage				1,000,000,000
Additional insurance that covers expenses that would otherwise be assumed by the well owner				100,000,000
Maximum liability amount for well control and re-drilling liability related to blowouts				50,000,000
Letters of credit and surety bonds
Letters of credit outstanding		650,000,000		653,000,000
Amount of letter of credit issued on behalf of TPDI				60,000,000
Number of subsidiaries that established the letter of credit on behalf of TPDI				1
Surety bonds outstanding		$ 12,000,000		$ 12,000,000

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Condensed Consolidating Financial Information

3 Months Ended

Mar. 31, 2012

Condensed Consolidating Financial Information

Condensed Consolidating Financial Information

Note 18—Condensed Consolidating Financial Information

Transocean Inc., a wholly owned subsidiary of Transocean Ltd., is the issuer of certain notes and debentures, which have been guaranteed by Transocean Ltd.  Transocean Ltd. has also guaranteed borrowings under the Five-Year Revolving Credit Facility.  Transocean Ltd.’s guarantee of debt securities of Transocean Inc. is full and unconditional.  Transocean Ltd. is not subject to any significant restrictions on its ability to obtain funds by dividends, loans or capital distributions from its consolidated subsidiaries.

The following tables present condensed consolidating financial information for (a) Transocean Ltd. (the “Parent Guarantor”), (b) Transocean Inc. (the “Subsidiary Issuer”), and (c) the other direct and indirect wholly owned and partially owned subsidiaries of the Parent Guarantor (the “Other Subsidiaries”), none of which guarantee any indebtedness of the Subsidiary Issuer.  The tables also include the consolidating adjustments necessary to present the condensed financial statements on a consolidated basis.  The following condensed consolidating financial information may not necessarily be indicative of the results of operations, financial position or cash flows had the subsidiaries operated as independent entities (in millions):

	Three months ended March 31, 2012
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Operating revenues	$	—		$	—		$	2,336		$	(5	)	$	2,331
Cost and expenses	11			1			1,823			(5		)	1,830
Loss on impairment	—			—			(227		)	—			(227		)
Loss on disposal of assets, net	—			—			(4		)	—			(4		)
Operating income (loss)	(11		)	(1		)	282			—			270
Other income (expense), net
Interest expense, net	(3		)	(134		)	(28		)	—			(165		)
Equity in earnings	56			202			—			(258		)	—
Other, net	—			(9		)	2			—			(7		)
	53			59			(26		)	(258		)	(172		)
Income from continuing operations before income tax expense	42			58			256			(258		)	98
Income tax expense	—			—			24			—			24
Income from continuing operations	42			58			232			(258		)	74
Loss from discontinued operations, net of tax	—			—			(15		)	—			(15		)
Net Income	42			58			217			(258		)	59
Net income attributable to noncontrolling interest	—			—			17			—			17
Net income attributable to controlling interest	42			58			200			(258		)	42
Other comprehensive loss before income taxes	(4		)	(8		)	(4		)	—			(16		)
Income taxes related to other comprehensive loss	—			—			(3		)	—			(3		)
Other comprehensive loss, net of income taxes	(4		)	(8		)	(7		)	—			(19		)
Total comprehensive income	38			50			210			(258		)	40
Total comprehensive income attributable to noncontrolling interest	—			—			17			—			17
Total comprehensive income attributable to controlling interest	$	38		$	50		$	193		$	(258	)	$	23

	Three months ended March 31, 2011
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Operating revenues	$	—		$	—		$	2,148		$	(4	)	$	2,144
Cost and expenses	10			1			1,773			(4		)	1,780
Gain on disposal of assets, net	—			—			8			—			8
Operating income (loss)	(10		)	(1		)	383			—			372
Other income (expense), net
Interest income (expense), net	—			(131		)	1			—			(130		)
Equity in earnings	320			479			2			(799		)	2
Other, net	—			(23		)	24			—			1
	320			325			27			(799		)	(127		)
Income from continuing operations before income tax expense	310			324			410			(799		)	245
Income tax expense	—			—			81			—			81
Income from continuing operations	310			324			329			(799		)	164
Income from discontinued operations, net of tax	—			—			176			—			176
Net income	310			324			505			(799		)	340
Net income attributable to noncontrolling interest	—			—			30			—			30
Net income attributable to controlling interest	310			324			475			(799		)	310
Other comprehensive income (loss) before income taxes	(3		)	(5		)	11			—			3
Income taxes related to other comprehensive loss	—			—			(2		)	—			(2		)
Other comprehensive income (loss), net of income taxes	(3		)	(5		)	9			—			1
Total comprehensive income	307			319			514			(799		)	341
Total comprehensive income attributable to noncontrolling interest	—			—			34			—			34
Total comprehensive income attributable to controlling interest	$	307		$	319		$	480		$	(799	)	$	307

	March 31, 2012
	Parent Guarantor		Subsidiary Issuer		Other Subsidiaries		Consolidating adjustments			Consolidated
Assets
Cash and cash equivalents	$	5	$	2,185	$	1,792	$	—		$	3,982
Other current assets	10		877		4,290		(1,486		)	3,691
Total current assets	15		3,062		6,082		(1,486		)	7,673
Property and equipment, net	1		—		22,322		—			22,323
Goodwill	—		—		3,087		—			3,087
Investment in affiliates	16,560		27,782		—		(44,342		)	—
Other assets	—		1,642		17,605		(17,615		)	1,632
Total assets	16,576		32,486		49,096		(63,443		)	34,715
Liabilities and equity
Debt due within one year	—		2,185		607		—			2,792
Other current liabilities	17		428		4,013		(1,486		)	2,972
Total current liabilities	17		2,613		4,620		(1,486		)	5,764
Long-term debt	790		13,626		13,863		(17,615		)	10,664
Other long-term liabilities	31		467		1,928		—			2,426
Total long-term liabilities	821		14,093		15,791		(17,615		)	13,090
Commitments and contingencies	—		—		—		—			—
Redeemable noncontrolling interest	—		—		138		—			138
Total equity	15,738		15,780		28,547		(44,342		)	15,723
Total liabilities and equity	$	16,576	$	32,486	$	49,096	$	(63,443	)	$	34,715

	December 31, 2011
	Parent Guarantor		Subsidiary Issuer		Other Subsidiaries		Consolidating adjustments			Consolidated
Assets
Cash and cash equivalents	$	3	$	2,793	$	1,221	$	—		$	4,017
Other current assets	8		784		4,493		(1,693		)	3,592
Total current assets	11		3,577		5,714		(1,693		)	7,609
Property and equipment, net	1		—		22,528		—			22,529
Goodwill	—		—		3,205		—			3,205
Investment in affiliates	16,503		27,582		—		(44,085		)	—
Other assets	—		1,368		17,908		(17,531		)	1,745
Total assets	16,515		32,527		49,355		(63,309		)	35,088
Liabilities and equity
Debt due within one year	—		1,693		346		—			2,039
Other current liabilities	294		367		4,351		(1,693		)	3,319
Total current liabilities	294		2,060		4,697		(1,693		)	5,358
Long-term debt	495		14,308		14,225		(17,531		)	11,497
Other long-term liabilities	25		439		1,962		—			2,426
Total long-term liabilities	520		14,747		16,187		(17,531		)	13,923
Commitments and contingencies
Redeemable noncontrolling interest	—		—		116		—			116
Total equity	15,701		15,720		28,355		(44,085		)	15,691
Total liabilities and equity	$	16,515	$	32,527	$	49,355	$	(63,309	)	$	35,088

	Three months ended March 31, 2012
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Cash flows from operating activities	$	(15	)	$	(114	)	$	669		$	—		$	540
Cash flows from investing activities
Capital expenditures	—			—			(260		)	—			(260		)
Proceeds from disposal of assets, net	—			—			41			—			41
Investing activities with affiliates, net	—			(283		)	183			100			—
Other, net	—			10			2			—			12
Net cash provided by (used in) investing activities	—			(273		)	(34		)	100			(207		)
Cash flows from financing activities
Repayments of debt	—			(29		)	(118		)	—			(147		)
Proceeds from restricted cash investments	—			—			108			—			108
Deposits to restricted cash investments	—			—			(42		)	—			(42		)
Distribution of qualifying additional paid-in capital	(278		)	—			—			—			(278		)
Financing activities with affiliates, net	295			(183		)	(12		)	(100		)	—
Other, net	—			(9		)	—			—			(9		)
Net cash provided by (used in) financing activities	17			(221		)	(64		)	(100		)	(368		)
Net increase (decrease) in cash and cash equivalents	2			(608		)	571			—			(35		)
Cash and cash equivalents at beginning of period	3			2,793			1,221			—			4,017
Cash and cash equivalents at end of period	$	5		$	2,185		$	1,792		$	—		$	3,982

	Three months ended March 31, 2011
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Cash flows from operating activities	$	(13	)	$	(77	)	$	480		$	—		$	390
Cash flows from investing activities
Capital expenditures	—			—			(240		)	—			(240		)
Proceeds from disposal of assets, net	—			—			13			—			13
Proceeds from disposal of discontinued operations, net	—			—			259			—			259
Investing activities with affiliates, net	—			(21		)	(509		)	530			—
Other, net	—			—			(6		)	—			(6		)
Net cash provided by (used in) investing activities	—			(21		)	(483		)	530			26
Cash flows from financing activities
Changes in short-term borrowings, net	—			51			—			—			51
Proceeds from debt	—			5			—			—			5
Repayments of debt	—			(12		)	(35		)	—			(47		)
Financing activities with affiliates, net	—			509			21			(530		)	—
Other, net	—			(7		)	—			—			(7		)
Net cash provided by (used in) financing activities	—			546			(14		)	(530		)	2
Net increase (decrease) in cash and cash equivalents	(13		)	448			(17		)	—			418
Cash and cash equivalents at beginning of period	38			2,041			1,315			—			3,394
Cash and cash equivalents at end of period	$	25		$	2,489		$	1,298		$	—		$	3,812

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Drilling Fleet (Details 2) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Dispositions
Net cash proceeds from sale of assets	$ 41	$ 13
Gain (loss) on the sale of assets	(4)	8
Assets held for sale
Carrying amount	53		26
Standard Jackups Roger W. Mowell, Transocean Nordic, Transocean Shelf Explorer and Trident 17
Assets held for sale
Carrying amount	31
Sale of Standard Jackup Transocean Mercury
Dispositions
Net cash proceeds from sale of assets		10
Gain (loss) on the sale of assets		9
Gain (loss) on the sale of assets per diluted share		$ 0.03
GSF Rig 136
Dispositions
Net cash proceeds from sale of assets	36
Sale of Other Assets
Dispositions
Recognized gain (loss) on disposal of unrelated assets	$ (4)	$ (1)

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Significant Accounting Policies (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Share-based compensation expense
Share-based compensation expense	$ 23	$ 27
Capitalized interest
Capitalized interest costs on construction work in progress	$ 13	$ 15

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Redeemable Noncontrolling Interest (Tables)

3 Months Ended

Mar. 31, 2012

Redeemable Noncontrolling Interest

Changes in redeemable noncontrolling interest

	Three months ended March 31,
	2012		2011
Redeemable noncontrolling interest
Balance, beginning of period	$	116	$	25
Net income attributable to noncontrolling interest	22		28
Other comprehensive loss attributable to noncontrolling interest	—		4
Balance, end of period	$	138	$	57

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Debt (Details 2) (USD $) In Millions, unless otherwise specified			1 Months Ended	3 Months Ended		3 Months Ended		12 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Feb. 29, 2012 1.50% Series B Convertible Senior Notes due December 2037	Mar. 31, 2011 1.50% Series B Convertible Senior Notes due December 2037	Dec. 31, 2011 1.50% Series B Convertible Senior Notes due December 2037	Mar. 31, 2012 1.50% Series C Convertible Senior Notes due December 2037 Y	Mar. 31, 2011 1.50% Series C Convertible Senior Notes due December 2037	Dec. 31, 2011 1.50% Series C Convertible Senior Notes due December 2037
Carrying amounts of Convertible Senior Notes
Convertible debt instrument effective interest rate (as a percent)								5.28%
Remaining period over which discount will be amortized (in years)						1
Interest expense				$ 20		$ 21	$ 20
Principal amount outstanding					30	1,722		1,722
Debt Instrument, Unamortized Discount						44		59
Total debt	13,456	13,536			30	1,678		1,663
Carrying amount of equity component					4	276		276
Aggregate principal amount of debt repurchased			30
Aggregate cash payment made for debt repurchased			$ 30

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Financial Instruments (Details) (USD $)	Mar. 31, 2012	Dec. 31, 2011
Carrying amount
Financial instruments
Cash and cash equivalents	$ 3,982,000,000	$ 4,017,000,000
Accounts receivable	2,238,000,000	2,176,000,000
Notes receivable and working capital loan receivable	129,000,000	139,000,000
Restricted cash investments	913,000,000	928,000,000
Long-term debt, including current maturities	12,635,000,000	12,698,000,000
Long-term debt of consolidated variable interest entities, including current maturities	821,000,000	838,000,000
Derivative instruments, assets	36,000,000	36,000,000
Derivative instruments, liabilities	32,000,000	38,000,000
Notes receivable and working capital loan receivable
Notes receivable, current	26,000,000	37,000,000
Notes receivable, noncurrent	103,000,000	102,000,000
Debt
Fixed rate debt	11,900,000,000	11,900,000,000
Variable-rate debt	746,000,000	761,000,000
Carrying amount | TPDI and ADDCL Credit Facilities
Financial instruments
Restricted cash investments	56,000,000	39,000,000
Carrying amount | Aker Drilling
Financial instruments
Restricted cash investments	857,000,000	889,000,000
Fair value
Financial instruments
Cash and cash equivalents	3,982,000,000	4,017,000,000
Accounts receivable	2,238,000,000	2,176,000,000
Notes receivable and working capital loan receivable	129,000,000	139,000,000
Restricted cash investments	959,000,000	975,000,000
Long-term debt, including current maturities	13,800,000,000	13,074,000,000
Long-term debt of consolidated variable interest entities, including current maturities	821,000,000	838,000,000
Derivative instruments, assets	36,000,000	36,000,000
Derivative instruments, liabilities	32,000,000	38,000,000
Debt
Fixed rate debt	13,100,000,000	12,200,000,000
Variable-rate debt	821,000,000	838,000,000
Fair value | Aker Drilling
Financial instruments
Restricted cash investments	$ 897,000,000	$ 930,000,000

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Discontinued Operations (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended			1 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011	Oct. 31, 2011 Challenger Minerals	Feb. 28, 2011 Caspian Sea Operations
Discontinued Operations
Proceeds from disposal of discontinued operations, net		$ 259		$ 24	$ 259
Gain on the disposal of the discontinued operations before tax				12
Gain on disposal of the discontinued operations per diluted share					$ 0.52
Summarized results of discontinued operations
Operating revenues	3	26
Costs and expenses	(2)	(23)
Loss on impairment	(6)
Gain (loss) on disposal of discontinued operations, net	(14)	173			169
Income (loss) from discontinued operations before income tax expense	(19)	176
Income tax benefit	4
Income (loss) from discontinued operations, net of tax	(15)	176
Loss on impairment, net of tax	(4)
Impairment loss per diluted share from discontinued operations, net of tax	$ 0.01
Assets
Oil and gas properties, net	19		24
Other related assets	2		2
Assets held for sale	21		26
Accounts receivable	2		6
Other assets	11		25
Other current assets	13		31
Liabilities
Accounts payable	1		3
Other liabilities	8		14
Other current liabilities	$ 9		$ 17

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Significant Accounting Policies

3 Months Ended

Mar. 31, 2012

Significant Accounting Policies

Significant Accounting Policies

Note 2—Significant Accounting Policies

Basis of presentation—We have prepared our accompanying unaudited condensed consolidated financial statements in accordance with accounting principles generally accepted in the United States (“U.S.”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the U.S. Securities and Exchange Commission (“SEC”).  Pursuant to such rules and regulations, these financial statements do not include all disclosures required by accounting principles generally accepted in the U.S. for complete financial statements.  The condensed consolidated financial statements reflect all adjustments, which are, in the opinion of management, necessary for a fair presentation of financial position, results of operations and cash flows for the interim periods.  Such adjustments are considered to be of a normal recurring nature unless otherwise noted.  Operating results for the three months ended March 31, 2012 are not necessarily indicative of the results that may be expected for the year ending December 31, 2012 or for any future period.  The accompanying condensed consolidated financial statements and notes thereto should be read in conjunction with the audited consolidated financial statements and notes thereto as of December 31, 2011 and 2010 and for each of the three years in the period ended December 31, 2011 included in our annual report on Form 10-K filed on February 27, 2012.

Accounting estimates—To prepare financial statements in accordance with accounting principles generally accepted in the U.S., we are required 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, defined benefit pension plans and other postretirement benefits, contingencies and share-based compensation.  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 considerable 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 entity.  See Note 4—Variable Interest Entities.

Share-based compensation—Share-based compensation expense was $23 million and $27 million for the three months ended March 31, 2012 and 2011, respectively.

Capitalized interest—We capitalize interest costs for qualifying construction and upgrade projects.  We capitalized interest costs on construction work in progress of $13 million and $15 million for the three months ended March 31, 2012 and 2011, respectively.

Reclassifications—We have made certain reclassifications, which did not have an effect on net income, to prior period amounts to conform with the current period’s presentation.  These reclassifications did not have a material effect on our condensed 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 19—Subsequent Events.

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Condensed Consolidating Financial Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Condensed Consolidating Financial Information
Operating revenues	$ 2,331	$ 2,144
Cost and expenses	1,830	1,780
Loss on impairment	(227)
Gain (loss) on disposal of assets, net	(4)	8
Operating income	270	372
Other income (expense), net
Interest income (expense), net	(165)	(130)
Equity in earnings		2
Other, Net	(7)	1
Total other income (expense), net	(172)	(127)
Income from continuing operations before income tax expense	98	245
Income tax expense	24	81
Income from continuing operations	74	164
Income (loss) from discontinued operations, net of tax	(15)	176
Net income	59	340
Net income attributable to noncontrolling interest	17	30
Net income attributable to controlling interest	42	310
Other comprehensive income (loss) before income taxes	(16)	3
Income taxes related to other comprehensive income (loss)	(3)	(2)
Other comprehensive income (loss), net of income taxes	(19)	1
Total comprehensive income	40	341
Total comprehensive income attributable to noncontrolling interest	17	34
Total comprehensive income attributable to controlling interest	23	307
Five Year Revolving Credit Facility
Condensed Consolidating Financial Information
Term of revolving credit facility	5 years
Parent Guarantor
Condensed Consolidating Financial Information
Cost and expenses	11	10
Operating income	(11)	(10)
Other income (expense), net
Interest income (expense), net	(3)
Equity in earnings	56	320
Total other income (expense), net	53	320
Income from continuing operations before income tax expense	42	310
Income from continuing operations	42	310
Net income	42	310
Net income attributable to controlling interest	42	310
Other comprehensive income (loss) before income taxes	(4)	(3)
Other comprehensive income (loss), net of income taxes	(4)	(3)
Total comprehensive income	38	307
Total comprehensive income attributable to controlling interest	38	307
Subsidiary Issuer
Condensed Consolidating Financial Information
Cost and expenses	1	1
Operating income	(1)	(1)
Other income (expense), net
Interest income (expense), net	(134)	(131)
Equity in earnings	202	479
Other, Net	(9)	(23)
Total other income (expense), net	59	325
Income from continuing operations before income tax expense	58	324
Income from continuing operations	58	324
Net income	58	324
Net income attributable to controlling interest	58	324
Other comprehensive income (loss) before income taxes	(8)	(5)
Other comprehensive income (loss), net of income taxes	(8)	(5)
Total comprehensive income	50	319
Total comprehensive income attributable to controlling interest	50	319
Other Subsidiaries
Condensed Consolidating Financial Information
Operating revenues	2,336	2,148
Cost and expenses	1,823	1,773
Loss on impairment	(227)
Gain (loss) on disposal of assets, net	(4)	8
Operating income	282	383
Other income (expense), net
Interest income (expense), net	(28)	1
Equity in earnings		2
Other, Net	2	24
Total other income (expense), net	(26)	27
Income from continuing operations before income tax expense	256	410
Income tax expense	24	81
Income from continuing operations	232	329
Income (loss) from discontinued operations, net of tax	(15)	176
Net income	217	505
Net income attributable to noncontrolling interest	17	30
Net income attributable to controlling interest	200	475
Other comprehensive income (loss) before income taxes	(4)	11
Income taxes related to other comprehensive income (loss)	(3)	(2)
Other comprehensive income (loss), net of income taxes	(7)	9
Total comprehensive income	210	514
Total comprehensive income attributable to noncontrolling interest	17	34
Total comprehensive income attributable to controlling interest	193	480
Consolidating adjustments
Condensed Consolidating Financial Information
Operating revenues	(5)	(4)
Cost and expenses	(5)	(4)
Other income (expense), net
Equity in earnings	(258)	(799)
Total other income (expense), net	(258)	(799)
Income from continuing operations before income tax expense	(258)	(799)
Income from continuing operations	(258)	(799)
Net income	(258)	(799)
Net income attributable to controlling interest	(258)	(799)
Total comprehensive income	(258)	(799)
Total comprehensive income attributable to controlling interest	$ (258)	$ (799)

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Variable Interest Entities (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012 note drillingunit entity	Dec. 31, 2011
Consolidated variable interest entities
Variable interest entities for which we are the primary beneficiary	2
Carrying amounts associated with consolidated variable interest entities
Assets	$ 2,520	$ 2,492
Liabilities	987	1,007
Net carrying amount	1,533	1,485
Unconsolidated Variable interest entities
Number of notes receivable from sale of Midwater Floaters	2
Number of Midwater Floaters sold (in drilling units)	2
Stated interest rate on notes receivable received from sale of Midwater Floaters (as a percent)	9.00%
Stated interest rate on working capital loan (as a percent)	10.00%
Aggregate carrying amounts of notes receivable in connection with sale of Midwater Floaters	109	110
Aggregate carrying amounts of working capital loan receivable in connection with sale of Midwater Floaters	20	29
Aggregate exposure to loss on receivable instruments in connection with sale of Midwater Floaters	129
TPDI
Carrying amounts associated with consolidated variable interest entities
Assets	1,591	1,562
Liabilities	660	673
Net carrying amount	931	889
ADDCL
Carrying amounts associated with consolidated variable interest entities
Assets	929	930
Liabilities	327	334
Net carrying amount	$ 602	$ 596

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Business Combination (Tables)

3 Months Ended

Mar. 31, 2012

Business Combination

Schedule of pro forma combined operating results

	Three months ended March 31,
	2011
Operating revenues	$	2,244
Operating income	420
Income from continuing operations	167
Per share earnings from continuing operations
Basic	$	0.43
Diluted	$	0.43

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2012

Variable Interest Entities

Carrying Amounts of Variable Interest Entities

	March 31, 2012						December 31, 2011
	Assets		Liabilities		Net carrying amount		Assets		Liabilities		Net carrying amount
Variable interest entity
TPDI	$	1,591	$	660	$	931	$	1,562	$	673	$	889
ADDCL	929		327		602		930		334		596
Total	$	2,520	$	987	$	1,533	$	2,492	$	1,007	$	1,485

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Postemployment Benefit Plans (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net periodic benefit costs, before tax
Service cost	$ 19	$ 16
Interest cost	20	20
Expected Return on Plan Assets	(20)	(21)
Settlements and curtailments	2
Actuarial losses, net	11	6
Net periodic benefit costs	32	21
Funding contributions	12	21
U.S. Plans
Net periodic benefit costs, before tax
Service cost	12	11
Interest cost	14	14
Expected Return on Plan Assets	(15)	(16)
Settlements and curtailments	2
Actuarial losses, net	10	6
Net periodic benefit costs	23	15
Funding contributions	3	13
Non-U.S. Plans
Net periodic benefit costs, before tax
Service cost	7	5
Interest cost	5	5
Expected Return on Plan Assets	(5)	(5)
Actuarial losses, net	1
Net periodic benefit costs	8	5
Funding contributions	8	7
OPEB Plans
Net periodic benefit costs, before tax
Interest cost	1	1
Net periodic benefit costs	1	1
Funding contributions	$ 1	$ 1

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Business Combination (Details) (Aker Drilling)	1 Months Ended	3 Months Ended
	Oct. 31, 2011 USD ($)	Mar. 31, 2012 USD ($)	Mar. 31, 2011 USD ($)	Oct. 03, 2011 USD ($)	Oct. 03, 2011 NOK
Business Combination
Percentage of equity held by entity immediately before the acquisition date				0.99	0.99
Aggregate amount paid				$ 1,400,000,000	7,900,000,000
Purchase price allocated to assets and liabilities at estimated fair value
Current assets				323,000,000
Drilling rigs and other property and equipment				1,800,000,000
Other assets				756,000,000
Current liabilities				272,000,000
Long-term debt				1,600,000,000
Restricted cash investment	901,000,000
Goodwill				273,000,000
Contract drilling revenues associated with the operations of Aker Drilling included in operating revenues		95,000,000
Pro forma combined operating results
Operating revenues			2,244,000,000
Operating income			420,000,000
Income from continuing operations			$ 167,000,000
Per share earnings from continuing operations
Basic (in dollars per share)			$ 0.43
Diluted (in dollars per share)			$ 0.43

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2012

Income Taxes

Valuation allowance for non-current deferred tax assets

	March 31, 2012		December 31, 2011
Valuation allowance for non-current deferred tax assets	$	181	$	183

Schedule of unrecognized tax benefits, including related interest and penalties

	March 31, 2012		December 31, 2011
Unrecognized tax benefits, excluding interest and penalties	$	493	$	509
Interest and penalties	271		272
Unrecognized tax benefits, including interest and penalties	$	764	$	781

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Discontinued Operations (Tables)

3 Months Ended

Mar. 31, 2012

Discontinued Operations

Summarized results of discontinued operations

	Three months ended March 31,
	2012			2011
Operating revenues	$	3		$	26
Costs and expenses	(2		)	(23		)
Loss on impairment (a)	(6		)	—
Gain (loss) on disposal of discontinued operations, net	(14		)	173
Income (loss) from discontinued operations before income tax expense	(19		)	176
Income tax benefit	4			—
Income (loss) from discontinued operations, net of tax	$	(15	)	$	176

(a)During the three months ended March 31, 2012, we recognized a loss on impairment of our oil and gas properties, which were classified as assets held for sale, in the amount of $6 million ($4 million or $0.01 per diluted share from discontinued operations, net of tax) since the carrying amount of the properties exceeded the estimated fair value less costs to sell the properties.  We estimated fair value based on significant observable inputs, representing a Level 1 fair value measurement, including a binding sale and purchase agreement for the properties.

Assets and liabilities of discontinued operations

	March 31, 2012		December 31, 2011
Assets
Oil and gas properties, net	$	19	$	24
Other related assets	2		2
Assets held for sale	$	21	$	26
Accounts receivable	$	2	$	6
Other assets	11		25
Other current assets	$	13	$	31
Liabilities
Accounts payable	$	1	$	3
Other liabilities	8		14
Other current liabilities	$	9	$	17

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Nature of Business

3 Months Ended

Mar. 31, 2012

Nature of Business

Nature of Business

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 March 31, 2012, we owned or had partial ownership interests in and operated 130 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, 45 Standard Jackups and one swamp barge.  In addition, we had two Ultra-Deepwater drillships 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 United Kingdom (“U.K”). subsidiaries (together, “ADTI”).  ADTI conducts drilling management services primarily on either a dayrate or a completed-project, fixed-price (or “turnkey”) basis.

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2012

Earnings Per Share

Earnings Per Share

	Three months ended March 31,
	2012				2011
	Basic		Diluted		Basic			Diluted
Numerator for earnings per share
Income from continuing operations attributable to controlling interest	$	57	$	57	$	134		$	134
Undistributed earnings allocable to participating securities	—		—		(1		)	(1		)
Income from continuing operations available to shareholders	$	57	$	57	$	133		$	133
Denominator for earnings per share
Weighted-average shares outstanding	350		350		319			319
Effect of stock options and other share-based awards	—		—		—			1
Weighted-average shares for per share calculation	350		350		319			320
Per share earnings from continuing operations	$	0.16	$	0.16	$	0.42		$	0.42

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Condensed Consolidating Financial Information (Tables)

3 Months Ended

Mar. 31, 2012

Condensed Consolidating Financial Information

Schedule of condensed consolidating statement of operations

	Three months ended March 31, 2012
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Operating revenues	$	—		$	—		$	2,336		$	(5	)	$	2,331
Cost and expenses	11			1			1,823			(5		)	1,830
Loss on impairment	—			—			(227		)	—			(227		)
Loss on disposal of assets, net	—			—			(4		)	—			(4		)
Operating income (loss)	(11		)	(1		)	282			—			270
Other income (expense), net
Interest expense, net	(3		)	(134		)	(28		)	—			(165		)
Equity in earnings	56			202			—			(258		)	—
Other, net	—			(9		)	2			—			(7		)
	53			59			(26		)	(258		)	(172		)
Income from continuing operations before income tax expense	42			58			256			(258		)	98
Income tax expense	—			—			24			—			24
Income from continuing operations	42			58			232			(258		)	74
Loss from discontinued operations, net of tax	—			—			(15		)	—			(15		)
Net Income	42			58			217			(258		)	59
Net income attributable to noncontrolling interest	—			—			17			—			17
Net income attributable to controlling interest	42			58			200			(258		)	42
Other comprehensive loss before income taxes	(4		)	(8		)	(4		)	—			(16		)
Income taxes related to other comprehensive loss	—			—			(3		)	—			(3		)
Other comprehensive loss, net of income taxes	(4		)	(8		)	(7		)	—			(19		)
Total comprehensive income	38			50			210			(258		)	40
Total comprehensive income attributable to noncontrolling interest	—			—			17			—			17
Total comprehensive income attributable to controlling interest	$	38		$	50		$	193		$	(258	)	$	23

	Three months ended March 31, 2011
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Operating revenues	$	—		$	—		$	2,148		$	(4	)	$	2,144
Cost and expenses	10			1			1,773			(4		)	1,780
Gain on disposal of assets, net	—			—			8			—			8
Operating income (loss)	(10		)	(1		)	383			—			372
Other income (expense), net
Interest income (expense), net	—			(131		)	1			—			(130		)
Equity in earnings	320			479			2			(799		)	2
Other, net	—			(23		)	24			—			1
	320			325			27			(799		)	(127		)
Income from continuing operations before income tax expense	310			324			410			(799		)	245
Income tax expense	—			—			81			—			81
Income from continuing operations	310			324			329			(799		)	164
Income from discontinued operations, net of tax	—			—			176			—			176
Net income	310			324			505			(799		)	340
Net income attributable to noncontrolling interest	—			—			30			—			30
Net income attributable to controlling interest	310			324			475			(799		)	310
Other comprehensive income (loss) before income taxes	(3		)	(5		)	11			—			3
Income taxes related to other comprehensive loss	—			—			(2		)	—			(2		)
Other comprehensive income (loss), net of income taxes	(3		)	(5		)	9			—			1
Total comprehensive income	307			319			514			(799		)	341
Total comprehensive income attributable to noncontrolling interest	—			—			34			—			34
Total comprehensive income attributable to controlling interest	$	307		$	319		$	480		$	(799	)	$	307

Schedule of condensed consolidating balance sheet

	March 31, 2012
	Parent Guarantor		Subsidiary Issuer		Other Subsidiaries		Consolidating adjustments			Consolidated
Assets
Cash and cash equivalents	$	5	$	2,185	$	1,792	$	—		$	3,982
Other current assets	10		877		4,290		(1,486		)	3,691
Total current assets	15		3,062		6,082		(1,486		)	7,673
Property and equipment, net	1		—		22,322		—			22,323
Goodwill	—		—		3,087		—			3,087
Investment in affiliates	16,560		27,782		—		(44,342		)	—
Other assets	—		1,642		17,605		(17,615		)	1,632
Total assets	16,576		32,486		49,096		(63,443		)	34,715
Liabilities and equity
Debt due within one year	—		2,185		607		—			2,792
Other current liabilities	17		428		4,013		(1,486		)	2,972
Total current liabilities	17		2,613		4,620		(1,486		)	5,764
Long-term debt	790		13,626		13,863		(17,615		)	10,664
Other long-term liabilities	31		467		1,928		—			2,426
Total long-term liabilities	821		14,093		15,791		(17,615		)	13,090
Commitments and contingencies	—		—		—		—			—
Redeemable noncontrolling interest	—		—		138		—			138
Total equity	15,738		15,780		28,547		(44,342		)	15,723
Total liabilities and equity	$	16,576	$	32,486	$	49,096	$	(63,443	)	$	34,715

	December 31, 2011
	Parent Guarantor		Subsidiary Issuer		Other Subsidiaries		Consolidating adjustments			Consolidated
Assets
Cash and cash equivalents	$	3	$	2,793	$	1,221	$	—		$	4,017
Other current assets	8		784		4,493		(1,693		)	3,592
Total current assets	11		3,577		5,714		(1,693		)	7,609
Property and equipment, net	1		—		22,528		—			22,529
Goodwill	—		—		3,205		—			3,205
Investment in affiliates	16,503		27,582		—		(44,085		)	—
Other assets	—		1,368		17,908		(17,531		)	1,745
Total assets	16,515		32,527		49,355		(63,309		)	35,088
Liabilities and equity
Debt due within one year	—		1,693		346		—			2,039
Other current liabilities	294		367		4,351		(1,693		)	3,319
Total current liabilities	294		2,060		4,697		(1,693		)	5,358
Long-term debt	495		14,308		14,225		(17,531		)	11,497
Other long-term liabilities	25		439		1,962		—			2,426
Total long-term liabilities	520		14,747		16,187		(17,531		)	13,923
Commitments and contingencies
Redeemable noncontrolling interest	—		—		116		—			116
Total equity	15,701		15,720		28,355		(44,085		)	15,691
Total liabilities and equity	$	16,515	$	32,527	$	49,355	$	(63,309	)	$	35,088

Schedule of condensed consolidating statement of cash flows

	Three months ended March 31, 2012
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Cash flows from operating activities	$	(15	)	$	(114	)	$	669		$	—		$	540
Cash flows from investing activities
Capital expenditures	—			—			(260		)	—			(260		)
Proceeds from disposal of assets, net	—			—			41			—			41
Investing activities with affiliates, net	—			(283		)	183			100			—
Other, net	—			10			2			—			12
Net cash provided by (used in) investing activities	—			(273		)	(34		)	100			(207		)
Cash flows from financing activities
Repayments of debt	—			(29		)	(118		)	—			(147		)
Proceeds from restricted cash investments	—			—			108			—			108
Deposits to restricted cash investments	—			—			(42		)	—			(42		)
Distribution of qualifying additional paid-in capital	(278		)	—			—			—			(278		)
Financing activities with affiliates, net	295			(183		)	(12		)	(100		)	—
Other, net	—			(9		)	—			—			(9		)
Net cash provided by (used in) financing activities	17			(221		)	(64		)	(100		)	(368		)
Net increase (decrease) in cash and cash equivalents	2			(608		)	571			—			(35		)
Cash and cash equivalents at beginning of period	3			2,793			1,221			—			4,017
Cash and cash equivalents at end of period	$	5		$	2,185		$	1,792		$	—		$	3,982

	Three months ended March 31, 2011
	Parent Guarantor			Subsidiary Issuer			Other Subsidiaries			Consolidating adjustments			Consolidated
Cash flows from operating activities	$	(13	)	$	(77	)	$	480		$	—		$	390
Cash flows from investing activities
Capital expenditures	—			—			(240		)	—			(240		)
Proceeds from disposal of assets, net	—			—			13			—			13
Proceeds from disposal of discontinued operations, net	—			—			259			—			259
Investing activities with affiliates, net	—			(21		)	(509		)	530			—
Other, net	—			—			(6		)	—			(6		)
Net cash provided by (used in) investing activities	—			(21		)	(483		)	530			26
Cash flows from financing activities
Changes in short-term borrowings, net	—			51			—			—			51
Proceeds from debt	—			5			—			—			5
Repayments of debt	—			(12		)	(35		)	—			(47		)
Financing activities with affiliates, net	—			509			21			(530		)	—
Other, net	—			(7		)	—			—			(7		)
Net cash provided by (used in) financing activities	—			546			(14		)	(530		)	2
Net increase (decrease) in cash and cash equivalents	(13		)	448			(17		)	—			418
Cash and cash equivalents at beginning of period	38			2,041			1,315			—			3,394
Cash and cash equivalents at end of period	$	25		$	2,489		$	1,298		$	—		$	3,812

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Derivatives and Hedging (Details) In Millions, unless otherwise specified					3 Months Ended
	Mar. 31, 2012 4.95% Senior Notes due November 2015	Mar. 31, 2012 5.25% Senior Notes due March 2013	Mar. 31, 2012 5% Notes due February 2013	Mar. 31, 2012 11% Callable Bonds	Mar. 31, 2012 Interest rate swaps Derivatives designated as hedging instruments subsidiary	Mar. 31, 2012 Interest rate swaps Derivative not designated as hedging instruments USD ($)	Mar. 31, 2012 Interest rate swaps 4.95% Senior Notes due November 2015 Derivatives designated as hedging instruments	Mar. 31, 2012 Interest rate swaps 5.25% Senior Notes due March 2013 Derivatives designated as hedging instruments	Mar. 31, 2012 Interest rate swaps 5% Notes due February 2013 Derivatives designated as hedging instruments	Mar. 31, 2012 Interest rate swaps Fair value hedges Derivatives designated as hedging instruments USD ($)	Mar. 31, 2012 Interest rate swaps Cash flow hedges Derivatives designated as hedging instruments USD ($)	Mar. 31, 2012 Cross-currency swaps Cash flow hedges Derivatives designated as hedging instruments USD ($)	Mar. 31, 2012 Cross-currency swaps Cash flow hedges Derivatives designated as hedging instruments NOK
Derivatives and Hedging
Number of wholly owned subsidiaries in interest rate swap agreements					2
Derivative, underlying risk					interest rate
Derivative, hedge designation					fair value
Interest rate on notes hedged to reduce exposure to changes in fair value (as a percent)	4.95%	5.25%	5.00%	11.00%			4.95%	5.25%	5.00%
Interest rate description to determine the variable interest on debt hedged					three-month London Interbank Offered Rate
Aggregate notional amount						$ 241				$ 1,400	$ 438
Weighted average variable rate (as a percent)						0.50%				3.70%	0.50%
Weighted average fixed rate (as a percent)						4.20%				5.10%	2.30%
Notional amount, pay												102
Notional amount, receive													560
Weighted average fixed rate, pay (as a percent)												8.90%	8.90%
Weighted average fixed rate, receive (as a percent)												11.00%	11.00%

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating revenues
Contract drilling revenues	$ 2,203	$ 1,950
Contract drilling intangible revenues	11	10
Other revenues	117	184
Total operating revenues	2,331	2,144
Costs and expenses
Operating and maintenance	1,410	1,359
Depreciation and amortization	351	354
General and administrative	69	67
Total costs and expenses	1,830	1,780
Loss on impairment	(227)
Gain (loss) on disposal of assets, net	(4)	8
Operating income	270	372
Other income (expense), net
Interest income	15	15
Interest expense, net of amounts capitalized	(180)	(145)
Other, net	(7)	3
Total other income (expense), net	(172)	(127)
Income from continuing operations before income tax expense	98	245
Income tax expense	24	81
Income from continuing operations	74	164
Income (loss) from discontinued operations, net of tax	(15)	176
Net income	59	340
Net income attributable to noncontrolling interest	17	30
Net income attributable to controlling interest	$ 42	$ 310
Earnings per share-basic
Earnings from continuing operations (in dollars per share)	$ 0.16	$ 0.42
Earnings (loss) from discontinued operations (in dollars per share)	$ (0.04)	$ 0.54
Earnings per share (in dollars per share)	$ 0.12	$ 0.96
Earnings per share-diluted
Earnings from continuing operations (in dollars per share)	$ 0.16	$ 0.42
Earnings (loss) from discontinued operations (in dollars per share)	$ (0.04)	$ 0.54
Earnings per share (in dollars per share)	$ 0.12	$ 0.96
Weighted-average shares outstanding
Basic (in shares)	350	319
Diluted (in shares)	350	320

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Impairments (Details) (USD $)	3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Impairment of goodwill and other indefinite-lived intangible assets
Estimated loss on impairment of goodwill		$ 5,200,000,000
Estimate of loss on impairment of goodwill per diluted share		$ 16.15
Adjustment to original estimate of goodwill	118,000,000
Adjustment to original estimate of goodwill, per diluted share	$ 0.34
GSF Rig 136
Assets held for sale
Loss on impairment of assets held for sale	17,000,000
Loss on impairment of assets per diluted share	$ 0.05
Trade name intangible asset
Assets held for sale
Loss on impairment of assets per diluted share	$ 0.07
Impairment of goodwill and other indefinite-lived intangible assets
Impairment loss on indefinite-lived intangible asset	39,000,000
Impairment loss on indefinite-lived intangible asset, continuing operations, net of tax	25,000,000
Customer relationships
Assets held for sale
Loss on impairment of assets per diluted share	$ 0.11
Impairment of definite-lived intangible assets
Impairment loss on finite-lived intangible asset	53,000,000
Impairment loss on finite-lived intangible asset, continuing operations	$ 37,000,000

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (USD $) In Millions, unless otherwise specified	Total	Total controlling interest shareholders' equity	Shares	Additional paid-in capital	Treasury shares, at cost	Retained earnings	Accumulated other comprehensive loss	Noncontrolling interest
Balance at Dec. 31, 2010	$ 21,375	$ 21,383	$ 4,482	$ 7,504	$ (240)	$ 9,969	$ (332)	$ (8)
Balance (in shares) at Dec. 31, 2010			319
Increase (Decrease) in Shareholders' Equity
Share-based compensation	27	27		27
Issuance of shares under share-based compensation plans	(10)	(10)	6	(16)
Issuance of shares under share-based compensation plans (in shares)			1
Net income attributable to controlling interest	310					310
Other comprehensive loss attributable to controlling interest							(3)
Total comprehensive income attributable to controlling interest	307	307
Total comprehensive income (loss) attributable to noncontrolling interest	34							3
Total comprehensive income	310
Other, net	3	3		3
Balance at Mar. 31, 2011	21,705	21,710	4,488	7,518	(240)	10,279	(335)	(5)
Balance (in shares) at Mar. 31, 2011			320
Balance at Dec. 31, 2011	15,691	15,701	4,982	7,211	(240)	4,244	(496)	(10)
Balance (in shares) at Dec. 31, 2011			350
Increase (Decrease) in Shareholders' Equity
Share-based compensation	23	23		23
Issuance of shares under share-based compensation plans	(8)	(8)	9	(17)
Issuance of shares under share-based compensation plans (in shares)			1
Net income attributable to controlling interest	42					42
Other comprehensive loss attributable to controlling interest							(19)
Total comprehensive income attributable to controlling interest	23	23
Total comprehensive income (loss) attributable to noncontrolling interest	17							(5)
Total comprehensive income	18
Other, net	(1)	(1)		(1)
Balance at Mar. 31, 2012	$ 15,723	$ 15,738	$ 4,991	$ 7,216	$ (240)	$ 4,286	$ (515)	$ (15)
Balance (in shares) at Mar. 31, 2012			351

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Shareholders' Equity (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	1 Months Ended	3 Months Ended
	Dec. 31, 2008 subsidiary	Mar. 31, 2012	Dec. 31, 2011	May 31, 2011 installment
Distribution of qualifying additional paid-in capital
Cash distribution approved in the form of additional paid-in capital (in dollars per share)				$ 3.16
Number of quarterly installments (in installments)				4
Amount of installment (in dollars per share)				$ 0.79
Installment of dividend paid		$ 278
Shares held by subsidiary
Number of issued shares to a subsidiary to satisfy obligations in connection with awards granted under incentive plans or other rights to acquire shares of stocks	16
Number of subsidiaries to whom shares were issued	1
Number of shares held by subsidiary		12	12

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Derivatives and Hedging (Tables)

3 Months Ended

Mar. 31, 2012

Derivatives designated as hedging instruments

Derivatives designated as hedging and not designated as hedging instruments

Schedule of effect on the entity's condensed consolidated statement of operations resulting from changes in the fair values of derivatives designated as cash flow hedges

		Three months ended March 31,
	Statement of operations classification	2012			2011
Loss associated with effective portion	Interest expense, net of amounts capitalized	$	2		$	2
Gain associated with ineffective portion	Interest expense, net of amounts capitalized	(1		)	—
Gain associated with effective portion	Other, net	(5		)	—

Schedule of balance sheet classification and aggregate carrying amount of the entity's derivatives measured at fair value

	Balance sheet classification	March 31, 2012		December 31, 2011
Interest rate swaps, fair value hedges	Other current assets	$	14	$	5
Interest rate swaps, fair value hedges	Other assets	21		31
Interest rate swaps, cash flow hedges	Other current liabilities	1		—
Interest rate swaps, cash flow hedges	Other long-term liabilities	16		16
Cross-currency swaps, cash flow hedges	Other current assets	1		—
Cross-currency swaps, cash flow hedges	Other long-term liabilities	2		7

Derivatives designated as hedging instruments | Interest rate swaps

Derivatives designated as hedging and not designated as hedging instruments

Schedule of aggregate notional amounts and the weighted average interest rates associated with derivatives

	Aggregate notional amount		Weighted average variable rate		Weighted average fixed rate
Interest rate swaps, fair value hedges	$	1,400	3.7	%	5.1	%
Interest rate swaps, cash flow hedges	438		0.5	%	2.3	%

Derivatives designated as hedging instruments | Cross-currency swaps

Derivatives designated as hedging and not designated as hedging instruments

Schedule of aggregate notional amounts and the weighted average interest rates associated with derivatives

	Pay				Receive
	Notional amount		Weighted average fixed rate		Notional amount		Weighted average fixed rate
Cross-currency swaps, cash flow hedges	$	102	8.9	%	NOK	560	11	%

Derivative not designated as hedging instruments | Interest rate swaps

Derivatives designated as hedging and not designated as hedging instruments

Schedule of aggregate notional amounts and the weighted average interest rates associated with derivatives

	Aggregate notional amount		Weighted average variable rate		Weighted average fixed rate
Interest rate swaps not designated as hedging instruments	$	241	0.5	%	4.2	%

Schedule of effect on the entity's condensed consolidated statement of operations resulting from changes in the fair values of derivatives designated as cash flow hedges

		Three months ended March 31,
	Statement of operations classification	2012		2011
Interest rate swaps not designated as hedging instruments	Interest expense, net of amounts capitalized	$	1	$	—

Schedule of balance sheet classification and aggregate carrying amount of the entity's derivatives measured at fair value

	Balance sheet classification	March 31, 2012		December 31, 2011
Interest rate swaps not designated as hedging instruments	Other long-term liabilities	$	13	$	15

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Subsequent Events (Details)	1 Months Ended				1 Months Ended
	Dec. 31, 2011 USD ($)	Dec. 31, 2011 BRL	Apr. 30, 2012 Tax investigations subsidiary	Mar. 31, 2012 Drilling fleet Standard Jackups, GSF Adriatic II USD ($)	Apr. 30, 2012 Brazil Frade field incident developments in 2012 USD ($)	Mar. 31, 2012 Debt Aker Drilling USD ($)
Subsequent Events
Number of subsidiaries against which notification of criminal charges are issued			2
Number of subsidiaries against which notification of criminal charges are extending			1
Carrying value of drilling fleet assets reclassified to assets held for sale				$ 54,000,000
Prepayment of debt						115,000,000
Amount sought under civil public action filed in 2012 by a federal prosecutor in Brazilian town of Campos in Rio de Janeiro State	$ 11,000,000,000	20,000,000,000			$ 11,000,000,000

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Redeemable Noncontrolling Interest

3 Months Ended

Mar. 31, 2012

Redeemable Noncontrolling Interest

Redeemable Noncontrolling Interest

Note 15—Redeemable Noncontrolling Interest

Quantum owns the 50 percent interest in TPDI that is not owned by us and has the unilateral right, pursuant to a put option agreement, to exchange its interest in TPDI for our shares or cash, at its election, at an amount based on an appraisal of the fair value of the drillships that are owned by TPDI, subject to certain adjustments.  Accordingly, we present Quantum’s interest as redeemable noncontrolling interest on our condensed consolidated balance sheets.  Changes in redeemable noncontrolling interest were as follows (in millions):

	Three months ended March 31,
	2012		2011
Redeemable noncontrolling interest
Balance, beginning of period	$	116	$	25
Net income attributable to noncontrolling interest	22		28
Other comprehensive loss attributable to noncontrolling interest	—		4
Balance, end of period	$	138	$	57

On February 29, 2012, Quantum exercised its rights under the put option agreement, and on March 29, 2012, Quantum elected to exchange its interest in TPDI for our shares, net of Quantum’s share of TPDI’s indebtedness.  Quantum has the right, prior to closing of this exchange, to change its election to cash, net of Quantum’s share of TPDI’s indebtedness.  Therefore, we have continued to present Quantum’s interest as redeemable noncontrolling interest on our condensed consolidated balance sheets.

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Postemployment Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2012

Postemployment Benefit Plans

Net Periodic Benefit Costs Before Tax

	Three months ended March 31, 2012											Three months ended March 31, 2011
	U.S. Plans			Non-U.S. Plans			OPEB Plans		Total			U.S. Plans			Non-U.S. Plans			OPEB Plans		Total
Net periodic benefit costs
Service cost	$	12		$	7		$	—	$	19		$	11		$	5		$	—	$	16
Interest cost	14			5			1		20			14			5			1		20
Expected return on plan assets	(15		)	(5		)	—		(20		)	(16		)	(5		)	—		(21		)
Settlements and curtailments	2			—			—		2			—			—			—		—
Actuarial losses, net	10			1			—		11			6			—			—		6
Prior service cost, net	—			—			—		—			—			—			—		—
Transition obligation, net	—			—			—		—			—			—			—		—
Net periodic benefit costs	$	23		$	8		$	1	$	32		$	15		$	5		$	1	$	21
Funding contributions	$	3		$	8		$	1	$	12		$	13		$	7		$	1	$	21

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Financial Instruments

3 Months Ended

Mar. 31, 2012

Financial Instruments

Financial Instruments

Note 17—Financial Instruments

The carrying amounts and fair values of our financial instruments were as follows (in millions):

	March 31, 2012				December 31, 2011
	Carrying amount		Fair value		Carrying amount		Fair value
Cash and cash equivalents	$	3,982	$	3,982	$	4,017	$	4,017
Accounts receivable	2,238		2,238		2,176		2,176
Notes receivable and working capital loan receivable	129		129		139		139
Restricted cash investments	913		959		928		975
Long-term debt, including current maturities	12,635		13,800		12,698		13,074
Long-term debt of consolidated variable interest entities, including current maturities	821		821		838		838
Derivative instruments, assets	36		36		36		36
Derivative instruments, liabilities	32		32		38		38

We estimated the fair value of each class of financial instruments, for which estimating fair value is practicable, by applying the following methods and assumptions:

Cash and cash equivalents—The carrying amount of cash and cash equivalents, which are stated at cost plus accrued interest, approximates fair value because of the short maturities of those instruments.

Accounts receivable—The carrying amount, net of valuation allowance, approximates fair value because of the short maturities of those instruments.

Notes receivable and working capital loan receivable—The aggregate carrying amount represents the amortized cost of our investments, which approximates the estimated fair value.  We measured the estimated fair value using significant unobservable inputs, representing a Level 3 fair value measurement, including the credit ratings of the borrowers.  At March 31, 2012, the aggregate carrying amount of our notes receivable and working capital loan receivable was $129 million, including $26 million and $103 million recorded in other current assets and other assets, respectively.  At December 31, 2011, the aggregate carrying amount of our notes receivable and working capital loan receivable was $139 million, including $37 million and $102 million recorded in other current assets and other assets, respectively.

Restricted cash investments—The carrying amount of the Aker Restricted Cash Investments represents the amortized cost of our investment, which was at $857 million and $889 million at March 31, 2012 and December 31, 2011, respectively.  We measured the estimated fair value of the Aker Restricted Investments using significant other observable inputs, representing a Level 2 fair value measurement.  The estimated fair value of the Aker Restricted Cash Investments was $897 million and $930 million at March 31, 2012 and December 31, 2011, respectively.

The aggregate carrying amount of the restricted cash investments for the TPDI Credit Facilities and the ADDCL Credit Facilities approximates fair value due to the short term nature of the instruments in which the restricted cash investments are held.  The aggregate carrying amount of the restricted cash investments for the TPDI Credit Facilities and the ADDCL Credit Facilities was $56 million and $39 million at March 31, 2012 and December 31, 2011, respectively.

Debt—The aggregate carrying amount of our fixed-rate debt was $11.9 billion at March 31, 2012 and December 31, 2011.  We measured the estimated fair value of our fixed-rate debt using significant other observable inputs, representing a Level 2 fair value measurement, including the terms and credit spreads for the instruments.  The aggregate estimated fair value of our fixed-rate debt was $13.1 billion and $12.2 billion at March 31, 2012 and December 31, 2011, respectively.

The aggregate carrying amount of our variable-rate debt approximates fair value because the terms of those debt instruments include short-term interest rates and exclude penalties for prepayment.  We measured the estimated fair value of our variable-rate debt using significant other observable inputs, representing a Level 2 fair value measurement, including the terms and credit spreads for the instruments.  The aggregate carrying amount of our variable-rate debt was $746 million and $761 million at March 31, 2012 and December 31, 2011, respectively.

Debt of consolidated variable interest entities—The aggregate carrying amount of the variable-rate debt of our consolidated variable interest entities approximates fair value because the terms of those debt instruments include short-term interest rates and exclude penalties for prepayments.  We measured the estimated fair value of the debt of our consolidated variable interest entities using significant other observable inputs, representing a Level 2 fair value measurement, including the terms and credit spreads of the instruments.  The aggregate carrying amount of the variable-rate debt of our consolidated variable interest entities was $821 million and $838 million at March 31, 2012 and December 31, 2011, respectively.

Derivative instruments—The aggregate carrying amount of our derivative instruments represents the estimated fair value, measured using significant other observable inputs, representing a Level 2 fair value measurement, including the interest rates and terms of the instruments.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Cash flows from operating activities
Net income	$ 59	$ 340
Adjustments to reconcile to net cash provided by operating activities:
Amortization of drilling contract intangibles	(11)	(10)
Depreciation and amortization	351	354
Share-based compensation expense	23	27
Loss on impairment	227
(Gain) loss on disposal of assets, net	4	(8)
(Gain) loss on disposal of discontinued operations, net	14	(173)
Amortization of debt issue costs, discounts and premiums, net	18	26
Deferred income taxes	(30)	11
Other, net	21	(3)
Changes in deferred revenue, net	(12)	46
Changes in deferred expenses, net	(49)	(36)
Changes in operating assets and liabilities	(75)	(184)
Net cash provided by operating activities	540	390
Cash flows from investing activities
Capital expenditures	(260)	(240)
Proceeds from disposal of assets, net	41	13
Proceeds from disposal of discontinued operations, net		259
Other, net	12	(6)
Net cash provided by (used in) investing activities	(207)	26
Cash flows from financing activities
Changes in short-term borrowings, net		51
Proceeds from debt		5
Repayments of debt	(147)	(47)
Proceeds from restricted cash investments	108
Deposits to restricted cash investments	(42)
Distribution of qualifying additional paid-in capital	(278)
Other, net	(9)	(7)
Net cash provided by (used in) financing activities	(368)	2
Net increase (decrease) in cash and cash equivalents	(35)	418
Cash and cash equivalents at beginning of period	4,017	3,394
Cash and cash equivalents at end of period	$ 3,982	$ 3,812

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net income	$ 59	$ 340
Other comprehensive income (loss) before income taxes
Unrecognized components of net periodic benefit costs	(28)	(6)
Unrecognized gain on derivative instruments	2	1
Recognized components of net periodic benefit costs	13	6
Recognized (gain) loss on derivative instruments	(3)	2
Other comprehensive income (loss) before income taxes	(16)	3
Income taxes related to other comprehensive income (loss)	(3)	(2)
Other comprehensive income (loss), net of income taxes	(19)	1
Total comprehensive income	40	341
Total comprehensive income attributable to noncontrolling interest	17	34
Total comprehensive income attributable to controlling interest	$ 23	$ 307

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Drilling Fleet

3 Months Ended

Mar. 31, 2012

Drilling Fleet

Drilling Fleet

Note 10—Drilling Fleet

Expansion—Construction work in progress, recorded in property and equipment, was $1.6 billion and $1.4 billion at March 31, 2012 and December 31, 2011, respectively.  Capital expenditures and other capital additions, including capitalized interest, for our major construction projects during the three months ended March 31, 2012 or during the year ended December 31, 2011 were as follows (in millions):

	Three months ended March 31, 2012		Through December 31, 2011		Total costs
Transocean Andaman (a)	$	19	$	119	$	138
Transocean Siam Driller (a)	19		119		138
Transocean Honor (b)	16		216		232
Ultra-Deepwater Floater TBN1 (c)	14		138		152
Ultra-Deepwater Floater TBN2 (c)	8		137		145
Deepwater Champion (d) (e)	2		776		778
Transocean Ao Thai (f)	1		79		80
Capitalized interest	13		108		121
Mobilization costs	5		26		31
Total	$	97	$	1,718	$	1,815

(a)In December 2010, we purchased Transocean Siam Driller and Transocean Andaman, two Keppel FELS Super B class design jackups, which are under construction at Keppel FELS’ yard in Singapore and are expected to commence operations in the first quarter of 2013.

(b)In November 2010, we purchased Transocean Honor, a PPL Pacific Class 400 design jackup, which was offshore Angola undergoing testing and final customer acceptance as of March 31, 2012 and is expected to commence operations in the second quarter of 2012.

(c)The costs for Ultra-Deepwater Floater TBN1 and Ultra-Deepwater Floater TBN2 include our initial investment of $136 million each, representing the estimated fair value of the rigs at the time of our acquisition of Aker Drilling, completed in October 2011.  Currently under construction at the Daewoo Shipbuilding & Marine Engineering Co. Ltd. shipyard in Korea, we expect to take delivery of the two Ultra-Deepwater drillships in the first and second quarter of 2014.

(d)The accumulated construction costs of this rig are no longer included in construction work in progress as of March 31, 2012.

(e)The costs for Deepwater Champion include our initial investment of $109 million, representing the estimated fair value of the rig at the time of our merger with GlobalSantaFe Corporation in November 2007.  Deepwater Champion commenced operations in May 2011.

(f)In June 2011, we purchased Transocean Ao Thai, a Keppel FELS Super B class design jackup, which is under construction at Keppel FELS’ yard in Singapore and is expected to commence operations in the fourth quarter of 2013.

Dispositions—During the three months ended March 31, 2012, in connection with our efforts to dispose of non-strategic assets, we sold the Standard Jackup GSF Rig 136 and related equipment.  As a result of the sale, we received net cash proceeds of $36 million (See Note 6—Impairments).  For the three months ended March 31, 2012, we recognized a net loss on disposal of unrelated assets of $4 million.

During the three months ended March 31, 2011, in connection with our efforts to dispose of non-strategic assets, we sold the High-Specification Jackup Trident 20 and the Standard Jackup Transocean Mercury.  The sale of Trident 20 reflected our decision to discontinue operations in the Caspian Sea (see Note 8—Discontinued Operations).  In connection with the sale of Transocean Mercury, we received net cash proceeds of $10 million and recognized a net gain on disposal of the drilling unit of $9 million ($0.03 per diluted share from continuing operations), which had no tax effect.  For the three months ended March 31, 2011, we recognized a net loss on disposal of unrelated assets in the amount of $1 million.

Assets held for sale—During the three months ended March 31, 2012, we committed to plans to sell our Standard Jackups, Roger W. Mowell, Transocean Nordic, Transocean Shelf Explorer and Trident 17.  At March 31, 2012, these drilling units and related equipment were classified as assets held for sale with an aggregate net carrying amount of $31 million.  See Note 19—Subsequent Events.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2012	Apr. 24, 2012
Document and Entity Information
Entity Registrant Name	Transocean Ltd.
Entity Central Index Key	0001451505
Document Type	10-Q
Document Period End Date	Mar. 31, 2012
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		350,503,380
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1

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Debt

3 Months Ended

Mar. 31, 2012

Debt

Debt

Note 11—Debt

Debt, net of unamortized discounts, premiums and fair value adjustments, was comprised of the following (in millions):

	March 31, 2012						December 31, 2011
	Transocean Ltd. and subsidiaries		Consolidated variable interest entities		Consolidated total		Transocean Ltd. and subsidiaries		Consolidated variable interest entities		Consolidated total
5% Notes due February 2013	$	253	$	—	$	253	$	253	$	—	$	253
5.25% Senior Notes due March 2013 (a)	507		—		507		507		—		507
TPDI Credit Facilities due March 2015	—		455		455		—		473		473
4.95% Senior Notes due November 2015 (a)	1,120		—		1,120		1,120		—		1,120
Aker Revolving Credit and Term Loan Facility due December 2015	572		—		572		594		—		594
5.05% Senior Notes due December 2016 (a)	999		—		999		999		—		999
Callable Bonds due February 2016	278		—		278		267		—		267
ADDCL Credit Facilities due December 2017	—		218		218		—		217		217
Eksportfinans Loans due January 2018	852		—		852		884		—		884
6.00% Senior Notes due March 2018 (a)	998		—		998		998		—		998
7.375% Senior Notes due April 2018 (a)	247		—		247		247		—		247
TPDI Notes due October 2019	—		148		148		—		148		148
6.50% Senior Notes due November 2020 (a)	899		—		899		899		—		899
6.375% Senior Notes due December 2021 (a)	1,199		—		1,199		1,199		—		1,199
7.45% Notes due April 2027 (a)	97		—		97		97		—		97
8% Debentures due April 2027 (a)	57		—		57		57		—		57
7% Notes due June 2028	311		—		311		311		—		311
Capital lease contract due August 2029	671		—		671		676		—		676
7.5% Notes due April 2031 (a)	598		—		598		598		—		598
1.50% Series B Convertible Senior Notes due December 2037 (a)	—		—		—		30		—		30
1.50% Series C Convertible Senior Notes due December 2037 (a)	1,678		—		1,678		1,663		—		1,663
6.80% Senior Notes due March 2038 (a)	999		—		999		999		—		999
7.35% Senior Notes due December 2041 (a)	300		—		300		300		—		300
Total debt	12,635		821		13,456		12,698		838		13,536
Less debt due within one year
5% Notes due February 2013	253		—		253		—		—		—
5.25% Senior Notes due March 2013 (a)	507		—		507		—		—		—
TPDI Credit Facilities due March 2015	—		70		70		—		70		70
Aker Revolving Credit and Term Loan Facility due December 2015	90		—		90		90		—		90
ADDCL Credit Facilities due November 2017	—		27		27		—		27		27
Eksportfinans Loans due January 2018	149		—		149		142		—		142
Capital lease contract due August 2029	18		—		18		17		—		17
1.50% Series B Convertible Senior Notes due December 2037 (a)	—		—		—		30		—		30
1.50% Series C Convertible Senior Notes due December 2037 (a)	1,678		—		1,678		1,663		—		1,663
Total debt due within one year	2,695		97		2,792		1,942		97		2,039
Total long-term debt	$	9,940	$	724	$	10,664	$	10,756	$	741	$	11,497

(a)Transocean Inc., a 100 percent owned subsidiary of Transocean Ltd., is the issuer of the notes and debentures, which have been guaranteed by Transocean Ltd.  Transocean Ltd. has also guaranteed borrowings under the Five-Year Revolving Credit Facility.  Transocean Ltd. and Transocean Inc. are not subject to any significant restrictions on their ability to obtain funds from their consolidated subsidiaries by dividends, loans or return of capital distributions.  See Note 18—Condensed Consolidating Financial Information.

Scheduled maturities—In preparing the scheduled maturities of our debt, we assume the noteholders will exercise their options to require us to repurchase the 1.50% Series C Convertible Senior Notes in December 2012.  At March 31, 2012, the scheduled maturities of our debt were as follows (in millions):

	Transocean Ltd.and subsidiaries			Consolidated variable interest entities		Consolidated total
Twelve months ending March 31,
2013	$	2,728		$	97	$	2,825
2014	260			98		358
2015	1,336			373		1,709
2016	1,762			33		1,795
2017	175			35		210
Thereafter	6,377			185		6,562
Total debt, excluding unamortized discounts, premiums and fair value adjustments	12,638			821		13,459
Total unamortized discounts, premiums and fair value adjustments, net	(3		)	—		(3		)
Total debt	$	12,635		$	821	$	13,456

Five-Year Revolving Credit Facility—We have a $2.0 billion revolving credit facility established by the Five-Year Revolving Credit Facility Agreement dated November 1, 2011 (the “Five-Year Revolving Credit Facility”).  Throughout the term of the Five-Year Revolving Credit Facility, we pay a facility fee on the daily unused amount of the underlying commitment, which ranges from 0.13 percent to 0.33 percent, based on our Debt Rating, and was 0.275 percent at March 31, 2012.  At March 31, 2012, we had $24 million in letters of credit issued and outstanding, we had no borrowings outstanding, and we had $2.0 billion available borrowing capacity under the Five-Year Revolving Credit Facility.

TPDI Credit Facilities—TPDI has a bank credit agreement for a $1.265 billion secured credit facility (the “TPDI Credit Facilities”), comprised of a $1.0 billion senior term loan, a $190 million junior term loan and a $75 million revolving credit facility, which was established to finance the construction of and is secured by Dhirubhai Deepwater KG1 and Dhirubhai Deepwater KG2.  One of our subsidiaries participates as a lender in the senior and junior term loans with an aggregate commitment of $595 million.  At March 31, 2012, $910 million was outstanding under the TPDI Credit Facilities, of which $455 million was due to one of our subsidiaries and was eliminated in consolidation.  On March 31, 2012, the weighted-average interest rate was 2.1 percent.  See Note 12—Derivatives and Hedging.

At March 31, 2012, TPDI had an outstanding letter of credit in the amount of $60 million to satisfy its liquidity requirements under the TPDI Credit Facilities.  The letter of credit was issued under an uncommitted credit facility that has been established by one of our subsidiaries.  Additionally TPDI is required to maintain certain cash balances in accounts restricted for the payment of the scheduled installments on the TPDI Credit Facilities.  TPDI had restricted cash investments of $26 million and $23 million at March 31, 2012 and December 31, 2011, respectively.

Aker Revolving Credit and Term Loan Facility—Aker Drilling has a credit facility established by the Revolving Credit and Term Loan Facility Agreement dated February 21, 2011 (the “Aker Revolving Credit and Term Loan Facility”), comprised of a $500 million revolving credit facility and a $400 million term loan, which is secured by Transocean Spitsbergen and Transocean Barents.  At March 31, 2012, aggregate borrowings of $570 million were outstanding under the Aker Revolving Credit and Term Loan Facility at a weighted-average interest rate of 3.0 percent.

Callable Bonds—Aker Drilling is the obligor on the FRN Aker Drilling ASA Senior Unsecured Callable Bond Issue 2011/2016 (the “FRN Callable Bonds”) and the 11% Aker Drilling ASA Senior Unsecured Callable Bond Issue 2011/2016 (the “11% Callable Bonds,” and together with the FRN Callable Bonds, the “Callable Bonds”), which are publicly traded on the Oslo Stock Exchange.  At March 31, 2012, the total aggregate principal amounts of the FRN Callable Bonds and the 11% Callable Bonds were NOK 940 million and NOK 560 million, equivalent to $165 million and $98 million, respectively, using an exchange rate of NOK 5.69 to US $1.00.  At March 31, 2012, the interest rate on the FRN Callable Bonds was 9.7 percent.  See Note 12—Derivatives and Hedging.

ADDCL Credit Facilities—ADDCL has a senior secured bank credit agreement for a credit facility (the “ADDCL Primary Loan Facility”) comprised of Tranche A and Tranche C for $215 million and $399 million, respectively, which was established to finance the construction of and is secured by Discoverer Luanda.  Unaffiliated financial institutions provide the commitment for and borrowings under Tranche A, and one of our subsidiaries provides the commitment for Tranche C.  At March 31, 2012, $190 million was outstanding under Tranche A at a weighted-average interest rate of 1.5 percent.  At March 31, 2012, $399 million was outstanding under Tranche C, which was eliminated in consolidation.

Additionally, ADDCL has a secondary bank credit agreement for a $90 million credit facility (the “ADDCL Secondary Loan Facility” and together with the ADDCL Primary Loan Facility, the “ADDCL Credit Facilities”), for which one of our subsidiaries provides 65 percent of the total commitment.  At March 31, 2012, $79 million was outstanding under the ADDCL Secondary Loan Facility, of which $51 million was due to one of our subsidiaries and has been eliminated in consolidation.  On March 31, 2012, the weighted-average interest rate was 3.6 percent.

ADDCL is required to maintain certain cash balances in accounts restricted for the payment of the scheduled installments on the ADDCL Credit Facilities.  ADDCL had restricted cash investments of $30 million and $16 million at March 31, 2012 and December 31, 2011, respectively.

Eksportfinans Loans—The Eksportfinans Loans require cash collateral to remain on deposit at a financial institution (the “Aker Restricted Cash Investments”) through expiration.  The aggregate principal amount of the Aker Restricted Cash Investments was $857 million and $889 million at March 31, 2012 and December 31, 2011, respectively.

TPDI Notes—TPDI has issued promissory notes (the “TPDI Notes”) payable to its two shareholders, Quantum Pacific Management Limited (“Quantum”) and one of our subsidiaries, which have maturities through October 2019.  At March 31, 2012, the aggregate outstanding principal amount was $296 million, of which $148 million was due to one of our subsidiaries and has been eliminated in consolidation.  On March 31, 2012, the weighted-average interest rate was 2.7 percent.  See Note 15—Redeemable Noncontrolling Interest.

1.50% Series B and 1.50% Series C Convertible Senior Notes—Including amortization of the unamortized discount, the effective interest rates for the Series C Convertible Senior Notes was 5.28 percent.  At March 31, 2012, the remaining period over which the discount will be amortized is less than one year.  Interest expense, excluding amortization of debt issue costs, was as follows (in millions):

	Three months ended March 31,
	2012		2011
Interest expense
Series B Convertible Senior Notes due 2037	$	—	$	20
Series C Convertible Senior Notes due 2037	21		20

The carrying amounts of the liability components of the outstanding Convertible Senior Notes were as follows (in millions):

	March 31, 2012							December 31, 2011
	Principal amount		Unamortized discount			Carrying amount		Principal amount		Unamortized discount			Carrying amount
Carrying amount of liability component
Series B Convertible Senior Notes due 2037	$	—	$	—		$	—	$	30	$	—		$	30
Series C Convertible Senior Notes due 2037	1,722		(44		)	1,678		1,722		(59		)	1,663

The carrying amounts of the equity components of the outstanding Convertible Senior Notes were as follows (in millions):

	March 31, 2012		December 31, 2011
Carrying amount of equity component
Series B Convertible Senior Notes due 2037	$	—	$	4
Series C Convertible Senior Notes due 2037	276		276

In February 2012, we redeemed the remaining $30 million of aggregate principal amount of our Series B Convertible Senior Notes for an aggregate cash payment of $30 million.

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CONDENSED CONSOLIDATED BALANCE SHEETS (USD $) In Millions, unless otherwise specified	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Assets
Cash and cash equivalents	$ 3,982	$ 4,017
Accounts receivable, net of allowance for doubtful accounts of $28 at March 31, 2012 and December 31, 2011	2,238	2,176
Materials and supplies, net of allowance for obsolescence of $76 and $73 at March 31, 2012 and December 31, 2011, respectively	663	627
Deferred income taxes, net	142	142
Assets held for sale	53	26
Other current assets	595	621
Total current assets	7,673	7,609
Property and equipment	28,960	29,037
Property and equipment of consolidated variable interest entities	2,255	2,252
Less accumulated depreciation	8,892	8,760
Property and equipment, net	22,323	22,529
Goodwill	3,087	3,205
Other assets	1,632	1,745
Total assets	34,715	35,088
Liabilities and equity
Accounts payable	841	880
Accrued income taxes	70	89
Debt due within one year	2,695	1,942
Debt of consolidated variable interest entities due within one year	97	97
Other current liabilities	2,061	2,350
Total current liabilities	5,764	5,358
Long-term debt	9,940	10,756
Long-term debt of consolidated variable interest entities	724	741
Deferred income taxes, net	512	523
Other long-term liabilities	1,914	1,903
Total long-term liabilities	13,090	13,923
Commitments and contingencies
Redeemable noncontrolling interest	138	116
Shares, CHF 15.00 par value, 402,282,355 authorized, 167,617,649 conditionally authorized, 365,135,298 issued at March 31, 2012 and December 31, 2011; 350,500,518 and 349,805,793 outstanding at March 31, 2012 and December 31, 2011, respectively	4,991	4,982
Additional paid-in capital	7,216	7,211
Treasury shares, at cost, 2,863,267 held at March 31, 2012 and December 31, 2011	(240)	(240)
Retained earnings	4,286	4,244
Accumulated other comprehensive loss	(515)	(496)
Total controlling interest shareholders' equity	15,738	15,701
Noncontrolling interest	(15)	(10)
Total equity	15,723	15,691
Total liabilities and equity	$ 34,715	$ 35,088

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Business Combination

3 Months Ended

Mar. 31, 2012

Business Combination

Business Combination

Note 5—Business Combination

As of October 3, 2011, the acquisition date, we held 99 percent of the shares of Aker Drilling ASA (“Aker Drilling”), a Norwegian company formerly listed on the Oslo Stock Exchange, 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 of Aker Drilling 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.

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 acquisition 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 and other assets and to evaluate the assumed tax positions and contingencies.

In the three months ended March 31, 2012, our operating revenues included approximately $95 million of contract drilling revenues associated with the operations of the two Harsh Environment, Ultra-Deepwater semisubmersibles that we acquired in our acquisition of Aker Drilling.

Unaudited pro forma combined operating results, assuming the acquisition was completed as of January 1, 2011, were as follows (in millions, except per share data):

	Three months ended March 31,
	2011
Operating revenues	$	2,244
Operating income	420
Income from continuing operations	167
Per share earnings from continuing operations
Basic	$	0.43
Diluted	$	0.43

The pro forma financial information includes various adjustments, primarily related to additional depreciation expense 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.

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Variable Interest Entities

3 Months Ended

Mar. 31, 2012

Variable Interest Entities

Variable Interest Entities

Note 4—Variable Interest Entities

Consolidated variable interest entities—We consolidate the operating results, assets and liabilities of Transocean Pacific Drilling Inc. (“TPDI”), a consolidated British Virgin Islands joint venture company, and Angola Deepwater Drilling Company Limited (“ADDCL”), a consolidated Cayman Islands joint venture company, which are two variable interest entities for which we are the primary beneficiary.  The carrying amounts associated with our consolidated variable interest entities, after eliminating the effect of intercompany transactions, were as follows (in millions):

	March 31, 2012						December 31, 2011
	Assets		Liabilities		Net carrying amount		Assets		Liabilities		Net carrying amount
Variable interest entity
TPDI	$	1,591	$	660	$	931	$	1,562	$	673	$	889
ADDCL	929		327		602		930		334		596
Total	$	2,520	$	987	$	1,533	$	2,492	$	1,007	$	1,485

See Note 15—Redeemable Noncontrolling Interest.

Unconsolidated variable interest entities—As holder of two notes receivable and a lender under a working capital loan, we have a variable interest in Awilco Drilling plc (“Awilco”), a U.K. company listed on the Oslo Stock Exchange.  In the three months ended March 31, 2012, Awilco encountered operational downtime, both planned and unplanned, and disputed billings.  In the three months ended March 31, 2012, we reevaluated whether Awilco met the definition of a variable interest entity.  Based on our reevaluation, we determined that Awilco now met the definition of a variable interest entity since its equity at risk is insufficient to permit it to carry on its activities without additional subordinated financial support.  We also continue to believe that we were not the primary beneficiary since we did not have the power to direct the activities that most significantly impact the entity’s economic performance.

The notes receivable were originally accepted in exchange for and are secured by two drilling units.  The notes receivable have stated interest rates of nine percent and are payable in scheduled quarterly installments of principal and interest through maturity in January 2015.  The working capital loan, also secured by the two drilling units, has a stated interest rate of 10 percent and is payable in scheduled quarterly installments of principal and interest through maturity in January 2013.  We evaluate the credit quality and financial condition of Awilco quarterly.  The aggregate carrying amount of the notes receivable was $109 million and $110 million at March 31, 2012 and December 31, 2011, respectively.  The aggregate carrying amount of the working capital loan receivable was $20 million and $29 million at March 31, 2012 and December 31, 2011, respectively.  At March 31, 2012, our aggregate exposure to loss on these receivable instruments was $129 million.

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Shareholders' Equity

3 Months Ended

Mar. 31, 2012

Shareholders' Equity

Shareholders' Equity

Note 16—Shareholders’ Equity

Distribution of qualifying additional paid-in capital—In May 2011, at our annual general meeting, our shareholders approved the distribution of additional paid-in capital in the form of a U.S. dollar denominated dividend of $3.16 per outstanding share, payable in four equal installments of $0.79 per outstanding share, subject to certain limitations.  On March 21, 2012, we paid the final installment in the amount of $278 million to shareholders of record as of February 24, 2012.

Shares held by subsidiary—In December 2008, we issued 16 million of our shares to one of our subsidiaries for future use to satisfy our obligations to deliver shares in connection with awards granted under our incentive plans or other rights to acquire our shares.  Our subsidiary held approximately 12 million shares at March 31, 2012 and December 31, 2011.

Accumulated other comprehensive loss—The changes in accumulated other comprehensive loss for the three months ended March 31, 2012 and 2011 were as follows (in millions):

	Three months ended March 31, 2012
	Unrecognized components of net periodic benefit costs			Unrecognized gains (losses) on derivative instruments			Unrecognized gains (losses) on marketable securities			Total
Balance, beginning of period	$	(501	)	$	7		$	(2	)	$	(496	)
Other comprehensive loss attributable to controlling interest	(18		)	(1		)	—			(19		)
Balance, end of period	$	(519	)	$	6		$	(2	)	$	(515	)

	Three months ended March 31, 2011
	Unrecognized components of net periodic benefit costs			Unrecognized gains (losses) on derivative instruments			Unrecognized gains (losses) on marketable securities			Total
Balance, beginning of period	$	(335	)	$	5		$	(2	)	$	(332	)
Other comprehensive loss attributable to controlling interest	(2		)	(1		)	—			(3		)
Balance, end of period	$	(337	)	$	4		$	(2	)	$	(335	)

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Derivatives and Hedging

3 Months Ended

Mar. 31, 2012

Derivatives and Hedging

Derivatives and Hedging

Note 12—Derivatives and Hedging

Derivatives designated as hedging instruments—Two of our wholly owned subsidiaries have entered into interest rate swaps, which are designated and have qualified as fair value hedges, to reduce our exposure to changes in the fair values of the 5% Notes due February 2013, the 5.25% Senior Notes due March 2013 and the 4.95% Senior Notes due November 2015.  The interest rate swaps have aggregate notional amounts equal to the corresponding face values of the hedged instruments and have stated maturities that coincide with those of the hedged instruments.  We have determined that the hedging relationships qualify for, and we have applied, the shortcut method of accounting, under which the interest rate swaps are considered to have no ineffectiveness and no ongoing assessment of effectiveness is required.  Accordingly, changes in the fair value of the interest rate swaps recognized in interest expense offset changes in the fair value of the hedged fixed-rate notes.  Through the stated maturities of the interest rate swaps, we receive semi-annual interest at a fixed rate equal to that of the underlying debt instrument and pay variable interest semi-annually at three-month London Interbank Offered Rate plus a margin.

TPDI has entered into interest rate swaps, which have been designated and qualify as a cash flow hedge, to reduce the variability of cash interest payments associated with the variable rate borrowings under the TPDI Credit Facilities through December 31, 2014.  The aggregate notional amount corresponds with the aggregate outstanding amount of the borrowings under the TPDI Credit Facilities.

Aker Drilling has entered into cross-currency interest rate swaps, which have been designated and qualify as a cash flow hedge, to reduce the variability of cash interest payments and the final principal payment, due at maturity in February 2016, associated with the changes in the U.S. dollar to Norwegian kroner exchange rate.  The aggregate notional amount corresponds with the aggregate outstanding amount of the 11% Callable Bonds.

At March 31, 2012, the aggregate notional amounts and the weighted average interest rates associated with our interest rate derivatives designated as hedging instruments were as follows (in millions, except weighted average interest rates):

	Aggregate notional amount		Weighted average variable rate		Weighted average fixed rate
Interest rate swaps, fair value hedges	$	1,400	3.7	%	5.1	%
Interest rate swaps, cash flow hedges	438		0.5	%	2.3	%

At March 31, 2012, the aggregate notional amounts and weighted average interest rates associated with our cross-currency derivatives designated as hedging instruments were as follows (in millions, except weighted average interest rates):

	Pay				Receive
	Notional amount		Weighted average fixed rate		Notional amount		Weighted average fixed rate
Cross-currency swaps, cash flow hedges	$	102	8.9	%	NOK	560	11	%

The effect on our condensed consolidated statements of operations resulting from changes in the fair values of derivatives designated as cash flow hedges was as follows (in millions):

		Three months ended March 31,
	Statement of operations classification	2012			2011
Loss associated with effective portion	Interest expense, net of amounts capitalized	$	2		$	2
Gain associated with ineffective portion	Interest expense, net of amounts capitalized	(1		)	—
Gain associated with effective portion	Other, net	(5		)	—

The balance sheet classification and aggregate carrying amount of our derivatives designated as hedging instruments, measured at fair value, were as follows (in millions):

	Balance sheet classification	March 31, 2012		December 31, 2011
Interest rate swaps, fair value hedges	Other current assets	$	14	$	5
Interest rate swaps, fair value hedges	Other assets	21		31
Interest rate swaps, cash flow hedges	Other current liabilities	1		—
Interest rate swaps, cash flow hedges	Other long-term liabilities	16		16
Cross-currency swaps, cash flow hedges	Other current assets	1		—
Cross-currency swaps, cash flow hedges	Other long-term liabilities	2		7

Derivatives not designated as hedging instruments—We have certain derivatives not designated as hedging instruments that we assumed in connection with our acquisition of Aker Drilling for which we receive interest at a fixed rate and we pay interest at a variable rate.  At March 31, 2012, the aggregate notional amounts and the weighted average interest rates associated with our interest rate derivatives not designated as hedging instruments were as follows (in millions, except weighted average interest rates):

	Aggregate notional amount		Weighted average variable rate		Weighted average fixed rate
Interest rate swaps not designated as hedging instruments	$	241	0.5	%	4.2	%

The effect on our condensed consolidated statements of operations resulting from changes in the fair values of derivatives not designated as hedging instruments was as follows (in millions):

		Three months ended March 31,
	Statement of operations classification	2012		2011
Interest rate swaps not designated as hedging instruments	Interest expense, net of amounts capitalized	$	1	$	—

The balance sheet classification and aggregate carrying amount of our derivatives not designated as hedging instruments, measured at fair value, were as follows (in millions):

	Balance sheet classification	March 31, 2012		December 31, 2011
Interest rate swaps not designated as hedging instruments	Other long-term liabilities	$	13	$	15

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Discontinued Operations

3 Months Ended

Mar. 31, 2012

Discontinued Operations

Discontinued Operations

Note 8—Discontinued Operations

Oil and gas properties—In March 2011, in connection with our efforts to dispose of non-strategic assets, 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, our wholly owned oil and gas subsidiaries.  In October 2011, we completed the sale of Challenger Minerals (North Sea) Limited for net cash proceeds of $24 million, and we recognized a gain on the disposal of the discontinued operations of $12 million.  Additionally, in February 2012, we entered into an agreement to sell the assets of Challenger Minerals Inc.  See Note 19—Subsequent Events.

Caspian Sea operations—In February 2011, in connection with our efforts to dispose of non-strategic assets, we sold the subsidiary that owns the High-Specification Jackup Trident 20, located in the Caspian Sea.  The disposal of this subsidiary, a component of our contract drilling services segment, reflects our decision to discontinue operations in the Caspian Sea.  As a result of the sale, we received net cash proceeds of $259 million and recognized a gain on the disposal of the discontinued operations of $169 million ($0.52 per diluted share from discontinued operations), which had no tax effect.  Through June 2011, we continued to operate Trident 20 under a bareboat charter to perform services for the customer and the buyer reimbursed us for the approximate cost of providing these services.  Additionally, we provided certain transition services to the buyer through September 2011.

Summarized results of discontinued operations—The summarized results of operations included in income from discontinued operations were as follows (in millions):

	Three months ended March 31,
	2012			2011
Operating revenues	$	3		$	26
Costs and expenses	(2		)	(23		)
Loss on impairment (a)	(6		)	—
Gain (loss) on disposal of discontinued operations, net	(14		)	173
Income (loss) from discontinued operations before income tax expense	(19		)	176
Income tax benefit	4			—
Income (loss) from discontinued operations, net of tax	$	(15	)	$	176

(a)During the three months ended March 31, 2012, we recognized a loss on impairment of our oil and gas properties, which were classified as assets held for sale, in the amount of $6 million ($4 million or $0.01 per diluted share from discontinued operations, net of tax) since the carrying amount of the properties exceeded the estimated fair value less costs to sell the properties.  We estimated fair value based on significant observable inputs, representing a Level 1 fair value measurement, including a binding sale and purchase agreement for the properties.

Assets and liabilities of discontinued operations— As a result of our decision to discontinue the operations of our oil and gas properties reporting unit and the operations of our Caspian Sea subsidiary, we have classified the related assets and liabilities of these components of our business to other current assets and other current liabilities as of December 31, 2011.  The carrying amounts of the major classes of assets and liabilities associated with these operations were classified as follows (in millions):

	March 31, 2012		December 31, 2011
Assets
Oil and gas properties, net	$	19	$	24
Other related assets	2		2
Assets held for sale	$	21	$	26
Accounts receivable	$	2	$	6
Other assets	11		25
Other current assets	$	13	$	31
Liabilities
Accounts payable	$	1	$	3
Other liabilities	8		14
Other current liabilities	$	9	$	17

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Shareholders' Equity (Details 2) (USD $) In Millions, unless otherwise specified					3 Months Ended								3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011	Dec. 31, 2010	Mar. 31, 2012 Unrecognized components of net periodic benefit costs	Mar. 31, 2011 Unrecognized components of net periodic benefit costs	Mar. 31, 2012 Unrecognized gains (losses) on derivative investments	Mar. 31, 2011 Unrecognized gains (losses) on derivative investments	Mar. 31, 2012 Unrecognized gains (losses) on marketable securities	Dec. 31, 2011 Unrecognized gains (losses) on marketable securities	Mar. 31, 2011 Unrecognized gains (losses) on marketable securities	Dec. 31, 2010 Unrecognized gains (losses) on marketable securities	Mar. 31, 2012 Accumulated other comprehensive income (loss), Total	Mar. 31, 2011 Accumulated other comprehensive income (loss), Total
Changes in accumulated other comprehensive income
Accumulated other comprehensive loss, balance beginning of period	$ (515)	$ (496)	$ (335)	$ (332)	$ (501)	$ (335)	$ 7	$ 5	$ (2)	$ (2)	$ (2)	$ (2)	$ (496)	$ (332)
Other comprehensive loss attributable to controlling interest					(18)	(2)	(1)	(1)					(19)	(3)
Accumulated other comprehensive loss, balance end of period	$ (515)	$ (496)	$ (335)	$ (332)	$ (519)	$ (337)	$ 6	$ 4	$ (2)	$ (2)	$ (2)	$ (2)	$ (515)	$ (335)

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Impairments

3 Months Ended

Mar. 31, 2012

Impairments

Impairments

Note 6—Impairments

Assets held for sale—During the three months ended March 31, 2012, we recognized a loss of $17 million ($0.05 per diluted share from continuing operations), which had no tax effect, associated with the impairment of GSF Rig 136, which was classified as an asset held for sale at the time of impairment.  We measured the impairment of the drilling unit and related equipment as the amount by which the carrying amount exceeded the estimated fair value less costs to sell.  We estimated the fair value of the assets using significant observable inputs, representing a Level 1 fair value measurement, including a binding sale and purchase agreement for the drilling unit and related equipment.

Definite-lived intangible assets—During the three months ended March 31, 2012, we determined that the customer relationships intangible asset associated with our drilling management services reporting unit was impaired due to the declining market outlook for these services in the shallow water of U.S. Gulf of Mexico as well as the increased regulatory environment for obtaining drilling permits and the diminishing demand for our drilling management services.  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, representing a Level 3 fair value measurement, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.  As a result of our valuation, we determined that the carrying amount of the customer relationships intangible asset exceeded its fair value, and we recognized a loss on impairment of $53 million ($37 million, or $0.11 per diluted share from continuing operations, net of tax) in the three months ended March 31, 2012.

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.  In the year ended December 31, 2011, we recognized a loss on impairment, representing our best estimate, in the amount of $5.2 billion ($16.15 per diluted share from continuing operations), which had no tax effect.  In the three months ended March 31, 2012, we completed our analysis and recognized an incremental adjustment to our original estimate in the amount of $118 million ($0.34 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 our contract drilling services reporting unit based on significant unobservable inputs, representing a Level 3 fair value measurement, including assumptions for future commodity prices, projected demand for our services, rig availability and dayrates.

During the three months ended March 31, 2012, we determined that the trade name intangible asset associated with our drilling management services reporting unit was impaired due to the declining market outlook for these services in the shallow water of U.S. Gulf of Mexico as well as the increased regulatory environment for obtaining drilling permits and the diminishing demand for drilling management services.  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, representing a Level 3 fair value measurement, including assumptions for future commodity prices, projected demand for drilling management services, rig availability and dayrates.  As a result of our valuation, we determined that the carrying amount of the trade name intangible asset exceeded its fair value, and we recognized a loss on impairment of $39 million ($25 million, or $0.07 per diluted share from continuing operations, net of tax) in the three months ended March 31, 2012.

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Income Taxes

3 Months Ended

Mar. 31, 2012

Income Taxes

Income Taxes

Note 7—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.

Our estimated annual effective tax rates were 25.5 percent and 19.3 percent for the three months ended March 31, 2012 and 2011, respectively.  These rates were based on estimated annual income before income taxes for each period after adjusting for various discrete items, including certain immaterial adjustments to prior period tax expense.

Deferred taxes—The valuation allowance for our non-current deferred tax assets was as follows (in millions):

	March 31, 2012		December 31, 2011
Valuation allowance for non-current deferred tax assets	$	181	$	183

Unrecognized tax benefits—The liabilities related to our unrecognized tax benefits, including related interest and penalties that we recognize as a component of income tax expense, were as follows (in millions):

	March 31, 2012		December 31, 2011
Unrecognized tax benefits, excluding interest and penalties	$	493	$	509
Interest and penalties	271		272
Unrecognized tax benefits, including interest and penalties	$	764	$	781

Tax returns—We file federal and local tax returns in several jurisdictions throughout the world.  With few exceptions, we are no longer subject to examinations of our U.S. and non-U.S. tax matters for years prior to 2003.  For the three months ended March 31, 2012, the amount of current tax benefit recognized from the settlement of disputes with tax authorities and from the expiration of statutes of limitations was $38 million.

We engage in ongoing discussions with tax authorities regarding the resolution of tax matters in the various jurisdictions in which we operate.  Both the ultimate resolutions of these tax matters and the timing of any resolution or closure of the tax audits are highly uncertain.  It is reasonably possible that the total amount of our existing liabilities for unrecognized tax benefits could decrease by up to 15 percent or increase by up to 10 percent in the next 12 months.

Our tax returns in the major jurisdictions in which we operate, other than the U.S., Norway and Brazil which are mentioned below, are generally subject to examination for periods ranging from three to six years.  We have agreed to extensions beyond the statute of limitations in two major jurisdictions for up to 17 years.  Tax authorities in certain jurisdictions are examining our tax returns and in some cases have issued assessments.  We are defending our tax positions in those jurisdictions.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect the ultimate liability to have a material adverse effect on our consolidated statement of financial position or results of operations, although it may have a material adverse effect on our consolidated cash flows.

U.S. tax investigations—With respect to our 2004 U.S. federal income tax return, the U.S. tax authorities withdrew all of their previously proposed tax adjustments, including all claims related to transfer pricing.  In January 2012, a judge in the U.S. Tax Court entered a decision of no deficiency for the 2004 tax year and cancelled the trial previously scheduled to take place in February 2012.  With respect to our 2005 U.S. federal income tax returns, the U.S. tax authorities have withdrawn all of their previously proposed tax adjustments, except a claim regarding transfer pricing for certain charters of drilling rigs between our subsidiaries, resulting in a total proposed adjustment of approximately $50 million, excluding interest.  We believe an unfavorable outcome on this assessment with respect to 2005 activities would not result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  Although we believe the transfer pricing for these charters is materially correct, we have been unable to reach a resolution with the tax authorities.

In May 2010, we received an assessment from the U.S. tax authorities related to our 2006 and 2007 U.S. federal income tax returns.  In July 2010, we filed a protest letter with the U.S. tax authorities responding to this assessment.  The significant issues raised in the assessment relate to transfer pricing for certain charters of drilling rigs between our subsidiaries and the creation of intangible assets resulting from the performance of engineering services between our subsidiaries.  These two items would result in net adjustments of approximately $278 million of additional taxes, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe our U.S. federal income tax returns are materially correct as filed, and we intend to continue to vigorously defend against all such claims.

In addition, the May 2010 assessment included adjustments related to a series of restructuring transactions that occurred between 2001 and 2004.  These restructuring transactions impacted our basis in our former subsidiary, TODCO, which we disposed of in 2004 and 2005.  The authorities are disputing the amount of capital losses that resulted from the disposition of TODCO.  We utilized a portion of the capital losses to offset capital gains on our U.S federal income tax returns for 2006 through 2009.  The majority of the capital losses were unutilized and expired on December 31, 2009.  The adjustments would also impact the amount of certain net operating losses and other carryovers in 2006 and later years.  The authorities are also contesting the characterization of certain amounts of income received in 2006 and 2007 as capital gain and thus the availability of the capital loss to offset such gains.  These claims with respect to our U.S. federal income tax returns for 2006 through 2009 could result in net tax adjustments of approximately $295 million.  An unfavorable outcome on these potential adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe that our U.S federal income tax returns are materially correct as filed, and we intend to vigorously defend against any potential claims.

The May 2010 assessment also included certain claims with respect to withholding taxes and certain other items resulting in net tax adjustments of approximately $160 million, excluding interest.  In addition, the tax authorities assessed penalties associated with the various tax adjustments for the 2006 and 2007 audits in the aggregate amount of approximately $88 million, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  We believe that our U.S. federal income tax returns are materially correct as filed, and we intend to vigorously defend against potential claims.

In February 2012, we received an assessment from the U.S. tax authorities related to our 2008 and 2009 U.S. federal income tax returns.  The significant issues raised in the assessment relate to transfer pricing for certain charters of drilling rigs between our subsidiaries and the creation of intangible assets resulting from the performance of engineering services between our subsidiaries.  These items would result in net adjustments of approximately $473 million of additional taxes, excluding interest.  An unfavorable outcome on these adjustments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  Furthermore, if the authorities were to continue to pursue these positions with respect to subsequent years and were successful in such assertions, our effective tax rate on worldwide earnings with respect to years following 2009 could increase substantially, and could have a material adverse effect on our consolidated results of operations and cash flows.  We believe our U.S. federal income tax returns are materially correct as filed, and we intend to continue to vigorously defend against all such claims.

Norway tax investigations—Norwegian civil tax and criminal authorities are investigating various transactions undertaken by our subsidiaries in 2001 and 2002 as well as the actions of certain employees of our former external tax advisors on these transactions.  The authorities issued tax assessments of approximately $274 million, plus interest, related to certain restructuring transactions, approximately $120 million, plus interest, related to the migration of a subsidiary that was previously subject to tax in Norway, approximately $72 million, plus interest, related to a 2001 dividend payment, and approximately $7 million, plus interest, related to certain foreign exchange deductions and dividend withholding tax.  We have filed or expect to file appeals to these tax assessments.  We have provided a parent company guarantee in the amount of approximately $123 million, with respect to one of these tax disputes.  Furthermore, we may be required to provide some form of additional financial security, in an amount up to $754 million, including interest and penalties, for other assessed amounts as these disputes are appealed and addressed by the Norwegian courts.  The authorities have indicated that they plan to seek penalties of 60 percent on most but not all matters.  In June 2011, the Norwegian authorities issued criminal indictments against two of our subsidiaries alleging misleading or incomplete disclosures in Norwegian tax returns for the years 1999 through 2002, as well as inaccuracies in Norwegian statutory financial statements for the years ended December 31, 1996 through 2001.  The criminal trial has been scheduled for December 2012.  Two employees of our former external tax advisors were also issued indictments with respect to the disclosures in our tax returns.  In October 2011, the Norwegian authorities issued criminal indictments against a Norwegian tax attorney related to certain of our restructuring transactions and to the 2001 dividend payment.  The indicted Norwegian tax attorney worked for us in an advisory capacity on these transactions.  We believe these charges are without merit and do not alter our technical assessment of the underlying claims.  In January 2012, the Norwegian authorities supplemented the previously issued criminal indictments by issuing a financial claim of approximately $323 million, jointly and severally, against our two subsidiaries, the two external advisors and the external tax attorney.  This compensation claim directly overlaps with an existing civil tax assessment and does not represent an incremental financial exposure to us.  In February 2012, the authorities dropped the previously existing tax assessment related to a certain restructuring transaction.  We believe our Norwegian tax returns are materially correct as filed, and we intend to vigorously contest any assertions by the Norwegian civil and criminal authorities in connection with the various transactions being investigated.  An unfavorable outcome on the Norwegian civil and criminal tax matters could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect the ultimate resolution of these matters to have a material adverse effect on our consolidated statement of financial position or results of operations, although it may have a material adverse effect on our consolidated cash flows.  See Note 19—Subsequent Events.

Brazil tax investigations—Certain of our Brazilian income tax returns for the years 2000 through 2004 are currently under examination.  The Brazilian tax authorities have issued tax assessments totaling $114 million, plus a 75 percent penalty in the amount of $86 million and interest through December 31, 2011 in the amount of $163 million.  An unfavorable outcome on these proposed assessments could result in a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We believe our returns are materially correct as filed, and we are vigorously contesting these assessments.  On January 25, 2008, we filed a protest letter with the Brazilian tax authorities, and we are currently engaged in the appeals process.

Other tax matters—We conduct operations through our various subsidiaries in a number of countries throughout the world.  Each country has its own tax regimes with varying nominal rates, deductions and tax attributes.  From time to time, we may identify changes to previously evaluated tax positions that could result in adjustments to our recorded assets and liabilities.  Although we are unable to predict the outcome of these changes, we do not expect the effect, if any, resulting from these assessments to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

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Earnings Per Share

3 Months Ended

Mar. 31, 2012

Earnings Per Share

Earnings Per Share

Note 9—Earnings Per Share

The numerator and denominator used for the computation of basic and diluted per share earnings from continuing operations were as follows (in millions, except per share data):

	Three months ended March 31,
	2012				2011
	Basic		Diluted		Basic			Diluted
Numerator for earnings per share
Income from continuing operations attributable to controlling interest	$	57	$	57	$	134		$	134
Undistributed earnings allocable to participating securities	—		—		(1		)	(1		)
Income from continuing operations available to shareholders	$	57	$	57	$	133		$	133
Denominator for earnings per share
Weighted-average shares outstanding	350		350		319			319
Effect of stock options and other share-based awards	—		—		—			1
Weighted-average shares for per share calculation	350		350		319			320
Per share earnings from continuing operations	$	0.16	$	0.16	$	0.42		$	0.42

For the three months ended March 31, 2012 and 2011, respectively, 1.8 million and 1.2 million share-based awards were excluded from the calculation since the effect would have been anti-dilutive.

The 1.50% Series B Convertible Senior Notes and 1.50% Series C Convertible Senior Notes did not have an effect on the calculation for the periods presented.  See Note 11—Debt.

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Condensed Consolidating Financial Information (Details 3) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Condensed Consolidating Financial Information
Cash flows from operating activities	$ 540	$ 390
Cash flows from investing activities
Capital expenditures	(260)	(240)
Proceeds from disposal of assets, net	41	13
Proceeds from disposal of discontinued operations, net		259
Other, net	12	(6)
Net cash provided by (used in) investing activities	(207)	26
Cash flows from financing activities
Changes in short-term borrowings, net		51
Proceeds from debt		5
Repayments of debt	(147)	(47)
Proceeds from restricted cash investments	108
Deposits to restricted cash investments	(42)
Distribution of qualifying additional paid-in capital	(278)
Other, net	(9)	(7)
Net cash provided by (used in) financing activities	(368)	2
Net increase (decrease) in cash and cash equivalents	(35)	418
Cash and cash equivalents at beginning of period	4,017	3,394
Cash and cash equivalents at end of period	3,982	3,812
Parent Guarantor
Condensed Consolidating Financial Information
Cash flows from operating activities	(15)	(13)
Cash flows from financing activities
Distribution of qualifying additional paid-in capital	(278)
Financing activities with affiliates, net	295
Net cash provided by (used in) financing activities	17
Net increase (decrease) in cash and cash equivalents	2	(13)
Cash and cash equivalents at beginning of period	3	38
Cash and cash equivalents at end of period	5	25
Subsidiary Issuer
Condensed Consolidating Financial Information
Cash flows from operating activities	(114)	(77)
Cash flows from investing activities
Investing activities with affiliates, net	(283)	(21)
Other, net	10
Net cash provided by (used in) investing activities	(273)	(21)
Cash flows from financing activities
Changes in short-term borrowings, net		51
Proceeds from debt		5
Repayments of debt	(29)	(12)
Financing activities with affiliates, net	(183)	509
Other, net	(9)	(7)
Net cash provided by (used in) financing activities	(221)	546
Net increase (decrease) in cash and cash equivalents	(608)	448
Cash and cash equivalents at beginning of period	2,793	2,041
Cash and cash equivalents at end of period	2,185	2,489
Other Subsidiaries
Condensed Consolidating Financial Information
Cash flows from operating activities	669	480
Cash flows from investing activities
Capital expenditures	(260)	(240)
Proceeds from disposal of assets, net	41	13
Proceeds from disposal of discontinued operations, net		259
Investing activities with affiliates, net	183	(509)
Other, net	2	(6)
Net cash provided by (used in) investing activities	(34)	(483)
Cash flows from financing activities
Repayments of debt	(118)	(35)
Proceeds from restricted cash investments	108
Deposits to restricted cash investments	(42)
Financing activities with affiliates, net	(12)	21
Net cash provided by (used in) financing activities	(64)	(14)
Net increase (decrease) in cash and cash equivalents	571	(17)
Cash and cash equivalents at beginning of period	1,221	1,315
Cash and cash equivalents at end of period	1,792	1,298
Consolidating adjustments
Cash flows from investing activities
Investing activities with affiliates, net	100	530
Net cash provided by (used in) investing activities	100	530
Cash flows from financing activities
Financing activities with affiliates, net	(100)	(530)
Net cash provided by (used in) financing activities	$ (100)	$ (530)

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Condensed Consolidating Financial Information (Details 2) (USD $) In Millions, unless otherwise specified	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011	Dec. 31, 2010
Assets
Cash and cash equivalents	$ 3,982	$ 4,017	$ 3,812	$ 3,394
Other current assets	3,691	3,592
Total current assets	7,673	7,609
Property and equipment, net	22,323	22,529
Goodwill	3,087	3,205
Other assets	1,632	1,745
Total assets	34,715	35,088
Liabilities and equity
Debt due within one year	2,792	2,039
Other current liabilities	2,972.0	3,319.0
Total current liabilities	5,764	5,358
Long-term debt	10,664	11,497
Other long-term liabilities	2,426	2,426
Total long-term liabilities	13,090	13,923
Commitments and contingencies
Redeemable noncontrolling interest	138	116	57	25
Total equity	15,723	15,691	21,705	21,375
Total liabilities and equity	34,715	35,088
Parent Guarantor
Assets
Cash and cash equivalents	5	3	25	38
Other current assets	10	8
Total current assets	15	11
Property and equipment, net	1	1
Investment in affiliates	16,560	16,503
Total assets	16,576	16,515
Liabilities and equity
Other current liabilities	17.0	294.0
Total current liabilities	17	294
Long-term debt	790	495
Other long-term liabilities	31	25
Total long-term liabilities	821	520
Commitments and contingencies
Total equity	15,738	15,701
Total liabilities and equity	16,576	16,515
Subsidiary Issuer
Assets
Cash and cash equivalents	2,185	2,793	2,489	2,041
Other current assets	877	784
Total current assets	3,062	3,577
Investment in affiliates	27,782	27,582
Other assets	1,642	1,368
Total assets	32,486	32,527
Liabilities and equity
Debt due within one year	2,185	1,693
Other current liabilities	428.0	367.0
Total current liabilities	2,613	2,060
Long-term debt	13,626	14,308
Other long-term liabilities	467	439
Total long-term liabilities	14,093	14,747
Commitments and contingencies
Total equity	15,780	15,720
Total liabilities and equity	32,486	32,527
Other Subsidiaries
Assets
Cash and cash equivalents	1,792	1,221	1,298	1,315
Other current assets	4,290	4,493
Total current assets	6,082	5,714
Property and equipment, net	22,322	22,528
Goodwill	3,087	3,205
Other assets	17,605	17,908
Total assets	49,096	49,355
Liabilities and equity
Debt due within one year	607	346
Other current liabilities	4,013.0	4,351.0
Total current liabilities	4,620	4,697
Long-term debt	13,863	14,225
Other long-term liabilities	1,928	1,962
Total long-term liabilities	15,791	16,187
Commitments and contingencies
Redeemable noncontrolling interest	138	116
Total equity	28,547	28,355
Total liabilities and equity	49,096	49,355
Consolidating adjustments
Assets
Other current assets	(1,486)	(1,693)
Total current assets	(1,486)	(1,693)
Investment in affiliates	(44,342)	(44,085)
Other assets	(17,615)	(17,531)
Total assets	(63,443)	(63,309)
Liabilities and equity
Debt due within one year	0
Other current liabilities	(1,486.0)	(1,693.0)
Total current liabilities	(1,486)	(1,693)
Long-term debt	(17,615)	(17,531)
Total long-term liabilities	(17,615)	(17,531)
Commitments and contingencies
Total equity	(44,342)	(44,085)
Total liabilities and equity	$ (63,443)	$ (63,309)

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Debt (Tables)

3 Months Ended

Mar. 31, 2012

Debt

Debt, net of unamortized discounts, premiums and fair value adjustments

	March 31, 2012						December 31, 2011
	Transocean Ltd. and subsidiaries		Consolidated variable interest entities		Consolidated total		Transocean Ltd. and subsidiaries		Consolidated variable interest entities		Consolidated total
5% Notes due February 2013	$	253	$	—	$	253	$	253	$	—	$	253
5.25% Senior Notes due March 2013 (a)	507		—		507		507		—		507
TPDI Credit Facilities due March 2015	—		455		455		—		473		473
4.95% Senior Notes due November 2015 (a)	1,120		—		1,120		1,120		—		1,120
Aker Revolving Credit and Term Loan Facility due December 2015	572		—		572		594		—		594
5.05% Senior Notes due December 2016 (a)	999		—		999		999		—		999
Callable Bonds due February 2016	278		—		278		267		—		267
ADDCL Credit Facilities due December 2017	—		218		218		—		217		217
Eksportfinans Loans due January 2018	852		—		852		884		—		884
6.00% Senior Notes due March 2018 (a)	998		—		998		998		—		998
7.375% Senior Notes due April 2018 (a)	247		—		247		247		—		247
TPDI Notes due October 2019	—		148		148		—		148		148
6.50% Senior Notes due November 2020 (a)	899		—		899		899		—		899
6.375% Senior Notes due December 2021 (a)	1,199		—		1,199		1,199		—		1,199
7.45% Notes due April 2027 (a)	97		—		97		97		—		97
8% Debentures due April 2027 (a)	57		—		57		57		—		57
7% Notes due June 2028	311		—		311		311		—		311
Capital lease contract due August 2029	671		—		671		676		—		676
7.5% Notes due April 2031 (a)	598		—		598		598		—		598
1.50% Series B Convertible Senior Notes due December 2037 (a)	—		—		—		30		—		30
1.50% Series C Convertible Senior Notes due December 2037 (a)	1,678		—		1,678		1,663		—		1,663
6.80% Senior Notes due March 2038 (a)	999		—		999		999		—		999
7.35% Senior Notes due December 2041 (a)	300		—		300		300		—		300
Total debt	12,635		821		13,456		12,698		838		13,536
Less debt due within one year
5% Notes due February 2013	253		—		253		—		—		—
5.25% Senior Notes due March 2013 (a)	507		—		507		—		—		—
TPDI Credit Facilities due March 2015	—		70		70		—		70		70
Aker Revolving Credit and Term Loan Facility due December 2015	90		—		90		90		—		90
ADDCL Credit Facilities due November 2017	—		27		27		—		27		27
Eksportfinans Loans due January 2018	149		—		149		142		—		142
Capital lease contract due August 2029	18		—		18		17		—		17
1.50% Series B Convertible Senior Notes due December 2037 (a)	—		—		—		30		—		30
1.50% Series C Convertible Senior Notes due December 2037 (a)	1,678		—		1,678		1,663		—		1,663
Total debt due within one year	2,695		97		2,792		1,942		97		2,039
Total long-term debt	$	9,940	$	724	$	10,664	$	10,756	$	741	$	11,497

(a)Transocean Inc., a 100 percent owned subsidiary of Transocean Ltd., is the issuer of the notes and debentures, which have been guaranteed by Transocean Ltd.  Transocean Ltd. has also guaranteed borrowings under the Five-Year Revolving Credit Facility.  Transocean Ltd. and Transocean Inc. are not subject to any significant restrictions on their ability to obtain funds from their consolidated subsidiaries by dividends, loans or return of capital distributions.  See Note 18—Condensed Consolidating Financial Information.

Scheduled maturities of debt

	Transocean Ltd.and subsidiaries			Consolidated variable interest entities		Consolidated total
Twelve months ending March 31,
2013	$	2,728		$	97	$	2,825
2014	260			98		358
2015	1,336			373		1,709
2016	1,762			33		1,795
2017	175			35		210
Thereafter	6,377			185		6,562
Total debt, excluding unamortized discounts, premiums and fair value adjustments	12,638			821		13,459
Total unamortized discounts, premiums and fair value adjustments, net	(3		)	—		(3		)
Total debt	$	12,635		$	821	$	13,456

Interest expense, excluding amortization of debt issue costs

	Three months ended March 31,
	2012		2011
Interest expense
Series B Convertible Senior Notes due 2037	$	—	$	20
Series C Convertible Senior Notes due 2037	21		20

Carrying amounts of liability components of outstanding convertible senior notes

	March 31, 2012							December 31, 2011
	Principal amount		Unamortized discount			Carrying amount		Principal amount		Unamortized discount			Carrying amount
Carrying amount of liability component
Series B Convertible Senior Notes due 2037	$	—	$	—		$	—	$	30	$	—		$	30
Series C Convertible Senior Notes due 2037	1,722		(44		)	1,678		1,722		(59		)	1,663

Carrying amounts of equity components of outstanding convertible senior notes

	March 31, 2012		December 31, 2011
Carrying amount of equity component
Series B Convertible Senior Notes due 2037	$	—	$	4
Series C Convertible Senior Notes due 2037	276		276

XML

Debt (Details)												3 Months Ended								3 Months Ended																																3 Months Ended																																										3 Months Ended														3 Months Ended
	Mar. 31, 2012 USD ($)	Mar. 31, 2012 NOK	Dec. 31, 2011 USD ($)	Mar. 31, 2012 5% Notes due February 2013 USD ($)	Dec. 31, 2011 5% Notes due February 2013 USD ($)	Mar. 31, 2012 5.25% Senior Notes due March 2013 USD ($)	Dec. 31, 2011 5.25% Senior Notes due March 2013 USD ($)	Mar. 31, 2012 TPDI Credit Facilities due March 2015 USD ($)	Dec. 31, 2011 TPDI Credit Facilities due March 2015 USD ($)	Mar. 31, 2012 4.95% Senior Notes due November 2015 USD ($)	Dec. 31, 2011 4.95% Senior Notes due November 2015 USD ($)	Mar. 31, 2012 Aker Revolving Credit and Term Loan Facility due December 2015 USD ($)	Dec. 31, 2011 Aker Revolving Credit and Term Loan Facility due December 2015 USD ($)	Mar. 31, 2012 Aker Revolving Credit Facility due December 2015 USD ($)	Feb. 21, 2011 Aker Term Loan Facility due December 2015 USD ($)	Mar. 31, 2012 5.05% Senior Notes due December 2016 USD ($)	Dec. 31, 2011 5.05% Senior Notes due December 2016 USD ($)	Mar. 31, 2012 Callable Bonds due February 2016 USD ($)	Dec. 31, 2011 Callable Bonds due February 2016 USD ($)	Mar. 31, 2012 FRN Callable Bonds USD ($)	Mar. 31, 2012 FRN Callable Bonds NOK	Mar. 31, 2012 11% Callable Bonds USD ($)	Mar. 31, 2012 11% Callable Bonds NOK	Mar. 31, 2012 Eksportfinans Loans due January 2018 USD ($)	Dec. 31, 2011 Eksportfinans Loans due January 2018 USD ($)	Mar. 31, 2012 6.00% Senior Notes due March 2018 USD ($)	Dec. 31, 2011 6.00% Senior Notes due March 2018 USD ($)	Mar. 31, 2012 7.375% Senior Notes due April 2018 USD ($)	Dec. 31, 2011 7.375% Senior Notes due April 2018 USD ($)	Mar. 31, 2012 6.50% Senior Notes due November 2020 USD ($)	Dec. 31, 2011 6.50% Senior Notes due November 2020 USD ($)	Mar. 31, 2012 6.375% Senior Notes due December 2021 USD ($)	Dec. 31, 2011 6.375% Senior Notes due December 2021 USD ($)	Mar. 31, 2012 7.45% Notes due April 2027 USD ($)	Dec. 31, 2011 7.45% Notes due April 2027 USD ($)	Mar. 31, 2012 8% Debentures due April 2027 USD ($)	Dec. 31, 2011 8% Debentures due April 2027 USD ($)	Mar. 31, 2012 7% Notes due June 2028 USD ($)	Dec. 31, 2011 7% Notes due June 2028 USD ($)	Mar. 31, 2012 Capital lease contract due August 2029 USD ($)	Dec. 31, 2011 Capital lease contract due August 2029 USD ($)	Mar. 31, 2012 7.5% Notes due April 2031 USD ($)	Dec. 31, 2011 7.5% Notes due April 2031 USD ($)	Mar. 31, 2012 1.50% Series B Convertible Senior Notes due December 2037	Dec. 31, 2011 1.50% Series B Convertible Senior Notes due December 2037 USD ($)	Mar. 31, 2012 1.50% Series C Convertible Senior Notes due December 2037 USD ($)	Dec. 31, 2011 1.50% Series C Convertible Senior Notes due December 2037 USD ($)	Mar. 31, 2012 6.80% Senior Notes due March 2038 USD ($)	Dec. 31, 2011 6.80% Senior Notes due March 2038 USD ($)	Mar. 31, 2012 7.35% Senior Notes due December 2041 USD ($)	Dec. 31, 2011 7.35% Senior Notes due December 2041 USD ($)	Mar. 31, 2012 Five Year Revolving Credit Facility USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 5% Notes due February 2013 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 5% Notes due February 2013 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 5.25% Senior Notes due March 2013 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 5.25% Senior Notes due March 2013 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 4.95% Senior Notes due November 2015 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 4.95% Senior Notes due November 2015 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries Aker Revolving Credit and Term Loan Facility due December 2015 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries Aker Revolving Credit and Term Loan Facility due December 2015 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 5.05% Senior Notes due December 2016 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 5.05% Senior Notes due December 2016 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries Callable Bonds due February 2016 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries Callable Bonds due February 2016 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries Eksportfinans Loans due January 2018 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries Eksportfinans Loans due January 2018 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 6.00% Senior Notes due March 2018 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 6.00% Senior Notes due March 2018 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 7.375% Senior Notes due April 2018 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 7.375% Senior Notes due April 2018 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 6.50% Senior Notes due November 2020 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 6.50% Senior Notes due November 2020 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 6.375% Senior Notes due December 2021 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 6.375% Senior Notes due December 2021 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 7.45% Notes due April 2027 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 7.45% Notes due April 2027 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 8% Debentures due April 2027 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 8% Debentures due April 2027 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 7% Notes due June 2028 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 7% Notes due June 2028 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries Capital lease contract due August 2029 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries Capital lease contract due August 2029 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 7.5% Notes due April 2031 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 7.5% Notes due April 2031 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 1.50% Series B Convertible Senior Notes due December 2037 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 1.50% Series C Convertible Senior Notes due December 2037 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 1.50% Series C Convertible Senior Notes due December 2037 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 6.80% Senior Notes due March 2038 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 6.80% Senior Notes due March 2038 USD ($)	Mar. 31, 2012 Transocean Ltd. and Subsidiaries 7.35% Senior Notes due December 2041 USD ($)	Dec. 31, 2011 Transocean Ltd. and Subsidiaries 7.35% Senior Notes due December 2041 USD ($)	Mar. 31, 2012 Transocean Inc.	Mar. 31, 2012 Consolidated variable interest entities USD ($)	Dec. 31, 2011 Consolidated variable interest entities USD ($)	Mar. 31, 2012 Consolidated variable interest entities TPDI Credit Facilities due March 2015 USD ($)	Dec. 31, 2011 Consolidated variable interest entities TPDI Credit Facilities due March 2015 USD ($)	Mar. 31, 2012 Consolidated variable interest entities ADDCL Credit Facilities due December 2017 USD ($)	Dec. 31, 2011 Consolidated variable interest entities ADDCL Credit Facilities due December 2017 USD ($)	Mar. 31, 2012 Consolidated variable interest entities TPDI Notes due October 2019 USD ($)	Dec. 31, 2011 Consolidated variable interest entities TPDI Notes due October 2019 USD ($)	Mar. 31, 2012 TPDI TPDI Credit Facilities due March 2015 USD ($)	Dec. 31, 2011 TPDI TPDI Credit Facilities due March 2015 USD ($)	Mar. 31, 2012 TPDI TPDI Credit Facilities Senior Term Loan Due March 2015 USD ($)	Mar. 31, 2012 TPDI TPDI Credit Facilities Junior Term Loan Due March 2015 USD ($)	Mar. 31, 2012 TPDI TPDI Credit Facilities Revolving Credit Facility Due March 2015 USD ($)	Mar. 31, 2012 TPDI TPDI Notes due October 2019 USD ($) shareholder	Dec. 31, 2011 TPDI TPDI Notes due October 2019 USD ($)	Mar. 31, 2012 TPDI Uncommitted Credit Facility Established by Subsidiary USD ($)	Mar. 31, 2012 ADDCL ADDCL Credit Facilities Tranche A Due November 2017 USD ($)	Mar. 31, 2012 ADDCL ADDCL Credit Facilities Tranche C Due November 2017 USD ($)	Mar. 31, 2012 ADDCL ADDCL Secondary Loan Facility Due December 2015 USD ($)	Dec. 31, 2011 ADDCL ADDCL Secondary Loan Facility Due December 2015 USD ($)
Long-term debt by current and noncurrent
Total debt	$ 13,456,000,000		$ 13,536,000,000	$ 253,000,000	$ 253,000,000	$ 507,000,000	$ 507,000,000	$ 455,000,000	$ 473,000,000	$ 1,120,000,000	$ 1,120,000,000	$ 572,000,000	$ 594,000,000			$ 999,000,000	$ 999,000,000	$ 278,000,000	$ 267,000,000					$ 852,000,000	$ 884,000,000	$ 998,000,000	$ 998,000,000	$ 247,000,000	$ 247,000,000	$ 899,000,000	$ 899,000,000	$ 1,199,000,000	$ 1,199,000,000	$ 97,000,000	$ 97,000,000	$ 57,000,000	$ 57,000,000	$ 311,000,000	$ 311,000,000	$ 671,000,000	$ 676,000,000	$ 598,000,000	$ 598,000,000		$ 30,000,000	$ 1,678,000,000	$ 1,663,000,000	$ 999,000,000	$ 999,000,000	$ 300,000,000	$ 300,000,000		$ 12,635,000,000	$ 12,698,000,000	$ 253,000,000	$ 253,000,000	$ 507,000,000	$ 507,000,000	$ 1,120,000,000	$ 1,120,000,000	$ 572,000,000	$ 594,000,000	$ 999,000,000	$ 999,000,000	$ 278,000,000	$ 267,000,000	$ 852,000,000	$ 884,000,000	$ 998,000,000	$ 998,000,000	$ 247,000,000	$ 247,000,000	$ 899,000,000	$ 899,000,000	$ 1,199,000,000	$ 1,199,000,000	$ 97,000,000	$ 97,000,000	$ 57,000,000	$ 57,000,000	$ 311,000,000	$ 311,000,000	$ 671,000,000	$ 676,000,000	$ 598,000,000	$ 598,000,000	$ 30,000,000	$ 1,678,000,000	$ 1,663,000,000	$ 999,000,000	$ 999,000,000	$ 300,000,000	$ 300,000,000		$ 821,000,000	$ 838,000,000	$ 455,000,000	$ 473,000,000	$ 218,000,000	$ 217,000,000	$ 148,000,000	$ 148,000,000						$ 148,000,000	$ 148,000,000
Debt due within one year	2,792,000,000		2,039,000,000	253,000,000		507,000,000		70,000,000	70,000,000			90,000,000	90,000,000											149,000,000	142,000,000															18,000,000	17,000,000				30,000,000	1,678,000,000	1,663,000,000						2,695,000,000	1,942,000,000	253,000,000		507,000,000				90,000,000	90,000,000					149,000,000	142,000,000															18,000,000	17,000,000			30,000,000	1,678,000,000	1,663,000,000						97,000,000	97,000,000	70,000,000	70,000,000	27,000,000	27,000,000
Long-term debt	10,664,000,000		11,497,000,000																																																		9,940,000,000	10,756,000,000																																									724,000,000	741,000,000
Debt instrument interest rate stated percentage				5.00%		5.25%				4.95%						5.05%						11.00%	11.00%			6.00%		7.375%		6.50%		6.375%		7.45%		8.00%		7.00%				7.50%		1.50%		1.50%		6.80%		7.35%
Percentage ownership interest in Transocean Inc. by Transocean Ltd.																																																																																														100.00%
Scheduled maturities of debt
2013	2,825,000,000																																																				2,728,000,000																																										97,000,000
2014	358,000,000																																																				260,000,000																																										98,000,000
2015	1,709,000,000																																																				1,336,000,000																																										373,000,000
2016	1,795,000,000																																																				1,762,000,000																																										33,000,000
2017	210,000,000																																																				175,000,000																																										35,000,000
Thereafter	6,562,000,000																																																				6,377,000,000																																										185,000,000
Total debt, excluding unamortized discounts, premiums and fair value adjustments	13,459,000,000																																																				12,638,000,000																																										821,000,000
Total unamortized discounts, premiums and fair value adjustments	(3,000,000)																																																				(3,000,000)
Total debt	13,456,000,000		13,536,000,000	253,000,000	253,000,000	507,000,000	507,000,000	455,000,000	473,000,000	1,120,000,000	1,120,000,000	572,000,000	594,000,000			999,000,000	999,000,000	278,000,000	267,000,000					852,000,000	884,000,000	998,000,000	998,000,000	247,000,000	247,000,000	899,000,000	899,000,000	1,199,000,000	1,199,000,000	97,000,000	97,000,000	57,000,000	57,000,000	311,000,000	311,000,000	671,000,000	676,000,000	598,000,000	598,000,000		30,000,000	1,678,000,000	1,663,000,000	999,000,000	999,000,000	300,000,000	300,000,000		12,635,000,000	12,698,000,000	253,000,000	253,000,000	507,000,000	507,000,000	1,120,000,000	1,120,000,000	572,000,000	594,000,000	999,000,000	999,000,000	278,000,000	267,000,000	852,000,000	884,000,000	998,000,000	998,000,000	247,000,000	247,000,000	899,000,000	899,000,000	1,199,000,000	1,199,000,000	97,000,000	97,000,000	57,000,000	57,000,000	311,000,000	311,000,000	671,000,000	676,000,000	598,000,000	598,000,000	30,000,000	1,678,000,000	1,663,000,000	999,000,000	999,000,000	300,000,000	300,000,000		821,000,000	838,000,000	455,000,000	473,000,000	218,000,000	217,000,000	148,000,000	148,000,000						148,000,000	148,000,000
Credit facility term (in years)																																																				5 years
Borrowing capacity, maximum														500,000,000																																						2,000,000,000																																																			1,265,000,000				75,000,000				215,000,000	399,000,000	90,000,000
Weighted-average interest rate (as a percent)																																																																																																							2.10%								1.50%		3.60%
Debt instrument face amount															400,000,000																																																																																										1,000,000,000	190,000,000
Minimum facility fee on the daily amount of five-year revolving credit facility (as a percent)																																																				0.13%
Maximum facility fee on the daily amount of five-year revolving credit facility (as a percent)																																																				0.33%
Commitment fee percentage at period end																																																				0.275%
Credit facility available borrowing capacity																																																				2,000,000,000
Letters of credit issued and outstanding																																																				24,000,000																																																										60,000,000
Principal amount outstanding																				165,000,000	940,000,000	98,000,000	560,000,000																						30,000,000	1,722,000,000	1,722,000,000																																																													296,000,000			190,000,000
Aggregate commitment of subsidiary in secured term loan								595,000,000
Credit facility amount outstanding												570,000,000																																																																																											910,000,000										79,000,000
Debt due to a subsidiary, eliminated in consolidation																																																																																																							455,000,000					148,000,000				399,000,000	51,000,000
Restricted investments used as security for debt instruments																								857,000,000	889,000,000																																																																														26,000,000	23,000,000									30,000,000	16,000,000
NOK exchange rate		5.69
Number of shareholders to which TPDI has issued promissory notes																																																																																																												2
Weighted-average interest rate (as a percent)												3.00%								9.70%	9.70%																																																																																							2.70%
Percentage of total commitment under ADDCL secondary bank credit agreement provided by subsidiary																																																																																																																	65.00%

XML

Contingencies

3 Months Ended

Mar. 31, 2012

Contingencies

Contingencies

Note 14—Contingencies

Macondo well incident

Overview—On April 22, 2010, the Ultra-Deepwater Floater Deepwater Horizon sank after a blowout of the Macondo well caused a fire and explosion on the rig.  Eleven persons were declared dead and others were injured as a result of the incident.  At the time of the explosion, Deepwater Horizon was located approximately 41 miles off the coast of Louisiana in Mississippi Canyon Block 252 and was contracted to BP America Production Co. (“BP”).

We are currently unable to estimate the full impact the Macondo well incident will have on us.  We have recognized a liability for estimated loss contingencies that we believe are probable and for which a reasonable estimate can be made.  As of March 31, 2012, we have recognized a liability for such loss contingencies in the amount of $1.2 billion.  This liability takes into account certain events related to the litigation and investigations arising out of the incident.  There are loss contingencies related to the Macondo well incident that we believe are reasonably possible and for which we do not believe a reasonable estimate can be made.  These contingencies could increase the liabilities we ultimately recognize.  As of March 31, 2012, we have also recognized an asset of $222 million associated with the portion of our estimated losses that we believe is recoverable from insurance.  Although we have available policy limits that could result in additional amounts recoverable from insurance, we are not currently able to estimate the amount of such additional recoverable amounts.  Our estimates involve a significant amount of judgment.  As a result of new information or future developments, we may adjust our estimated loss contingencies arising out of the Macondo well incident, and the resulting liabilities could have a material adverse effect on our consolidated statement of financial position, results of operations and cash flows.  As of December 31, 2011, the amount of the estimated liability was $1.2 billion, and the estimated recoverable amount was $220 million.

Many of the Macondo well related claims are pending in the U.S. District Court, Eastern District of Louisiana (the “MDL Court”).  The first phase of a three-phase trial was scheduled to commence on March 5, 2012.  However, on March 2, 2012, BP and the Plaintiff’s Steering Committee (the “PSC”) announced that they had agreed to a partial settlement related primarily to private party environmental and economic loss claims as well as response effort related claims (the “BP/PSC Settlement”).  The BP/PSC Settlement has resulted in the trial being stayed until the court has issued an order outlining a new trial plan.  BP has disclosed that (a) the BP/PSC Settlement is subject to a final written agreement and court approvals, (b) the proposed settlement provides that to the extent provided by law, BP will assign to the PSC certain of its claims, rights and recoveries against us for damages with protections such that the PSC is barred from collecting any amounts from us unless it is finally determined that we cannot recover such amounts from BP, and (c) BP will have the right to approve any settlement between us and the PSC.  We are unable to predict the form of the new trial plan or when trial will commence.  Further, there can be no assurance as to the outcome of the trial, that the trial will proceed according to a new proposed schedule, that we will not enter into a settlement as to some or all of the matters related to the Macondo well incident, including those to be determined at a trial, or the timing or terms of any such settlement.

In April 2011, several defendants in the Macondo well litigation before the Multi-District Litigation Panel (the “MDL”) filed cross-claims or third-party claims against us and certain of our subsidiaries, and other defendants.  BP filed a claim seeking contribution under the Oil Pollution Act of 1990 (“OPA”) and maritime law, subrogation and claimed breach of contract, unseaworthiness, negligence and gross negligence.  BP also sought a declaration that it is not liable in contribution, indemnification, or otherwise to us.  Anadarko Petroleum Corporation (“Anadarko”), which owns a 25 percent non-operating interest in the Macondo well, asserted claims of negligence, gross negligence, and willful misconduct and is seeking indemnity under state and maritime law and contribution under maritime and state law as well as OPA.  MOEX Offshore 2007 LLC (“MOEX”), which owns a 10 percent non-operating interest in the Macondo well, filed claims of negligence under state and maritime law, gross negligence under state law, gross negligence and willful misconduct under maritime law and is seeking indemnity under state and maritime law and contribution under maritime law and OPA.  Cameron International Corporation (“Cameron”), the manufacturer and designer of the blowout preventer, asserted multiple claims for contractual indemnity and declarations regarding contractual obligations under various contracts and quotes and is also seeking non-contractual indemnity and contribution under maritime law and OPA.  As part of the BP/PSC Settlement, one or more of these claims against us and certain of our subsidiaries may be assigned to the PSC.  Halliburton Company (“Halliburton”), which provided cementing and mud-logging services to the operator, filed a claim seeking contribution and indemnity under maritime law, contractual indemnity and alleging negligence and gross negligence.  Additionally, certain other third parties filed claims for indemnity and contribution.

On April 20, 2011, we filed cross-claims and counter-claims against BP, Halliburton, Cameron, Anadarko, MOEX, certain of these parties’ affiliates, the U.S. and certain other third parties.  We seek indemnity, contribution (including contribution under OPA), and subrogation under OPA, and we have asserted claims for breach of warranty of workmanlike performance, strict liability for manufacturing and design defect, breach of express contract, and damages for the difference between the fair market value of Deepwater Horizon and the amount received from insurance proceeds.  We are not pursuing arbitration on the key contractual issues with BP; instead, we are relying on the court to resolve the disputes.  With regard to the U.S., we are not currently seeking recovery of monetary damages, but rather a declaration regarding relative fault and contribution via credit, setoff, or recoupment.

Notices of alleged non-compliance—The final Joint Investigation Team report was issued on September 14, 2011.  Subsequently, the Department of the Interior’s Bureau of Safety and Environmental Enforcement issued four notices of alleged non-compliance with regulatory requirements to us on October 12, 2011.  While we cannot predict or provide assurance as to the full outcome of these citations, they could result in the assessment of civil penalties.  Our appeal is stayed by mutual agreement with the Department of Interior until a ruling is issued in the MDL.

Insurance coverage—In May 2010, we received notice from BP maintaining that it believes that it is entitled to additional insured status under our excess liability insurance program.  In response, many of our insurers filed declaratory judgment actions in the Houston Division of the U.S. District Court for the Southern District of Texas in May 2010 seeking a judgment declaring that they have limited additional insured obligation to the operator.  Our insurers have also received notices from Anadarko and MOEX advising of their intent to preserve any rights they may have to our insurance policies as an additional insured under the drilling contract.  We, Anadarko and MOEX each have entered into the declaratory judgment actions.  The actions have been transferred to the MDL for discovery purposes in the MDL Court.  On November 15, 2011, the court ruled that coverage rights are limited to the scope of Transocean’s indemnity of BP in the drilling contract.  A final judgment has been entered, and BP has filed a notice of appeal.  While we cannot predict when the appellate court will hear arguments, or the outcome of the appeal, briefs are due by May 7, 2012 and responses are due by June 6, 2012.

At the time of the Macondo well incident, our excess liability insurance program offered aggregate insurance coverage of $950 million, exclusive of a $15 million deductible and a $50 million self-insured layer through our wholly owned captive insurance subsidiary.  This excess liability insurance coverage consisted of a first and a second layer of $150 million each, a third and fourth layer of $200 million each and a fifth layer of $250 million.  The $250 million fifth layer contained different contractual terms, compared to the first four layers, with regard to additional insured status, such that we believe with reasonable certainty that BP, Anadarko and MOEX do not have contractual right to additional insured status under that layer of our insurance program.

Additionally, our first layer of excess insurers filed interpleader actions on June 17, 2011.  The insurers contend that they face multiple, and potentially competing, claims to the relevant insurance proceeds.  In these actions, the insurers effectively ask the court to manage disbursement of the funds to the alleged claimants, as appropriate, and discharge the insurers of any additional liability.  The parties to the suits have executed a protocol, and claims have been submitted to the court for review.  The parties to the interpleaders have agreed to a protocol to facilitate the reimbursement and funding of settlements of personal injury and fatality claims of our crew and vendors using insurance funds.  To date, no payments have yet been received.

Litigation—As of March 31, 2012, 373 actions or claims were pending against us, along with other unaffiliated defendants, in state and federal courts.  Additionally, government agencies have initiated investigations into the Macondo well incident.  We have categorized below the nature of the legal actions or claims.  We are evaluating all claims and intend to vigorously defend any claims and pursue any and all defenses available.  In addition, we believe we are entitled to contractual defense and indemnity for all wrongful death and personal injury claims made by non-employees and third-party subcontractors’ employees as well as all liabilities for pollution or contamination, other than for pollution or contamination originating on or above the surface of the water.  See “—Contractual indemnity.”

Wrongful death and personal injury—As of March 31, 2012, we have been named, along with other unaffiliated defendants, in 19 complaints that were pending in state and federal courts in Louisiana and Texas involving multiple plaintiffs that allege wrongful death and other personal injuries arising out of the Macondo well incident.  Per the order of the MDL, these claims have been centralized for discovery purposes in the MDL Court.  The complaints generally allege negligence and seek awards of unspecified economic damages and punitive damages.  BP, MI-SWACO, Weatherford Ltd. and Cameron and certain of their affiliates, have, based on contractual arrangements, also made indemnity demands upon us with respect to personal injury and wrongful death claims asserted by our employees or representatives of our employees against these entities.  See “—Contractual indemnity.”

Economic loss—As of March 31, 2012, we and certain of our subsidiaries were named, along with other unaffiliated defendants, in 139 individual complaints as well as 185 putative class-action complaints that were pending in the federal and state courts in Louisiana, Texas, Mississippi, Alabama, Georgia, Kentucky, South Carolina, Tennessee, Florida and possibly other courts.  The complaints generally allege, among other things, potential economic losses as a result of environmental pollution arising out of the Macondo well incident and are based primarily on the OPA and state OPA analogues.  The plaintiffs are generally seeking awards of unspecified economic, compensatory and punitive damages, as well as injunctive relief.  These actions have been transferred to the MDL.  See “—Contractual indemnity.”

Federal securities claims—Two federal securities law class actions were pending in the U.S. District Court, Southern District of New York, naming us and certain of our officers and directors as defendants.  One of these actions, which was dismissed on March 20, 2012, generally alleged violations of Section 10(b) of the Securities Exchange Act of 1934 (the “Exchange Act”), Rule 10b-5, as promulgated under the Exchange Act, and Section 20(a) of the Exchange Act in connection with the Macondo well incident.  The plaintiffs sought awards of unspecified economic damages, including damages resulting from the decline in our stock price after the Macondo well incident.  The plaintiffs could file an appeal to the dismissal of this action.  The other action, which is still pending, was filed by a former GlobalSantaFe Corporation shareholder, alleging that the proxy statement related to our shareholder meeting in connection with our merger with GlobalSantaFe Corporation violated Section 14(a) of the Exchange Act, Rule 14a-9 promulgated thereunder and Section 20(a) of the Exchange Act.  The plaintiff claims that GlobalSantaFe Corporation shareholders received inadequate consideration for their shares as a result of the alleged violations and seeks rescission and compensatory damages.  The defendants filed a motion to dismiss the claim, but on March 30, 2012, the court denied defendant’s motion.  Defendants have the ability to appeal the ruling but have not yet done so.  A pretrial scheduling conference is set for May 17, 2012, at which time discovery and motion practice deadlines will be established.

Other federal statutes—Several of the claimants have made assertions under the statutes, including the Clean Water Act, the Endangered Species Act, the Migratory Bird Treaty Act, the Clean Air Act, the Comprehensive Environmental Response Compensation and Liability Act and the Emergency Planning and Community Right-to-Know Act.

Shareholder derivative claims—In June 2010, two shareholder derivative suits were filed by our shareholders naming us as a nominal defendant and certain of our officers and directors as defendants in the District Courts of the State of Texas.  The first case generally alleges breach of fiduciary duty, unjust enrichment, abuse of control, gross mismanagement and waste of corporate assets in connection with the Macondo well incident and the other generally alleges breach of fiduciary duty, unjust enrichment and waste of corporate assets in connection with the Macondo well incident.  The plaintiffs are generally seeking, on behalf of us, restitution and disgorgement of all profits, benefits and other compensation from the defendants.  Under current schedule orders, an amended consolidated complaint must be filed by the plaintiffs by June 5, 2012.

Government claims—On December 15, 2010, the U.S. Department of Justice (“DOJ”) filed a civil lawsuit against us and other unaffiliated defendants.  The complaint alleges violations under OPA and the Clean Water Act, including claims for per barrel civil penalties of up to $1,100 per barrel or up to $4,300 per barrel if gross negligence or willful misconduct is established, and the DOJ reserved its rights to amend the complaint to add new claims and defendants.  The U.S. government has estimated that up to 4.1 million barrels of oil were discharged and subject to penalties.  The complaint asserts that all defendants named are jointly and severally liable for all removal costs and damages resulting from the Macondo well incident.  On December 6, 2011, the DOJ filed a motion for partial summary judgment seeking a ruling that we were jointly and severely liable under OPA, and liable for civil penalties under the Clean Water Act, for all of the discharges from the Macondo well on the theory that discharges not only came from the well but also from the blowout preventer and riser, appurtenances of Deepwater Horizon.

On January 9, 2012, we filed our opposition to the motion and filed a cross-motion for partial summary judgment seeking a ruling that we are not liable for the subsurface discharge of hydrocarbons.  On February 22, 2012, the MDL Court ruled that we are not liable as a responsible party for damages under OPA with respect to the below surface discharges from the Macondo well.  The court also ruled that the below surface discharge was discharged from the well facility, and not from the Deepwater Horizon vessel, within the meaning of the Clean Water Act, and that we therefore are not liable for such discharges as an owner of the vessel under the Clean Water Act.  However, the court ruled that the issue of whether we could be held liable for such discharge under the Clean Water Act as an “operator” of the well facility could not be resolved on summary judgment.  The court did not determine whether we could be liable for removal costs under OPA, or the extent of such removal costs.

In addition to the civil complaint, the DOJ served us with civil investigative demands on December 8, 2010.  These demands were part of an investigation by the DOJ to determine if we made false claims, or false statements in support of claims, in connection with the operator’s acquisition of the leasehold interest in the Mississippi Canyon Block 252, Gulf of Mexico and drilling operations on Deepwater Horizon.

The DOJ is also conducting a criminal investigation into the Macondo well incident.  On March 7, 2011, the DOJ announced the formation of a new task force to lead the criminal investigation.  The task force served us with informal requests for documents in March 2011, and a grand jury issued a subpoena requesting documents from us on April 13, 2011.  We have had a number of communications with the task force since that time, and the task force has made informal requests for additional information from us from time to time.  The task force is investigating possible violations by us and certain unaffiliated parties of the Clean Water Act, the Migratory Bird Treaty Act, the Refuse Act, the Endangered Species Act, and the Seaman’s Manslaughter Act, among other federal statutes, and possible criminal liabilities including fines under those statutes and under the Alternative Fines Act.  Under the Alternatives Fines Act, a corporate defendant convicted of a criminal offense may be subject to a fine in the amount of twice the gross pecuniary loss suffered by third parties as a result of the offense.  If we are charged with or convicted of certain criminal environmental offenses, we may be subject to suspension or debarment as a contractor or subcontractor on certain government contracts, including leases.

In June 2010, the Louisiana Department of Environmental Quality (the “LDEQ”) issued a consolidated compliance order and notice of potential penalty to us and certain of our subsidiaries asking us to eliminate and remediate discharges of oil and other pollutants into waters and property located in the State of Louisiana, and to submit a plan and report in response to the order.  In October 2010, the LDEQ rescinded its enforcement actions against us and our subsidiaries but reserved its rights to seek civil penalties for future violations of the Louisiana Environmental Quality Act.

In September 2010, the State of Louisiana filed a declaratory judgment seeking to designate us as a responsible party under OPA and the Louisiana Oil Spill Prevention and Response Act for the discharges emanating from the Macondo well.

Additionally, suits have been filed by the State of Alabama and the cities of Greenville, Evergreen, Georgiana and McKenzie, Alabama in the U.S. District Court, Middle District of Alabama; the Mexican States of Veracruz, Quintana Roo and Tamaulipas in the U.S. District Court, Western District of Texas; and the City of Panama City Beach, Florida in the U.S. District Court, Northern District of Florida.  Suits were also filed by the City of New Orleans, by and on behalf of multiple Parishes, and by or on behalf of the Town of Grand Isle, Grand Isle Independent Levee District, the Town of Jean Lafitte, the Lafitte Area Independent Levee District, the City of Gretna, the City of Westwego, and the City of Harahan in the MDL Court.  Additional suits were filed by or on behalf of other Parishes in the respective Parish courts and were removed to federal court.  A local government master complaint also was filed in which cities, municipalities, and other local government entities can and have joined.  Generally, these governmental entities allege economic losses under OPA and other statutory environmental state claims and also assert various common law state claims.  The claims have been centralized in the MDL and will proceed in accordance with the MDL scheduling order.  The city of Panama City Beach’s claim was voluntarily dismissed.

On August 26, 2011, the MDL Court ruled on the motion to dismiss certain economic loss claims.  The court ruled that state law, both statutory and common law, is preempted by maritime law, notwithstanding OPA’s savings provisions.  Accordingly, all claims brought under state law were dismissed.  Secondly, general maritime law claims that do not allege physical damage to a proprietary interest were dismissed, unless the claim falls into the commercial fisherman exception.  The court ruled that OPA claims for economic loss do not require physical damage to a proprietary interest.  Third, the MDL Court ruled that presentment under OPA is a mandatory condition precedent to filing suit against a responsible party.  Finally, the MDL Court ruled that claims for punitive damages may be available under general maritime law in claims against responsible parties and non-responsible parties.  Certain Louisiana parishes have appealed portions of this ruling, and briefs are due by May 14, 2012 and responses are due by June 13, 2012.

The Mexican States’ OPA claims were dismissed for failure to demonstrate that recovery under OPA was authorized by treaty or executive agreement.  This ruling may be appealed.

By letter dated May 5, 2010, the Attorneys General of the five Gulf Coast states of Alabama, Florida, Louisiana, Mississippi and Texas informed us that they intend to seek recovery of pollution clean-up costs and related damages arising from the Macondo well incident.  In addition, by letter dated June 21, 2010, the Attorneys General of the 11 Atlantic Coast states of Connecticut, Delaware, Georgia, Maine, Maryland, Massachusetts, New Hampshire, New York, North Carolina, Rhode Island and South Carolina informed us that their states have not sustained any damage from the Macondo well incident but they would like assurances that we will be responsible financially if damages are sustained.  We responded to each letter from the Attorneys General and indicated that we intend to fulfill our obligations as a responsible party for any discharge of oil from Deepwater Horizon on or above the surface of the water, and we assume that the operator will similarly fulfill its obligations under OPA for discharges from the undersea well.

Wreck removal—By letter dated December 6, 2010, the U.S. Coast Guard requested us to formulate and submit a comprehensive oil removal plan to remove any diesel fuel contained in the sponsons and fuel tanks that can be recovered from Deepwater Horizon.  We have conducted a survey of the rig wreckage and have confirmed that no diesel fuel remains on the rig.  We have insurance coverage for wreck removal for up to 25 percent of Deepwater Horizon’s insured value, or $140 million, with any excess wreck removal liability generally covered to the extent of our remaining excess liability limits.  The U.S. Coast Guard has not requested that we remove the rig wreckage from the sea floor.

Contractual indemnity—Under our drilling contract for Deepwater Horizon, the operator has agreed, among other things, to assume full responsibility for and defend, release and indemnify us from any loss, expense, claim, fine, penalty or liability for pollution or contamination, including control and removal thereof, arising out of or connected with operations under the contract other than for pollution or contamination originating on or above the surface of the water from hydrocarbons or other specified substances within the control and possession of the contractor, as to which we agreed to assume responsibility and protect, release and indemnify the operator.  Although we do not believe it is applicable to the Macondo well incident, we also agreed to indemnify and defend the operator up to a limit of $15 million for claims for loss or damage to third parties arising from pollution caused by the rig while it is off the drilling location, while the rig is underway or during drive off or drift off of the rig from the drilling location.  The operator has also agreed, among other things, (1) to defend, release and indemnify us against loss or damage to the reservoir, and loss of property rights to oil, gas and minerals below the surface of the earth and (2) to defend, release and indemnify us and bear the cost of bringing the well under control in the event of a blowout or other loss of control.  We agreed to defend, release and indemnify the operator for personal injury and death of our employees, invitees and the employees of our subcontractors while the operator agreed to defend, release and indemnify us for personal injury and death of its employees, invitees and the employees of its other subcontractors, other than us.  We have also agreed to defend, release and indemnify the operator for damages to the rig and equipment, including salvage or removal costs.

Although we believe we are entitled to contractual defense and indemnity, given the potential amounts involved in connection with the Macondo well incident, the operator has sought to avoid its indemnification obligations.  In particular, the operator, in response to our request for indemnification, has generally reserved all of its rights and stated that it could not at this time conclude that it is obligated to indemnify us.  In doing so, the operator has asserted that the facts are not sufficiently developed to determine who is responsible and has cited a variety of possible legal theories based upon the contract and facts still to be developed.  We believe this reservation of rights is without justification and that the operator is required to honor its indemnification obligations contained in our contract and described above.

In April 2011, BP filed a claim seeking a declaration that it is not liable to us in contribution, indemnification, or otherwise.  On November 1, 2011, we filed a motion for partial summary judgment, seeking enforcement of the indemnity obligations for pollution and civil fines and penalties contained in the drilling contract with BP.  On January 26, 2012, the court ruled that the drilling contract requires BP to indemnify us for compensatory damages asserted by third parties against us related to pollution that did not originate on or above the surface of the water, even if the claim is the result of our strict liability, negligence, or gross negligence. The court also held that BP does not owe us indemnity to the extent that we are held liable for civil penalties under the Clean Water Act or for punitive damages.  The court deferred ruling on BP’s argument that we breached the drilling contract or materially increased BP’s risk or prejudiced its rights so as to vitiate BP’s indemnity obligations.  Our motion for partial summary judgment and the court’s ruling did not address the issue of contractual indemnity for criminal fines and penalties.  The law generally considers contractual indemnity for criminal fines and penalties to be against public policy.

Other legal proceedings

Brazil Frade field incident—On or about November 7, 2011, oil was released from fissures in the ocean floor in the vicinity of a development well being drilled by Chevron off the coast of Rio de Janeiro in the Frade field with Sedco 706.  The release was ultimately controlled, the well was plugged, and the released oil is being contained by Chevron.

On March 15, 2012, Chevron publicly announced that it had identified a new sheen in Frade field whose source was determined to be seepage from an 800-meter fissure 3 kilometers away from the location of the November incident.  Chevron and the Brazilian National Agency of Petroleum have publicly stated that, while further studies are being conducted, the new seepage, which is estimated by Chevron at five liters, appears to be unrelated to the November incident.

On or about December 13, 2011, a federal prosecutor in the town of Campos in Rio de Janeiro State filed a civil public action against Chevron and us seeking BRL 20.0 billion, equivalent to approximately $11.0 billion, and seeking a preliminary and permanent injunction preventing Chevron and us from operating in Brazil.  The prosecutor amended the requested injunction on December 15, 2011, to seek to prevent Chevron and us from conducting extraction or transportation activities in Brazil and to seek to require Chevron to stop the release and remediate its effects.  On January 11, 2012, a judge of the federal court in Campos issued an order finding that the case should be transferred to the federal court in Rio de Janeiro.  The prosecutor has appealed this jurisdictional decision, and that appeal remains pending.  On February 24, 2012, the court in Rio de Janeiro issued an order denying the federal prosecutor’s request for a preliminary injunction.  On March 27, 2012, the federal prosecutor filed an appeal of that denial, citing the new March 2012 seepage as a reason to overrule the decision denying the preliminary injunction.  On March 30, 2012, the appellate court issued a decision denying the federal prosecutor’s appeal and upholding the trial court’s decision to deny the preliminary injunction.  On March 28, 2012, the original trial court complaint was served on us.  The lawsuit will continue in the trial court, and there remains a risk that Brazilian authorities could temporarily or permanently enjoin us from further operations in Brazil.

On December 21, 2011, a federal police marshal investigating the release filed a report with the federal court in Rio de Janeiro State recommending the indictment of Chevron, us, and 17 individuals, five of whom are our employees.  The report recommended indictment on four counts, three alleging environmental offenses and one alleging false statements by Chevron in connection with its cleanup efforts.  The federal court in Rio de Janeiro State forwarded the report to the federal court in Campos for a decision on the proper jurisdiction for the matter.  On March 16, 2012, the Campos federal prosecutor sought and obtained from a special duty judge in Rio de Janeiro injunctions against the 17 individuals preventing them from leaving the country without court permission and requiring the Campos court to obtain their passports.  On March 21, 2012, the Campos prosecutor issued the recommended indictments against the two companies and the 17 individuals.  The prosecutor requested that the defendants be enjoined from disposing of property and that bail be set at BRL 10 million for the companies and BRL 1 million for the individuals.  The indictments must be approved by a court of competent jurisdiction to become effective.  As of March 31, 2012, the court has not yet approved the indictments.

On March 27, 2012, the union of oil industry workers in Brazil, Federacao Unica dos Petroleiros (“FUP”), filed a civil lawsuit in federal court in Rio de Janeiro against Chevron and us seeking revocation of Chevron’s and our contracts and permits in Brazil.  The lawsuit also seeks unspecified damages.  FUP does not represent our workers.  As of March 31, 2012, we had not yet been served with this lawsuit.

The drilling services and charter contracts between Chevron and us provide, among other things, for Chevron to indemnify and defend us for claims based on pollution or contamination originating from below the surface of the water, including claims for control or removal or property loss or damage, including but not limited to third-party claims and liabilities, with an excludable amount of $250,000 per occurrence if the claim arises from our negligence.  We have submitted a claim for indemnity and defense to Chevron under these contracts.  Chevron has responded that our request is premature, and has requested that we confirm our intent to indemnify and defend Chevron regarding alleged violations of safety regulations aboard Sedco 706 that have resulted in the issuance of notices of infractions and any other claims or liabilities that may fall within our legal obligations.  Discussions between Chevron and us are ongoing.

We intend to defend vigorously against any claims that are brought based on the incident.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect it to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  See Note 19—Subsequent Events

Asbestos Litigation—In 2004, several of our subsidiaries were named, along with numerous other unaffiliated defendants, in 21 complaints filed on behalf of 769 plaintiffs in the Circuit Courts of the State of Mississippi and which claimed injuries arising out of exposure to asbestos allegedly contained in drilling mud during these plaintiffs’ employment in drilling activities between 1965 and 1986.  Each individual plaintiff was subsequently required to file a separate lawsuit, and the original 21 multi-plaintiff complaints were then dismissed by the Circuit Courts.  The amended complaints resulted in one of our subsidiaries being named as a direct defendant in seven cases.  As a result of the acquisition of GlobalSantaFe Corporation, we are defending an additional seven cases.  We have or may have an indirect interest in an additional 12 cases, for a total of 26 cases of interest.  The complaints generally allege that the defendants used or manufactured asbestos-containing drilling mud additives for use in connection with drilling operations and have included allegations of negligence, products liability, strict liability and claims allowed under the Jones Act and general maritime law.  The plaintiffs generally seek awards of unspecified compensatory and punitive damages.  In each of these cases, the complaints have named other unaffiliated defendant companies, including companies that allegedly manufactured the drilling-related products that contained asbestos.  All of these cases are being governed for discovery and trial setting by a single Case Management Order entered by a Special Master appointed by the court to reside over all the cases, and none of the seven cases in which we are a named defendant have been scheduled for trial or pre-trial discovery.  The preliminary information available on these claims is not sufficient to determine if there is an identifiable period for alleged exposure to asbestos, whether any asbestos exposure in fact occurred, the vessels potentially involved in the claims, or the basis on which the plaintiffs would support claims that their injuries were related to exposure to asbestos.  However, the initial evidence available would suggest that we would have significant defenses to liability and damages.  None of our companies have manufactured or distributed drilling mud or additives for same, and the handling of such additives by one of our employees would be a relatively infrequent occurrence that likely would have involved a non-asbestos product.  In 2011, the Special Master issued a ruling that a Jones Act employer defendant, such as us, cannot be sued for punitive damages, and we expect this ruling to apply to each of our seven cases.  To date, seven of the 769 cases have gone to trial against defendants who allegedly manufactured or distributed drilling mud additives.  None of these cases have involved an individual Jones Act employer, and we have not been a defendant in any of these cases.  Two of the cases resulted in defense verdicts, and one case ended with a hung jury.  Four cases resulted in verdicts for the plaintiff.  Because the jury awarded punitive damages, two of these cases resulted in a substantial verdict in favor of the plaintiff; however both of these verdicts have since been vacated by the trial court.  One was vacated on the basis that the plaintiff failed to meet its burden of proof.  While the court’s decision is consistent with our general evaluation of the strength of these cases, it is currently being reviewed on appeal.  The second plaintiff verdict was vacated because the presiding judge was removed from hearing any asbestos cases due to a conflict of interest.  The two remaining plaintiff verdicts are under appeal by the defendants.  We intend to defend these lawsuits vigorously, although there can be no assurance as to the ultimate outcome.  We historically have maintained broad liability insurance, although we are not certain whether insurance will cover the liabilities, if any, arising out of these claims.  Based on our evaluation of the exposure to date, we do not expect the liability, if any, resulting from these claims to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

One of our subsidiaries was involved in lawsuits arising out of the subsidiary’s involvement in the design, construction and refurbishment of major industrial complexes.  The operating assets of the subsidiary were sold and its operations discontinued in 1989, and the subsidiary has no remaining assets other than the insurance policies involved in its litigation, with its insurers and, either directly or indirectly as the beneficiary of a qualified settlement fund, funding from settlements with insurers, assigned rights from insurers and coverage-in-place settlement agreements with insurers, and funds received from the commutation of certain insurance policies.  The subsidiary has been named as a defendant, along with numerous other companies, in lawsuits alleging bodily injury or personal injury as a result of exposure to asbestos.  As of March 31, 2012, the subsidiary was a defendant in approximately 990 lawsuits, some of which include multiple plaintiffs, and we estimate that there are approximately 2,158 plaintiffs in these lawsuits.  For many of these lawsuits, we have not been provided with sufficient information from the plaintiffs to determine whether all or some of the plaintiffs have claims against the subsidiary, the basis of any such claims, or the nature of their alleged injuries.  The first of the asbestos-related lawsuits was filed against the subsidiary in 1990.  Through March 31, 2012, the costs incurred to resolve claims, including both defense fees and expenses and settlement costs, have not been material, all known deductibles have been satisfied or are inapplicable, and the subsidiary’s defense fees and expenses and settlement costs have been met by insurance made available to the subsidiary.  The subsidiary continues to be named as a defendant in additional lawsuits, and we cannot predict the number of additional cases in which it may be named a defendant nor can we predict the potential costs to resolve such additional cases or to resolve the pending cases.  However, the subsidiary has in excess of $1.0 billion in insurance limits potentially available to the subsidiary.  Although not all of the policies may be fully available due to the insolvency of certain insurers, we believe that the subsidiary will have sufficient funding from settlements and claims payments from insurers, assigned rights from insurers and coverage-in-place settlement agreements with insurers to respond to these claims.  While we cannot predict or provide assurance as to the final outcome of these matters, we do not believe that the current value of the claims where we have been identified will have a material impact on our consolidated statement of financial position, results of operations or cash flows.

Rio de Janeiro tax assessment—In the third quarter of 2006, we received tax assessments of approximately $196 million from the state tax authorities of Rio de Janeiro in Brazil against one of our Brazilian subsidiaries for taxes on equipment imported into the state in connection with our operations.  The assessments resulted from a preliminary finding by these authorities that our subsidiary’s record keeping practices were deficient.  We currently believe that the substantial majority of these assessments are without merit.  We filed an initial response with the Rio de Janeiro tax authorities on September 9, 2006 refuting these additional tax assessments.  In September 2007, we received confirmation from the state tax authorities that they believe the additional tax assessments are valid, and as a result, we filed an appeal on September 27, 2007 to the state Taxpayer’s Council contesting these assessments.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect it to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Brazilian import license assessment—In the fourth quarter of 2010, one of our Brazilian subsidiaries received an assessment from the Brazilian federal tax authorities in Rio de Janeiro of approximately $235 million based upon the alleged failure to timely apply for import licenses for certain equipment and for allegedly providing improper information on import license applications.  We responded to the assessment on December 22, 2010, and we currently believe that a substantial majority of the assessment is without merit.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect it to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Other matters—We are involved in various tax matters and various regulatory matters.  We are also involved in lawsuits relating to damage claims arising out of hurricanes Katrina and Rita, all of which are insured and which are not material to us.  As of March 31, 2012, we were involved in a number of other lawsuits, including a dispute for municipal tax payments in Brazil and a dispute involving customs procedures in India, neither of which is material to us, and all of which have arisen in the ordinary course of our business.  We do not expect the liability, if any, resulting from these other matters to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  We cannot predict with certainty the outcome or effect of any of the litigation matters specifically described above or of any such other pending or threatened litigation.  There can be no assurance that our beliefs or expectations as to the outcome or effect of any lawsuit or other litigation matter will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

Other environmental matters

Hazardous waste disposal sites—We have certain potential liabilities under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and similar state acts regulating cleanup of various hazardous waste disposal sites, including those described below.  CERCLA is intended to expedite the remediation of hazardous substances without regard to fault.  Potentially responsible parties (“PRPs”) for each site include present and former owners and operators of, transporters to and generators of the substances at the site.  Liability is strict and can be joint and several.

We have been named as a PRP in connection with a site located in Santa Fe Springs, California, known as the Waste Disposal, Inc. site.  We and other PRPs have agreed with the U.S. Environmental Protection Agency (“EPA”) and the DOJ to settle our potential liabilities for this site by agreeing to perform the remaining remediation required by the EPA.  The form of the agreement is a consent decree, which has been entered by the court.  The parties to the settlement have entered into a participation agreement, which makes us liable for approximately eight percent of the remediation and related costs.  The remediation is complete, and we believe our share of the future operation and maintenance costs of the site is not material.  There are additional potential liabilities related to the site, but these cannot be quantified, and we have no reason at this time to believe that they will be material.

One of our subsidiaries has been ordered by the California Regional Water Quality Control Board (“CRWQCB”) to develop a testing plan for a site known as Campus 1000 Fremont in Alhambra, California.  This site was formerly owned and operated by certain of our subsidiaries.  It is presently owned by an unrelated party, which has received an order to test the property.  We have also been advised that one or more of our subsidiaries is likely to be named by the EPA as a PRP for the San Gabriel Valley, Area 3, Superfund site, which includes this property.  Testing has been completed at the property but no contaminants of concern were detected.  In discussions with CRWQCB staff, we were advised of their intent to issue us a “no further action” letter but it has not yet been received.  Based on the test results, we would contest any potential liability.  We have no knowledge at this time of the potential cost of any remediation, who else will be named as PRPs, and whether in fact any of our subsidiaries is a responsible party.  The subsidiaries in question do not own any operating assets and have limited ability to respond to any liabilities.

Resolutions of other claims by the EPA, the involved state agency or PRPs are at various stages of investigation.  These investigations involve determinations of:

·the actual responsibility attributed to us and the other PRPs at the site;

·appropriate investigatory or remedial actions; and

·allocation of the costs of such activities among the PRPs and other site users.

Our ultimate financial responsibility in connection with those sites may depend on many factors, including:

·the volume and nature of material, if any, contributed to the site for which we are responsible;

·the number of other PRPs and their financial viability; and

·the remediation methods and technology to be used.

It is difficult to quantify with certainty the potential cost of these environmental matters, particularly in respect of remediation obligations.  Nevertheless, based upon the information currently available, we believe that our ultimate liability arising from all environmental matters, including the liability for all other related pending legal proceedings, asserted legal claims and known potential legal claims which are likely to be asserted, is adequately accrued and should not have a material effect on our statement of financial position or results of operations.  Estimated costs of future expenditures for environmental remediation obligations are not discounted to their present value.

Contamination litigation

On July 11, 2005, one of our subsidiaries was served with a lawsuit filed on behalf of three landowners in Louisiana in the 12th Judicial District Court for the Parish of Avoyelles, State of Louisiana.  The lawsuit named 19 other defendants, all of which were alleged to have contaminated the plaintiffs’ property with naturally occurring radioactive material, produced water, drilling fluids, chlorides, hydrocarbons, heavy metals and other contaminants as a result of oil and gas exploration activities.  Experts retained by the plaintiffs issued a report suggesting significant contamination in the area operated by the subsidiary and another codefendant (the “Co-Defendant”), and claimed that over $300 million would be required to properly remediate the contamination.  The experts retained by the defendants conducted their own investigation and concluded that the remediation costs would amount to no more than $2.5 million.  The Co-Defendant settled the actions with the three landowners (the “Settlement”).  The Co-Defendant subsequently filed suit in 2008 against the subsidiary and certain of its insurers in the Court of Avoyelles Parish to determine their liability for the Settlement.

On March 11, 2010, the Co-Defendant filed a motion for leave to amend the pending litigation in Avoyelles Parish to add GlobalSantaFe Corporation, Transocean Worldwide Inc., its successor, and two other subsidiaries under the “single business enterprise” doctrine contained in Louisiana law, as well as various additional insurers.  The single business enterprise doctrine is similar to corporate veil piercing doctrines.  A subsequent amendment added a claim for abuse of process under Louisiana law for an earlier bankruptcy filed by the subsidiary in Delaware, which was ultimately dismissed by a bankruptcy court and various other actions undertaken by our subsidiary, GlobalSantaFe Corporation and Transocean Worldwide Inc.

A scheduling order has been entered in the Avoyelles Parish lawsuit and a jury trial is set on these matters for September 17, 2012.  Discovery is ongoing.  The subsidiary has filed a motion for summary judgment for defense costs against various insurers, and the motion is set for hearing on April 23, 2012.

We believe that the legal theories advanced by the Co-Defendant should not be applied against the subsidiary, GlobalSantaFe Corporation or Transocean Worldwide Inc. and the two other subsidiaries.  We intend to continue to vigorously defend against any action taken in an attempt to impose liability under the theories discussed above or otherwise and believe there are good and valid defenses thereto.  While we cannot predict or provide assurance as to the final outcome of these proceedings, we do not expect them to have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Retained risk

Our hull and machinery and excess liability insurance program consists of commercial market and captive insurance policies.  We periodically evaluate our insurance limits and self-insured retentions.  As of March 31, 2012, the insured value of our drilling rig fleet was approximately $36.0 billion, excluding our rigs under construction.

Under the hull and machinery program, we generally maintain a $125 million per occurrence deductible, limited to a maximum of $250 million per policy period.  Subject to the same shared deductible, we also have coverage for costs incurred to mitigate damage to a rig up to an amount equal to 25 percent of a rig’s insured value.  Also subject to the same shared deductible, we have additional coverage for wreck removal for up to 25 percent of a rig’s insured value, with any excess generally covered to the extent of our remaining excess liability coverage described below.  However, we generally retain the risk for all hull and machinery exposures for our Standard Jackups and swamp barge, which are self-insured through our wholly owned captive insurance company.

We carry $793 million of commercial market excess liability coverage, exclusive of the deductibles and self-insured retention, noted below, which generally covers offshore risks such as personal injury, third-party property claims, and third-party non-crew claims, including wreck removal and pollution.  Our excess liability coverage has (1) separate $10 million per occurrence deductibles on crew personal injury liability and on collision liability claims and (2) a separate $5 million per occurrence deductible on other third-party non-crew claims.  Through our wholly owned captive insurance company, we have retained the risk of the primary $50 million excess liability coverage, along with $157 million of the excess liability coverage, of which we have re-insured $25 million in the commercial market.  In addition, we generally retain the risk for any liability losses in excess of $1.0 billion.

We also carry $100 million of additional insurance that generally covers expenses that would otherwise be assumed by the well owner, such as costs to control the well, redrill expenses and pollution from the well.  This additional insurance provides coverage for such expenses in circumstances in which we have legal or contractual liability arising from our gross negligence or willful misconduct.

We have elected to self-insure operators extra expense coverage for ADTI and for the operations of our former oil and gas properties reporting unit (see Note 8—Discontinued Operations).  This coverage provides protection against expenses related to well control, pollution and redrill liability associated with blowouts.  ADTI’s customers assume, and indemnify ADTI for, liability associated with blowouts in excess of a contractually agreed amount, generally $50 million.

We generally do not have commercial market insurance coverage for loss of revenue, unless it is contractually required, or for physical damage losses, including liability for wreck removal expenses, to our fleet caused by named windstorms in the U.S. Gulf of Mexico and war perils worldwide.

Letters of credit and surety bonds

We had letters of credit outstanding totaling $653 million and $650 million at March 31, 2012 and December 31, 2011, respectively, issued under various committed and uncommitted credit lines provided by several banks to guarantee various contract bidding, performance activities and customs obligations.  Included in the letters of credit outstanding at March 31, 2012 was a $60 million letter of credit issued under an uncommitted credit facility that has been established by one of our subsidiaries for TPDI to satisfy its liquidity requirements under the TPDI Credit Facilities (see Note 11—Debt).

As is customary in the contract drilling business, we also have various surety bonds in place that secure customs obligations relating to the importation of our rigs and certain performance and other obligations.  We had outstanding surety bonds totaling $12 million at March 31, 2012 and December 31, 2011.

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Subsequent Events

3 Months Ended

Mar. 31, 2012

Subsequent Events

Subsequent Events

Note 19—Subsequent Events

Norway tax investigations—In April 2012, the Norwegian tax authorities supplemented the previously issued criminal indictments against our two subsidiaries by extending a criminal indictment against a third subsidiary on the same matter, alleging misleading or incomplete disclosures in Norwegian tax returns for the years 2001 and 2002.

Discontinued operations—Subsequent to March 31, 2012, we completed the sale of the assets of Challenger Minerals Inc.

Dispositions—Subsequent to March 31, 2012, we completed the sales of Roger W. Mowell, Transocean Nordic and Transocean Shelf Explorer.

Assets held for sale—Subsequent to March 31, 2012, we entered into an agreement to sell the Standard Jackup GSF Adriatic II, and we reclassified the drilling unit and related equipment, having an aggregate carrying amount of $54 million, to assets held for sale.

Aker Term Loan Facility—Subsequent to March 31, 2012, we prepaid $115 million of borrowings under the Aker Term Loan Facility.

Brazil Frade field incident—On April 3, 2012 the same federal prosecutor who filed the original civil public action filed a new civil lawsuit against Chevron and us in federal court in Campos.  The lawsuit cites the March 2012 seepage and seeks a broad injunction against Chevron and us to prevent them from doing business in Brazil and from removing property or profits from Brazil.  The lawsuit also seeks approximately $11.0 billion in damages from Chevron and us.

On April 16, 2012, the Campos court issued an order stating that it did not have jurisdiction in this matter and transferred the cases to the court in Rio de Janeiro.

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Drilling Fleet (Details) (USD $)	3 Months Ended	12 Months Ended	15 Months Ended	3 Months Ended	12 Months Ended	15 Months Ended	3 Months Ended	12 Months Ended	15 Months Ended	3 Months Ended	12 Months Ended	15 Months Ended	3 Months Ended	12 Months Ended	15 Months Ended		3 Months Ended	12 Months Ended	15 Months Ended		3 Months Ended	12 Months Ended	15 Months Ended		3 Months Ended	12 Months Ended	15 Months Ended	3 Months Ended	12 Months Ended	15 Months Ended	3 Months Ended	12 Months Ended	15 Months Ended
	Mar. 31, 2012	Dec. 31, 2011 drillingunit	Mar. 31, 2012	Mar. 31, 2012 Transocean Andaman	Dec. 31, 2011 Transocean Andaman	Mar. 31, 2012 Transocean Andaman	Mar. 31, 2012 Transocean Siam Driller	Dec. 31, 2011 Transocean Siam Driller	Mar. 31, 2012 Transocean Siam Driller	Mar. 31, 2012 Transocean Honor	Dec. 31, 2011 Transocean Honor	Mar. 31, 2012 Transocean Honor	Mar. 31, 2012 Ultra-Deepwater Floater TBN1	Dec. 31, 2011 Ultra-Deepwater Floater TBN1	Mar. 31, 2012 Ultra-Deepwater Floater TBN1	Oct. 31, 2011 Ultra-Deepwater Floater TBN1	Mar. 31, 2012 Ultra-Deepwater Floater TBN2	Dec. 31, 2011 Ultra-Deepwater Floater TBN2	Mar. 31, 2012 Ultra-Deepwater Floater TBN2	Oct. 31, 2011 Ultra-Deepwater Floater TBN2	Mar. 31, 2012 Deepwater Champion	Dec. 31, 2011 Deepwater Champion	Mar. 31, 2012 Deepwater Champion	Nov. 30, 2007 Deepwater Champion	Mar. 31, 2012 Transocean Ao Thai	Dec. 31, 2011 Transocean Ao Thai	Mar. 31, 2012 Transocean Ao Thai	Mar. 31, 2012 Capitalized interest	Dec. 31, 2011 Capitalized interest	Mar. 31, 2012 Capitalized interest	Mar. 31, 2012 Mobilization costs	Dec. 31, 2011 Mobilization costs	Mar. 31, 2012 Mobilization costs
Drilling Fleet
Construction work in progress, recorded in property and equipment	$ 1,600,000,000	$ 1,400,000,000	$ 1,600,000,000
Capital expenditures and other capital additions, including capitalized interest, for our major construction projects
Capital expenditures and other capital additions, including capitalized interest costs	97,000,000	1,718,000,000	1,815,000,000	19,000,000	119,000,000	138,000,000	19,000,000	119,000,000	138,000,000	16,000,000	216,000,000	232,000,000	14,000,000	138,000,000	152,000,000		8,000,000	137,000,000	145,000,000		2,000,000	776,000,000	778,000,000		1,000,000	79,000,000	80,000,000	13,000,000	108,000,000	121,000,000	5,000,000	26,000,000	31,000,000
Initial investment in construction project																$ 136,000,000				$ 136,000,000				$ 109,000,000
Number of Harsh Environment, Ultra-Deepwater semisubmersibles acquired (in drilling units)		2

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Nature of Business (Details)	Mar. 31, 2012 drillingunit
Nature of Business
Number of mobile offshore drilling units	130
Number of High-Specification Floaters (in drilling units)	50
Number of Midwater Floaters (in drilling units)	25
Number of High-Specification Jackups (in drilling units)	9
Number of Standard Jackups (in drilling units)	45
Number of swamp barge (in drilling units)	1
Number of Ultra-Deepwater drillships under construction (in drilling units)	2
Number of High-Specification Jackups under construction (in drilling units)	4

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) In Millions, except Share data, unless otherwise specified	Mar. 31, 2012 USD ($)	Mar. 31, 2012 CHF	Dec. 31, 2011 USD ($)	Dec. 31, 2011 CHF
CONDENSED CONSOLIDATED BALANCE SHEETS
Accounts receivable, net of allowance for doubtful accounts (in dollars)	$ 28		$ 28
Materials and supplies, net of allowance for obsolescence (in dollars)	$ 76		$ 73
Shares, CHF par value (in Swiss francs per share)		15.00		15.00
Shares, authorized	402,282,355	402,282,355	402,282,355	402,282,355
Shares, conditionally authorized	167,617,649	167,617,649	167,617,649	167,617,649
Shares, issued	365,135,298	365,135,298	365,135,298	365,135,298
Shares, outstanding	350,500,518	350,500,518	349,805,793	349,805,793
Treasury shares	2,863,267	2,863,267	2,863,267	2,863,267

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2012

New Accounting Pronouncements

New Accounting Pronouncements

Note 3—New Accounting Pronouncements

Recently Adopted Accounting Standards

Intangibles-goodwill and other—Effective January 1, 2012, we adopted 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.  Our adoption did not have an effect on our condensed consolidated financial statements.

Fair value measurements—Effective January 1, 2012, we adopted the accounting standards update that requires additional disclosure about fair value measurements that involve significant unobservable inputs, including additional quantitative information about the unobservable inputs, a description of valuation techniques used, and a qualitative evaluation of the sensitivity of these measurements.  Our adoption did not have a material effect on the disclosures contained in our notes to condensed consolidated financial statements.

Recently Issued Accounting Standards

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 our condensed consolidated balance sheet or the disclosures contained in our notes to condensed consolidated financial statements.

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Redeemable Noncontrolling Interest (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Redeemable Noncontrolling Interest
Percentage interest in joint venture (TPDI) that is held by an unaffiliated party (Quantum)	50.00%
Redeemable noncontrolling interest
Balance, beginning of period	$ 116	$ 25
Net income attributable to noncontrolling interest	22	28
Other comprehensive loss attributable to noncontrolling interest		4
Balance, end of period	$ 138	$ 57

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2012

Significant Accounting Policies

Basis of presentation

We have prepared our accompanying unaudited condensed consolidated financial statements in accordance with accounting principles generally accepted in the United States (“U.S.”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the U.S. Securities and Exchange Commission (“SEC”).  Pursuant to such rules and regulations, these financial statements do not include all disclosures required by accounting principles generally accepted in the U.S. for complete financial statements.  The condensed consolidated financial statements reflect all adjustments, which are, in the opinion of management, necessary for a fair presentation of financial position, results of operations and cash flows for the interim periods.  Such adjustments are considered to be of a normal recurring nature unless otherwise noted.  Operating results for the three months ended March 31, 2012 are not necessarily indicative of the results that may be expected for the year ending December 31, 2012 or for any future period.  The accompanying condensed consolidated financial statements and notes thereto should be read in conjunction with the audited consolidated financial statements and notes thereto as of December 31, 2011 and 2010 and for each of the three years in the period ended December 31, 2011 included in our annual report on Form 10-K filed on February 27, 2012.

Accounting estimates

To prepare financial statements in accordance with accounting principles generally accepted in the U.S., we are required 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, defined benefit pension plans and other postretirement benefits, contingencies and share-based compensation.  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 considerable 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 entity.  See Note 4—Variable Interest Entities.

Share-based compensation

Share-based compensation expense was $23 million and $27 million for the three months ended March 31, 2012 and 2011, respectively.

Capitalized interest

We capitalize interest costs for qualifying construction and upgrade projects.  We capitalized interest costs on construction work in progress of $13 million and $15 million for the three months ended March 31, 2012 and 2011, respectively.

Reclassifications

We have made certain reclassifications, which did not have an effect on net income, to prior period amounts to conform with the current period’s presentation.  These reclassifications did not have a material effect on our condensed 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 19—Subsequent Events.

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Shareholders' Equity (Tables)

3 Months Ended

Mar. 31, 2012

Shareholders' Equity

Changes in accumulated other comprehensive income

	Three months ended March 31, 2012
	Unrecognized components of net periodic benefit costs			Unrecognized gains (losses) on derivative instruments			Unrecognized gains (losses) on marketable securities			Total
Balance, beginning of period	$	(501	)	$	7		$	(2	)	$	(496	)
Other comprehensive loss attributable to controlling interest	(18		)	(1		)	—			(19		)
Balance, end of period	$	(519	)	$	6		$	(2	)	$	(515	)

	Three months ended March 31, 2011
	Unrecognized components of net periodic benefit costs			Unrecognized gains (losses) on derivative instruments			Unrecognized gains (losses) on marketable securities			Total
Balance, beginning of period	$	(335	)	$	5		$	(2	)	$	(332	)
Other comprehensive loss attributable to controlling interest	(2		)	(1		)	—			(3		)
Balance, end of period	$	(337	)	$	4		$	(2	)	$	(335	)

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Postemployment Benefit Plans

3 Months Ended

Mar. 31, 2012

Postemployment Benefit Plans

Postemployment Benefit Plans

Note 13—Postemployment Benefit Plans

We have several defined benefit pension plans, both funded and unfunded, covering substantially all of our U.S. employees, including certain frozen plans, assumed in connection with our mergers, that cover certain current employees and certain former employees and directors of our predecessors (the “U.S. Plans”).  We also have various defined benefit plans in the U.K., Norway, Nigeria, Egypt and Indonesia that cover our employees in those areas (the “Non-U.S. Plans”).  Additionally, we offer several unfunded contributory and noncontributory other postretirement employee benefit plans covering substantially all of our U.S. employees (the “OPEB Plans”).

The components of net periodic benefit costs, before tax, and funding contributions for these plans were as follows (in millions):

	Three months ended March 31, 2012											Three months ended March 31, 2011
	U.S. Plans			Non-U.S. Plans			OPEB Plans		Total			U.S. Plans			Non-U.S. Plans			OPEB Plans		Total
Net periodic benefit costs
Service cost	$	12		$	7		$	—	$	19		$	11		$	5		$	—	$	16
Interest cost	14			5			1		20			14			5			1		20
Expected return on plan assets	(15		)	(5		)	—		(20		)	(16		)	(5		)	—		(21		)
Settlements and curtailments	2			—			—		2			—			—			—		—
Actuarial losses, net	10			1			—		11			6			—			—		6
Prior service cost, net	—			—			—		—			—			—			—		—
Transition obligation, net	—			—			—		—			—			—			—		—
Net periodic benefit costs	$	23		$	8		$	1	$	32		$	15		$	5		$	1	$	21
Funding contributions	$	3		$	8		$	1	$	12		$	13		$	7		$	1	$	21