UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended ~~September~~June 30, ~~2019~~2020

☐ 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 001-38373

Transocean Ltd.

(Exact name of registrant as specified in its charter)

Switzerland	98-0599916
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

Turmstrasse 30 Steinhausen, Switzerland	6312
(Address of principal executive offices)	(Zip Code)


+41 (41)749-0500
(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:



Title of each class	Trading symbol	Name of each exchange on which registered
Shares, CHF 0.10 par value	RIG	New York Stock Exchange
0.50% Exchangeable Senior Bonds due 2023	RIG/23	New York Stock Exchange

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 every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes þ No ◻

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

Large accelerated filer þ Accelerated filer ◻ Non--accelerated filer ◻ Smaller reporting company ☐ Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ◻

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 ~~October 22, 2019, 611,861,630~~July 23, 2020, 614,612,545 shares were outstanding.

Table of Contents

TRANSOCEAN LTD. AND SUBSIDIARIES

INDEX TO QUARTERLY REPORT ON FORM 10-Q

QUARTER ENDED ~~SEPTEMBER~~JUNE 30, ~~2019~~2020

Table of Contents

PART I.FINANCIAL INFORMATION

Item I.

Financial Statements

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In millions, except per share data)

(Unaudited)


	Three months ended				Nine months ended				Three months ended				Six months ended
	September 30,				September 30,				June 30,				June 30,
	2019		2018		2019		2018		2020		2019		2020		2019

Contract drilling revenues	$	784	$	816	$	2,296	$	2,270	$	930	$	758	$	1,689	$	1,512

Costs and expenses
Operating and maintenance		547		447		1,565		1,302		525		510		1,065		1,018
Depreciation and amortization		212		201		648		614		196		219		402		436
General and administrative		45		35		139		134		45		45		88		94
		804		683		2,352		2,050		766		774		1,555		1,548
Loss on impairment		(583)		(432)		(584)		(1,446)		(429)		(1)		(597)		(1)
Loss on disposal of assets, net		(4)		(6)		(7)		—
Gain (loss) on disposal of assets, net										1		(10)		—		(3)
Operating loss		(607)		(305)		(647)		(1,226)		(264)		(27)		(463)		(40)

Other income (expense), net
Interest income		11		11		33		36		4		12		13		22
Interest expense, net of amounts capitalized		(166)		(160)		(500)		(455)		(153)		(168)		(313)		(334)
Loss on retirement of debt		(12)		(1)		(39)		(3)
Gain (loss) on retirement of debt										4		(9)		(53)		(27)
Other, net		3		16		34		6		(56)		23		(44)		31
		(164)		(134)		(472)		(416)		(201)		(142)		(397)		(308)
Loss before income tax expense		(771)		(439)		(1,119)		(1,642)		(465)		(169)		(860)		(348)
Income tax expense (benefit)		54		(30)		83		118
Income tax expense										32		37		28		29

Net loss		(825)		(409)		(1,202)		(1,760)		(497)		(206)		(888)		(377)
Net income (loss) attributable to noncontrolling interest		—		—		2		(6)
Net income attributable to noncontrolling interest										—		2		1		2
Net loss attributable to controlling interest	$	(825)	$	(409)	$	(1,204)	$	(1,754)	$	(497)	$	(208)	$	(889)	$	(379)

Loss per share
Basic	$	(1.35)	$	(0.88)	$	(1.97)	$	(3.86)	$	(0.81)	$	(0.34)	$	(1.45)	$	(0.62)
Diluted	$	(1.35)	$	(0.88)	$	(1.97)	$	(3.86)	$	(0.81)	$	(0.34)	$	(1.45)	$	(0.62)

Weighted-average shares outstanding
Basic		613		463		612		454		615		612		615		612
Diluted		613		463		612		454		615		612		615		612

See accompanying notes.

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Table of Contents

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(In millions)

(Unaudited)


	Three months ended				Nine months ended				Three months ended				Six months ended
	September 30,				September 30,				June 30,				June 30,
	2019		2018		2019		2018		2020		2019		2020		2019

Net loss	$	(825)	$	(409)	$	(1,202)	$	(1,760)	$	(497)	$	(206)	$	(888)	$	(377)
Net income (loss) attributable to noncontrolling interest		—		—		2		(6)
Net income attributable to noncontrolling interest										—		2		1		2
Net loss attributable to controlling interest		(825)		(409)		(1,204)		(1,754)		(497)		(208)		(889)		(379)

Components of net periodic benefit costs before reclassifications		—		(1)		7		(4)		—		—		(9)		7
Components of net periodic benefit costs reclassified to net loss		—		2		1		4		2		1		4		1

Other comprehensive income before income taxes		—		1		8		—
Other comprehensive income (loss) before income taxes										2		1		(5)		8
Income taxes related to other comprehensive income		—		—		—		—		—		—		—		—
Other comprehensive income		—		1		8		—
Other comprehensive income (loss)										2		1		(5)		8
Other comprehensive income attributable to noncontrolling interest		—		—		—		—		—		—		—		—
Other comprehensive income attributable to controlling interest		—		1		8		—
Other comprehensive income (loss) attributable to controlling interest										2		1		(5)		8

Total comprehensive loss		(825)		(408)		(1,194)		(1,760)		(495)		(205)		(893)		(369)
Total comprehensive income (loss) attributable to noncontrolling interest		—		—		2		(6)
Total comprehensive income attributable to noncontrolling interest										—		2		1		2
Total comprehensive loss attributable to controlling interest	$	(825)	$	(408)	$	(1,196)	$	(1,754)	$	(495)	$	(207)	$	(894)	$	(371)

See accompanying notes.

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Table of Contents

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In millions, except share data)

(Unaudited)


	September 30,		December 31,		June 30,		December 31,
	2019		2018		2020		2019

Assets
Cash and cash equivalents	$	1,906	$	2,160	$	1,511	$	1,790
Accounts receivable, net of allowance for doubtful accounts
of less than $1 at December 31, 2018		639		604
Materials and supplies, net of allowance for obsolescence
of $123 and $134 at September 30, 2019 and December 31, 2018, respectively		475		474
Accounts receivable, net of allowance of $2 at June 30, 2020						703		654
Materials and supplies, net of allowance of $122 and $127 at June 30, 2020 and December 31, 2019, respectively						457		479
Restricted cash accounts and investments		551		551		437		558
Other current assets		200		159		176		159
Total current assets		3,771		3,948		3,284		3,640

Property and equipment		24,203		25,811		23,318		24,281
Less accumulated depreciation		(5,255)		(5,403)		(5,309)		(5,434)
Property and equipment, net		18,948		20,408		18,009		18,847
Contract intangible assets		655		795		507		608
Deferred income taxes, net		21		66		17		20
Other assets		1,054		448		1,008		990
Total assets	$	24,449	$	25,665	$	22,825	$	24,105

Liabilities and equity
Accounts payable	$	308	$	269	$	264	$	311
Accrued income taxes		35		70		42		64
Debt due within one year		349		373		578		568
Other current liabilities		797		746		704		781
Total current liabilities		1,489		1,458		1,588		1,724

Long-term debt		9,041		9,605		8,480		8,693
Deferred income taxes, net		193		64		294		266
Other long-term liabilities		1,784		1,424		1,476		1,555
Total long-term liabilities		11,018		11,093		10,250		10,514

Commitments and contingencies

Shares, CHF 0.10 par value, 639,674,422 authorized, 142,365,398 conditionally authorized, 617,970,525 issued
and 611,849,468 outstanding at September 30, 2019, and 638,285,574 authorized, 143,754,246 conditionally
authorized, 610,581,677 issued and 609,649,291 outstanding at December 31, 2018		59		59
Shares, CHF 0.10 par value, 824,648,925 authorized, 142,365,398 conditionally authorized, 639,674,414 issued
and 614,612,545 outstanding at June 30, 2020, and 639,674,422 authorized, 142,365,398 conditionally
authorized, 617,970,525 issued and 611,871,374 outstanding at December 31, 2019						60		59
Additional paid-in capital		13,415		13,394		13,438		13,424
Accumulated deficit		(1,246)		(67)		(2,188)		(1,297)
Accumulated other comprehensive loss		(295)		(279)		(329)		(324)
Total controlling interest shareholders’ equity		11,933		13,107		10,981		11,862
Noncontrolling interest		9		7		6		5
Total equity		11,942		13,114		10,987		11,867
Total liabilities and equity	$	24,449	$	25,665	$	22,825	$	24,105

See accompanying notes.

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Table of Contents

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(In millions)

(Unaudited)


	Three months ended				Nine months ended				Three months ended				Six months ended
	September 30,				September 30,				June 30,				June 30,
	2019		2018		2019		2018		2020		2019		2020		2019
Shares
Balance, beginning of period	$	59	$	44	$	59	$	37	$	60	$	59	$	59	$	59
Issuance of shares in acquisition transactions		—		—		—		7
Issuance of shares under share-based compensation plans										—		—		1		—
Balance, end of period	$	59	$	44	$	59	$	44		60	$	59	$	60	$	59

Additional paid-in capital
Balance, beginning of period	$	13,405	$	12,022	$	13,394	$	11,031	$	13,431	$	13,396	$	13,424	$	13,394
Share-based compensation		9		8		28		36		7		10		15		19
Issuance of shares in acquisition transactions		—		—		—		739
Equity component of convertible debt instruments		—		—		—		172
Acquisition of redeemable noncontrolling interest		—		—		—		53
Allocated capital for transactions with holders of noncontrolling interest		—		2		—		5
Other, net		1		1		(7)		(3)		—		(1)		(1)		(8)
Balance, end of period	$	13,415	$	12,033	$	13,415	$	12,033	$	13,438	$	13,405	$	13,438	$	13,405

Retained earnings (accumulated deficit)
Accumulated deficit
Balance, beginning of period	$	(421)	$	584	$	(67)	$	1,929	$	(1,691)	$	(213)	$	(1,297)	$	(67)
Net loss attributable to controlling interest		(825)		(409)		(1,204)		(1,754)		(497)		(208)		(889)		(379)
Effect of adopting accounting standards updates		—		—		25		—		—		—		(2)		25
Balance, end of period	$	(1,246)	$	175	$	(1,246)	$	175	$	(2,188)	$	(421)	$	(2,188)	$	(421)

Accumulated other comprehensive loss
Balance, beginning of period	$	(295)	$	(291)	$	(279)	$	(290)	$	(331)	$	(296)	$	(324)	$	(279)
Other comprehensive income attributable to controlling interest		—		1		8		—
Other comprehensive income (loss) attributable to controlling interest										2		1		(5)		8
Effect of adopting accounting standards update		—		—		(24)		—		—		—		—		(24)
Balance, end of period	$	(295)	$	(290)	$	(295)	$	(290)	$	(329)	$	(295)	$	(329)	$	(295)

Total controlling interest shareholders’ equity
Balance, beginning of period	$	12,748	$	12,359	$	13,107	$	12,707	$	11,469	$	12,946	$	11,862	$	13,107
Total comprehensive loss attributable to controlling interest		(825)		(408)		(1,196)		(1,754)		(495)		(207)		(894)		(371)
Share-based compensation		9		8		28		36		7		10		15		19
Issuance of shares in acquisition transactions		—		—		—		746
Equity component of convertible debt instruments		—		—		—		172
Acquisition of redeemable noncontrolling interest		—		—		—		53
Allocated capital for transactions with holders of noncontrolling interest		—		2		—		5
Other, net		1		1		(6)		(3)		—		(1)		(2)		(7)
Balance, end of period	$	11,933	$	11,962	$	11,933	$	11,962	$	10,981	$	12,748	$	10,981	$	12,748

Noncontrolling interest
Balance, beginning of period	$	9	$	3	$	7	$	4	$	6	$	7	$	5	$	7
Total comprehensive income (loss) attributable to noncontrolling interest		—		(1)		2		(2)
Recognition of noncontrolling interest in business combination		—		—		—		33
Acquisition of noncontrolling interest		—		(1)		—		(31)
Allocated capital for transactions with holders of noncontrolling interest		—		(2)		—		(5)
Total comprehensive income attributable to noncontrolling interest										—		2		1		2
Balance, end of period	$	9	$	(1)	$	9	$	(1)	$	6	$	9	$	6	$	9

Total equity
Balance, beginning of period	$	12,757	$	12,362	$	13,114	$	12,711	$	11,475	$	12,953	$	11,867	$	13,114
Total comprehensive loss		(825)		(409)		(1,194)		(1,756)		(495)		(205)		(893)		(369)
Share-based compensation	��	9		8		28		36		7		10		15		19
Issuance of shares in acquisition transactions		—		—		—		746
Equity component of convertible debt instruments		—		—		—		172
Recognition of noncontrolling interest in business combination		—		—		—		33
Acquisition of redeemable noncontrolling interest		—		—		—		53
Acquisition of noncontrolling interest		—		(1)		—		(31)
Other, net		1		1		(6)		(3)		—		(1)		(2)		(7)
Balance, end of period	$	11,942	$	11,961	$	11,942	$	11,961	$	10,987	$	12,757	$	10,987	$	12,757

See accompanying notes.

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Table of Contents

TRANSOCEAN LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

(Unaudited)


	Nine months ended				Six months ended
	September 30,				June 30,
	2019		2018		2020		2019
Cash flows from operating activities
Net loss	$	(1,202)	$	(1,760)	$	(888)	$	(377)
Adjustments to reconcile to net cash provided by operating activities:
Contract intangible asset amortization		140		78		101		92
Depreciation and amortization		648		614		402		436
Share-based compensation expense		28		36		15		19
Loss on impairment		584		1,446		597		1
Loss on impairment of investment in unconsolidated affiliate						59		—
Loss on disposal of assets, net		7		—		—		3
Loss on retirement of debt		39		3		53		27
Deferred income tax expense		139		50		30		109
Other, net		28		12		32		11
Changes in deferred revenues, net		19		(127)		(10)		4
Changes in deferred costs, net		(21)		23		(4)		(6)
Changes in other operating assets and liabilities, net		(216)		(55)		(348)		(217)
Net cash provided by operating activities		193		320		39		102

Cash flows from investing activities
Capital expenditures		(259)		(140)		(153)		(138)
Proceeds from disposal of assets, net		52		37		3		40
Investments in unconsolidated affiliates		(77)		(107)		(6)		(62)
Unrestricted and restricted cash acquired in business combination		—		131
Proceeds from maturities of unrestricted and restricted investments		123		500		—		123
Deposits to unrestricted investments		—		(50)
Other, net		3		—		—		3
Net cash provided by (used in) investing activities		(158)		371
Net cash used in investing activities						(156)		(34)

Cash flows from financing activities
Proceeds from issuance of debt, net of discount and issue costs		1,056		1,319
Proceeds from issuance of debt, net of discounts and issue costs						743		1,056
Repayments of debt		(1,189)		(2,015)		(1,009)		(834)
Proceeds from investments restricted for financing activities		—		26
Payments to terminate derivative instruments		—		(92)
Other, net		(34)		(29)		(18)		(26)
Net cash used in financing activities		(167)		(791)
Net cash provided by (used in) financing activities						(284)		196

Net decrease in unrestricted and restricted cash and cash equivalents		(132)		(100)
Net increase (decrease) in unrestricted and restricted cash and cash equivalents						(401)		264
Unrestricted and restricted cash and cash equivalents, beginning of period		2,589		2,975		2,349		2,589
Unrestricted and restricted cash and cash equivalents, end of period	$	2,457	$	2,875	$	1,948	$	2,853

See accompanying notes.

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Table of Contents

TRANSOCEAN LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1—Business

Transocean Ltd. (together with its subsidiaries and predecessors, unless the context requires otherwise, “Transocean,” “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 ultra-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. As of ~~September~~June 30, ~~2019,~~2020, we owned or had partial ownership interests in and operated 45a fleet of 39 mobile offshore drilling units, including 2827 ultra-deepwater floaters 14and 12 harsh environment ~~floaters and 3 midwater~~ floaters. As of ~~September~~June 30, ~~2019,~~2020, we were constructing 2 ultra-deepwater drillships.

Note 2—Significant Accounting Policies

Presentation—We 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 (the “SEC”).~~Commission. 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 and ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, are not necessarily indicative of the results that may be expected for the year ending December 31, ~~2019,~~2020, 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, ~~2018~~2019 and ~~2017,~~2018, and for each of the three years in the period ended December 31, ~~2018,~~2019, included in our annual report on Form 10-K filed on February ~~19, 2019.~~18, 2020.

Accounting estimates—To prepare financial statements in accordance with accounting principles generally accepted in the U.S., we must 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,~~credit losses, allowance for excess and obsolete materials and supplies, ~~obsolescence,~~ assets held for sale, property and equipment, intangibles, leases, income taxes, contingencies, share-based compensation and postemployment benefit plans. We base our estimates and assumptions on historical experience and other factors that we believe are reasonable. 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 a valuation requires multiple input levels, 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.

Note 3—Accounting Standards ~~Updates~~Update

Recently adopted accounting standards

~~Leases~~Financial instruments – credit losses—Effective January 1, ~~2019,~~2020, we adopted the accounting standards update that requires ~~lessees~~entities to ~~recognize a right-of-use asset and lease liability~~estimate an expected lifetime credit loss on financial assets ranging from short-term trade accounts receivable to long-term financings. Our accounts receivable represent consideration earned for ~~virtually all leases and updates previous accounting standards~~performing services in various countries for lessors to align certain requirements with the updates to the revenue recognition accounting standards. We applied the transition method that required us to recognize right-of-use assets and lease liabilities as of the date of our adoption with no adjustment to prior periods. We applied the package of practical expedients that permitted us to carry forward historical lease classifications. For our drilling contracts, we recognize revenues based on the predominant component, which is the service component. As of January 1, 2019, for the finance leases under which we are the lessee, we reclassified to other assets $528 million, representing the unamortized right-of-use asset previously recorded in property and equipment, and we reclassified an aggregate remaining lease liability of $511 million,customers, including ~~$32 million and $479 million recorded in other current liabilities~~integrated oil companies, government-owned or government-controlled oil companies and other ~~long-term liabilities, respectively, previously recorded in debt due within one year and debt. As~~independent oil companies, the majority of ~~January 1, 2019, for operating leases under~~ which ~~we are~~currently have corporate family investment grade credit ratings. We established procedures to apply the ~~lessee, we recorded a non-cash adjustment to recognize an aggregate right-of-use asset~~requirements of $95 million, recorded in other assets, and a corresponding aggregate remaining lease liability of $133 million, including $15 million and $118 million recorded in other current liabilities and other long-term liabilities, respectively. We have accounted for lease and non-lease components of our operating leases as a single component. We have not recognized right-of-use assets or lease liabilities for our short-term leases. Our adoption did not have and is not expected in the future to have a material effect on our condensed consolidated statements of financial position, operations or cash flows. See Note 9—Leases.

~~Other comprehensive income~~~~—Effective January 1, 2019, we adopted~~ the accounting standards update ~~that allows for a reclassification from accumulated other comprehensive loss to accumulated deficit for stranded tax effects resulting from~~using the ~~Tax Cuts~~loss-rate method by reviewing our historical credit losses and

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued~~

~~(Unaudited)~~

~~Jobs Act of 2017. As of January 1, 2019, as a result of our adoption,~~ evaluating future expectations, and we recorded ~~an increase of $24 million to accumulated deficit~~the initial estimated allowance with a corresponding ~~decrease~~entry to accumulated ~~other comprehensive loss.~~

~~Statements of equity~~—Effective January 1, 2019, we adopted the SEC’s final rule that requires a reconciliation of the changes in shareholders’ equity to be presented for the current and comparative quarter and year-to-date periods, together with subtotals for each interim period. The final rule permits the disclosure requirements to be made either in a separate financial statement or in a note to the financial statements.deficit. Our adoption did not have a material effect on our condensed consolidated statements of financial position, operations or cash flows or on the disclosures contained in our notes to condensed consolidated financial statements.

~~Recently issued accounting standards~~Note 4—Unconsolidated Affiliates

~~Financial instruments – credit losses~~Investments—~~Effective no later than January 1, 2020, we will adopt~~We hold investments in various partially owned, unconsolidated companies, the accounting standards update that requires entities to estimate an expected lifetime credit loss on financial assets ranging from short-term trade accounts receivable to long-term financings. The update,most significant of which ~~permits early adoption,~~ is effective for annual reporting periods beginning after December 15, 2019, including interim periods within those annual periods. We continue to evaluate the requirements and do not expect our adoption to have a ~~material effect on our condensed consolidated statements of financial position, operations or cash flows or on the disclosures contained~~33.0 percent ownership interest in ~~our notes to condensed consolidated financial statements.~~

~~Note 4—Business Combinations~~

~~Overview~~

In the year ended December 31, 2018, we completed the acquisitions of Songa Offshore SE, a European public company limited by shares, or societas Europaea, existing under the laws of Cyprus (“Songa”Orion Holdings (Cayman) Limited (together with its subsidiary, “Orion”) ~~and Ocean Rig UDW Inc.~~, a Cayman Islands ~~exempted~~ company ~~with limited liability (“Ocean Rig”)~~that, through its wholly owned subsidiary, owns the harsh environment floater Transocean Norge. Additionally, we hold noncontrolling interests in certain companies that are involved in researching and developing technology to improve operational efficiency and reliability and to increase automation, sustainability and safety in drilling and other activities. In the ~~three and nine~~six months ended ~~September~~June 30, ~~2018, we incurred acquisition costs of $4 million~~2020 and ~~$11 million, respectively, recorded in general and administrative costs and expenses, related to these acquisitions.~~

~~Ocean Rig UDW Inc.~~

~~Consideration~~—To complete the Ocean Rig acquisition, we issued 147.7 million shares with a per share market value of $9.32, based on the market value of our shares on the acquisition date, and made an aggregate cash payment of $1.2 billion. The aggregate fair value of the consideration transferred in the business combination was as follows (in millions):

Total

Consideration transferred

Aggregate fair value of shares issued as partial consideration for Ocean Rig shares

$
1,377

Aggregate cash paid as partial consideration for Ocean Rig shares

1,168

Total consideration transferred in business combination

$
2,545

~~Assets and liabilities~~~~—In the three months ended September 30,~~ 2019, we completed our estimates of the fair values of the assets acquired and liabilities assumed. At September 30, 2019, the fair values of assets acquired and liabilities assumed, measured as of December 5, 2018, were as follows (in millions):

Total

Assets acquired

Cash and cash equivalents

$
152

Accounts receivable

76

Property and equipment

2,205

Drilling contract intangible assets

275

Other assets

115

Liabilities assumed

Accounts payable and other current liabilities

71

Construction contract intangible liabilities

132

Other long-term liabilities

54

Net assets acquired

$
2,566

In the nine months ended September 30, 2019, as a result of adjustments to assets acquired and liabilities assumed in the Ocean Rig acquisition, we recognized a gain of $11 million, recorded in other, net, asmade an adjustment to the previously recognized gain on bargain purchase. Including this adjustment, we have recognized a cumulative net gain of $21 million associated with the bargain purchase, primarily due to the decline in the market value of our shares between the announcement date and the closing date. We estimated the fair value of the rigs and related equipment by applying a combination of income and market approaches, using projected discounted cash flows and estimates of the exchange price that would be received for the assets in the principal or most advantageous markets for the assets in an orderly transaction between participants as of the acquisition date. We estimated the fair value of the drilling contracts by comparing the contractual dayrates over the remaining firm contract term and option periods relative to the projected market dayrates as of the acquisition

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(Unaudited)

~~date.~~aggregate cash contribution of $6 million and $59 million, respectively, to Orion. In the three months ended June 30, 2020, we recognized a loss of $59 million, which had no tax effect, recorded in other, net, associated with the impairment of our investment in Orion upon determination that the carrying amount of our equity-method investment exceeded the estimated fair value and that the impairment was other than temporary. We estimated the fair value of our investment using the construction contracts by comparing the contractual future payments and terms relative to the market payments and terms as of the acquisition date. Our estimates of fair value for the drilling units and contract intangiblesincome method, which required us to use significant unobservable inputs, representative of a Level 3 fair value measurement, including applying an assumed discount rate of 12 percent and making assumptions ~~related to~~about the future performance of the ~~assets, such as~~investment, including future ~~commodity prices, projected~~ demand and supply for ~~our services, rig availability,~~harsh environment floaters, rig utilization, ~~dayrates, remaining useful lives of the rigs~~revenue efficiency and ~~discount rates.~~

~~Note 5—Unconsolidated Affiliates~~

We hold investments in various partially owned, unconsolidated companies, including a 33.0 percent ownership interest in Orion Holdings (Cayman) Limited (“Orion”), a Cayman Islands company formed to construct and own the newbuild harsh environment floater ~~Transocean Norge~~ ~~through its wholly owned subsidiary. In the nine months ended September~~dayrates. At June 30, 2019 and 2018, we made an aggregate cash contribution of $74 million and $91 million, respectively, to Orion. We have agreed to contribute $33 million to Orion in January 2020. At September 30, 20192020 and December 31, ~~2018,~~2019, the aggregate carrying amount of our investment in Orion was ~~$163~~$106 million and ~~$91~~$164 million, respectively, recorded in other assets.

Related party transactions—We engage in certain related party transactions with Orion under a management services agreement for the operation and maintenance of the harsh environment floater Transocean Norge and marketing services agreement for the marketing of the rig. Prior to the rig’s placement into service, we also engaged in certain related party transactions with Orion under a shipyard care agreement for the construction of the rig and other matters related to its completion and delivery. In the three and ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, we ~~earned income~~received an aggregate cash payment of $1$26 million and $3$31 million, ~~recorded in other income, for agent fees~~respectively, primarily related to ~~procure equipment and services on behalf of Orion or its subsidiary under management services and~~the shipyard care ~~agreements.~~agreement. In the three and ~~nine~~six months ended ~~September~~June 30, 2019, we received an aggregate cash payment of ~~$41~~$20 million and ~~$74~~$33 million, respectively, ~~as reimbursement, together with~~primarily related to the ~~agent fees, for equipment~~commissioning, preparation and ~~services procured on behalf~~mobilization of ~~Orion or its subsidiary.~~

InTransocean Norge under the three and nine months ended September 30, 2019, we recognized rental expense of $3 million, recorded in operating and maintenance costs and expenses, and made an aggregate cash payment of $2 million toshipyard care agreement. We also lease the ~~harsh environment floater~~ ~~Transocean Norge~~rig under a short-term bareboat charter agreement, which is currently expected to expire in May 2020. In the three and nine months ended September 30, 2019, we made an aggregate cash payment of $9 million to acquire materials and supplies and other equipment from Orion. At September 30, 2019, we had receivables of $35 million and payables of $4 million, recorded in other current assets and other current liabilities, respectively, due from or to Orion or its subsidiary.March 2021.

Note 6—5—Revenues

Overview—The duration of our performance obligation varies by contract. As of ~~September~~June 30, ~~2019,~~2020, the drilling contract with the longest expected remaining duration, excluding unexercised options, extends through February 2028. In the nine months ended September 30, 2019, we recognized revenues of $10 million for performance obligations satisfied in previous periods due to certain revenues recognized on a cash basis. In the three and nine months ended September 30, 2018, we recognized revenues of $54 million and $147 million, respectively, for performance obligations satisfied in previous periods, primarily related to revenues for a customer’s contract termination and certain revenues recognized on a cash basis.

To obtain contracts with our customers, we incur pre-operating costs to prepare a rig for contract and deliver or mobilize athe rig to the drilling location. We defer such pre-operating costs and recognize the costs on a straight-line basis, consistent with the general pace of activity, in operating and maintenance costs over the estimated ~~firm period of drilling.~~contract period. In the three and ~~nine~~six months ended ~~September~~June 30, 2020, we recognized pre-operating costs of $23 million and $32 million, respectively. In the three and six months ended June 30, 2019, we recognized pre-operating costs of $4$3 million and ~~$10 million, respectively. In the three and nine months ended September 30, 2018, we recognized pre-operating costs of $14 million and $36~~$6 million, respectively. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, the unrecognized pre-operating costs to obtain contracts was ~~$21~~$38 million and $2$34 million, respectively, recorded in other assets.

In June 2020, we entered into a settlement and mutual release agreement with a customer, which provided for the final settlement of disputes related to performance obligations satisfied in prior periods. In connection with the settlement, among other things, our customer agreed to pay us $185 million in four equal installments through January 15, 2023. In the three and six months ended June 30, 2020, we recognized revenues of $177 million, representing the discounted value of the future payments, and recorded corresponding accounts receivable and other assets of $89 million and $88 million, respectively, net of imputed interest, which we will recognize in interest income over the scheduled payment period. In the six months ended June 30, 2019, we recognized revenues of $10 million, recognized on a cash basis, for performance obligations satisfied for another customer in prior periods.

Disaggregation—We recognized revenues as follows (in millions):


	Three months ended September 30, 2019										Three months ended September 30, 2018										Three months ended June 30, 2020										Three months ended June 30, 2019
	U.S.		Norway		Brazil		Other		Total		U.S.		Norway		Brazil		Other		Total		U.S.		Norway		Brazil		Other		Total		U.S.		Norway		Brazil		Other		Total

Ultra-deepwater floaters	$	317	$	—	$	27	$	149	$	493	$	396	$	—	$	1	$	86	$	483	$	440	$	—	$	57	$	139	$	636	$	309	$	—	$	28	$	149	$	486
Harsh environment floaters		4		200		—		77		281		—		174		—		91		265		—		207		—		86		293		—		173		—		78		251
Deepwater floaters		—		—		—		—		—		—		—		25		11		36		—		—		—		—		—		—		—		—		1		1
Midwater floaters		—		—		—		10		10		—		—		—		19		19		—		—		—		1		1		—		—		—		20		20
High-specification jackups		—		—		—		—		—		—		—		—		13		13
Total revenues	$	321	$	200	$	27	$	236	$	784	$	396	$	174	$	26	$	220	$	816	$	440	$	207	$	57	$	226	$	930	$	309	$	173	$	28	$	248	$	758

Nine months ended September 30, 2019

Nine months ended September 30, 2018


U.S.

Norway

Brazil

Other

Total

U.S.

Norway

Brazil

Other

Total

Ultra-deepwater floaters

$
940

$
—

$
81

$
434

$
1,455

$
1,162

$
—

$
1

$
168

$
1,331

Harsh environment floaters

4

554

—

232

790

—

467

—

254

721

Deepwater floaters

—

—

6

1

7

—

—

74

32

106

Midwater floaters

—

—

—

44

44

—

—

—

57

57

High-specification jackups

—

—

—

—

—

—

—

—

55

55

Total revenues

$
944

$
554

$
87

$
711

$
2,296

$
1,162

$
467

$
75

$
566

$
2,270


	Six months ended June 30, 2020										Six months ended June 30, 2019
	U.S.		Norway		Brazil		Other		Total		U.S.		Norway		Brazil		Other		Total

Ultra-deepwater floaters	$	727	$	—	$	116	$	321	$	1,164	$	623	$	—	$	54	$	285	$	962
Harsh environment floaters		—		414		—		99		513		—		354		—		155		509
Deepwater floaters		—		—		—		—		—		—		—		6		1		7
Midwater floaters		—		—		—		12		12		—		—		—		34		34
Total revenues	$	727	$	414	$	116	$	432	$	1,689	$	623	$	354	$	60	$	475	$	1,512

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued

(Unaudited)

Contract liabilities—We recognize contract liabilities, recorded in other current liabilities and other long-term liabilities, for mobilization, contract preparation, ~~and~~paid pre-operating standby time, capital upgrades and deferred revenues for declining dayrate contracts using the straight-line method over the remaining contract term. Contract liabilities for our contracts with customers were as follows (in millions):


	September 30,		December 31,		June 30,		December 31,
	2019		2018		2020		2019
Deferred contract revenues, recorded in other current liabilities	$	108	$	87	$	149	$	100
Deferred contract revenues, recorded in other long-term liabilities		397		399		370		429
Total contract liabilities	$	505	$	486	$	519	$	529

Significant changes in contract liabilities were as follows (in millions):


	Nine months ended				Six months ended
	September 30,				June 30,
	2019		2018		2020		2019
Total contract liabilities, beginning of period	$	486	$	625	$	529	$	486
Decrease due to recognition of revenues for goods and services		(83)		(192)		(108)		(58)
Increase due to goods and services transferred over time		102		65		98		62
Total contract liabilities, end of period	$	505	$	498	$	519	$	490

Note 7—6—Drilling Fleet

Construction work in progress—The changes in our construction work in progress, including capital expenditures and other capital additions, were as follows (in millions):


	Nine months ended				Six months ended
	September 30,				June 30,
	2019		2018		2020		2019
Construction work in progress, beginning of period	$	632	$	1,392	$	753	$	632

Capital expenditures
Newbuild construction program		90		64		70		41
Other equipment and construction projects		169		76		83		97
Total capital expenditures		259		140		153		138
Changes in accrued capital additions		32		(6)		(31)		21
Construction work in progress impaired		(5)		—
Construction work in progress acquired in business combination		—		26

Property and equipment placed into service						(98)		(76)
Newbuild construction program		—		(903)
Other property and equipment		(151)		(61)
Construction work in progress, end of period	$	767	$	588	$	777	$	715

Impairments of assets held and used—During the three months ended March 31, 2020, we identified indicators that the carrying amounts of our asset groups may not be recoverable. Such indicators included recent significant declines in commodity prices and the market value of our stock, a reduction of expected demand for ~~sale—In September 2019,~~our drilling services as our customers announced reductions of capital investments in response to commodity prices and a reduction of projected dayrates. As a result of our testing, we ~~announced~~determined that the carrying amount of our ~~intent to retire in an environmentally responsible way the ultra-deepwater floaters~~ ~~Discoverer Deep Seas, Discoverer Enterprise~~ ~~and~~ ~~Discoverer Spirit~~~~, along with related assets.~~midwater floater was impaired. In the ~~three and nine~~six months ended ~~September~~June 30, ~~2019,~~2020, we recognized ~~an aggregate~~a loss of ~~$578~~$31 million ($~~0.96~~0.05 per diluted share), which had 0 tax effect, associated with the impairment of ~~these assets and other equipment, which we determined were impaired at~~our midwater floater. We measured the ~~time we classified~~fair value of the drilling unit in this asset group by applying the market approach, using estimates of the exchange price that would be received for the assets in the principal or most advantageous markets for the assets in an orderly transaction between participants as of the measurement date. Our estimate of fair value required us to use significant other observable inputs, representative of Level 2 fair value measurements, including the marketability of the rig and prices of comparable rigs that may be sold for scrap value.

Impairments of assets held for ~~sale.~~

sale—During the ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2020, we announced our intent to sell or retire in an environmentally responsible way, the ultra-deepwater floater GSF Development Driller II, the harsh environment floaters ~~Deepwater Discovery, Deepwater Frontier~~, ~~Deepwater Millennium~~Polar Pioneer and ~~GSF C.R. Luigs~~Songa Dee and the midwater floaters ~~Songa Delta~~Sedco 711,Sedco 714 and ~~Songa Trym~~Transocean 712,, along with related assets. In the three and ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2020, we recognized an aggregate loss of ~~$433~~$419 million ($~~0.93~~420 million, or $0.68 per diluted share, net of tax) and $556 million ($0.90 per diluted share) ~~and $981 million ($2.15 per diluted share)~~, ~~respectively,~~ which had 0 tax effect, respectively, associated with the impairment of these assets, which we determined were impaired at the time we classified the assets as held for sale.

We measured the impairment of the drilling units and related assets 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 other observable inputs, representative of a Level 2 fair value ~~measurement,~~measurements, including indicative market values for the drilling units and related assets to be sold for scrap ~~value.~~value or other purposes.

Dispositions—During the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, in connection with our efforts to dispose of non-strategic assets, we completed the sale of the midwater floater Sedco 714 and related assets. In the six months ended June 30, 2020, we received aggregate

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued

(Unaudited)

net cash proceeds of $2 million associated with the disposal of these assets, and we received aggregate net cash proceeds of $1 million associated with the disposal of assets unrelated to rig sales.

During the six months ended June 30, 2019, we completed the sale of the ultra-deepwater floaters Deepwater Frontier and Deepwater Millennium ~~and~~ ~~Ocean Rig Paros~~, the harsh environment floater Eirik Raude, the deepwater floaters Jack Bates and Transocean 706 and the midwater floaters Actinia and Songa Delta, along with related assets. In the ~~nine~~six months ended ~~September~~June 30, 2019, we received aggregate net cash proceeds of ~~$47~~$37 million ~~and recognized an aggregate net gain of $2 million, which had 0 tax effect,~~ associated with the disposal of these assets. In the ~~nine~~six months

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued~~

~~(Unaudited)~~

ended ~~September~~June 30, 2019, we received aggregate net cash proceeds of $5$3 million and recognized an aggregate net loss of ~~$9 million associated with the disposal of assets unrelated to rig sales.~~

~~During the nine months ended September 30, 2018, we completed the sale of the ultra-deepwater floaters~~ ~~Cajun Express~~, ~~Deepwater Discovery,~~~~Deepwater Pathfinder~~, ~~Sedco Energy~~ ~~and~~ ~~Sedco Express~~~~, the deepwater floater~~ ~~Transocean Marianas~~ ~~and the midwater floater~~ ~~Songa Trym,~~ along with related assets. In the nine months ended September 30, 2018, we received aggregate net cash proceeds of $31 million and recognized an aggregate net gain of $6 million ($0.02 per diluted share), which had 0 tax effect, associated with the disposal of these assets. In the nine months ended September 30, 2018, we received aggregate net cash proceeds of $6 million and recognized an aggregate net loss of $6$3 million associated with the disposal of assets unrelated to rig sales.

Assets held for sale—At ~~September~~June 30, ~~2019,~~2020, the aggregate carrying amount of our assets held for sale, including the ultra-deepwater floater GSF Development Driller II, the harsh environment floaters ~~Discoverer Deep Seas, Discoverer Enterprise~~Polar Pioneer and ~~Discoverer Spirit~~ Songa Deeand the midwater floaters Sedco 711 and Transocean 712, along with related assets, was ~~$15~~$14 million, recorded in other current assets. At December 31, ~~2018, the aggregate carrying amount of our~~2019, we had 0 assets ~~held for sale, including the ultra-deepwater floaters~~ ~~Deepwater Frontier~~ ~~and~~ ~~Deepwater Millennium,~~ ~~the deepwater floaters~~ ~~Jack Bates~~ ~~and~~ ~~Transocean 706~~ ~~and the midwater floater~~ ~~Songa Delta~~~~, along with related assets, was $25 million, recorded in other current assets.~~

~~Note 8—Goodwill~~

~~During the three months ended June 30, 2018, we~~ classified as held for sale and impaired 3 ultra-deepwater floaters. We identified the impairment of these assets as an indicator that our goodwill may be impaired. In the nine months ended September 30, 2018, as a result of our interim goodwill impairment test, we recognized a loss of $462 million ($1.02 per diluted share), which had 0 tax effect, associated with the impairment of the full balance of our goodwill. We estimated the fair value of the contract drilling services reporting unit using the income approach. Our estimate of fair value required us to use significant unobservable inputs, representative of a Level 3 fair value measurement, including assumptions related to the future performance of the reporting unit, such as future commodity prices, projected demand for our services, rig availability and dayrates.sale.

~~Note 9—Leases~~

Our operating leases are principally for office space, real estate, storage facilities and operating equipment. At September 30, 2019, our operating leases had a weighted average discount rate of 6.3 percent and a weighted-average remaining lease term of 13.9 years.

~~Our finance lease of the ultra-deepwater drillship~~ ~~Petrobras 10000~~, which is scheduled to expire in August 2029, has an implicit interest rate of 7.8 percent and requires scheduled monthly payments of $6 million through lease expiration, after which we will have the right and obligation to acquire the drillship from the lessor for 1 dollar. In the nine months ended September 30, 2019, we recognized expense of $15 million, recorded in depreciation and amortization, associated with the amortization of the right-of-use asset.

~~The components of our lease costs were as follows (in millions):~~

Three months

Nine months

ended

ended

September 30,

September 30,

2019

2019

Lease costs

Operating lease costs

$
6

$
19

Short-term lease costs

3

4

Finance lease costs, amortization of right-of-use assets

5

15

Finance lease costs, interest on lease liabilities

9

29

Total lease costs

$
23

$
67

~~Supplemental cash flow information for our leases was as follows (in millions):~~

Nine months

ended

September 30,

2019

Cash paid for amounts included in the measurement of lease liabilities:

Operating cash flows from operating leases

$
14

Operating cash flows from finance lease

29

Financing cash flows from finance lease

24

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued~~

~~(Unaudited)~~

~~At September 30, 2019, the aggregate future minimum rental payments for our leases were as follows (in millions):~~

Operating

Finance

leases

lease

Twelve months ending September 30,

2020

$
18

$
71

2021

11

71

2022

12

71

2023

12

71

2024

11

71

Thereafter

132

345

Total future minimum rental payment

196

700

Less amount representing imputed interest

(72)

(213)

Present value of future minimum rental payments

124

487

Less current portion, recorded in other current liabilities

(14)

(34)

Long-term lease liabilities, recorded in other long-term liabilities

$
110

$
453

Note ~~10—~~7—Debt

Overview

Outstanding debt—The aggregate principal amounts and aggregate carrying amounts, net of debt-related balances, including unamortized discounts, premiums, issue costs and fair value adjustments of our debt, were as follows (in millions):


	Principal amount				Carrying amount				Principal amount				Carrying amount
	September 30,		December 31,		September 30,		December 31,		June 30,		December 31,		June 30,		December 31,
	2019		2018		2019		2018		2020		2019		2020		2019
6.50% Senior Notes due November 2020	$	208	$	286	$	209	$	288	$	198	$	206	$	198	$	206
6.375% Senior Notes due December 2021		224		328		224		327		184		222		184		221
5.52% Senior Secured Notes due May 2022		221		282		219		280		156		200		155		198
3.80% Senior Notes due October 2022		199		411		198		408		182		190		181		189
0.50% Exchangeable Bonds due January 2023		863		863		862		862		863		863		862		862
5.375% Senior Secured Notes due May 2023		525		—		517		—		503		525		498		518
9.00% Senior Notes due July 2023		753		1,250		738		1,221		—		714		—		701
5.875% Senior Secured Notes due January 2024		667		750		655		735		626		667		616		656
7.75% Senior Secured Notes due October 2024		450		480		441		469		390		420		383		412
6.25% Senior Secured Notes due December 2024		469		500		460		489		406		437		399		430
6.125% Senior Secured Notes due August 2025		534		600		524		588		501		534		493		525
7.25% Senior Notes due November 2025		750		750		737		736		750		750		738		737
7.50% Senior Notes due January 2026		750		750		743		742		750		750		744		743
6.875% Senior Secured Notes due February 2027		550		—		541		—		550		550		542		541
8.00% Senior Notes due February 2027										750		—		743		—
7.45% Notes due April 2027		88		88		86		86		88		88		86		86
8.00% Debentures due April 2027		57		57		57		57		57		57		57		57
7.00% Notes due June 2028		300		300		306		306		300		300		305		306
Finance lease contract due August 2029		—		511		—		511
7.50% Notes due April 2031		588		588		585		585		588		588		585		585
6.80% Senior Notes due March 2038		1,000		1,000		991		991		1,000		1,000		992		991
7.35% Senior Notes due December 2041		300		300		297		297		300		300		297		297
Total debt		9,496		10,094		9,390		9,978		9,142		9,361		9,058		9,261

Less debt due within one year
6.50% Senior Notes due November 2020										198		206		198		206
5.52% Senior Secured Notes due May 2022		87		83		86		81		90		88		90		87
9.00% Senior Notes due July 2023		3		—		3		—
5.375% Senior Secured Notes due May 2023										31		16		29		14
5.875% Senior Secured Notes due January 2024		83		83		79		79		83		83		79		79
7.75% Senior Secured Notes due October 2024		60		60		58		58		60		60		58		58
6.25% Senior Secured Notes due December 2024		62		62		60		60		62		62		60		60
6.125% Senior Secured Notes due August 2025		66		66		63		63		66		66		64		64
Finance lease contract due August 2029		—		32		—		32
Total debt due within one year		361		386		349		373		590		581		578		568
Total long-term debt	$	9,135	$	9,708	$	9,041	$	9,605	$	8,552	$	8,780	$	8,480	$	8,693

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued

(Unaudited)

Scheduled maturities—At ~~September~~June 30, ~~2019,~~2020, the scheduled maturities of our debt were as follows (in millions):


	Total		Total
Twelve months ending September 30,
2020	$	361
Twelve months ending June 30,
2021		602	$	590
2022		669		618
2023		2,582		1,793
2024		609		643
2025				455
Thereafter		4,673		5,043
Total principal amount of debt		9,496		9,142
Total debt-related balances, net		(106)		(84)
Total carrying amount of debt	$	9,390	$	9,058

~~Interest rate adjustments~~—The interest rates for certain of our notes are subject to adjustment from time to time upon a change to the credit rating of our non-credit enhanced senior unsecured long-term debt. As of September 30, 2019, the interest rate in effect for the 6.375% senior notes due December 2021, 3.80% senior notes due October 2022 and the 7.35% senior notes due December 2041 was 8.375 percent, 5.80 percent and 9.35 percent, respectively.

Secured Credit Facility—~~In June 2018, we entered into~~We have a ~~bank credit agreement, which established a $1.0~~$1.3 billion secured revolving credit facility, established under a bank credit agreement, as amended most recently in December 2019 (the “Secured Credit Facility”), and in May, July and September 2019, we amended the terms of the Secured Credit Facility to, among other changes, increase the borrowing capacity to $1.3 billion and add to and clarify the lender parties and their respective commitments under the facility. The Secured Credit Facilitywhich is scheduled to expire on ~~the earlier of (i)~~ June 22, ~~2023 or (ii) if greater than $300 million aggregate principal amount of our 9.00% senior notes due July 2023 remain outstanding in April 2023, such date.~~2023. The Secured Credit Facility is guaranteed by Transocean Ltd. and certain wholly owned ~~subsidiaries and is secured by, among other things, a lien on the ultra-deepwater floaters~~ ~~Deepwater Asgard, Deepwater Invictus~~, ~~Deepwater Skyros~~, ~~Dhirubhai Deepwater KG2~~ ~~and~~ ~~Discoverer Inspiration~~ ~~and the harsh environment floaters~~ ~~Transocean Barents~~ ~~and~~ ~~Transocean Spitsbergen~~~~, the aggregate carrying amount of which was $4.1 billion at September 30, 2019.~~subsidiaries. We may borrow under the Secured Credit Facility at either (1) the reserve adjusted London interbank offered rate plus a margin (the “Secured Credit Facility Margin”), which ranges from 2.625 percent to 3.375 percent based on the credit rating of the Secured Credit Facility, or (2) the base rate specified in the credit agreement plus the Secured Credit Facility Margin, minus 1 percent per annum. Throughout the term of the Secured Credit Facility, we pay a facility fee on the amount of the underlying commitment which ranges from 0.375 percent to 1.00 percent based on the credit rating of the Secured Credit Facility. At ~~September~~June 30, ~~2019,~~2020, based on the credit rating of the Secured Credit Facility on that date, the Secured Credit Facility Margin was ~~2.875~~3.25 percent and the facility fee was ~~0.625~~0.75 percent. At ~~September~~June 30, ~~2019,~~2020, we had 0 borrowings outstanding, ~~$15~~$25 million of letters of credit issued, and we had $1.3 billion of available borrowing capacity under the Secured Credit Facility.

Interest rate adjustments—The interest rates for certain of our notes are subject to adjustment from time to time upon a change to the credit rating of our non-credit enhanced senior unsecured long-term debt. As of June 30, 2020, the interest rate in effect for the 6.375% senior notes due December 2021, 3.80% senior notes due October 2022 and the 7.35% senior notes due December 2041 was 8.375 percent, 5.80 percent and 9.35 percent, respectively.

Exchangeable bonds—The 0.50% exchangeable senior bonds due January 30, 2023 (the “Exchangeable Bonds”) may be converted at any time prior to the maturity date at an exchange rate of 97.29756 shares per $1,000 note, equivalent to a conversion price of $10.28 per share, subject to adjustment upon the occurrence of certain events.

Debt issuances

Priority guaranteed senior unsecured notes—On January 17, 2020, we issued $750 million aggregate principal amount of 8.00% senior unsecured notes due February 2027 (the “8.00% Senior Notes”), and we received aggregate cash proceeds of $743 million, net of issue costs. The 8.00% Senior Notes are fully and unconditionally guaranteed by Transocean Ltd. and certain wholly owned subsidiaries of Transocean Inc. Such notes rank equal in right of payment to all of our existing and future unsecured unsubordinated obligations and rank structurally senior to the extent of the value of the assets of the subsidiaries guaranteeing the notes. We may redeem all or a portion of the 8.00% Senior Notes on or prior to February 1, 2023 at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision, and subsequently, at specified redemption prices. The indenture that governs the 8.00% Senior Notes contains covenants that, among other things, limit our ability to incur certain liens on our drilling units without equally and ratably securing the notes, engage in certain sale and lease back transactions covering any of our drilling units, allow our subsidiaries to incur certain additional debt, and consolidate, merge or enter into a scheme of arrangement qualifying as an amalgamation.

Senior secured notes—On February 1, 2019, we issued $550 million aggregate principal amount of 6.875% senior secured notes due February 2027 (the “6.875% Senior Secured Notes”), and we received ~~approximately $539 million~~ aggregate cash proceeds of $539 million, net of discount and issue costs. The 6.875% Senior Secured Notes are secured by the assets and earnings associated with the ultra-deepwater floater Deepwater Poseidon and the equity of the wholly owned subsidiaries that own or operate the collateral rig. Additionally, we were required to deposit $19 million in restricted cash accounts to satisfy debt service requirements. We are required to pay semiannual installments of (a) interest only through August 2021 and (b) principal and interest thereafter. We may redeem all or a portion of the 6.875% Senior Secured Notes on or prior to February 1, 2022 at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision, and subsequently, at specified redemption prices. We will be required to redeem the notes at a price equal to 100 percent of the aggregate principal amount, without a make-whole provision, upon the occurrence of certain events related to the collateral rig and the related drilling contract. The indenture that governs the 6.875% Senior Secured Notes contains covenants that limit the ability of our subsidiaries that own or operate the collateral rig to declare or pay dividends to their affiliates. The indenture also imposes a maximum collateral rig leverage ratio (the “Maximum Collateral Ratio”), represented by the net earnings of the rig relative to the debt balance, that changes over the term of the notes. Through December 31, 2020, the Maximum Collateral Ratio under the indenture is 5.75 to 1.00.

On May 24, 2019, we issued $525 million aggregate principal amount of 5.375% senior secured notes due May 2023 (the “5.375% Senior Secured Notes”), and we received ~~approximately $517 million~~ aggregate cash proceeds of $517 million, net of discount and issue costs. The 5.375% Senior Secured Notes are secured by the assets and earnings associated with the ultra-deepwater floaters Transocean Endurance and Transocean Equinox and the equity of the wholly owned subsidiaries that own or operate the collateral rigs. Additionally, we were required to deposit $14 million in restricted cash accounts to satisfy debt ~~service requirements. We are required to pay semiannual installments of (a) interest only through May~~service.

Debt retirements

During the six months ended June 30, 2020 and ~~(b) principal~~2019, we retired certain notes as a result of redemptions, tender offers and ~~interest thereafter. We may~~open market repurchases. On February 18, 2020, we made a payment to redeem ~~all or a portion of the 5.375% Senior Secured Notes on or prior to May 15, 2021 at a price equal to 100 percent of the aggregate principal amount plus~~in full, together with a make-whole provision, and subsequently, at specified redemption prices. We will be required to redeem the notes at a price equal to 100 percent of the aggregate principal amount, without a make-whole provision, upon the occurrence of certain events related to the collateral rigs and the related drilling contracts. The indenture that governs the 5.375% Senior Secured Notes contains covenants that limit the abilityour outstanding

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(Unaudited)

of our subsidiaries that own or operate the collateral rigs to declare or pay dividends to their affiliates. The indenture also imposes a Maximum Collateral Ratio, represented by the net earnings of the rig relative to the debt balance, that changes over the term of the notes. Through March 31, 2021, the Maximum Collateral Ratio under the indenture is 4.50 to 1.00.

~~On July 13, 2018, we issued $750 million aggregate principal amount of 5.875%~~9.00% senior ~~secured~~ notes due January 2024 (the “5.875% Senior Secured Notes”) and received aggregate cash proceeds of $733 million, net of discount and issue costs. In connection with the issuance of such notes, we were required to deposit $63 million in restricted cash accounts to satisfy debt service and reserve requirements. We are required to pay semiannual installments of principal and interest. The 5.875% Senior Secured Notes are secured by the assets and earnings associated with the harsh environment floaters ~~Transocean Enabler~~ ~~and~~ ~~Transocean Encourage~~ ~~and the equity of the wholly owned subsidiaries that own or operate the collateral rigs.~~

On July 20, 2018, we issued $600 million aggregate principal amount of 6.125% senior secured notes due August 2025 (the “6.125% Senior Secured Notes” and, together with the 5.875% Senior Secured Notes, the “2018 Senior Secured Notes”), and we received aggregate cash proceeds of $586 million, net of discount and issue costs. In connection with the issuance of such notes, we were required to deposit $51 million in restricted cash accounts to satisfy debt service and reserve requirements. We are required to pay semiannual installments of principal and interest. The 6.125% Senior Secured Notes are secured by the assets and earnings associated with the ultra-deepwater floater ~~Deepwater Pontus~~ ~~and the equity of the wholly owned subsidiaries that own or operate the collateral rig.~~

~~Exchangeable bonds~~—In the nine months ended September 30, 2018, we issued $863 million aggregate principal amount of 0.50% exchangeable senior bonds due January 30, 2023 (the “Exchangeable Bonds”), as partial consideration for the acquisition of Songa shares and as consideration for refinancing certain Songa indebtedness. The Exchangeable Bonds may be converted at any time prior to the maturity date at an exchange rate of 97.29756 shares per $1,000 note, equivalent to a conversion price of $10.28 per share, subject to adjustment upon the occurrence of certain events. We recorded the Exchangeable Bonds at the aggregate fair value of $1.0 billion, measured as of the issuance date, and recorded to additional paid-in capital the amount above par value, representing a substantial premium of $172 million. We estimated the fair value using significant other observable inputs, representative of a Level 2 fair value measurement, including the terms and credit spreads for the instruments.

~~Debt retirements~~

~~Tender offers~~—2023. On February 5, 2019, we completed cash tender offers to purchase certain notes ~~(the “2019 Tendered Notes”). We received valid tenders from holders of~~validly tendered. Additionally, during the six months ended June 30, 2020 and 2019, we repurchased in the open market certain notes. The aggregate principal amounts, ~~of the 2019 Tendered Notes~~cash payments and recognized gain or loss for such transactions were as follows (in millions):


	Nine months
	ended		Six months ended June 30,
	September 30,		2020						2019
	2019		Redeemed		Repurchased		Total		Tendered		Repurchased		Total
6.50% Senior Notes due November 2020	$	57	$	—	$	8	$	8	$	57	$	—	$	57
6.375% Senior Notes due December 2021		63		—		38		38		63		15		78
3.80% Senior Notes due October 2022		190		—		8		8		190		3		193
5.375% Senior Secured Notes due May 2023				—		22		22		—		—		—
9.00% Senior Notes due July 2023		200		714		—		714		200		112		312
Aggregate principal amount retired	$	510	$	714	$	76	$	790	$	510	$	130	$	640

Aggregate cash payment	$	522	$	767	$	63	$	830	$	522	$	136	$	658
Aggregate net loss	$	(18)
Aggregate net gain (loss)			$	(65)	$	12	$	(53)	$	(18)	$	(9)	$	(27)

~~Repurchases~~~~—We repurchased in the open market our debt securities with aggregate principal amounts as follows (in millions):~~

Nine months ended September 30,

2019

2018

6.50% Senior Notes due November 2020

$
21

$
—

6.375% Senior Notes due December 2021

41

—

3.80% Senior Notes due October 2022

22

95

9.00% Senior Notes due July 2023

297

—

Aggregate principal amount retired

$
381

$
95

Aggregate cash payment

$
395

$
95

Aggregate net loss for the three months ended September 30

$
(12)

$
—

Aggregate net loss for the nine months ended September 30

$
(21)

$
(1)

~~Other repayments~~—During the nine months ended September 30, 2018, in connection with the Songa acquisition, we assumed the rights and obligations under certain credit agreements, a subscription agreement and bond loan agreements. In the three and nine months ended September 30, 2018, we made an aggregate cash payment equivalent to $1.59 billion and $1.65 billion, respectively, to repay the debt obligations outstanding under these agreements, and we terminated the underlying agreements.

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued~~

~~(Unaudited)~~

Note ~~11—Derivative Instruments~~

~~Forward exchange contracts~~—At September 30, 2019, we held undesignated forward exchange contracts, extending through March 2020, with an aggregate notional payment amount of $93 million and an aggregate notional receive amount of NOK 810 million, representing a weighted average exchange rate of NOK 8.74 to $1. At September 30, 2019 and December 31, 2018, the net carrying amount of our undesignated forward exchange contracts was a liability of $3 million and $6 million, respectively, recorded in other current liabilities.

~~Currency swaps~~—In connection with the Songa acquisition, we acquired undesignated currency swaps to receive Norwegian kroner in exchange for U.S. dollars. In the nine months ended September 30, 2018, we made an aggregate cash payment of $92 million to terminate the currency swaps and we recognized a loss of $11 million, recorded in other, net.

~~Note 12—~~8—Income Taxes

Tax provision and rate—In the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, our effective tax rate was ~~(7.4)~~(3.2) percent and ~~(7.2)~~(8.3) percent, respectively, based on ~~income or~~ loss before income tax expense. In the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, the effect of various discrete period tax items was a net tax benefit of ~~$40~~$9 million and ~~a net tax expense of $91~~$30 million, respectively. In the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, such discrete items ~~were related to various items, including~~included the revenues recognized for the settlement of disputes, the loss on impairment of an investment in an unconsolidated affiliate, the carryback of net operating losses in the U.S. as a result of the Coronavirus Aid, Relief, and Economic Security Act, which included the release of valuation allowances previously recorded, as well as settlements and expirations of various uncertain tax positions, gains and losses on currency exchange rates and changes in valuation allowances. In the six months ended June 30, 2019, such discrete items included the settlement and reversal of various uncertain tax provisions and adjustments to our valuation allowance and adjustments to our deferred taxes for operating structural changes made in the U.S. In the ~~nine~~six months ended ~~September~~June 30, ~~2018, such discrete items were primarily related to the U.S. transition tax on non-U.S. earnings. In the nine months ended September 30,~~2020 and 2019, ~~and 2018,~~ our effective tax rate, excluding discrete items, was ~~(24.7)~~(12.0) percent and ~~(15.6)~~(18.0) percent, respectively, based on ~~income or~~ loss before income tax expense. Our effective tax rate in the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018, decreased primarily due to the adoption of a new operating structure, which reduces our exposure to the U.S. base erosion and anti-abuse tax and other cash taxes in the U.S. in the current and future years. To a lesser extent, our effective tax rate decreased due to changes in the relative blend of income from operations in certain jurisdictions.

Included in our tax provision for the nine months ended September 30, 2019, we recognized a tax benefit of $112 million, including interest and penalties, as a result of changes to our unrecognized tax benefits related to settlements that were closed in our favor, which was partially offset by tax expense of $94 million for unrecognized tax benefits related to new positions. See Note 17—Subsequent Events.

Tax returns—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 timing or the outcome of these proceedings, we do not expect the ultimate liability to have a material adverse effect on our condensed consolidated statement of financial position or results of operations, although it may have a material adverse effect on our condensed consolidated statement of cash flows.

Brazil tax investigations—In December 2005, the Brazilian tax authorities began issuing tax assessments with respect to our tax returns for the years 2000 through 2004. In January 2008, we filed a protest letter with the Brazilian tax authorities for these tax assessments, and we are currently engaged in the appeals process. In May 2014, the Brazilian tax authorities issued an additional tax assessment for the years 2009 and 2010, and in June 2014, we filed protests with the Brazilian tax authorities for these tax assessments. In ~~September~~the years ended December 31, 2018 and ~~in the first half of~~ 2019, a portion of ~~one~~each of the two cases was favorably closed. As of ~~September~~June 30, ~~2019,~~2020, the remaining aggregate tax assessment was for BRL ~~672~~732 million, equivalent to approximately ~~$162~~$134 million, including penalties and interest. We believe our returns are materially correct as filed, and we are vigorously contesting these assessments. An unfavorable outcome on these proposed assessments could result in a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows.

Other tax matters—We conduct operations through our various subsidiaries in 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. ~~It is reasonably possible that we may release certain liabilities for uncertain tax positions in the year ending December 31, 2019, primarily due to resolution of certain tax settlements.~~ Although we are unable to predict the outcome of ~~our tax positions,~~these changes, we do not expect the effect, if any, resulting from these adjustments to have a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued

(Unaudited)

Note ~~13—~~9—Loss Per Share

The numerator and denominator used to compute loss per share ~~loss~~ were as follows (in millions, except per share data):


	Three months ended September 30,								Nine months ended September 30,								Three months ended June 30,								Six months ended June 30,
	2019				2018				2019				2018				2020				2019				2020				2019
	Basic		Diluted		Basic		Diluted		Basic		Diluted		Basic		Diluted		Basic		Diluted		Basic		Diluted		Basic		Diluted		Basic		Diluted
Numerator for loss per share
Net loss attributable to controlling interest	$	(825)	$	(825)	$	(409)	$	(409)	$	(1,204)	$	(1,204)	$	(1,754)	$	(1,754)	$	(497)	$	(497)	$	(208)	$	(208)	$	(889)	$	(889)	$	(379)	$	(379)

Denominator for loss per share
Weighted-average shares outstanding		612		612		463		463		611		611		454		454		614		614		611		611		614		614		611		611
Effect of share-based awards and other equity instruments		1		1		—		—		1		1		—		—		1		1		1		1		1		1		1		1
Weighted-average shares for per share calculation		613		613		463		463		612		612		454		454		615		615		612		612		615		615		612		612

Loss per share	$	(1.35)	$	(1.35)	$	(0.88)	$	(0.88)	$	(1.97)	$	(1.97)	$	(3.86)	$	(3.86)	$	(0.81)	$	(0.81)	$	(0.34)	$	(0.34)	$	(1.45)	$	(1.45)	$	(0.62)	$	(0.62)

In the three and ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, we excluded from the calculation ~~12.2~~14.8 million and 13.0 million share-based awards, respectively, since the effect would have been anti-dilutive. In the three and ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, we excluded from the calculation ~~10.7~~12.6 million and 12.2 million share-based awards, respectively, since the effect would have been anti-dilutive. In the three and ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, we excluded from the calculation 84.0 million shares issuable upon conversion of the Exchangeable Bonds since the effect would have been anti-dilutive. In the three and ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, we excluded from the calculation 84.0 ~~million and 74.9~~ million shares issuable upon conversion of the Exchangeable Bonds ~~respectively,~~ since the effect would have been anti-dilutive.

Note ~~14—~~10—Contingencies

Legal proceedings

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 off the coast of Louisiana. At the time of the explosion, Deepwater Horizon was contracted to an affiliate of BP plc. ~~Following the incident, we have been subject to~~Most claims, both civil and criminal, ~~claims, as well as causes of action, fines and penalties by local, state and federal governments. Litigation commenced shortly after the incident, and most claims~~brought against us were consolidated by the U.S. Judicial Panel on Multidistrict Litigation and transferred to the U.S. District Court for the Eastern District of Louisiana (the “MDL Court”)., all of which have now been resolved. We ~~recognized a liability for the remaining estimated loss contingencies associated with litigation resulting from the Macondo well incident that we believe are probable~~will vigorously defend against any future actions not resolved by our previous settlements and ~~for which a reasonable estimate can be made.~~ pursue all defenses available.

At ~~September 30, 2019 and~~ December 31, ~~2018,~~2019, the remaining liability for estimated loss contingencies that we believe ~~are~~were probable and for which a reasonable estimate ~~can~~could be made was $124 million, ~~and $158 million, respectively,~~ recorded in other current liabilities, the majority of which is related to the settlement agreement that we and the Plaintiff Steering Committee filed with the MDL Court in May 2015 (the “PSC Settlement Agreement”)~~. A significant portion of the contingencies arising from the Macondo well incident has now been resolved or is pending release of funds from escrow. As for any actions not resolved~~, which was approved by ~~our previous settlements, we will vigorously defend those claims and pursue any and all defenses available.~~

~~On February 15, 2017,~~ the MDL Court ~~entered a final order and judgment approving the PSC Settlement Agreement.~~on February 15, 2017. Through the PSC Settlement Agreement, we agreed to pay a total of $212 million to be allocated between 2 classes of plaintiffs in exchange for a release of all respective claims each class has against us. As required under the PSC Settlement Agreement, we deposited the settlement amount into an escrow account established by the MDL Court. In ~~August 2019 and November 2018,~~June 2020, the MDL Court released ~~$33 million and $58 million, respectively, from~~the assets held in the escrow account to ~~make payments to~~satisfy our remaining obligations under the ~~plaintiffs.~~PSC Settlement Agreement. At ~~September 30, 2019 and~~ December 31, ~~2018,~~2019, the ~~remaining cash~~ balance held in the escrow account was ~~$124~~$125 million, ~~and $156 million, respectively,~~ recorded in restricted cash accounts and investments.

Asbestos litigation—In 2004, several of our subsidiaries were named, along with numerous other unaffiliated defendants, in complaints filed in the Circuit Courts of the State of Mississippi, and in 2014, a group of similar complaints were filed in Louisiana. The plaintiffs, former employees of some of the defendants, generally allege that the defendants used or manufactured asbestos containing drilling mud additives for use in connection with drilling operations, claiming 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, but the court-appointed special master has ruled that a Jones Act employer defendant, such as us, cannot be sued for punitive damages. At ~~September~~June 30, ~~2019, 9~~2020, 8 plaintiffs have claims pending in Louisiana, in which we have or may have an interest. We intend to defend these lawsuits vigorously, although we can provide no assurance as to the 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 ~~related~~ to ~~the complaints,~~date, we do not expect the liability, if any, resulting from these claims to have a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows.

NaN of our subsidiaries has been named as a defendant, along with numerous other companies, in lawsuits arising out of the subsidiary’s manufacture and sale of heat exchangers, and involvement in the construction and refurbishment of major industrial complexes

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued~~

~~(Unaudited)~~

alleging bodily injury or personal injury as a result of exposure to asbestos. As of ~~September~~June 30, ~~2019,~~2020, the subsidiary was a defendant in approximately ~~192~~222 lawsuits with a corresponding number of plaintiffs. For many of these lawsuits, we have not been provided 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 operating assets of the subsidiary were sold in 1989. In September 2018, the subsidiary and certain insurers agreed to a settlement of outstanding disputes that leaves the subsidiary with funding, including cash, annuities and coverage in place settlement, that we believe will be sufficient to respond to both the current lawsuits as well as future lawsuits of a similar

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(Unaudited)

nature. While we cannot predict or provide assurance as to the outcome of these matters, we do not expect the ultimate liability, if any, resulting from these claims ~~to have a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows.~~

~~Nigerian Cabotage Act litigation~~—In October 2007, 3 of our subsidiaries were each served a Notice and Demand from the Nigeria Maritime Administration and Safety Agency (“NIMASA”), imposing a 2 percent surcharge on the value of all contracts performed by us in Nigeria pursuant to the Coastal and Inland Shipping (Cabotage) Act 2003 (the “Cabotage Act”). Our subsidiaries each filed an originating summons in the Federal High Court in Lagos challenging the imposition of this surcharge on the basis that the Cabotage Act and associated levy is not applicable to offshore drilling rigs. The respondents challenged the competence of the suits on several procedural grounds. The court upheld the objections and dismissed the suits. In December 2010, our subsidiaries filed a new joint Cabotage Act suit. In June 2019, the Court of Appeal of Nigeria ruled the suits had been properly dismissed, confirming that offshore drilling rigs are not subject to the surcharges of the Cabotage Act. NIMASA has not indicated whether it intends to appeal. While we cannot predict or provide assurance as to the outcome of these proceedings, we do not expect the proceedings to have a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows.

Other matters—We are involved in various tax matters, various regulatory matters, and a number of claims and lawsuits, asserted and unasserted, 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 condensed 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, threatened, or possible litigation or liability. We can provide no assurance that our beliefs or expectations as to the outcome or effect of any tax, regulatory, lawsuit or other litigation matter will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

Environmental matters

We have certain potential liabilities under the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”) and similar state acts regulating cleanup of hazardous substances at 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. It is difficult to quantify the potential cost of environmental matters and remediation obligations. Liability is strict and can be joint and several.

One of our subsidiaries ~~has been~~was 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 agreed, under a participation agreement with the U.S. Environmental Protection Agency (the “EPA”) and the U.S. Department of Justice, to settle our potential liabilities by remediating the site. The remedial action for the site ~~and we have~~was completed ~~the required remediation.~~in 2006. Our share of the ongoing ~~operation~~operating and maintenance costs has been ~~insignificant. We have no reason to believe that~~insignificant, and we do not expect any additional potential liabilities ~~for the site will~~to be material.

One of our subsidiaries was ordered by the California Regional Water Quality Control Board to develop a testing plan for a site known as Campus 1000 Fremont in Alhambra, California, which is now a part of the San Gabriel Valley, Area 3, Superfund site. The current property owner, an unrelated party, performed the required testing and detected no contaminants, and based on such results, we would contest any potential liability. We have no knowledge of the potential cost of any remediation, who has been 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. ~~It is difficult to quantify the potential cost of environmental matters and remediation obligations.~~ Nevertheless, based on ~~the~~ available information, we do not expect the ultimate liability, if any, resulting from all environmental matters, ~~including the liability for all related pending legal proceedings, asserted legal claims~~ and known potential legal claims that are likely to be asserted, to have a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows.

~~Note 15—Equity~~

On January 30, 2018, we acquired an approximate 97.7 percent ownership interest in Songa. To complete the acquisition, we issued 66.9 million shares with a weighted average per share market value of $10.99 and $854 million aggregate principal amount of the Exchangeable Bonds.

~~- 16 -~~

~~Table of Contents~~

~~TRANSOCEAN LTD. AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS─continued~~

~~(Unaudited)~~

On the date of the Songa acquisition, we recognized noncontrolling interest of $33 million, representing the estimated fair value of the 2.3 percent ownership interest not owned by us. On March 28, 2018, we acquired the remaining Songa shares through a compulsory acquisition under Cyprus law, and as a result, Songa became our wholly owned subsidiary. As consideration, we issued 1.1 million shares with a weighted average per share market value of $9.76 and $9 million aggregate principal amount of Exchangeable Bonds and we made an aggregate cash payment of $8 million to the Songa shareholders who elected to receive a cash payment or failed to make an election, for an aggregate fair value of $30 million.

Note ~~16—~~11—Financial Instruments

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


	September 30, 2019				December 31, 2018				June 30, 2020				December 31, 2019
	Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
	amount		value		amount		value		amount		value		amount		value
Cash and cash equivalents	$	1,906	$	1,906	$	2,160	$	2,160	$	1,511	$	1,511	$	1,790	$	1,790
Restricted cash and cash equivalents		551		551		429		429		437		437		558		558
Restricted investments		—		—		123		123
Long-term debt, including current maturities		9,390		8,569		9,978		9,212		9,058		5,553		9,261		8,976
Derivative instruments, liabilities		3		3		6		6

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 our~~Our cash and ~~cash equivalents represents the historical cost, plus accrued interest. Our~~ cash equivalents are primarily invested in demand deposits, short-term time deposits and money market funds. The carrying amount of our cash and cash equivalents represents the historical cost, plus accrued interest, which approximates fair value because of the short maturities of the instruments.

Restricted cash and cash equivalents—~~The carrying amount of our~~Our restricted cash and cash equivalents, which are subject to restrictions due to collateral requirements, legislation, regulation or court order, are primarily invested in demand deposits, short-term time deposits and money market funds. The carrying amount of our restricted cash and cash equivalents represents the historical cost, plus accrued interest, which approximates fair value because of the near-term maturities of the instruments in which the restricted balances are held. At September 30, 2019, the aggregate carrying amount of such restricted cash and cash equivalents was $551 million, recorded in current assets. At December 31, 2018, the aggregate carrying amount of such restricted cash and cash equivalents was $429 million, including $428 million and $1 million recorded in current assets and other assets, respectively.

~~Restricted investments~~—The carrying amount of our restricted investments, which were held in escrow by court order, represents the amortized historical cost of the time deposits in which they are invested. The carrying amount of such restricted investments approximates fair value because of the near-termshort maturities of the instruments.

Debt—The carrying amount of our debt represents the principal amount, net of unamortized discounts, premiums, debt issue costs and fair value adjustments. We measured the estimated fair value of our debt using significant other observable inputs, representative of a Level 2 fair value measurement, including the terms and credit spreads for the instruments.

~~Derivative instruments~~—The carrying amount of our derivative instruments represents the estimated fair value of such instruments. We measured the estimated fair value of our derivative instruments using significant other observable inputs, representative of a Level 2 fair value measurement, including the terms and credit spreads for the instruments.

~~Note 17—Subsequent Events~~

~~Income taxes~~—Subsequent to September 30, 2019, the U.S. Treasury Department issued proposed regulations that clarify portions of the Tax Cuts and Jobs Act. As a result of the proposed regulations, we expect to recognize a tax benefit of approximately $90 million in the three months ending December 31, 2019.

~~Samsung Heavy Industries Co., Ltd.~~~~—In September 2019, two of our indirect, wholly owned subsidiaries delivered to Samsung Heavy Industries Co., Ltd. (“SHI”) notices of intent to relinquish their respective interests in~~ ~~Ocean Rig Santorini~~ ~~and~~ ~~Ocean Rig Crete~~, 2 ultra-deepwater drillships under construction. In October 2019, we agreed with SHI to cancel the construction contracts for the rigs in exchange for the parties terminating their respective obligations and liabilities under the construction contracts and our subsidiaries releasing to SHI their respective interests in the rigs. As a result, we expect to eliminate the construction contract intangible liabilities of $132 million in the three months ended December 31, 2019.

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Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Forward-Looking Information

The statements included in this quarterly 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 Section 27A of the United States (“U.S.”) Securities Act of 1933 and Section 21E of the U.S. Securities Exchange Act of 1934. Forward-looking statements in this quarterly report include, but are not limited to, statements about the following subjects:

◾the effect, impact, potential duration or other implications of the outbreak of a novel strain of coronavirus (“COVID-19”) and disputes and actions with respect to production levels by, among or between major oil and gas producing countries and any expectations we may have with respect thereto;

◾our results of operations, our revenue efficiency and other performance indicators and our cash flow from operations;

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

◾customer drilling contracts, including contract backlog, force majeure provisions, contract awards, commencements, extensions, terminations, renegotiations, contract option exercises, contract revenues, early termination payments, indemnity provisions and rig mobilizations;

◾liquidity, including availability under our bank credit agreement, and adequacy of cash flows for our obligations;

◾regulatory or other limitations imposed as a result of the acquisition of Songa Offshore SE (“Songa”), a European public company limited by shares, or societas Europaea, existing under the laws of Cyprus or the acquisition of Ocean Rig UDW Inc. (“Ocean Rig”), a Cayman Islands exempted company with limited liability;

◾~~the success of our business following completion of the acquisition of Songa or Ocean Rig;~~

◾~~the ability to successfully integrate our business with the Songa and Ocean Rig businesses;~~

◾~~the risk that we may be unable to achieve expected synergies from the acquisitions of Songa or Ocean Rig or that it may take longer or be more costly than expected to achieve those synergies;~~

◾debt levels, including impacts of athe current financial and economic downturn, and interest rates;

◾newbuild, upgrade, shipyard and other capital projects, including completion, relinquishment or abandonment, 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;

◾the optimization of rig-based spending;

◾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, ~~Nigeria,~~ Norway, Switzerland, the United Kingdom (“U.K.”), the U.S., Canada, Angola, and ~~the U.S.;~~India, among other jurisdictions;

◾legal and regulatory matters, including results and effects of current or potential 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

◾investment in recruitment, retention and personnel development initiatives, defined benefit pension plan contributions, the timing of severance payments and benefit payments.

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

◾

anticipates

◾

budgets

◾

estimates

◾

forecasts

◾

may

◾

plans

◾

projects

◾

should

◾

believes

◾

could

◾

expects

◾

intends

◾

might

◾

predicts

◾

scheduled

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

◾those described under “Item 1A. Risk Factors” included in Part I of our annual report on Form 10-K for the year ended December 31, ~~2018;~~2019 and in Part II of our quarterly report on Form 10-Q for the quarterly period ended March 31, 2020;

◾the effects of public health threats, pandemics and epidemics, such as the outbreak of COVID-19, and the adverse impact thereof on our business, financial condition and results of operations, including, but not limited to, our growth, operating costs, supply chain, labor availability, logistical capabilities, customer demand for our services and industry demand generally, our liquidity, the price of our securities and trading markets with respect thereto, our ability to access capital markets, and the global economy and financial markets generally;

◾the effects of actions by, or disputes among or between, members of the Organization of Petroleum Exporting Countries and other oil and natural gas producing countries with respect to production levels or other matters related to the prices of oil and natural gas;

◾the adequacy of and access to our sources of liquidity;

◾our inability to obtain drilling contracts for our rigs that do not have contracts;

◾our inability to renew drilling contracts at comparable dayrates;

◾operational performance;

◾the cancellation of drilling contracts currently included in our reported contract backlog;

◾losses on impairment of long-lived assets;

◾shipyard, construction and other delays;

◾the results of meetings of our shareholders;

◾changes in political, social and economic conditions;

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

◾other factors discussed in this quarterly 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. We expressly disclaim any obligations or undertaking to release publicly any updates or revisions to any forward-looking statement to reflect any change in our expectations or beliefs with regard to the statement or any change in events, conditions or circumstances on which any forward-looking statement is based, except as required by law.

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Business

Transocean Ltd. (together with its subsidiaries and predecessors, unless the context requires otherwise, “Transocean”, “we,” “us” or “our”) is a leading international provider of offshore contract drilling services for oil and gas wells. As of ~~October 22, 2019,~~July 23, 2020, we owned or had partial ownership interests in and operated 4539 mobile offshore drilling units, including 2827 ultra-deepwater floaters 14and 12 harsh environment ~~floaters and three midwater~~ floaters. As of ~~October 22, 2019,~~July 23, 2020, we were constructing two ultra-deepwater drillships.

We provide contract drilling services in a single, global operating segment, which 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 ultra-deepwater and harsh environment drilling services. ~~We believe our~~Our drilling fleet is one of the most versatile ~~fleets~~ in the world, consisting of drillships and semisubmersible floaters used in support of offshore drilling activities and offshore support services on a worldwide basis.

Our contract drilling services 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 operate, build or upgrade our rigs are determined by the activities and needs of our customers.

Significant Events

Debt issuance—On ~~February 1, 2019,~~January 17, 2020, we issued ~~$550~~$750 million aggregate principal amount of ~~6.875%~~8.00% senior ~~secured~~unsecured notes due February 2027 (the ~~“6.875%~~“8.00% Senior ~~Secured~~ Notes”), and we received ~~$539 million~~ aggregate cash proceeds of $743 million, net of discount and issue costs. On May 24, 2019, we issued $525 million aggregate principal amount of 5.375% senior secured notes due May 2023 (the “5.375% Senior Secured Notes”), and we received $517 million aggregate cash proceeds, net of discount and issue costs. See “—Liquidity and Capital Resources—Sources and uses of liquidity.”

Early debt retirement—~~During~~On January 17, 2020, we provided a notice to redeem in full our outstanding 9.00% senior notes due July 2023 (the “9.00% Senior Notes”). On February 18, 2020, we made a payment of $767 million, including the ~~nine~~make-whole provision, to redeem the 9.00% Senior Notes, and in the three months ended ~~September 30, 2019,~~March 31, 2020, we completed cash tender offers to purchase certain notes (the “2019 Tendered Notes”). In the nine months ended September 30, 2019, we made an aggregate cash payment of $522 million to settle the 2019 Tendered Notes and recognized a loss of ~~$18~~$65 million associated with the retirement of debt. See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

~~During~~In the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, we repurchased in the open market ~~$381~~$76 million aggregate principal amount of certain of our debt securities. We made an aggregate cash payment of ~~$395~~$63 million and recognized an aggregate net ~~loss~~gain of ~~$21~~$12 million associated with the retirement of such debt. See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

Settlement—In June 2020, we entered into a settlement and mutual release agreement with a customer, which provided for the final settlement of disputes. In connection with the settlement, among other things, our customer agreed to pay us $185 million in four equal installments through January 15, 2023. See “—Operating Results.”

Impairments—In the ~~three~~six months ended ~~September~~June 30, ~~2019,~~2020, we recognized an aggregate loss of ~~$583~~$556 million primarily associated with the impairment of one ultra-deepwater floater, two harsh environment floaters and three ~~ultra-deepwater~~midwater floaters, along with related assets, which we determined were impaired at the time we classified the assets as held for sale. See “—Operating ~~Results” and “—Liquidity and Capital Resources—Drilling fleet.~~Results.”

~~Fleet expansion~~~~—We hold~~In the three months ended June 30, 2020, we recognized a ~~33.0 percent interest~~loss of $59 million, which had no tax effect, recorded in other, net, associated with the impairment of our investment in Orion Holdings (Cayman) Limited ~~(“Orion”~~(together with its subsidiary, “Orion”), since we determined that the ~~company~~carrying amount of our investment exceeded the estimated fair value. See “—Operating Results.”.

During the three months ended March 31, 2020, we identified indicators that ~~through its wholly owned subsidiary, owns~~ the ~~harsh environment floater~~ ~~Transocean Norge.~~ ~~In August 2019, Orion completed construction~~asset groups in our contract drilling services reporting unit may not be recoverable. As a result of our testing, we determined that the carrying amount of the remaining drilling rig and ~~placed it into service. One~~related assets in our midwater floater asset group was impaired. In the six months ended June 30, 2020, we recognized a loss of ~~our subsidiaries operates~~$31 million associated with the ~~rig under a short-term bareboat charter to complete a six-well drilling contract for one~~impairment of ~~our customers.~~these held and used assets. See “—~~Liquidity and Capital Resources—Drilling fleet.”~~Operating Results”.

~~In September 2019, two of our indirect, wholly owned subsidiaries delivered to Samsung Heavy Industries Co., Ltd. (“SHI”) notices of intent to relinquish their respective interests in~~ ~~Ocean Rig Santorini~~ ~~and~~ ~~Ocean Rig Crete~~, two ultra-deepwater drillships under construction. In October 2019, we agreed with SHI to cancel the construction contracts for the rigs in exchange for the parties terminating their respective obligations and liabilities under the construction contracts and our subsidiaries releasing to SHI their respective interests in the rigs. See “—Liquidity and Capital Resources—Drilling fleet.”Outlook

~~Dispositions~~Drilling market—During the ~~nine months ended September 30,~~latter part of 2019, ~~we completed~~ the ~~sale~~demand for our drilling services steadily increased and contract durations and dayrates substantially improved in all geographic market sectors. This momentum was interrupted, late in the first quarter 2020, by the economic disruption associated with the global COVID-19 pandemic and the significant decline of ~~three ultra-deepwater floaters, one harsh environment floater, two deepwater floaters~~commodity prices spurred both by this pandemic and ~~two midwater floaters, along~~by production disputes among major oil producing countries, driving significant oversupply.

Since initiating efforts to mitigate the spread of COVID-19 many governments have begun to lift some of the restrictions on business and individual movement, and demand for hydrocarbons has begun to improve, although it has still not recovered to pre-pandemic levels. The market also remains in an oversupplied state due to the peak global production that coincided with ~~related assets,~~a significant reduction in consumption. Additionally, the effects of COVID-19 continue to develop and ~~we received $47 million~~change at a rapid pace. For instance, many countries that re-opened their economies beginning in ~~aggregate net cash proceeds. See “—Operating Results” and “—Liquidity and Capital Resources—Drilling fleet.”~~the second quarter of 2020 have subsequently seen significant increases in the number of reported cases of COVID-19, causing governments to reimpose certain restrictions that had previously been lifted.

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Table of Contents

~~Outlook~~As a result, many of our customers have reduced capital expenditures and delayed investment decisions for the remainder of 2020 resulting in several previously sanctioned offshore projects being either delayed or cancelled. These actions have an adverse impact on our near-term market outlook., reversing the positive trends experienced in 2019. It is currently unclear how long these reductions and delays will persist.

~~Drilling market~~~~—Our long-term view~~Longer term, as the negative effects of these global events eventually subside, and oil prices improve and stabilize, we believe the prospects of the offshore drilling floater market ~~is positive,~~will significantly improve, especially for the highest specification vessels. ~~Near term, contracting activity continues to improve, as both fixture durations and dayrates are increasing. In the past five years,~~The structural efficiency gains achieved by the offshore oil and gas industry ~~has achieved structural efficiency gains that~~in the past six years have ~~substantially~~materially improved the economics of offshore development ~~projects. These~~projects, and we believe such efficiency gains ~~have resulted in project break-even oil~~will make these projects attractive again when the commodity prices insufficiently recover from the ~~range of $40 per barrel or below in many operating basins, which compares increasingly favorably to onshore shale prospects, and positively impacting our customers’ investment decisions.~~

Over the past year, opportunities have continued to increase for our drilling services, and we have recently observed some of the highest dayrates in most jurisdictions since the downturn began in 2014. In markets requiring high-specification harsh environment floating drilling rigs, such as the Norwegian and U.K. North Sea and Eastern Canada, the limited supply of these specialized rigs has tightened the market, resulting in the placement of several newbuild rigs on improved terms and conditions. In benign environment offshore drilling markets, the utilization of ultra-deepwater drilling rigs continues to solidify and active supply is approaching full utilization in many regions. Tender activity has increased and demand driven dayrates continue to improve, particularly for the latest generation and highest capability units. We expect this trend to continue into 2020 and beyond.

As of October 17, 2019, our contract backlog was $10.8 billion. The risks of drilling project delays, contract renegotiations and contract terminations and cancellations have diminished as oil prices have improved and stabilized.current levels.

Fleet status—We refer to the availability of our rigs in terms of the uncommitted fleet rate. The uncommitted fleet rate is defined as the number of uncommitted days divided by the total number of rig calendar days in the measurement period, expressed as a percentage. An uncommitted day is defined as a calendar day during which a rig is idle or stacked, is not contracted to a customer and is not committed to a shipyard. The uncommitted fleet rates exclude the effect of priced options. As of ~~October 17, 2019,~~July 15, 2020, the uncommitted fleet rates for the remainder of ~~2019~~2020 and each of the four years in the period ending December 31, ~~2023~~2024 were as follows:


	2019		2020		2021		2022		2023		2020		2021		2022		2023		2024
Uncommitted fleet rate
Ultra-deepwater floaters	38	%	55	%	72	%	83	%	83	%	47	%	67	%	84	%	83	%	83	%
Harsh environment floaters	34	%	47	%	64	%	68	%	83	%	35	%	51	%	63	%	80	%	98	%
Midwater floaters	67	%	67	%	98	%	100	%	100	%

Performance and Other Key Indicators

Contract backlog—Contract backlog is defined as the maximum contractual operating dayrate multiplied by the number of days remaining in the firm contract period, excluding revenues for mobilization, demobilization, contract preparation, other incentive provisions or reimbursement revenues, which are not expected to be significant to our contract drilling revenues. The contract backlog represents the maximum contract drilling revenues that can be earned considering the contractual operating dayrate in effect during the firm contract period. The contract backlog for our fleet was as follows:


	October 17,		July 25,		February 11,		July 15,		April 16,		February 14,
	2019		2019		2019		2020		2020		2020

Contract backlog	(In millions)						(In millions)
Ultra-deepwater floaters	$	7,643	$	7,985	$	8,404	$	6,487	$	6,936	$	7,282
Harsh environment floaters		3,074		3,366		3,716		2,403		2,662		2,836
Midwater floaters		60		71		97		—		—		45
Total contract backlog	$	10,777	$	11,422	$	12,217	$	8,890	$	9,598	$	10,163

We believe our industry-leading contract backlog sets us apart from the competition. Our contract backlog includes only firm commitments, 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 contracted newbuild ~~units~~unit that ~~are~~is currently under construction but excludes amounts related to the conditional agreement we have for our second newbuild unit 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~~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.

~~- 20 -~~

~~Table~~The COVID-19 pandemic and the volatility in oil prices in the first half of ~~Contents~~2020, which have included precipitous drops in oil prices could have significant adverse consequences for the financial condition of our customers. This may result in contract cancellations, early terminations, customers seeking price reductions or more favorable economic terms, a reduced ability to ultimately collect receivables, or entry into lower dayrate contracts or having to idle, stack or retire more of our rigs.

Average daily revenue—Average daily revenue is defined as contract drilling revenues, excluding revenues for contract terminations, ~~and~~ reimbursements and contract intangible ~~revenues,~~amortization, earned per operating day. An operating day is defined as a calendar day during which a rig is contracted to earn a dayrate during the firm contract period after commencement of operations. The average daily revenue for our fleet was as follows:


	Three months ended						Three months ended
	September 30,		June 30		September 30,		June 30,		March 31,		June 30,
	2019		2019		2018		2020		2020		2019
Average daily revenue
Ultra-deepwater floaters	$	339,400	$	335,400	$	340,500	$	296,500	$	332,600	$	335,400
Harsh environment floaters	$	298,300	$	301,700	$	309,000	$	331,900	$	303,100	$	301,700
Deepwater floaters	$	—	$	—	$	195,700
Midwater floaters	$	106,200	$	163,700	$	98,500	$	99,400	$	112,600	$	163,700
High-specification jackups	$	—	$	—	$	145,700
Total fleet average daily revenue	$	314,500	$	314,900	$	295,000	$	307,800	$	314,900	$	314,900

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Our average daily revenue fluctuates relative to market conditions and our revenue efficiency. The average daily revenue may ~~also~~ be affected by revenues for lump sum bonuses or demobilization fees received from our customers. Our total fleet average daily revenue is also affected by the mix of rig classes being operated, as deepwater floaters, midwater floaters and high-specification jackups are typically contracted at lower dayrates compared to ultra-deepwater floaters and harsh environment floaters. We no longer operate deepwater floaters, midwater floaters or high-specification jackups. We include newbuilds in the calculation when the rigs commence operations upon acceptance by the customer. We remove rigs from the calculation upon disposal or classification as held for sale, unless we continue to operate rigs subsequent to sale, in which case we remove the rigs at the time of completion or novation of the contract.

Revenue efficiency—Revenue efficiency is defined as actual contract drilling revenues, excluding revenues for contract terminations and reimbursements, for the measurement period divided by the maximum revenue calculated for the measurement period, expressed as a percentage. Maximum revenue is defined as the greatest amount of contract drilling revenues, excluding revenues for contract terminations and reimbursements, the drilling unit could earn for the measurement period, excluding amounts related to incentive provisions. The revenue efficiency rates for our fleet were as follows:

Three months ended

September 30,

June 30

September 30,


2019

2019

2018

Revenue efficiency

Ultra-deepwater floaters

98
%

98
%

95
%

Harsh environment floaters

96
%

95
%

95
%

Deepwater floaters

—
%

—
%

96
%

Midwater floaters

79
%

130
%

98
%

High-specification jackups

—
%

—
%

99
%

Total fleet average revenue efficiency

97
%

98
%

95
%


	Three months ended
	June 30,		March 31,		June 30,
	2020		2020		2019
Revenue efficiency
Ultra-deepwater floaters	98	%	97	%	98	%
Harsh environment floaters	97	%	89	%	95	%
Midwater floaters	79	%	87	%	130	%
Total fleet average revenue efficiency	97	%	94	%	98	%

Revenue efficiency measures our ability to ultimately convert our contractual opportunities into revenues. Our revenue efficiency rate varies due to revenues earned under alternative contractual dayrates, such as a ~~waiting-on-weather~~waiting on weather rate, repair rate, standby rate, force majeure rate or zero rate, that may apply under certain circumstances. Our revenue efficiency rate is also affected by incentive performance bonuses or penalties. We include newbuilds in the calculation when the rigs commence operations upon acceptance by the customer. We exclude rigs that are not operating under contract, such as those that are stacked.

Rig utilization—Rig utilization is defined as the total number of operating days divided by the total number of rig calendar days in the measurement period, expressed as a percentage. The rig utilization rates for our fleet were as follows:


	Three months ended						Three months ended
	September 30,		June 30		September 30,		June 30,		March 31,		June 30,
	2019		2019		2018		2020		2020		2019
Rig utilization
Ultra-deepwater floaters	51	%	50	%	56	%	61	%	61	%	50	%
Harsh environment floaters	79	%	76	%	83	%	80	%	63	%	76	%
Deepwater floaters	—	%	—	%	100	%
Midwater floaters	33	%	39	%	43	%	25	%	39	%	39	%
High-specification jackups	—	%	—	%	100	%
Total fleet average rig utilization	58	%	56	%	65	%	66	%	60	%	56	%

Our rig utilization rate declines as a result of idle and stacked rigs and during shipyard and mobilization periods 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. We remove rigs from the calculation upon disposal or classification as held for sale. Accordingly, our rig utilization can increase when idle or stacked units are removed from our drilling fleet.

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Operating Results

Three months ended ~~September~~June 30, ~~2019~~2020 compared to the three months ended ~~September~~June 30, ~~2018~~2019

The following is an analysis of our operating results. See “—Performance and Other Key Indicators” for definitions of operating days, average daily revenue, revenue efficiency and rig utilization.


	Three months ended September 30,										Three months ended June 30,
	2019			2018			Change		% Change		2020			2019			Change		% Change

	(In millions, except day amounts and percentages)										(In millions, except day amounts and percentages)

Operating days		2,489			2,592			(103)	(4)	%		2,401			2,411			(10)	nm
Average daily revenue	$	314,500		$	295,000		$	19,500	7	%	$	307,800		$	314,900		$	(7,100)	(2)	%
Revenue efficiency		97	%		95	%						97	%		98	%
Rig utilization		58	%		65	%						66	%		56	%

Contract drilling revenues	$	784		$	816		$	(32)	(4)	%	$	930		$	758		$	172	23	%

Operating and maintenance expense		(547)			(447)			(100)	(22)	%		(525)			(510)			(15)	(3)	%
Depreciation and amortization expense		(212)			(201)			(11)	(5)	%		(196)			(219)			23	11	%
General and administrative expense		(45)			(35)			(10)	(29)	%		(45)			(45)			—	nm
Loss on impairment		(583)			(432)			(151)	(35)	%		(429)			(1)			(428)	nm
Loss on disposal of assets, net		(4)			(6)			2	33	%
Gain (loss) on disposal of assets, net												1			(10)			11	nm
Operating loss		(607)			(305)			(302)	(99)	%		(264)			(27)			(237)	nm

Other income (expense), net
Interest income		11			11			—	nm			4			12			(8)	(67)	%
Interest expense, net of amounts capitalized		(166)			(160)			(6)	(4)	%		(153)			(168)			15	9	%
Loss on retirement of debt		(12)			(1)			(11)	nm
Gain (loss) on retirement of debt												4			(9)			13	nm
Other, net		3			16			(13)	81	%		(56)			23			(79)	nm
Loss before income tax expense		(771)			(439)			(332)	(76)	%		(465)			(169)			(296)	nm
Income tax (expense) benefit		(54)			30			(84)	nm
Income tax expense												(32)			(37)			5	14	%
Net loss	$	(825)		$	(409)		$	(416)	nm		$	(497)		$	(206)		$	(291)	nm

“nm” means not meaningful.

Contract drilling revenues—Contract drilling revenues ~~decreased~~increased for the three months ended ~~September~~June 30, ~~2019,~~2020, compared to the three months ended ~~September~~June 30, ~~2018,~~2019, primarily due to the following: (a) $177 million resulting from the settlement of disputes in the three months ended June 30, 2020, (b) approximately ~~$60~~$35 million resulting from the reactivations of two ultra-deepwater floaters in Brazil, (c) approximately $25 million resulting from a harsh environment floater that we placed into service in August 2019 and (d) approximately $21 million resulting from the early termination of a contract for the convenience of a customer. These increases were partially offset by the following decreases: (a) approximately $70 million resulting from lower activity and (b) approximately $20 million resulting from rigs sold or classified as held for sale, (b) approximately $50 million resulting from lower activity and more shipyard days and (c) $37 million resulting from contract early terminations and cancellations recognized in the three months ended September 30, 2018. These decreases were partially offset by the following increases: (a) approximately $55 million resulting from operations acquired in the Ocean Rig acquisition, (b) approximately $30 million resulting from a rig reactivated in the nine months ended September 30, 2019, (c) approximately $20 million resulting from the newbuild harsh environment floater that commenced operations in August 2019 and (d) approximately $10 million resulting from higher revenue efficiency.sale.

Costs and expenses—Operating and maintenance costs and expenses increased for the three months ended ~~September~~June 30, ~~2019,~~2020, compared to the three months ended ~~September~~June 30, ~~2018,~~2019, primarily due to the following: (a) approximately ~~$80 million resulting from operations acquired in the Ocean Rig acquisition, including the reactivation of two rigs, (b) approximately~~ $30 million resulting from ~~higher operating~~personnel and related costs ~~primarily shipyard activities~~associated with the COVID-19 pandemic, (b) $30 million resulting from litigation and ~~the reactivation of a rig and~~settlement costs, (c) approximately ~~$20~~$25 million resulting from the ~~newbuild~~operations of the harsh environment floater that ~~commenced operations~~we placed into service in August ~~2019.~~2019, (d) approximately $10 million resulting from offshore and onshore severance costs and (e) approximately $10 million resulting from the reactivations of two ultra-deepwater floaters in Brazil. These increases were partially offset by ~~a decrease of~~the following decreases: (a) approximately ~~$30~~$45 million resulting from reduced shipyard costs and delayed in-service maintenance costs, (b) approximately $25 million resulting from rigs now stacked or idle and (c) approximately $20 million resulting from rigs sold or classified as held for sale.

Depreciation and amortization expense ~~increased~~decreased for the three months ended ~~September~~June 30, ~~2019,~~2020, compared to the three months ended ~~September~~June 30, ~~2018,~~2019, primarily due to ~~an increase of approximately $19 million resulting from the rigs acquired in the Ocean Rig acquisition, partially offset by a decrease of approximately $7~~$20 million resulting from rigs sold or classified as held for ~~sale.~~

~~General and administrative costs and expenses increased for the three months ended September~~sale subsequent to June 30, 2019, compared to the three months ended September 30, 2018, primarily due to the following: (a) approximately $6 million resulting from increased personnel costs, (b) approximately $4 million resulting from increased professional fees, (c) approximately $3 million resulting from increased rent expense, partially offset by (d) $4 million of costs related to the Ocean Rig acquisition in the three months ended September 30, 2018.2019.

Loss on impairment of assets—~~Loss~~In the three months ended June 30, 2020, we recognized a loss on the impairment of assets, ~~resulted primarily from the impairment~~including an aggregate net loss of ~~certain~~$419 million associated with assets that we determined were impaired at the time we classified ~~the assets~~them as held for sale.

Other income and expense—Interest expense, net of amounts capitalized, ~~increased~~decreased in the three months ended ~~September~~June 30, ~~2019,~~2020, compared to the three months ended ~~September~~June 30, ~~2018,~~2019, primarily due to a decrease of $34 million resulting from debt retired or repaid, including the full redemption of the 9.00% Senior Notes in February 2020, partially offset by an increase of ~~approximately $33~~$19 million resulting from debt issued, ~~subsequent to~~including the 8.00% Senior Notes in January 2020 and the 5.375% senior secured notes due May 2023 (the “5.375% Senior Secured Notes”) in May 2019.

In the three months ended June 30, ~~2018, partially offset by a decrease~~2020, we recognized an aggregate net gain of ~~approximately $25~~$4 million ~~resulting from~~associated with the retirement of ~~debt.~~$21 million aggregate principal amount of our debt securities repurchased in the open market. In the three months ended June 30, 2019,

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~~In the three months ended September 30, 2019,~~ we recognized aan aggregate net loss onof $9 million resulting from the retirement of ~~$251~~$130 million aggregate principal amount of our debt securities repurchased in the open market.

Other ~~income,~~expense, net, ~~decreased~~increased in the three months ended ~~September~~June 30, ~~2019,~~2020, compared to the three months ended ~~September~~June 30, ~~2018,~~2019, primarily due to the following: (a) ~~reduced income~~a loss of ~~$12~~$59 million ~~resulting from~~associated with the impairment of our ~~dual-activity patent and~~equity-method investment in Orion, (b) annet increased loss of $3$10 million resulting from currency exchange ~~rate changes.~~rates and (c) a gain of $10 million recognized in the prior-year period resulting from the bargain purchase of Ocean Rig UDW Inc. (“Ocean Rig”), completed in the year ended December 31, 2018.

Income tax expense—In the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, our effective tax rate was ~~(6.9)~~(6.8) percent and ~~6.7~~(21.9) percent, respectively, based on ~~income or~~ loss before income tax expense. In the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, the effect of ~~the~~ various discrete period tax items was a net tax ~~benefit~~expense of ~~$10~~$11 million and a net tax ~~expense~~benefit of $1$5 million, respectively. In the three months ended ~~September~~June 30, 2020, such discrete items included the revenues recognized for the settlement of disputes, the loss on impairment of investment in an unconsolidated affiliate, certain return to provision adjustments, withholding tax accruals, gains and losses on currency exchange rates and changes to valuation allowances. In the three months ended June 30, 2019, such discrete items ~~were related to various items, including~~included settlements ~~and expirations~~ of various uncertain tax positions, partially offset by changes in the valuation allowance related to deferred tax ~~assets.~~assets and adjustments to our deferred taxes for operating structural changes made in the U.S. In the three months ended ~~September~~June 30, 2018, such discrete items were primarily related to a decrease in the U.S. transition tax on non-U.S. earnings, tax expense for unrecognized tax benefits associated with tax position taken in prior years2020 and ~~return to provision adjustments. In the three months ended September 30,~~ 2019, ~~and 2018,~~ our effective tax rate, excluding discrete items, was ~~(37.5)~~(15.0) percent and ~~2,757.6~~(25.4) percent, respectively, based on ~~income or~~ loss before income tax expense. In the three months ended September 30, 2019 compared to the three months ended September 30, 2018, our effective tax rate, excluding discrete items, decreased primarily due to changes in the relative blend of income from operations in certain jurisdictions and the loss before income taxes.

Due ~~to factors related~~ to our operating activities and organizational structure, 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 effective tax rate calculation for the three months ended ~~September~~June 30, ~~2019,~~2020, a significant portion of our income tax expense was generated in countries in which income taxes are imposed on ~~deemed, rather than actual, profits,~~gross revenues, with the most significant of these countries being Angola and India. Conversely, the countries in which we incurred the most significant income taxes during this period that were based on income before income tax include Brazil, Canada, the U.S., Switzerland, ~~Norway,~~and the U.K. ~~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 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.

~~Nine~~Six months ended ~~September~~June 30, ~~2019~~2020 compared to the ~~nine~~six months ended ~~September~~June 30, ~~2018~~2019


	Nine months ended September 30,										Six months ended June 30,
	2019			2018			Change		% Change		2020			2019			Change		% Change

	(In millions, except day amounts and percentages)										(In millions, except day amounts and percentages)

Operating days		7,350			7,203			147	2	%		4,820			4,861			(41)	(1)	%
Average daily revenue	$	312,000		$	297,300		$	14,700	5	%	$	311,300		$	310,700		$	600	nm
Revenue efficiency		98	%		95	%						96	%		98	%
Rig utilization		57	%		58	%						63	%		56	%

Contract drilling revenues	$	2,296		$	2,270		$	26	1	%	$	1,689		$	1,512		$	177	12	%

Operating and maintenance expense		(1,565)			(1,302)			(263)	(20)	%		(1,065)			(1,018)			(47)	(5)	%
Depreciation and amortization expense		(648)			(614)			(34)	(6)	%		(402)			(436)			34	8	%
General and administrative expense		(139)			(134)			(5)	(4)	%		(88)			(94)			6	6	%
Loss on impairment		(584)			(1,446)			862	60	%		(597)			(1)			(596)	nm
Loss on disposal of assets, net		(7)			—			(7)	nm			—			(3)			3	nm
Operating loss		(647)			(1,226)			579	47	%		(463)			(40)			(423)	nm

Other income (expense), net
Interest income		33			36			(3)	(8)	%		13			22			(9)	(41)	%
Interest expense, net of amounts capitalized		(500)			(455)			(45)	(10)	%		(313)			(334)			21	6	%
Loss on retirement of debt		(39)			(3)			(36)	nm			(53)			(27)			(26)	(96)	%
Other, net		34			6			28	nm			(44)			31			(75)	nm
Loss before income tax expense		(1,119)			(1,642)			523	32	%		(860)			(348)			(512)	nm
Income tax expense		(83)			(118)			35	30	%		(28)			(29)			1	3	%
Net loss	$	(1,202)		$	(1,760)		$	558	32	%	$	(888)		$	(377)		$	(511)	nm

“nm” means not meaningful.

Contract drilling revenues—Contract drilling revenues increased for the six months ended June 30, 2020, compared to the six months ended June 30, 2019, primarily due to the following: (a) $177 million resulting from the settlement of disputes in the six months ended June 30, 2020, (b) approximately $65 million resulting from the reactivations of two ultra-deepwater floaters in Brazil, (c) approximately $40 million resulting from the operations of the harsh environment floater that we placed into service in August 2019, (d) approximately $35 million resulting from increased dayrates and (e) approximately $21 million resulting from the early termination of a contract for the

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~~Contract drilling revenues~~—Contract drilling revenues increased for the nine months ended September 30, 2019, compared to the nine months ended September 30, 2018, primarily due to the following: (a) approximately $220 million resulting from operations acquired in the Ocean Rig and Songa acquisitions, (b) approximately $65 million resulting from the reactivationconvenience of two rigs, (c) approximately $55 million resulting from higher revenue efficiency, (d) approximately $40 million resulting from the commencement of operations of our newbuild ultra-deepwater drillship and a ~~harsh environment floater and (e) approximately $10 million resulting from increased revenues associated with customer reimbursables.~~customer. These increases were partially offset by the following decreases: (a) approximately ~~$160~~$115 million resulting from lower revenues on rigs stacked or idle, (b) approximately $35 million resulting from lower revenue efficiency, (c) approximately $30 million resulting from rigs sold or classified as held for sale, (b) $112 million resulting from contract early terminations and cancellations recognized in the nine months ended September 30, 2018, (c) approximately $70 million resulting from lower dayrates and (d) approximately $20 million resulting from stacked or idle rigs.sale.

Costs and expenses—Operating and maintenance costs and expenses increased for the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, compared to the ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, primarily due to the following: (a) approximately ~~$200 million resulting from operations acquired in the Ocean Rig and Songa acquisitions, including two rig reactivations, (b) approximately~~ $55 million resulting from ~~increased operating costs primarily due to shipyard activity, (c)~~the harsh environment floater that we placed into service in August 2019, (b) approximately ~~$50~~$40 million resulting from the ~~reactivation~~reactivations of two ~~rigs, (d)~~ultra-deepwater floaters in Brazil, (c) approximately $20 million resulting from higher costs associated with the commencement of operations of our newbuild ultra-deepwater drillship and a harsh environment floater and (e) approximately $10 million resulting from increased costs associated with customer reimbursables. These increases were partially offset by a decrease of approximately $70 million resulting from rigs sold or classified as held for sale.

Depreciation and amortization expense increased for the nine months ended September 30, 2019, compared to the nine months ended September 30, 2018, primarily due to approximately $65 million resulting from the rigs acquired in the Ocean Rig and Songa acquisitions, partially offset by approximately $33 million resulting from rigs sold or classified as held for sale.

General and administrative costs and expenses increased for the nine months ended September 30, 2019, compared to the nine months ended September 30, 2018, primarily due to the following: (a) approximately $7 million resulting from increased legal and professional fees, (b) approximately $7$30 million resulting from personnel and ~~other~~related costs associated with the COVID-19 pandemic, (d) $30 million related to ~~Ocean Rig in the current-year period~~settlements and ~~(c)~~litigation and (e) approximately $5$15 million resulting from ~~increased rent expense.~~offshore and onshore severance costs. These increases were partially offset by the following decreases: (a) approximately ~~$11~~$75 million ~~of acquisition~~resulting from reduced shipyard and delayed in-service maintenance costs, ~~related~~(b) approximately $35 million resulting from rigs sold or classified as held for sale and (c) approximately $15 million resulting from rigs now stacked or idle.

Depreciation and amortization expense decreased for the six months ended June 30, 2020, compared to the ~~Songa~~six months ended June 30, 2019, primarily due to $31 million resulting from rigs sold or classified as held for sale subsequent to June 30, 2019.

General and ~~Ocean Rig acquisitions~~administrative costs and expenses decreased for the six months ended June 30, 2020, compared to the six months ended June 30, 2019, primarily due to the following: (a) $5 million resulting from costs recognized in the prior-year period related to the integration of Ocean Rig and (b) ~~approximately~~$5 million resulting from reduced legal and professional fees, partially offset by (c) $4 million resulting from ~~reduced personnel~~increased costs ~~primarily~~ related to ~~the early retirement of certain personnel in the prior-year period.~~our cybersecurity program.

Loss on impairment of assets—In the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, we recognized ~~losses primarily related to~~a loss on the impairment of assets, including an aggregate ~~impairment~~net loss of ~~$578~~$556 million associated with ~~certain~~ assets that we determined were impaired at the time we classified the assets as held for sale. In the nine months ended September 30, 2018, we recognized losses related to the following: (a) $981 million associated with the impairment of certain assets upon classificationthem as held for sale, ~~and (b) $462~~a loss of $31 million associated with the impairment of our ~~goodwill.~~midwater floater asset group and a loss of $10 million associated with the impairment of other assets.

Other income and expense—Interest expense, net of amounts capitalized, ~~increased~~decreased in the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, compared to the ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, primarily due to ~~approximately $123~~a decrease of $61 million resulting from the debt retired or repaid, including the full redemption of the 9.00% Senior Notes in February 2020, partially offset by an increase of $42 million resulting from debt issued, ~~subsequent to~~including the 8.00% Senior Notes in January ~~1, 2018,~~2020, the 5.375% Senior Secured Notes in May 2019 and the 6.875% senior secured notes due February 2027 (the “6.875% Senior Secured Notes”) in February 2019.

In the six months ended June 30, 2020, we recognized a loss of $65 million associated with the full redemption of the 9.00% Senior Notes, partially offset by ~~a decrease~~an aggregate net gain of ~~approximately $72~~$12 million resulting from the retirement of ~~debt as a result of scheduled maturities, the purchase of the 2019 Tendered Notes and our open market repurchases.~~

In the nine months ended September 30, 2019, we recognized a net loss on retirement of debt as follows: (a) $18 million resulting from retirement of the validly tendered 2019 Tendered Notes and (b) $21 million resulting from repurchases of $381$76 million aggregate principal amount of our debt ~~securities.~~securities repurchased in the open market. In the six months ended June 30, 2019, we recognized a loss of $18 million associated with the retirement of notes validly tendered in the tender offers made in the prior-year period (the “2019 Tendered Notes”) and an aggregate net loss of $9 million resulting from the retirement of $130 million aggregate principal amount of our debt securities repurchased in the open market.

Other ~~income,~~expense, net, increased in the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, compared to the ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, primarily ~~related~~due to the following: (a) ~~increased income of $28 million resulting from currency exchange rate changes, including~~ a loss of ~~$12~~$59 million ~~recognized~~associated with the impairment of our equity-method investment in Orion in the ~~prior-year period related to undesignated currency swaps acquired in the Songa acquisition~~six months ended June 30, 2020 and (b) ~~an incremental~~a gain of $11 million recognized in the ~~current-year~~prior-year period resulting from the bargain purchase of Ocean ~~Rig. Partially offsetting these increases was (a) reduced income of $12 million resulting from our dual-activity patent and (b) a gain of $4 million recognized~~Rig, completed in the ~~prior-year period resulting from undesignated interest rate swaps acquired in the Songa acquisition and terminated subsequent to September 30,~~year ended December 31, 2018.

Income tax expense—In the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, our effective tax rate was ~~(7.4)~~(3.2) percent and ~~(7.2)~~(8.3) percent, respectively, based on ~~income or~~ loss before income tax expense. In the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, the effect of various discrete period tax items was a net tax benefit of ~~$40~~$9 million and ~~a net tax expense of $91~~$30 million, respectively. In the ~~nine~~six months ended ~~September~~June 30, 2020, such discrete items included the revenues recognized for the settlement of disputes, the loss on impairment of investment in an unconsolidated affiliate, the carryback of net operating losses in the U.S. as a result of the Coronavirus Aid, Relief, and Economic Security Act which included the release of valuation allowances previously recorded, as well as settlements and expirations of various uncertain tax positions, gains and losses on currency exchange rates and changes to valuation allowances. In the six months ended June 30, 2019, such discrete items ~~were related to various items, including~~included settlements and ~~expirations~~reversals of various uncertain tax positions and adjustments to our deferred taxes for operating structural changes made in the U.S. In the ~~nine~~six months ended ~~September~~June 30, ~~2018, such discrete items were primarily related to the U.S. transition tax on non-U.S. earnings. In the nine months ended September 30,~~2020 and 2019, ~~and 2018,~~ our effective tax rate, excluding discrete items, was ~~(24.7)~~(12.0) percent and ~~(15.6)~~(18.0) percent, respectively, based on ~~income or~~ loss before income tax expense. Our effective tax rate in the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 compared to the ~~nine~~six months ended ~~September~~June 30, ~~2018, decreased~~2019, increased primarily due to the adoption of a new operating structure, which reduces our exposure to the U.S. base erosion and anti-abuse tax and other cash taxes in the U.S. in the current and future years. To a lesser extent, our effective tax rate decreased due to changes in the relative blend of income from operations in certain jurisdictions.

~~- 24 -~~

~~Table of Contents~~

For the nine months ended September 30, 2019 and 2018, to calculate our annual estimated effective income tax rate in accordance with accounting standards for the provision of income taxes, we excluded certain operating losses in taxable jurisdictions for which we do not expect to realize a tax benefit. For the nine months ended September 30, 2019 and 2018, our annual estimated effective income tax rate would have been (27.5) percent and (32.8) percent, respectively, if we had included all jurisdictions in our calculations.

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Table of Contents

on income before income tax include Brazil, Canada, the U.S., Switzerland, ~~Norway,~~and the U.K. ~~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 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.

Liquidity and Capital Resources

Sources and uses of cash

At ~~September~~June 30, ~~2019,~~2020, we had ~~$1.9~~$1.5 billion in unrestricted cash and cash equivalents and ~~$551~~$437 million in restricted cash and cash equivalents. In the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, our primary sources of cash were ~~as follows: (1)~~(a) net cash proceeds from the issuance of debt ~~(2)~~and (b) net cash provided by our operating ~~activities and (3) proceeds from maturities of restricted investments.~~activities. Our primary uses of cash were ~~as follows:~~ (a) repayments of debt and (b) capital ~~expenditures and (c) investments in unconsolidated affiliates.~~expenditures.


	Nine months ended						Six months ended
	September 30,						June 30,
	2019		2018		Change		2020		2019		Change

	(In millions)						(In millions)
Cash flows from operating activities
Net loss	$	(1,202)	$	(1,760)	$	558	$	(888)	$	(377)	$	(511)
Non-cash items, net		1,613		2,239		(626)		1,289		698		591
Changes in operating assets and liabilities, net		(218)		(159)		(59)		(362)		(219)		(143)
	$	193	$	320	$	(127)	$	39	$	102	$	(63)

Net cash provided by operating activities decreased primarily due to ~~a modest increase~~cash payments of $125 million released from restricted cash accounts to satisfy our remaining obligations under the Plaintiff Steering Committee settlement agreement (the “PSC Settlement Agreement”) in ~~operating days, partially offset by increased operating costs resulting from reactivations.~~June 2020.


	Nine months ended						Six months ended
	September 30,						June 30,
	2019		2018		Change		2020		2019		Change

	(In millions)						(In millions)
Cash flows from investing activities
Capital expenditures	$	(259)	$	(140)	$	(119)	$	(153)	$	(138)	$	(15)
Proceeds from disposal of assets, net		52		37		15		3		40		(37)
Unrestricted and restricted cash acquired in business combination		—		131		(131)
Investments in unconsolidated affiliates		(77)		(107)		30		(6)		(62)		56
Proceeds from unrestricted and restricted short-term investments, net of deposits		123		450		(327)
Proceeds from unrestricted and restricted short-term investments								—		123		(123)
Other, net		3		—		3		—		3		(3)
	$	(158)	$	371	$	(529)	$	(156)	$	(34)	$	(122)

Net cash used in investing activities increased primarily due to (a) ~~reduced~~ proceeds from maturities of ~~unrestricted and restricted~~short-term investments ~~net of deposits, (b) unrestricted and restricted cash acquired~~ in the ~~Songa acquisition in the nine~~six months ended ~~September~~June 30, ~~2018~~2019 with no comparable activity in the ~~current-year period,~~six months ended June 30, 2020, (b) reduced net proceeds from disposal of assets and (c) increased capital expenditures, partially offset by (d) reduced investments in unconsolidated ~~affiliates and (e) increased net proceeds from disposal of assets.~~affiliates.

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	Nine months ended						Six months ended
	September 30,						June 30,
	2019		2018		Change		2020		2019		Change

	(In millions)						(In millions)
Cash flows from financing activities
Proceeds from issuance of debt, net of discount and issue costs	$	1,056	$	1,319	$	(263)
Proceeds from issuance of debt, net of discounts and issue costs							$	743	$	1,056	$	(313)
Repayments of debt		(1,189)		(2,015)		826		(1,009)		(834)		(175)
Proceeds from investments restricted for financing activities		—		26		(26)
Payments to terminate derivative instruments		—		(92)		92
Other, net		(34)		(29)		(5)		(18)		(26)		8
	$	(167)	$	(791)	$	624	$	(284)	$	196	$	(480)

Net cash used in financing activities ~~decreased~~increased primarily due to (a) decreased cash used to repay debt and (b) cash paid to terminate certain derivative instruments assumed in the Songa acquisition in the nine months ended September 30, 2018 with no comparable activity in the current-year period, partially offset by (c) decreasedreduced net cash proceeds from the issuance of the ~~6.875%~~8.00% Senior ~~Secured Notes and the 5.375% Senior Secured~~ Notes in the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 compared to the net cash proceeds from the issuance of the ~~5.875%~~5.375% Senior Secured Notes and the ~~6.125%~~6.875% Senior Secured Notes in the prior-year period and (b) increased cash used to repay debt related to the full redemption of the 9.00% Senior Notes and open market repurchases in the six months ended June 30, 2020 compared to the cash used to repay debt related to the 2019 Tendered Notes and open market repurchases in the prior-year period.

Sources and uses of liquidity

Overview—We expect to use existing unrestricted cash balances, internally generated cash flows, borrowings under the Secured Credit Facility, ~~as defined below,~~ proceeds from the disposal of assets or proceeds from the issuance of additional debt to fulfill anticipated obligations, which may include capital expenditures, working capital and other operational requirements, scheduled debt maturities or other payments. We may also consider establishing additional financing arrangements with banks or other capital providers. Additionally, at our 2020 annual general meeting, our shareholders approved a proposal to amend our Articles of Association to increase the total number of shares that may be issued using our authorized share capital to a maximum of approximately 185.0 million shares, representing approximately 30 percent of our issued shares as of March 10, 2020. Subject to market conditions and other factors, we may also be required to provide collateral for

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future financing arrangements. In each case subject to then existing market conditions and to our ~~then~~ expected liquidity needs, among other factors, we may continue to use a portion of our cash on hand, 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, or through debt redemptions or tender offers.

The effects of the COVID-19 pandemic and the volatility and declines in oil prices in the first half of 2020 could have significant adverse consequences for general economic, financial and business conditions, as well as for our business and financial position and the business and financial position of our customers and suppliers and may, among other things, impact our ability to generate cash flows from operations, access the capital markets on acceptable terms or at all, and affect our future need or ability to borrow under our Secured Credit Facility. In addition to our potential sources of funding, the effects of such global events may impact our liquidity or need to alter our allocation or sources of capital, implement further cost reduction measures and change our financial strategy. Although the COVID-19 pandemic and the volatility and declines in oil prices in the first half of 2020 could have a broad range of effects on our sources and uses of liquidity, the ultimate effect thereon, if any, will depend on future developments, which cannot be predicted at this time.

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 ratings, industry conditions, general economic conditions, market conditions and market perceptions of us and our industry. The rating of our non-credit enhanced senior unsecured long-term debt (“Debt Rating”) is below investment grade. Such Debt Rating has caused us to experience increased fees and interest rates under agreements governing certain of our senior notes. Further downgrades may affect or limit our ability to access debt markets in the future. 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. An economic downturn like the one we are currently experiencing 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.

Our internally generated cash flows are directly related to our business and the market sectors in which we operate. We have generated positive cash flows from operating activities over recent years and, ~~while~~although we cannot provide assurances, we currently expect that such cash flows will continue to be positive over the next year. However, among other factors, if the drilling market deteriorates, or if we experience poor ~~operational~~operating results, or if we incur expenses to, for example, reactivate, stack or otherwise assure the marketability of our fleet, cash flows from operations may be reduced or negative.

Secured Credit Facility—~~In June 2018, we entered into~~We have a ~~bank credit agreement, which established a $1.0~~$1.3 billion secured revolving credit facility, established under a bank credit agreement, as amended most recently in December 2019 (the “Secured Credit Facility”), ~~and in May, July and September 2019, we amended the terms of the Secured Credit Facility~~which is scheduled to ~~among other changes, increase the borrowing capacity to $1.3 billion and add to and clarify the lender parties and their respective commitments under the facility.~~expire on June 22, 2023. The Secured Credit Facility is scheduled to expire on the earlier of (i) June 22, 2023 or (ii) if greater than $300 million aggregate principal amount of our 9.00% senior notes due July 2023 remain outstanding in April 2023, such date.guaranteed by Transocean Ltd. and certain subsidiaries. The Secured Credit Facility is secured by, among other things, a lien on the ultra-deepwater floaters Deepwater Asgard, Deepwater Invictus,, Deepwater Orion, Deepwater Skyros,, Dhirubhai Deepwater KG2 and Discoverer Inspiration and the harsh environment floaters Transocean Barentsand Transocean Spitsbergen. The Secured Credit Facility contains covenants that, among other things, include maintenance of certain guarantee and collateral coverage ratios, a maximum debt to capitalization ratio of 0.60 to 1.00 and minimum liquidity of $500 million. The Secured Credit Facility also restricts the ability of Transocean Ltd. and certain of our subsidiaries to, among other things, merge, consolidate or otherwise make changes to the corporate structure, incur liens, incur additional indebtedness, enter into transactions with affiliates and pay dividends and other distributions. In order to borrow under the Secured Credit Facility, we must, at the time of the borrowing request, not be in default under the ~~bank credit agreement~~Secured Credit Facility and make certain representations and warranties, including with respect to compliance with laws and solvency, to the lenders. Repayment of borrowings under the Secured Credit Facility are subject to acceleration upon the occurrence of an event of default. WeUnder the agreements governing certain of our debt and finance lease, 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. A default under our public debt indentures, the agreements governing our senior secured notes, our finance lease contract or any other debt owed to unaffiliated entities that exceeds $125 million could trigger a default under the Secured Credit Facility and, if not waived by the lenders, could cause us to lose access to the Secured Credit Facility. At ~~October 22, 2019,~~July 23, 2020, we had no borrowings outstanding, ~~$15~~$21 million of letters of credit issued, and we had $1.3 billion of available borrowing capacity under the Secured Credit Facility.

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Debt issuances—On January 17, 2020, we issued $750 million aggregate principal amount of our 8.00% Senior Notes, and we received aggregate cash proceeds of $743 million, net of issue costs. We may redeem all or a portion of the 8.00% Senior Notes on or prior to February 1, 2023 at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision, and subsequently, at specified redemption prices

On February 1, 2019, we issued $550 million aggregate principal amount of 6.875% Senior Secured Notes, and we received aggregate cash proceeds of $539 million, net of discount and issue costs. The indenture that governs the 6.875% Senior Secured Notes contains covenants that, among other things, limit the ability of our subsidiaries that own or operate the collateral rig Deepwater Poseidon to declare or pay dividends to their affiliates. We may redeem all or a portion of the 6.875% Senior Secured Notes on or prior to February 1, 2022 at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision, and subsequently, at specified redemption prices.

On May 24, 2019, we issued $525 million aggregate principal amount of 5.375% Senior Secured Notes, and we received aggregate cash proceeds of $517 million, net of discount and issue costs. The indenture that governs the 5.375% Senior Secured Notes contains covenants that, among other things, limit the ability of our subsidiaries that own or operate the collateral rigs Transocean Endurance and

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Transocean Equinox to declare or pay dividends to their affiliates. We may redeem all or a portion of the 5.375% Senior Secured Notes on or prior to May 15, 2021 at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision, and subsequently, at specified redemption prices.

Early debt retirement—On January 17, 2020, we provided a notice to redeem in full our outstanding 9.00% Senior Notes and on February 18, 2020, we made a cash payment of $767 million, including the make-whole provision, to redeem the notes. In ~~July 2018,~~the six months ended June 30, 2020, we ~~issued $750~~repurchased in the open market $76 million aggregate principal amount of the 5.875% senior secured notes due January 2024 (the “5.875% Senior Secured Notes”) and $600 million aggregate principal amount of 6.125% senior secured notes due August 2025 (the “6.125% Senior Secured Notes” and together with the 5.875% Senior Secured Notes, the “2018 Senior Secured Notes”), and we received aggregate cash proceeds of $733 million and $586 million, respectively, net of discount and issue costs. The indentures that govern the 2018 Senior Secured Notes contain covenants that, among other things, limit the ability of our ~~subsidiaries that own or operate the collateral rigs~~ ~~Transocean Enabler~~, ~~Transocean Encourage~~ ~~and~~ ~~Deepwater Pontus~~ to declare or pay dividends to their affiliates. We may redeem all or a portion of the 2018 Senior Secured Notes at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision. We will be required to redeem the notes at a price equal to 100 percent of the aggregate principal amount without a make-whole provision, upon the occurrence of certain events related to the collateral rigs and the related drilling contracts.

On October 25, 2018, we issued $750 million aggregate principal amount of 7.25% senior notes due November 2025 (the “7.25% Senior Notes”), and we received aggregate cash proceeds of $735 million, net of issue costs. We may redeem all or a portion of the 7.25% Senior Notes at any time prior to November 1, 2021 at a price equal to 100 percent of the aggregate principal amount plus a make-whole provision, and on or after November 1, 2021, at specified redemption prices.

~~Business combinations~~—On January 30, 2018, we acquired an approximate 97.7 percent ownership interest in Songa. On March 28, 2018, we acquired the remaining shares not owned by us through a compulsory acquisition under Cyprus law, and as a result, Songa became our wholly owned subsidiary. To complete these transactions, we issued 68.0 million shares as partial considerationdebt securities for the acquisition of Songa shares. Additionally, we issued $863 million aggregate principal amount of 0.50% exchangeable senior bonds due January 30, 2023 (the “Exchangeable Bonds”) as partial consideration for the acquisition of Songa shares and partial settlement of certain Songa indebtedness. Holders of the Exchangeable Bonds may convert the notes into shares of Transocean Ltd. at any time prior to maturity at a rate of 97.29756 shares per $1,000 note, equivalent to a conversion price of $10.28 per share, subject to adjustment upon the occurrence of certain events. Holders of Exchangeable Bonds may require us to repurchase all or a portion of such holder’s Exchangeable Bonds upon the occurrence of certain events.

On December 5, 2018, we acquired Ocean Rig in a merger transaction, and as a result, Ocean Rig became our wholly owned subsidiary. To complete the acquisition, we issued 147.7 million shares and made an aggregate cash payment of ~~$1.2 billion.~~$63 million.

~~Investments in unconsolidated affiliates~~~~—We hold a 33.0 percent ownership interest in Orion, the company that owns the harsh environment floater~~ ~~Transocean Norge~~. In the nine months ended September 2019, we made an aggregate cash contribution of $74 million to Orion. In the year ended December 31, 2018, we made an aggregate contribution of $91 million to Orion. We have agreed to contribute $33 million in January 2020. Additionally, in the year ended December 31, 2018, we made cash contributions of $16 million to other companies involved in researching and developing technology to improve automation in drilling and other activities.

~~Early debt retirement~~—On February 5, 2019, ~~we completed cash tender offers to purchase the 2019 Tendered Notes. We~~having received valid tenders from holders of $510 million aggregate principal amount of the 2019 Tendered Notes, ~~and~~ we made an aggregate cash payment of $522 million to settle the 2019 Tendered Notes.

In the ~~nine months~~year ended ~~September 30,~~December 31, 2019, we repurchased in the open market ~~$381~~$434 million aggregate principal amount of our debt securities for an aggregate cash payment of ~~$395~~$449 million.

Investments in unconsolidated affiliates—In the six months ended June 30, 2020 and the year ended December 31, ~~2018, we repurchased in the open market $95 million aggregate principal amount of our debt securities for an aggregate cash payment of $95 million.~~

In connection with the Songa acquisition, we assumed rights and obligations under certain credit agreements and a subscription agreement establishing two term loan facilities and a bond facility. In the year ended December 31, 2018,2019, we made an aggregate cash ~~payment~~contribution of ~~$1.59 billion~~$6 million and $77 million, respectively, to ~~repay~~investments in noncontrolling ownership interests in certain unconsolidated affiliates, the ~~borrowings under~~most significant of which is our 33.0 percent ownership interest in Orion, the ~~facilities and terminated~~company that, through its wholly owned subsidiary, owns the underlying credit agreements and subscription agreement. We also assumed the indebtedness related to two bond loans and we assumed the rights and obligations under a credit agreement for a secured borrowing facility. In the year ended December 31, 2018, we made an aggregate cash payment equivalent to $67 million to repay the two bond loans and the borrowings outstanding under the secured borrowing facility, and we terminated the underlying credit agreement.

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~~Derivative instruments~~—In connection with the Songa acquisition, we acquired certain currency swaps. In February 2018, we made an aggregate cash payment of $92 million in connection with the settlement and termination of the currency swaps.harsh environment floater Transocean Norge.

Litigation settlements—On May 29, 2015, together with the Plaintiff Steering Committee, we filed ~~a settlement agreement (the “PSC~~the PSC Settlement ~~Agreement”)~~Agreement, in which we agreed to pay a total of $212 million, and in exchange, the two classes of plaintiffs agreed to release all respective claims against us. ~~On February 15, 2017,~~As required under the PSC Settlement Agreement, which was approved by the U.S. District Court for the Eastern District of Louisiana (the “MDL Court”) ~~entered a final order and judgment approving the PSC Settlement Agreement. As required under the PSC Settlement Agreement,~~on February 15, 2017, we made a cash deposit of $212 million into an escrow account established by the MDL Court for the settlement. In June 2020 and August 2019, ~~and November 2018,~~ the MDL Court released $125 million and $33 million, ~~and $58 million~~respectively, from the escrow account to ~~make payments to~~satisfy our remaining obligations under the ~~plaintiffs.~~PSC Settlement Agreement.

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. On February 12, 2010, our board of directors authorized our management to implement the share repurchase program. ~~In the nine months ended September~~At June 30, ~~2019 and the year ended December 31, 2018, we did not purchase shares under our share repurchase program. At October 22, 2019,~~2020, the authorization remaining under the share repurchase program was for the repurchase of up to CHF 3.2 billion, equivalent to approximately ~~$3.3~~$3.4 billion, of our outstanding shares. We intend to fund any repurchases using available cash balances and cash from operating activities. The share repurchase program could be suspended or discontinued by our board of directors or company management, as applicable, at any time. We may decide, based ~~upon~~on our ongoing capital requirements, the price of our shares, regulatory and tax considerations, cash flow generation, the amount and duration of our contract backlog, general market conditions, debt rating considerations and other factors, that we should retain cash, reduce debt, make capital investments or acquisitions or otherwise use cash for general corporate purposes. Decisions regarding the amount, if any, and timing of any share repurchases will be made from time to time based ~~upon~~on these factors. Any repurchased shares under the share repurchase program would be held by us for cancellation by the shareholders at a future general meeting of shareholders.

Contractual obligations—As of ~~September~~June 30, ~~2019,~~2020, with exception to the following, there have been no material changes to the contractual obligations as previously disclosed in “Part II. 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, ~~2018:~~2019:


			Twelve months ending September 30,										Twelve months ending June 30,
	Total		2020		2021 - 2022		2023 - 2024		Thereafter		Total		2021		2022 - 2023		2024 - 2025		Thereafter

	(in millions)										(in millions)
Contractual obligations
Debt	$	9,496	$	361	$	1,271	$	3,191	$	4,673	$	9,142	$	590	$	2,411	$	1,098	$	5,043
Interest on debt		4,474		601		1,089		811		1,973		4,197		561		1,000		807		1,829
Total	$	13,970	$	962	$	2,360	$	4,002	$	6,646	$	13,339	$	1,151	$	3,411	$	1,905	$	6,872

Other commercial commitments—As of ~~September~~June 30, ~~2019,~~2020, there have been no material changes to the commercial commitments as previously disclosed in “Part II. 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, ~~2018.~~2019.

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, new rig construction, or the acquisition of a rig under construction. We may commit to such investment without first obtaining customer contracts. Any 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. Our failure to secure drilling contracts for rigs under construction could have an adverse effect on our results of operations or cash flows.

~~We hold a 33.0 percent interest in Orion, the company that owns the harsh environment floater~~ ~~Transocean Norge~~. The Moss Maritime CS60 design is considered among the most capable semisubmersibles in the world. In August 2019, Orion completed construction of the rig and placed it into service. One of our subsidiaries operates the rig under a short-term bareboat charter to complete a six-well drilling contract for one of our customers. See Notes to Condensed Consolidated Financial Statements—Note 5—Unconsolidated Affiliates.

In connection with the Songa acquisition, we acquired seven mobile offshore drilling units, including five harsh environment floaters and two midwater floaters. In connection with the Ocean Rig acquisition, we acquired 11 mobile offshore drilling units, including nine ultra-deepwater floaters and two harsh environment floaters and the contracts relating to the construction of two ultra-deepwater drillships. In September 2019, two of our indirect, wholly owned subsidiaries delivered to SHI notices of intent to relinquish their respective interests in ~~Ocean Rig Santorini~~ ~~and~~ ~~Ocean Rig Crete~~, two ultra-deepwater drillships under construction. In October 2019, we agreed with SHI to cancel the construction contracts for the rigs in exchange for the parties terminating their respective obligations and liabilities under the construction contracts and our subsidiaries releasing to SHI their respective interests in the rigs. The table below reflects the reduction of projected expenditures resulting from the canceled construction contracts. See Notes to Condensed Consolidated Financial Statements—Note 17—Subsequent Events.

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In the nine months ended September 30, 2019, we made capital expenditures of $259 million, including capitalized interest of $28 million. We only capitalize interest costs during periods in which progress for construction projects continues to be underway. The historical and projected capital expenditures, capitalized interest and other cash or non-cash capital additions for our ongoing major construction projects were as follows:


			Total		Expected										Total costs		Expected
			costs for the		costs for the										for the		costs for the
	Total costs		nine months		three months						Total		Total costs		six months		six months								Total
	through		ended		ending						estimated		through		ended		ending								estimated
	December 31,		September 30,		December 31,		For the years ending December 31,				costs at		December 31,		June 30,		December 31,		For the years ending December 31,						costs at
	2018		2019		2019		2020		2021		completion		2019		2020		2020		2021		2022		2023		completion

	(In millions)												(In millions)
Ultra-Deepwater drillship TBN1 (a)	$	293	$	25	$	20	$	567	$	—	$	905
Deepwater Atlas (a)													$	329	$	21	$	31	$	596	$	67		51	$	1,095
Deepwater Titan (b)		216		65		26		202		636		1,145		309		49		105		609		88		—		1,160
Total	$	509	$	90	$	46	$	769	$	636	$	2,050	$	638	$	70	$	136	$	1,205	$	155	$	51	$	2,255

(a)

Deepwater Atlas~~Our unnamed~~, an ultra-deepwater drillship under construction at the Jurong Shipyard Pte Ltd. in Singapore ~~does not yet have~~has received an agreement for drilling services, subject to a ~~drilling contract~~final investment decision by the customer and its partners. If the conditions are satisfied, the newbuild unit is expected to commence operations under the drilling contract in the first half of 2022. The projected capital additions include estimates for one 20,000 pounds per square inch blowout preventer and other equipment required by the customer, some of which will be delivered and commissioned in the ~~third quarter of 2020. Following delivery of the unnamed ultra-deepwater drillship, we have included estimated costs of $40 million~~year ending December 31, 2023, subsequent to ~~mobilize~~placing the rig ~~to a location where it may be placed~~ in service. We will only commit to these incremental capital expenditures with the backing of a firm commitment by the customer.

(b)

Deepwater Titan,, an ultra-deepwater drillship under construction at the Jurong Shipyard Pte Ltd. in Singapore, is expected to commence operations under its drilling contract in the ~~fourth quarter~~first half of ~~2021.~~2022. The projected capital additions include estimates for an upgrade for two 20,000 pounds per square inch blowout preventers and other equipment required by our customer.

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 current 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 and financing arrangements with banks or other capital providers. We also have available credit under our Secured Credit Facility (see “—Sources and uses of liquidity”). Economic conditions could impact the availability of these sources of funding.

Dispositions—From time to time, we may also review the possible disposition of non-strategic drilling units. Considering ~~recent~~ market conditions, we have committed to plans to sell certain lower-specification drilling units for scrap value. During the ~~nine~~six months ended ~~September~~June 30, 2020 and the year ended December 31, 2019, we identified six such drilling units, respectively, that we have sold or intend to sell for scrap ~~value.~~value or other purposes. During the six months ended June 30, 2020, we completed the sale of one midwater floater, along with related assets, and we received net cash proceeds of $2 million. During the year ended December 31, ~~2018,~~2019, we ~~identified eight such drilling units that~~completed the sale of six ultra-deepwater floaters, one harsh environment floater, two deepwater floaters and two midwater floaters, along with related assets, and we ~~have sold or intend to sell for scrap value.~~received net cash proceeds of $64 million. We continue to evaluate the drilling units in our fleet and may identify additional lower specification drilling units to be sold for scrap value. During the nine months ended September 30, 2019, we completed the sale of three ultra-deepwater floaters, one harsh environment floater, two deepwater floaters and two midwater floaters, along with related assets, and we received net cash proceeds of $47 million. During the year ended December 31, 2018, we completed the sale of six ultra-deepwater floaters, one deepwater floater and one midwater floater, along with related assets, and we received net cash proceeds of $36 million.

Other Matters

Regulatory matters

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. See Notes to Condensed Consolidated Financial Statements—Note ~~14—~~10—Contingencies.

Tax matters

We conduct operations through our various subsidiaries in 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 adjustments to have a material adverse effect on our condensed consolidated statement of financial position, results of operations or cash flows. We file federal and local tax returns in several jurisdictions throughout the world. 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 condensed consolidated statement of financial position or results of operations, although it may have a material adverse effect on our condensed consolidated cash flows. See Notes to Condensed Consolidated Financial Statements—Note ~~12—~~8—Income ~~Taxes and Note 17—Subsequent Events.~~Taxes.

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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. We disclose our significant accounting policies 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 in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019.

For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates” in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019. We have discussed the development, selection and disclosure of these critical accounting policies and estimates with the audit committee of our board of directors. As of ~~September~~June 30, ~~2019,~~2020, there have been no material changes to the types of judgments, assumptions and estimates upon which our critical accounting policies and estimates are based.

Accounting Standards Updates

For a discussion of the new accounting standards updates that have had or are expected to have an effect on our condensed consolidated financial statements, see Notes to Condensed Consolidated Financial Statements—Note 3—Accounting Standards ~~Updates~~Update in this quarterly report on Form 10-Q and in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

Overview—We are exposed to interest rate risk, primarily associated with our long-term debt, including current maturities. Additionally, we are exposed to currency exchange rate risk related to our international operations. For a complete discussion of our interest rate risk and currency exchange rate risk, see “Part II. Item 7A. Quantitative and Qualitative Disclosures About Market Risk” in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019.

Interest rate risk—The following table presents the principal amounts and related weighted-average interest rates of our long-term debt instruments by contractual maturity date. The following table presents information as of ~~September~~June 30, ~~2019~~2020 for the 12-month periods ending ~~September~~June 30 (in millions, except interest rate percentages):


	Scheduled Maturity Date (a)																						Scheduled Maturity Date (a)
	2020			2021			2022			2023			2024			Thereafter			Total		Fair value		2021			2022			2023			2024			2025			Thereafter			Total		Fair value
Debt
Fixed rate (USD)	$	361		$	602		$	669		$	2,582		$	609		$	4,673		$	9,496	$	8,569	$	590		$	618		$	1,793		$	643		$	455		$	5,043		$	9,142	$	5,553
Average interest rate		6.24	%		6.26	%		6.97	%		4.98	%		6.26	%		7.26	%						6.26	%		6.83	%		3.29	%		6.23	%		6.84	%		7.40	%

At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, the fair value of our outstanding debt was ~~$8.6~~$5.6 billion and ~~$9.2~~$8.9 billion, respectively. During the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, the fair value of our debt decreased by ~~$643 million~~$3.3 billion due to the following: (a) a decrease of ~~approximately $862~~$2.8 billion due to changes in market prices for our outstanding debt, (b) a decrease of $834 million due to the ~~completion~~early retirement of ~~cash tender offers to purchase certain~~debt resulting from the redemption of the 9.00% senior notes ~~on February 5, 2019~~due July 2023 and open market repurchases of certain of our debt securities ~~(b) a decrease of approximately $544 million due to the reclassification of a finance lease contract to lease liabilities~~ and (c) a decrease of ~~approximately $264~~$184 million due to the repayment of debt at scheduled maturities, partially offset by (d) an increase of ~~approximately $1.1 billion~~$416 million due to the issuance of the ~~6.875% Senior Secured Notes and the 5.375% Senior Secured Notes and (e) an increase of approximately $77 million~~8.00% senior notes due ~~to changes in market prices for our outstanding debt.~~February 2027.

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 defined in the United States (“U.S.”) Securities Exchange Act of 1934 (the “Exchange Act”), Rules 13a-15 and 15d-15, as of the end of the period covered by this report. Our disclosure controls and procedures are designed 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 U.S. Securities and Exchange Commission’s rules and forms. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of ~~September~~June 30, ~~2019.~~2020.

Internal control over financial reporting—There were no changes to our internal control over financial reporting during the quarter ended ~~September~~June 30, ~~2019~~2020 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II.

OTHER INFORMATION

Item 1.

Legal Proceedings

Transocean Ltd. (together with its subsidiaries and predecessors, unless the context requires otherwise, “Transocean,” “we,” “us,” or “our”) has certain actions, claims and other matters pending as discussed and reported in “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note ~~13—~~15—Commitments and Contingencies” and “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Other Matters—Regulatory ~~matters—Consent Decree”~~matters” in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019. We are also involved in various tax matters as described in “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note ~~10—~~12—Income Taxes” and in “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Other Matters—Tax matters” in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019. All such actions, claims, tax and other matters are incorporated herein by reference.

The previously disclosed lawsuit filed against Global Marine Inc. (“Global Marine”), a Delaware corporation and our wholly owned subsidiary, by Wilmington Trust Company, in its capacity as trustee, was dismissed with prejudice on July 29, 2019, prohibiting the trustee from refiling a lawsuit based upon the claims alleged in the trustee’s lawsuit. Additionally, the holder of the majority in principal of Global Marine’s $300 million of outstanding 7.00% Notes due June 2028 (the “7.00% Notes”) has waived any alleged existing or past default related to the allegations in the trustee’s lawsuit, which prohibits any other holder of the 7.00% Notes from filing a lawsuit based upon the claims alleged in the trustee’s lawsuit. Subsequent to the dismissal of the lawsuit, Global Marine and Transocean Inc. entered into a supplemental indenture to the indenture governing the 7.00% Notes. The supplemental indenture provides that Transocean Inc. irrevocably and unconditionally guarantees all of the obligations of Global Marine under the indenture and the 7.00% Notes, and that Global Marine will publish certain financial information on an annual basis.

As of ~~September~~June 30, ~~2019,~~2020, we were also involved in a number of other lawsuits, claims and disputes, which have arisen in the ordinary course of our business and for which we do not expect the liability, if any, to have a material adverse effect on our condensed consolidated ~~statement of~~ 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 claim or dispute will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

In addition to the legal proceedings described above, we may from time to time identify other matters that we monitor through our compliance program or in response to events arising generally within our industry and in the markets where we do business. We evaluate matters on a case by case basis, investigate allegations in accordance with our policies and cooperate with applicable governmental authorities. Through the process of monitoring and proactive investigation, we strive to ensure no violation of our policies, Code of Integrity or law has, or will, occur; however, there can be no assurance as to the outcome of these matters.

Item 1A.

Risk Factors

There have been no material changes to the risk factors as previously disclosed in “Part I. Item 1A. Risk Factors” in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019 and “Part II. Item 1A. Risk Factors” in our quarterly report on Form 10-Q for the quarterly period ended March 31, 2020.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities


				Total	Maximum Number
				Number of Shares	(or Approximate Dollar Value)					Total number of shares	Approximate dollar value
	Total Number	Average		Purchased as Part	of Shares that May Yet Be Purchased		Total number	Average		purchased as part	of shares that may yet
	of Shares	Price Paid		of Publicly Announced	Under the Plans or Programs		of shares	price paid		of publicly announced	be purchased under the plans
Period	Purchased	Per Share		Plans or Programs (a)	(in millions) (a)		purchased	per share		plans or programs (a)	or programs (in millions) (a)
July 2019	—	$	—	—	$	3,250
August 2019	—		—	—		3,250
September 2019	—		—	—		3,250
April 2020							1,784	$	1.78	—	$	3,424
May 2020							—		—	—		3,424
June 2020							—		—	—		3,424
Total	—	$	—	—	$	3,250	1,784	$	1.78	—	$	3,424

(a)

In May 2009, at our annual general meeting, our shareholders approved and authorized our board of directors, at its discretion, to repurchase for cancellation any amount of our shares for an aggregate purchase price of up to CHF 3.5 billion. At ~~September~~June 30, ~~2019,~~2020, the authorization remaining under the share repurchase program was for the repurchase of our outstanding shares for an aggregate cost of up to CHF 3.2 billion, equivalent to ~~$3.3~~$3.4 billion. The share repurchase program could be suspended or discontinued by our board of directors or company management, as applicable, at any time. See “Part I. Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources and uses of liquidity.”

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Item 6.

Exhibits

(a)

Exhibits

The following exhibits are filed in connection with this quarterly report on Form 10-Q:


Number		Description	Location
	3.1	Articles of Association of Transocean Ltd.	Exhibit 3.1 to Transocean Ltd.’s’ s Current Report on Form 8-K (Commission File No. 001-38373) filed on May ~~13, 2019~~11, 2020
	3.2	Organizational Regulations of Transocean Ltd., adopted November 18, 2016	Exhibit 3.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 000-53533) filed on November 23, 2016
	~~4.1~~	~~Third Supplemental Indenture, dated as of July 29, 2019, among Global Marine Inc., Transocean Inc. and Wilmington Trust Company, as trustee~~	~~Exhibit 4.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 001-38373) filed on July 29, 2019~~
	10.1	~~Increase of Commitments~~Amended and Second Amendment to Credit Agreement and First Amendment to Guaranties, dated July 15, 2019, among Transocean Inc., the lenders and issuing banks parties thereto, Citibank, N.A., as administrative agent and for the limited purposes set forth therein,Restated 2015 Transocean Ltd. ~~and certain of its subsidiaries~~Long-Term Incentive Plan	Exhibit 10.1 to Transocean Ltd.’s Current Report on Form 8-K (Commission File No. 001-38373) filed on ~~July 15, 2019~~May 11, 2020
	10.2	~~Curative Agreement, dated September 24, 2019, between Transocean Inc.~~Terms and ~~Citibank, N.A., as administrative agent for the lenders under the Credit Agreement dated June 22, 2018, as amended~~Conditions of 2020 Executive Equity Awards	Filed herewith
	10.3	Terms and Conditions of 2020 Director Restricted Share Unit Award	Filed herewith
	31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934 and Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith
	31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934 and Section 302 of the Sarbanes-Oxley Act of 2002	Filed herewith
	32.1	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Furnished herewith
	32.2	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	Furnished herewith
	101	Interactive data files pursuant to Rule 405 of Regulation S-T formatted in Inline Extensible Business Reporting Language: (i) our condensed consolidated balance sheets as of ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018;~~2019; (ii) our condensed consolidated statements of operations for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018;~~2019; (iii) our condensed consolidated statements of comprehensive loss for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018;~~2019; (iv) our condensed consolidated statements of equity for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018;~~2019; (v) our condensed consolidated statements of cash flows for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018;~~2019; and (vi) the notes to condensed consolidated financial statements	Filed herewith
	104	The cover page from our quarterly report on Form 10-Q for the quarterly period ended ~~September~~June 30, ~~2019,~~2020, formatted in Inline Extensible Business Reporting Language	Filed herewith

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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 ~~October 29, 2019.~~July 30, 2020.


TRANSOCEAN LTD.



By:	/s/ Mark L. Mey
	Mark L. Mey
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)



By:	/s/ David Tonnel
	David Tonnel
	Senior Vice President and ~~Corporate Controller~~Chief Accounting Officer
	(Principal Accounting Officer)

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		Page
PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Statements of Operations	1
	Condensed Consolidated Statements of Comprehensive Loss	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	1814
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3025
Item 4.	Controls and Procedures	3025

PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	3126
Item 1A.	Risk Factors	3126
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3126
Item 6.	Exhibits	3227


	Total
Consideration transferred
Aggregate fair value of shares issued as partial consideration for Ocean Rig shares	$	1,377
Aggregate cash paid as partial consideration for Ocean Rig shares		1,168
Total consideration transferred in business combination	$	2,545


	Total
Assets acquired
Cash and cash equivalents	$	152
Accounts receivable		76
Property and equipment		2,205
Drilling contract intangible assets		275
Other assets		115

Liabilities assumed
Accounts payable and other current liabilities		71
Construction contract intangible liabilities		132
Other long-term liabilities		54
Net assets acquired	$	2,566


	Nine months ended September 30, 2019										Nine months ended September 30, 2018
	U.S.		Norway		Brazil		Other		Total		U.S.		Norway		Brazil		Other		Total

Ultra-deepwater floaters	$	940	$	—	$	81	$	434	$	1,455	$	1,162	$	—	$	1	$	168	$	1,331
Harsh environment floaters		4		554		—		232		790		—		467		—		254		721
Deepwater floaters		—		—		6		1		7		—		—		74		32		106
Midwater floaters		—		—		—		44		44		—		—		—		57		57
High-specification jackups		—		—		—		—		—		—		—		—		55		55
Total revenues	$	944	$	554	$	87	$	711	$	2,296	$	1,162	$	467	$	75	$	566	$	2,270


	Operating		Finance
	leases		lease
Twelve months ending September 30,
2020	$	18	$	71
2021		11		71
2022		12		71
2023		12		71
2024		11		71
Thereafter		132		345
Total future minimum rental payment		196		700
Less amount representing imputed interest		(72)		(213)
Present value of future minimum rental payments		124		487
Less current portion, recorded in other current liabilities		(14)		(34)
Long-term lease liabilities, recorded in other long-term liabilities	$	110	$	453