Transocean Ltd. (NYSE: RIG) returns to profit with Q2 cash flow surge
Rhea-AI Filing Summary
Transocean Ltd. reported second quarter 2026 contract drilling revenues of $966 million and net income of $170 million, compared with a loss of $938 million a year earlier. Basic earnings per share were $0.15, and total fleet revenue efficiency was 97.0%. Adjusted EBITDA was $312 million, while net cash from operating activities reached $236 million and free cash flow was $212 million.
Total debt (principal) declined to $5,107 million at June 30, 2026, with a net debt to EBITDA ratio of 2.8x. As of August 5, 2026, contract backlog was approximately $6.7 billion, excluding a conditional Equinor agreement for three harsh environment semisubmersibles valued at about $1.0 billion. For 3Q26, the company guides contract drilling revenues of $920–$960 million and full‑year 2026 revenues of $3.9–$3.975 billion, with total liquidity forecast between $1.25–$1.35 billion.
Positive
- Transocean returned to profitability with $170 million Q2 2026 net income, compared with a prior-year loss of $938 million.
- The company generated strong cash generation in Q2 2026, with net cash from operating activities of $236 million and $212 million of free cash flow.
- Total debt (principal) decreased to $5,107 million at June 30, 2026 from $6,654 million a year earlier, reducing the net debt to EBITDA ratio to 2.8x.
- As of August 5, 2026, Transocean reported contract backlog of approximately $6.7 billion, excluding a conditional Equinor agreement worth about $1.0 billion for three harsh environment semisubmersibles.
Negative
- Sequential performance softened, as contract drilling revenues declined by $115 million from Q1 2026 to $966 million, and adjusted EBITDA fell by $128 million to $312 million.
Filing Explained
The latest balance sheet shows higher issued and outstanding share counts, but the filing does not identify the transaction or holder mechanics behind the change.
As of
The higher reported share count could reduce an existing holder’s percentage ownership if it reflects additional issuance and no offsetting change, but the filing does not identify the transaction that produced the change.
The Fleet Status Report adds approximately
The release also refers to a proposed business combination with Valaris Limited but provides no consideration, closing conditions, or ownership mechanics; those details remain the material items needed to assess its effect on common holders.
8-K Event Classification
Key Figures
Key Terms
revenue efficiency financial
free cash flow financial
contract backlog financial
ultra-deepwater floaters technical
harsh environment semisubmersibles technical
Earnings Snapshot
For 3Q26, contract drilling revenues are guided to $920–$960 million and operating and maintenance expense to $595–$625 million; for FY26, revenues are guided to $3.9–$3.975 billion with capital expenditures of $150 million and total liquidity $1.25–$1.35 billion.
AI-generated analysis. How Rhea-AI works. Not financial advice.
FAQ
What were Transocean (RIG) revenues and earnings for Q2 2026?
How did Transocean (RIG) cash flow and free cash flow look in Q2 2026?
What is Transocean (RIG) contract backlog and the Equinor agreement value?
What guidance did Transocean (RIG) provide for Q3 and full-year 2026?
How has Transocean (RIG) debt and liquidity changed by mid-2026?
What are key fleet performance metrics for Transocean (RIG) in Q2 2026?
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM
CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Date of report (date of earliest event reported):
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+ | ||
(Registrant’s telephone number, including area code) | ||
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
Securities registered pursuant to Section 12(b) of the Act:
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Indicate by check mark whether the registrant is an emerging growth company as defined in as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
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. ☐
Item 2.02. | Results of Operations and Financial Condition |
Transocean Ltd.’s press release dated August 5, 2026, concerning financial results for the second quarter 2026, furnished as Exhibit 99.1 to this report, is incorporated by reference herein.
Item 7.01. | Regulation FD Disclosure |
We issue a report entitled “Transocean Fleet Status Report,” which includes drilling rig status and contract information. A report dated August 5, 2026, is furnished as Exhibit 99.2 to this Current Report on Form 8-K and is incorporated herein by reference. You may subscribe to the Transocean “E-mail Alerts,” which based upon your selections will alert you to new Transocean press releases, financial and other updates. This free service will send you an automated email containing the Fleet Status Report press release and a link to our website: www.deepwater.com, where the reports are posted each quarter under “Investors/Fleet Status Report.” You may subscribe to this service in the footer of any of the website’s Investors pages by selecting “E-mail Alerts” then providing your email address. Please select the alerts to which you prefer to subscribe and click “Submit.”
Item 9.01. | Financial Statements and Exhibits |
(d) Exhibits
Number | Description |
99.1 | Press Release Reporting Second Quarter 2026 Financial Results |
99.2 | Fleet Status Report dated August 5, 2026 |
101 | Interactive data files pursuant to Rule 405 of Regulation S-T formatted in Inline Extensible Business Reporting Language |
104 | Cover Page Interactive Data File (formatted as inline XBRL) |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, hereunto duly authorized.
TRANSOCEAN LTD. | ||
Date: August 5, 2026 | By | /s/ Debra Kupferman |
Debra Kupferman | ||
Authorized Person | ||
EXHIBIT 99.1
TRANSOCEAN LTD. REPORTS second QUARTER 2026 RESULTS
STEINHAUSEN, Switzerland, August 5, 2026—Transocean Ltd. (NYSE: RIG) today reported financial results for the second quarter of 2026. The Company will host a conference call and webcast at 9 a.m. EDT, 3 p.m. CEST, on Thursday, August 6, 2026, with participation details included in this release. Supplemental schedules have been posted to the Investors section of the Company’s website at www.deepwater.com.
Second quarter 2026 Key points
| ◾ | Contract drilling revenues were $966 million with strong revenue efficiency(1) of 97.0%. |
| ◾ | Net income was $170 million or $0.04 per diluted share. |
| ◾ | Adjusted EBITDA was $312 million, reflecting a margin of 32.2%. |
| ◾ | Net cash provided by operating activities was $236 million; net of capital expenditures of $24 million, free cash flow was $212 million. |
| ◾ | Ended the period with total liquidity of more than $1.3 billion, including the undrawn revolving credit facility. |
| ◾ | Added $292 million in contract backlog(2) at a weighted average dayrate of about $461,000. |
“Transocean delivered a strong second quarter, supported by 97% revenue efficiency and solid adjusted EBITDA margins, resulting in excellent cash flow and improved liquidity,” said Keelan Adamson, Transocean’s CEO. “Our performance reflects our ongoing commitment to create value through the cycle by optimizing the value of our differentiated fleet, generating industry-leading free cash flow, and enhancing our capital structure.
“We expect to see demand for our highest specification rigs increase in the coming years with industry utilization for deepwater and harsh environment assets projected to move well into the 90% range during 2027. Our recent contract awards across Norway, Australia, the U.S. Gulf, and the Ivory Coast, together with the $1.0 billion Equinor agreement for three harsh environment semisubmersibles, show that customers continue to secure rig capacity. With our differentiated fleet, strong execution capabilities, and improving financial flexibility, we believe Transocean is well positioned to deliver long-term value for our shareholders.”
2Q26 Financial Summary
| Three months ended | | | | | | Three months ended | | | | | ||||||||
| June 30, | | March 31, | | sequential | | June 30, | | year-over-year | ||||||||||
| 2026 | | 2026 | | change | | 2025 | | change | ||||||||||
(In millions, except per share amounts and percentages) | | | | | | | | | | | | | | | | | | | |
Contract drilling revenues | $ | 966 | | | $ | 1,081 | | | $ | (115) | | | $ | 988 | | | $ | (22) | |
Revenue efficiency | | 97.0 | % | | | 97.3 | % | | | | | | | 96.6 | % | | | | |
Operating and maintenance expense | $ | 608 | | | $ | 606 | | | $ | (2) | | | $ | 599 | | | $ | (9) | |
Net income (loss) | $ | 170 | | | $ | 71 | | | $ | 99 | | | $ | (938) | | | $ | 1,108 | |
Basic earnings (loss) per share | $ | 0.15 | | | $ | 0.06 | | | $ | 0.09 | | | $ | (1.06) | | | $ | 1.21 | |
Diluted earnings (loss) per share | $ | 0.04 | | | $ | 0.06 | | | $ | (0.02) | | | $ | (1.06) | | | $ | 1.10 | |
| | | | | | | | | | | | | | | | | | | |
Adjusted EBITDA | $ | 312 | | | $ | 440 | | | $ | (128) | | | $ | 344 | | | $ | (32) | |
Adjusted EBITDA margin | | 32.2 | % | | | 40.7 | % | | | | | | | 34.9 | % | | | | |
Adjusted net income (loss) | $ | 158 | | | $ | (28) | | | $ | 186 | | | $ | 19 | | | $ | 139 | |
Adjusted diluted earnings (loss) per share | $ | 0.03 | | | $ | (0.03) | | | $ | 0.06 | | | $ | — | | | $ | 0.03 | |
| | | | | | | | | | | | | | | | | | | |
Net cash provided by operating activities | $ | 236 | | | $ | 164 | | | $ | 72 | | | $ | 128 | | | $ | 108 | |
Free cash flow | $ | 212 | | | $ | 136 | | | $ | 76 | | | $ | 104 | | | $ | 108 | |
Total debt, principal amount, end of period | $ | 5,107 | | | $ | 5,137 | | | $ | (30) | | | $ | 6,654 | | | $ | (1,547) | |
| ◾ | Contract drilling revenues were lower sequentially, primarily due to the expected decrease in rig utilization for this quarter. |
| ◾ | Interest expense, excluding the $134 million effect of the bifurcated exchange feature of the 4.625% Exchangeable Bonds due 2029, was $114 million compared to the $123 million in the prior quarter. |
| ◾ | Cash taxes paid, net of tax refunds of $22 million, were $10 million. |
Fleet Status Report and contract backlog
| ◾ | The Company today issued its Fleet Status Report. Since its May 2026 report, the Company added five new fixtures with an aggregate incremental backlog of approximately $292 million and a weighted average dayrate of about $461,000. |
| ◾ | As of August 5, 2026, the total backlog is approximately $6.7 billion. This figure excludes $1.0 billion of backlog for work with Equinor, which will be added subject to receipt of approvals from license partners. |
The Fleet Status Report can be accessed on the Company’s website: www.deepwater.com.
2026 Third Quarter and Full Year OUTLOOK
The following table includes guidance on key items for the third quarter and full year of 2026:
| | 3Q26E | | | | FY26E | |
(In millions, except percentages) | | | | | | | |
Contract drilling revenues | $ | 920 – 960 | | | $ | 3,900 – 3,975 | |
Revenue efficiency, fleet wide (1) | | 96.5% | | | | 96.5% | |
| | | | | | | |
Selected costs and expenses | | | | | | | |
Operating and maintenance expense | $ | 595 – 625 | | | $ | 2,325 – 2,400 | |
General and administrative | $ | 45 | | | $ | 170 – 180 | |
Interest expense | $ | 113 | | | $ | 475 | |
Interest income | $ | 5 – 10 | | | $ | 30 – 35 | |
| | | | | | | |
Capital expenditures | $ | 40 – 50 | | | $ | 150 | |
Cash taxes | $ | 25 – 30 | | | $ | 55 – 60 | |
Total liquidity | | — | | | $ | 1,250 – 1,350 | |
Conference Call Information
Transocean will host a conference call at 9 a.m. EDT, 3 p.m. CEST, on Thursday, August 6, 2026. To participate, dial +1 785-424-1222 approximately 15 minutes prior to the scheduled start time and refer to conference code 715943.
The call will be webcast in a listen-only mode at: www.deepwater.com, by selecting Investors, News, and Webcasts. Supplemental materials that may be referenced during the call will be available on the Company’s website at: www.deepwater.com, by selecting Investors, Financial Reports.
A replay of the call will be available after 12 p.m. EDT, 6 p.m. CEST, on Thursday, August 6, 2026. The replay, which will be archived for approximately 30 days, can be accessed at +1 402-220-7239, passcode 715943. The replay will also be available on the Company’s website.
Non-GAAP Financial Measures
We present our financial statements in accordance with accounting principles generally accepted in the U.S. (“U.S. GAAP”). We believe certain financial measures, such as Adjusted Net Income, EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt, which are non-GAAP measures, provide users of our financial statements with supplemental information that may be useful in evaluating our operating performance. We believe that such non-GAAP measures, when read in conjunction with our financial statements presented under U.S. GAAP, can be used to better assess our performance from period to period and relative to performance of other companies in our industry, without regard to financing methods, historical cost basis or capital structure. Such non-GAAP measures should be considered as a supplement to, and not as a substitute for, financial measures prepared in accordance with U.S. GAAP.
All non-GAAP measure reconciliations to the most comparative U.S. GAAP measures are displayed in quantitative schedules on the Company’s website at: www.deepwater.com.
About Transocean
Transocean is a leading international provider of offshore contract drilling services for oil and gas wells. The Company specializes in technically demanding sectors of the global offshore drilling business with a particular focus on ultra-deepwater and harsh environment drilling services and operates the highest specification floating offshore drilling fleet in the world.
Transocean owns or has partial ownership interests in and operates a fleet of 27 mobile offshore drilling units, consisting of 20 ultra-deepwater drillships and seven harsh environment semisubmersibles.
For more information about Transocean, please visit: www.deepwater.com.
Forward-Looking Statements
The statements described herein or in the Fleet Status Report that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements could contain words such as “believe,” “primarily,” “should,” “outlook,” “future,” “schedule,” “progress,” “possible,” “will,” “expect,” “estimate,” “may,” “approximate,” “could,” “plan,” or other similar expressions. Forward-looking statements in the Fleet Status Report include, but are not limited to, statements involving estimated duration of customer contracts, contract dayrate amounts, future contract commencement dates and locations, planned shipyard projects and other out-of-service time, sales of drilling units, and the cost and timing of mobilizations and reactivations. Forward-looking statements are based on management’s current expectations and assumptions, and are subject to inherent uncertainties, risks and changes in circumstances that are difficult to predict. As a result, actual results could differ materially from those indicated in these forward-looking statements. Factors that could cause actual results to differ materially include, but are not limited to, the level of activity in offshore oil and gas
exploration and development, exploration success by producers, operating hazards and delays, risks associated with international operations, actions by customers and other third parties, the fluctuation of current and future prices of oil and gas, the global and regional supply and demand for oil and gas, the intention to scrap certain drilling rigs, the effects of the spread of and mitigation efforts by governments, businesses and individuals related to contagious illnesses, and other factors, including our expectations regarding the timing, completion and anticipated benefits of the proposed business combination with Valaris Limited, an exempted company limited by shares incorporated under the laws of Bermuda, and those and other risks discussed in the Company's most recent Annual Report on Form 10-K for the year ended December 31, 2025, and in the Company's other filings with the SEC, which are available free of charge on the SEC's website at: www.sec.gov. Should one or more of these risks or uncertainties materialize, or the other consequences of such a development worsen, or should underlying assumptions prove incorrect, actual results may vary materially from those indicated or expressed or implied by such forward-looking statements. All subsequent written and oral forward-looking statements attributable to the Company 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 of which speaks only as of the date of the particular statement. We expressly disclaim any obligation or undertaking to release publicly any updates or revisions to any forward-looking statements 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.
This press release, or referenced documents, do not constitute an offer to sell, or a solicitation of an offer to buy, any securities, and do not constitute an offering prospectus within the meaning of the Swiss Financial Services Act (“FinSA”) or advertising within the meaning of the FinSA. Investors must rely on their own evaluation of Transocean and its securities, including the merits and risks involved. Nothing contained herein is, or shall be relied on as, a promise or representation as to the future performance of Transocean.
Notes
| (1) | Revenue efficiency is defined as actual operating 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 the drilling unit could earn for the measurement period, excluding revenues for incentive provisions, reimbursements and contract terminations. See the accompanying schedule entitled “Revenue Efficiency.” |
| (2) | Contract backlog is defined as the maximum contractual operating dayrate multiplied by the number of days remaining in the firm contract period, including certain performance-based provisions for which achievement is probable, and excluding provisions for mobilization, demobilization, contract preparation, other incentive provisions or reimbursement revenues, which are not expected to be material to our contract drilling revenues. The contract backlog represents the maximum contract drilling revenues that can be earned considering the reported operating dayrate in effect during the firm contract period. |
Analyst Contact:
Sarah Davidson
+1 713-232-7217
Media Contact:
Kristina Mays
+1 713-232-7734
TRANSOCEAN LTD. AND SUBSIDIARIES |
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS |
(in millions, except per share data) |
(Unaudited) |
| | Three months ended | | Six months ended | | ||||||||
| | June 30, | | June 30, | | ||||||||
| | 2026 | | 2025 | | 2026 | | 2025 |
| ||||
| | | | | | | | | | | | | |
Contract drilling revenues | | $ | 966 | | $ | 988 | | $ | 2,047 | | $ | 1,894 | |
| | | | | | | | | | | | | |
Costs and expenses | | | | | | | | | | | | | |
Operating and maintenance | | | 608 | | | 599 | | | 1,214 | | | 1,217 | |
Depreciation and amortization | | | 148 | | | 175 | | | 291 | | | 351 | |
General and administrative | | | 56 | | | 49 | | | 105 | | | 99 | |
| | | 812 | | | 823 | | | 1,610 | | | 1,667 | |
| | | | | | | | | | | | | |
Loss on impairment of assets | | | — | | | (1,136) | | | — | | | (1,136) | |
Gain (loss) on disposal of assets, net | | | (2) | | | 7 | | | 2 | | | 9 | |
Operating income (loss) | | | 152 | | | (964) | | | 439 | | | (900) | |
| | | | | | | | | | | | | |
Other income (expense), net | | | | | | | | | | | | | |
Interest income | | | 12 | | | 10 | | | 22 | | | 18 | |
Interest expense | | | 20 | | | (112) | | | (256) | | | (228) | |
Loss on retirement of debt | | | — | | | — | | | (11) | | | — | |
Other, net | | | — | | | (27) | | | 7 | | | (23) | |
| | | 32 | | | (129) | | | (238) | | | (233) | |
| | | | | | | | | | | | | |
Income (loss) before income taxes | | | 184 | | | (1,093) | | | 201 | | | (1,133) | |
Income tax expense (benefit) | | | 14 | | | (155) | | | (40) | | | (116) | |
Net income (loss) | | $ | 170 | | $ | (938) | | $ | 241 | | $ | (1,017) | |
| | | | | | | | | | | | | |
Earnings (loss) per share | | | | | | | | | | | | | |
Basic | | $ | 0.15 | | $ | (1.06) | | $ | 0.22 | | $ | (1.15) | |
Diluted | | $ | 0.04 | | $ | (1.06) | | $ | 0.21 | | $ | (1.15) | |
| | | | | | | | | | | | | |
Weighted-average shares outstanding | | | | | | | | | | | | | |
Basic | | | 1,120 | | | 888 | | | 1,115 | | | 885 | |
Diluted | | | 1,202 | | | 888 | | | 1,125 | | | 885 | |
TRANSOCEAN LTD. AND SUBSIDIARIES |
CONDENSED CONSOLIDATED BALANCE SHEETS |
(in millions, except par value) |
(Unaudited) |
| | June 30, | | December 31, | | ||
| | 2026 | | 2025 |
| ||
Assets | | | | | | | |
Cash and cash equivalents |
| $ | 509 | | $ | 620 | |
Accounts receivable, net of allowance of $2 at June 30, 2026 and December 31, 2025 | | | 604 | | | 540 | |
Materials and supplies, net of allowance of $146 and $140 at June 30, 2026 and December 31, 2025, respectively | | | 379 | | | 378 | |
Assets held for sale | | | 1 | | | 24 | |
Restricted cash and cash equivalents | | | 286 | | | 377 | |
Other current assets | | | 133 | | | 142 | |
Total current assets | | | 1,912 | | | 2,081 | |
| | | | | | | |
Property and equipment | | | 17,490 | | | 17,451 | |
Less accumulated depreciation | | | (5,147) | | | (4,874) | |
Property and equipment, net | | | 12,343 | | | 12,577 | |
| | | | | | | |
Deferred tax assets, net | | | 70 | | | 61 | |
Other assets | | | 842 | | | 923 | |
Total assets |
| $ | 15,167 | | $ | 15,642 | |
| | | | | | | |
Liabilities and equity | | | | | | | |
Accounts payable |
| $ | 283 | | $ | 242 | |
Accrued income taxes | | | 9 | | | 22 | |
Debt due within one year | | | 397 | | | 445 | |
Other current liabilities | | | 514 | | | 627 | |
Total current liabilities | | | 1,203 | | | 1,336 | |
| | | | | | | |
Long-term debt | | | 4,722 | | | 5,212 | |
Deferred tax liabilities, net | | | 340 | | | 404 | |
Other long-term liabilities | | | 532 | | | 582 | |
Total long-term liabilities | | | 5,594 | | | 6,198 | |
| | | | | | | |
Commitments and contingencies | | | | | | | |
| | | | | | | |
Shares, $0.10 par value, | | | | | | | |
1,445 authorized, 141 conditionally authorized, 1,304 issued and 1,117 outstanding at June 30, 2026 and | | | | | | | |
1,204 authorized, 141 conditionally authorized, 1,204 issued and 1,102 outstanding at December 31, 2025 | | | 112 | | | 110 | |
Additional paid-in capital | | | 15,617 | | | 15,604 | |
Accumulated deficit | | | (7,219) | | | (7,460) | |
Accumulated other comprehensive loss | | | (140) | | | (146) | |
Total equity | | | 8,370 | | | 8,108 | |
Total liabilities and equity |
| $ | 15,167 | | $ | 15,642 | |
TRANSOCEAN LTD. AND SUBSIDIARIES |
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS |
(in millions) |
(Unaudited) |
| | Six months ended | | ||||
| | June 30, | | ||||
| | 2026 | | 2025 | | ||
Cash flows from operating activities | | | | | | | |
Net income (loss) |
| $ | 241 | | $ | (1,017) | |
Adjustments to reconcile to net cash provided by operating activities: | | | | | | | |
Depreciation and amortization | | | 291 | | | 351 | |
Share-based compensation expense | | | 15 | | | 16 | |
Loss on impairment of assets | | | — | | | 1,136 | |
Gain on disposal of assets, net | | | (2) | | | (9) | |
Amortization of debt-related balances, net | | | 20 | | | 25 | |
(Gain) loss on adjustment to bifurcated compound exchange feature | | | 19 | | | (65) | |
Loss on retirement of debt | | | 11 | | | — | |
Deferred income tax benefit | | | (73) | | | (157) | |
Other, net | | | (1) | | | 31 | |
Changes in contract liabilities, net | | | (83) | | | (84) | |
Changes in deferred costs, net | | | 46 | | | 16 | |
Changes in other operating assets and liabilities, net | | | (84) | | | (89) | |
Net cash provided by operating activities | | | 400 | | | 154 | |
| | | | | | | |
Cash flows from investing activities | | | | | | | |
Capital expenditures | | | (52) | | | (84) | |
Investment in equity of unconsolidated affiliates | | | (2) | | | — | |
Proceeds from disposal of assets, net of costs to sell | | | 26 | | | 10 | |
Proceeds from disposal of investment in note receivable from unconsolidated affiliate | | | 13 | | | — | |
Proceeds from disposal of investment in equity of unconsolidated affiliate | | | — | | | 4 | |
Net cash used in investing activities | | | (15) | | | (70) | |
| | | | | | | |
Cash flows from financing activities | | | | | | | |
Repayments of debt | | | (586) | | | (240) | |
Other, net | | | (1) | | | (13) | |
Net cash used in financing activities | | | (587) | | | (253) | |
| | | | | | | |
Net decrease in unrestricted and restricted cash and cash equivalents | | | (202) | | | (169) | |
Unrestricted and restricted cash and cash equivalents, beginning of period | | | 997 | | | 941 | |
Unrestricted and restricted cash and cash equivalents, end of period |
| $ | 795 | | $ | 772 | |
TRANSOCEAN LTD. AND SUBSIDIARIES | |||||||||||
FLEET OPERATING STATISTICS | |||||||||||
| | | | | | | | | | | |
| | | | | | | | | | | |
| | Three months ended | | | |||||||
| | June 30, | | March 31, | | June 30, | | | |||
Contract Drilling Revenues (in millions) | | 2026 | | 2026 | | 2025 | | | |||
Ultra-deepwater floaters | | $ | 623 | | $ | 748 | | $ | 699 | | |
Harsh environment floaters | | | 343 | | | 333 | | | 289 | | |
Total contract drilling revenues | | $ | 966 | | $ | 1,081 | | $ | 988 | | |
| | Three months ended | | | |||||||
| | June 30, | | March 31, | | June 30, | | | |||
Average Daily Revenue (1) | | 2026 | | 2026 | | 2025 | | | |||
Ultra-deepwater floaters | | $ | 455,500 | | $ | 480,700 | | $ | 457,200 | | |
Harsh environment floaters | |
| 510,000 | |
| 463,800 | |
| 462,400 | | |
Total fleet average daily revenue | | $ | 472,500 | | $ | 475,600 | | $ | 458,600 | | |
| | | | | | | | | | | |
| | | Three months ended | | |||||||
| | | June 30, | | March 31, | | June 30, | | |||
Revenue Efficiency (2) | | | 2026 | | 2026 | | 2025 | | |||
Ultra-deepwater floaters | | | 95.7 | % | | 97.6 | % | | 96.7 | % | |
Harsh environment floaters | | | 99.5 | % | | 96.7 | % | | 96.3 | % | |
Total fleet average revenue efficiency | | | 97.0 | % | | 97.3 | % | | 96.6 | % | |
| | | Three months ended | | |||||||
| | | June 30, | | March 31, | | June 30, | | |||
Utilization (3) | | | 2026 | | 2026 | | 2025 | | |||
Ultra-deepwater floaters | | | 72.6 | % | | 82.1 | % | | 64.7 | % | |
Harsh environment floaters | | | 94.2 | % | | 100.0 | % | | 75.3 | % | |
Total fleet average rig utilization | | | 78.2 | % | | 86.7 | % | | 67.3 | % | |
| | | | | | | | | | | |
| | | | | | | | | | | |
(1) Average daily revenue is defined as operating revenues, excluding revenues for contract terminations, reimbursements and contract intangible amortization, earned per operating day. An operating day is defined as a day for which a rig is contracted to earn a dayrate during the firm contract period after operations commence. | |||||||||||
| | | | | | | | | | | |
(2) Revenue efficiency is defined as actual operating 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 the drilling unit could earn for the measurement period, excluding revenues for incentive provisions, reimbursements and contract terminations. | |||||||||||
| | | | | | | | | | | |
(3) 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. | |||||||||||
Transocean Ltd. and subsidiaries | | |||||||||||||||||||||
Non-GAAP Financial Measures and Reconciliations | | |||||||||||||||||||||
Adjusted Net Income (Loss) and Adjusted Diluted Earnings (Loss) Per Share | | |||||||||||||||||||||
(in millions, except per share data) | | |||||||||||||||||||||
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | YTD | | QTD | | YTD | | |||||||
| | | | | | | | | | 06/30/26 | | 06/30/26 | | 03/31/26 |
| |||||||
| | | | | | | | | | | | | | | | | | | | | | |
Net income | | | | | | | | | | | | | | $ | 241 | | $ | 170 | | $ | 71 | |
Acquisition and restructuring costs | | | | | | | | | | | | | | | 19 | | | 12 | | | 7 | |
Gain (loss) on disposal of assets, net | | | | | | | | | | | | | | | (2) | | | 3 | | | (5) | |
Loss on retirement of debt | | | | | | | | | | | | | | | 9 | | | — | | | 9 | |
Discrete tax items | | | | | | | | | | | | | |
| (137) | |
| (27) | |
| (110) | |
Adjusted Net Income (Loss) | | | | | | | | | | | | | | $ | 130 | | $ | 158 | | $ | (28) | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
Diluted earnings per share | | | | | | | | | | | | | | $ | 0.21 | | $ | 0.04 | | $ | 0.06 | |
Acquisition and restructuring costs | | | | | | | | | | | | | | | 0.02 | | | 0.01 | | | — | |
Gain (loss) on disposal of assets, net | | | | | | | | | | | | | | | — | | | — | | | — | |
Loss on retirement of debt | | | | | | | | | | | | | |
| 0.01 | |
| — | |
| 0.01 | |
Discrete tax items | | | | | | | | | | | | | |
| (0.12) | |
| (0.02) | |
| (0.10) | |
Adjusted Diluted Earnings (Loss) Per Share | | | | | | | | | | | | | | $ | 0.12 | | $ | 0.03 | | $ | (0.03) | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | YTD | | QTD | | YTD | | QTD | | YTD | | QTD | | YTD | | |||||||
| | 12/31/25 | | 12/31/25 | | 09/30/25 | | 09/30/25 | | 06/30/25 | | 06/30/25 | | 03/31/25 |
| |||||||
| | | | | | | | | | | | | | | | | | | | | | |
Net income (loss) attributable to controlling interest | | $ | (2,915) | | $ | 25 | | $ | (2,940) | | $ | (1,923) | | $ | (1,017) | | $ | (938) | | $ | (79) | |
Restructuring costs | | | 3 | | | — | | | 3 | | | 3 | | | — | | | — | | | — | |
Loss on impairment of assets, net of tax | | | 3,036 | | | — | | | 3,036 | | | 1,908 | | | 1,128 | | | 1,128 | | | — | |
Gain on disposal of assets, net | | | (4) | | | (4) | | | — | | | — | | | — | | | — | | | — | |
Loss on conversion of debt to equity | | | 99 | | | — | | | 99 | | | 75 | | | 24 | | | 24 | | | — | |
Gain on retirement of debt | | | (3) | | | (3) | | | — | | | — | | | — | | | — | | | — | |
Discrete tax items | |
| (179) | |
| 3 | |
| (182) | |
| (1) | |
| (181) | |
| (195) | |
| 14 | |
Adjusted Net Income (Loss) | | $ | 37 | | $ | 21 | | $ | 16 | | $ | 62 | | $ | (46) | | $ | 19 | | $ | (65) | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
Diluted earnings (loss) per share | | $ | (3.04) | | $ | 0.02 | | $ | (3.23) | | $ | (2.00) | | $ | (1.15) | | $ | (1.06) | | $ | (0.11) | |
Restructuring costs | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Loss on impairment of assets, net of tax | | | 3.16 | | | — | | | 3.34 | | | 1.98 | | | 1.27 | | | 1.27 | | | — | |
Gain on disposal of assets, net | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Loss on conversion of debt to equity | | | 0.10 | | | — | | | 0.11 | | | 0.08 | | | 0.03 | | | 0.03 | | | — | |
Gain on retirement of debt | |
| — | |
| — | |
| — | |
| — | |
| — | |
| — | |
| — | |
Discrete tax items | |
| (0.18) | |
| — | |
| (0.20) | |
| — | |
| (0.20) | |
| (0.22) | |
| 0.01 | |
Dilutive effect, 4.625% exchangeable bonds due December 2029 | | | — | | | — | | | (0.03) | | | — | | | (0.05) | | | (0.02) | | | — | |
Adjusted Diluted Earnings (Loss) Per Share | | $ | 0.04 | | $ | 0.02 | | $ | (0.01) | | $ | 0.06 | | $ | (0.10) | | $ | — | | $ | (0.10) | |
| | | | | | | | | | | | | | | | | | | | | | |
Transocean Ltd. and subsidiaries | | |||||||||||||||||||||
Non-GAAP Financial Measures and Reconciliations | | |||||||||||||||||||||
Earnings Before Interest, Taxes, Depreciation and Amortization and Related Margins | | |||||||||||||||||||||
(in millions, except percentages) | | |||||||||||||||||||||
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | YTD | | QTD | | YTD | | |||||||
| | | | | | | | | | 06/30/26 |
| 06/30/26 |
| 03/31/26 |
| |||||||
| | | | | | | | | | | | | | | | | | | | | | |
Contract drilling revenues | | | | | | | | | | | | | | $ | 2,047 | | $ | 966 | | $ | 1,081 | |
| | | | | | | | | | | | | | | | | | | | | | |
Net income | | | | | | | | | | | | | | $ | 241 | | $ | 170 | | $ | 71 | |
Interest expense, net of interest income | | | | | | | | | | | | | | | 234 | | | (32) | | | 266 | |
Income tax expense (benefit) | | | | | | | | | | | | | | | (40) | | | 14 | | | (54) | |
Depreciation and amortization | | | | | | | | | | | | | | | 291 | | | 148 | | | 143 | |
EBITDA | | | | | | | | | | | | | | | 726 | | | 300 | | | 426 | |
| | | | | | | | | | | | | | | | | | | | | | |
Acquisition and restructuring costs | | | | | | | | | | | | | | | 19 | | | 12 | | | 7 | |
Gain on disposal of assets, net | | | | | | | | | | | | | | | (4) | | | — | | | (4) | |
Loss on retirement of debt | | | | | | | | | | | | | | | 11 | | | — | | | 11 | |
Adjusted EBITDA | | | | | | | | | | | | | | $ | 752 | | $ | 312 | | $ | 440 | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
Profit margin | | | | | | | | | | | | | | | 11.8 | % | | 17.7 | % | | 6.5 | % |
EBITDA margin | | | | | | | | | | | | | | | 35.4 | % | | 31.0 | % | | 39.4 | % |
Adjusted EBITDA margin | | | | | | | | | | | | | | | 36.7 | % | | 32.2 | % | | 40.7 | % |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | YTD | | QTD | | YTD | | QTD | | YTD | | QTD | | YTD | | |||||||
| | 12/31/25 |
| 12/31/25 |
| 09/30/25 |
| 09/30/25 |
| 06/30/25 |
| 06/30/25 |
| 03/31/25 |
| |||||||
| | | | | | | | | | | | | | | | | | | | | | |
Contract drilling revenues | | $ | 3,965 | | $ | 1,043 | | $ | 2,922 | | $ | 1,028 | | $ | 1,894 | | $ | 988 | | $ | 906 | |
| | | | | | | | | | | | | | | | | | | | | | |
Net income (loss) | | $ | (2,915) | | $ | 25 | | $ | (2,940) | | $ | (1,923) | | $ | (1,017) | | $ | (938) | | $ | (79) | |
Interest expense, net of interest income | | | 515 | | | 163 | | | 352 | | | 142 | | | 210 | | | 102 | | | 108 | |
Income tax expense (benefit) | | | (33) | | | 57 | | | (90) | | | 26 | | | (116) | | | (155) | | | 39 | |
Depreciation and amortization | | | 659 | | | 147 | | | 512 | | | 161 | | | 351 | | | 175 | | | 176 | |
EBITDA | | | (1,774) | | | 392 | | | (2,166) | | | (1,594) | | | (572) | | | (816) | | | 244 | |
| | | | | | | | | | | | | | | | | | | | | | |
Restructuring costs | | | 3 | | | — | | | 3 | | | 3 | | | — | | | — | | | — | |
Loss on impairment of assets | | | 3,049 | | | — | | | 3,049 | | | 1,913 | | | 1,136 | | | 1,136 | | | — | |
Gain on disposal of assets, net | | | (4) | | | (4) | | | — | | | — | | | — | | | — | | | — | |
Gain on retirement of debt | | | (3) | | | (3) | | | — | | | — | | | — | | | — | | | — | |
Loss on conversion of debt to equity | | | 99 | | | — | | | 99 | | | 75 | | | 24 | | | 24 | | | — | |
Adjusted EBITDA | | $ | 1,370 | | $ | 385 | | $ | 985 | | $ | 397 | | $ | 588 | | $ | 344 | | $ | 244 | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
Profit (loss) margin | | | (73.5) | % | | 2.4 | % | | (100.6) | % | | (187.0) | % | | (53.7) | % | | (94.9) | % | | (8.7) | % |
EBITDA margin | | | (44.8) | % | | 37.5 | % | | (74.1) | % | | (154.9) | % | | (30.2) | % | | (82.5) | % | | 26.9 | % |
Adjusted EBITDA margin | | | 34.6 | % | | 36.8 | % | | 33.8 | % | | 38.7 | % | | 31.1 | % | | 34.9 | % | | 26.9 | % |
| | | | | | | | | | | | | | | | | | | | | | |
Transocean Ltd. and subsidiaries | ||||||||||||||||||||||
Non-GAAP Financial Measures and Reconciliations | ||||||||||||||||||||||
Free Cash Flow and Levered Free Cash Flow | ||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | YTD | | QTD | | YTD | | |||||||
| | | | | | | | | | 06/30/26 | | 06/30/26 | | 03/31/26 | | |||||||
| | | | | | | | | | | | | | | | | | | | | | |
Net cash provided by operating activities | | | | | | | | | | | | | | $ | 400 | | $ | 236 | | $ | 164 | |
Capital expenditures | | | | | | | | | | | | | | | (52) | | | (24) | | | (28) | |
Free Cash Flow | | | | | | | | | | | | | | | 348 | | | 212 | | | 136 | |
| | | | | | | | | | | | | | | | | | | | | | |
Debt repayments | | | | | | | | | | | | | | | (586) | | | (30) | | | (556) | |
Debt repayments, paid from debt proceeds | | | | | | | | | | | | | | | — | | | — | | | — | |
Levered Free Cash Flow | | | | | | | | | | | | | | $ | (238) | | $ | 182 | | $ | (420) | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
| | YTD | | QTD | | YTD | | QTD | | YTD | | QTD | | YTD | | |||||||
| | 12/31/25 | | 12/31/25 | | 09/30/25 | | 09/30/25 | | 06/30/25 | | 06/30/25 | | 03/31/25 | | |||||||
| | | | | | | | | | | | | | | | | | | | | | |
Net cash provided by operating activities | | $ | 749 | | $ | 349 | | $ | 400 | | $ | 246 | | $ | 154 | | $ | 128 | | $ | 26 | |
Capital expenditures | | | (123) | | | (28) | | | (95) | | | (11) | | | (84) | | | (24) | | | (60) | |
Free Cash Flow | | | 626 | | | 321 | | | 305 | | | 235 | | | 70 | | | 104 | | | (34) | |
| | | | | | | | | | | | | | | | | | | | | | |
Debt repayments | | | (1,556) | | | (1,106) | | | (450) | | | (210) | | | (240) | | | (30) | | | (210) | |
Debt repayments, paid from debt proceeds | | | 492 | | | 492 | | | — | | | — | | | — | | | — | | | — | |
Levered Free Cash Flow | | $ | (438) | | $ | (293) | | $ | (145) | | $ | 25 | | $ | (170) | | $ | 74 | | $ | (244) | |
| | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | |
Transocean Ltd. and subsidiaries | |||||||||||||||||
Non-GAAP Financial Measures and Reconciliations | |||||||||||||||||
Net Debt and Net Debt to EBITDA Ratio | |||||||||||||||||
(in millions, except ratios) | |||||||||||||||||
| | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | 06/30/26 | | | | 03/31/26 | |
| | | | | | | | | | | | | | | | | |
Debt, total principal amount | | | | | | | | | | | | $ 5,107 | | | | $ 5,137 | |
Cash and cash equivalents | | | | | | | | | | | | (509) | | | | (330) | |
Restricted cash and cash equivalents | | | | | | | | | | | | (286) | | | | (285) | |
Net Debt | | | | | | | | | | | | $ 4,312 | | | | $ 4,522 | |
| | | | | | | | | | | | | | | | | |
Adjusted EBITDA, trailing four quarters | | | | | | | | | | | | $ 1,534 | | | | $ 1,566 | |
| | | | | | | | | | | | | | | | | |
Net Debt to EBITDA Ratio | | | | | | | | | | | | 2.8 | x | | | 2.9 | x |
| | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | |
| | | | 12/31/25 | | | | 09/30/25 | | | | 06/30/25 | | | | 03/31/25 | |
| | | | | | | | | | | | | | | | | |
Debt, total principal amount | | | | $ 5,686 | | | | $ 6,297 | | | | $ 6,654 | | | | $ 6,734 | |
Cash and cash equivalents | | | | (620) | | | | (833) | | | | (377) | | | | (263) | |
Restricted cash and cash equivalents | | | | (377) | | | | (417) | | | | (395) | | | | (428) | |
Net Debt | | | | $ 4,689 | | | | $ 5,047 | | | | $ 5,882 | | | | $ 6,043 | |
| | | | | | | | | | | | | | | | | |
Adjusted EBITDA, trailing four quarters | | | | $ 1,370 | | | | $ 1,308 | | | | $ 1,253 | | | | $ 1,193 | |
| | | | | | | | | | | | | | | | | |
Net Debt to EBITDA Ratio | | | | 3.4 | x | | | 3.9 | x | | | 4.7 | x | | | 5.1 | x |
| | | | | | | | | | | | | | | | |
Transocean Ltd. and subsidiaries | | |||||||||||||||
Supplemental Effective Tax Rate Analysis | | |||||||||||||||
(in millions, except tax rates) | | |||||||||||||||
| | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | |
| | Three months ended | | Six months ended | | |||||||||||
| | June 30, | | March 31, | | June 30, | | June 30, | | June 30, |
| |||||
| | 2026 | | 2026 | | 2025 | | 2026 | | 2025 |
| |||||
| | | | | | | | | | | | | | | | |
Income (loss) before income taxes | | $ | 184 | | $ | 17 | | $ | (1,093) | | $ | 201 | | $ | (1,133) | |
Acquisition and restructuring costs | | | 12 | | | 7 | | | — | | | 19 | | | — | |
Loss on impairment of assets | | | — | | | — | | | 1,136 | | | — | | | 1,136 | |
Gain on disposal of assets, net | |
| — | |
| (4) | |
| — | |
| (4) | |
| — | |
Loss on conversion of debt to equity | |
| — | |
| — | |
| 24 | |
| — | |
| 24 | |
Loss on retirement of debt | |
| — | |
| 11 | |
| — | |
| 11 | |
| — | |
Adjusted income before income taxes | | $ | 196 | | $ | 31 | | $ | 67 | | $ | 227 | | $ | 27 | |
| | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | |
Income tax expense (benefit) | | $ | 14 | | $ | (54) | | $ | (155) | | $ | (40) | | $ | (116) | |
Acquisition and restructuring costs | |
| — | |
| — | |
| — | |
| — | | | — | |
Loss on impairment of assets | |
| — | |
| — | |
| 8 | |
| — | | | 8 | |
Gain on disposal of assets, net | |
| (3) | |
| 1 | |
| — | |
| (2) | |
| — | |
Loss on conversion of debt to equity | |
| — | |
| — | |
| — | |
| — | |
| — | |
Loss on retirement of debt | |
| — | |
| 2 | |
| — | |
| 2 | |
| — | |
Changes in estimates (1) | | | 27 | | | 110 | | | 195 | | | 137 | | | 181 | |
Adjusted income tax expense | | $ | 38 | | $ | 59 | | $ | 48 | | $ | 97 | | $ | 73 | |
| | | | | | | | | | | | | | | | |
Effective Tax Rate (2) | | | 7.8 | % | | (335.3) | % | | 14.2 | % | | (19.8) | % | | 10.3 | % |
| | | | | | | | | | | | | | | | |
Effective Tax Rate, excluding discrete items (3) | | | 19.4 | % | | 192.0 | % | | 70.0 | % | | 42.8 | % | | 268.9 | % |
| | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | |
(1) Our estimates change as we file tax returns, settle disputes with tax authorities, or become aware of changes in laws, operational changes and rig movements that have an effect on our (a) deferred taxes, (b) valuation allowances on deferred taxes and (c) other tax liabilities. | | |||||||||||||||
| | | | | | | | | | | | | | | | |
(2) Our effective tax rate is calculated as income tax expense or benefit divided by income or loss before income taxes. | | |||||||||||||||
| | | | | | | | | | | | | | | | |
(3) Our effective tax rate, excluding discrete items, is calculated as income tax expense or benefit, excluding various discrete items (such as changes in estimates and tax on items excluded from income or loss before income taxes), divided by income or loss before income taxes, excluding gains and losses on sales and similar items pursuant to the accounting standards for income taxes related to estimating the annual effective tax rate. | | |||||||||||||||
EXHIBIT 99.2
Transocean Ltd. Provides Quarterly Fleet Status Report
STEINHAUSEN, Switzerland—August 5, 2026—Transocean Ltd. (NYSE: RIG) today issued a quarterly Fleet Status Report that provides the current activity and contractual status of the Company’s fleet of offshore drilling rigs.
Updates
This quarter’s report includes the following updates:
| ◾ | Deepwater Conqueror – Awarded a two-well contract extension by an unnamed operator in the U.S. Gulf. |
| ◾ | Deepwater Proteus – Awarded a two-well contract with two one-well options by an unnamed operator in the U.S. Gulf. |
| ◾ | Deepwater Skyros – Awarded a one-well extension by Murphy in Ivory Coast. |
| ◾ | Transocean Norge – Awarded a five-well contract with three one-well options by Harbour Energy in Norway. |
| ◾ | Transocean Equinox – Awarded a two-well contract with five one-well options by Santos in Australia. |
The aggregate incremental backlog associated with these firm fixtures is approximately $292 million.
In addition, Equinor executed an agreement, conditional upon receipt of approvals from license partners, for three harsh environment semisubmersible rigs on the Norwegian shelf:
| ◾ | Transocean Enabler – Three-year program in direct continuation of the rig’s current program. |
| ◾ | Transocean Encourage – Two-year program in direct continuation of the rig’s current program. |
| ◾ | Transocean Endurance – Two-year program after conclusion of her current program and mobilization back to Norway from Australia. |
The total value of the Equinor agreement is approximately $1.0 billion.
As of August 5, 2026, the total backlog is approximately $6.7 billion. This figure excludes $1.0 billion of backlog for work with Equinor, which will be added subject to receipt of approvals from license partners.
The report can be accessed on the Company’s website: www.deepwater.com.
About Transocean
Transocean is a leading international provider of offshore contract drilling services for oil and gas wells. The Company specializes in technically demanding sectors of the global offshore drilling business with a particular focus on ultra-deepwater and harsh environment drilling services and operates the highest specification floating offshore drilling fleet in the world.
Transocean owns or has partial ownership interests in and operates a fleet of 27 mobile offshore drilling units,
consisting of 20 ultra-deepwater floaters and seven harsh environment floaters.
Forward-Looking Statements
The statements described herein that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements could contain words such as “approximately” or other similar expressions. Forward-looking statements are based on management’s current expectations and assumptions, and are subject to inherent uncertainties, risks and changes in circumstances that are beyond our control, and in many cases, cannot be predicted. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those indicated. Factors that could cause actual results to differ materially include, but are not limited to, the level of activity in offshore oil and gas exploration and development, exploration success by producers, operating hazards and delays, risks associated with international operations, actions by customers and other third parties, the fluctuation of current and future prices of oil and gas, the global and regional supply and demand for oil and gas, the intention to scrap certain drilling rigs, the effects of the spread of and mitigation efforts by governments, businesses and individuals related to contagious illnesses, and other factors, including our expectations regarding the timing, completion and anticipated benefits of the proposed business combination with Valaris Limited, an exempted company limited by shares incorporated under the laws of Bermuda, and other risks discussed in the Company’s most recent Annual Report on Form 10-K for the year ended December 31, 2025, and in the Company’s other filings with the SEC, which are available free of charge on the SEC’s website at: www.sec.gov. All subsequent written and oral forward-looking statements attributable to the Company 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. All non-GAAP financial measure reconciliations to the most comparative GAAP measure are displayed in quantitative schedules on the Company’s website at www.deepwater.com.
This press release, or referenced documents, do not constitute an offer to sell, or a solicitation of an offer to buy, any securities, and do not constitute an offering prospectus within the meaning of the Swiss Financial Services Act (“FinSA”) or advertising within the meaning of the FinSA. Nothing contained herein is, or shall be relied on as, a promise or representation as to the future performance of Transocean. Investors must rely on their own evaluation of Transocean and its securities, including the merits and risks involved, when making any investment decision involving Transocean securities.
Analyst Contact:
Sarah Davidson
+1 713-232-7217
Media Contact:
Kristina Mays
+1 713-232-7734
Updated: August 5, 2026 | | | | | | | | | | |
Significant Updates Noted in Bold | | | | | | | | | | |
| | Primary | | | | | | | Dayrate on | |
| | Hookload | Yr. | | | | Estimated | Estimated | Current | |
| Footnote | Capacity | Entered | | | | Start | End | Contract | |
Rig Type/Name | References | (Short Tons) | Service | Location | Customer | Status | Date | Date | (Dollars) | Additional Comments |
Ultra-Deepwater Drillships (20) | | | | | | | | | | |
Deepwater Titan | 1 | 1,700 | 2023 | USGOM | Chevron | Firm | Apr-23 | Apr-28 | 463,000 | |
Deepwater Atlas | | 1,700 | 2022 | USGOM | Beacon | Firm | Aug-26 | Oct-26 | 580,000 | |
| | | | USGOM | Beacon | Contingent | Oct-26 | Dec-26 | 650,000 | |
| | | | USGOM | Beacon | Firm | Dec-26 | Dec-26 | 580,000 | |
| | | | USGOM | Beacon | Contingent | Dec-26 | Feb-27 | 650,000 | |
| | | | USGOM | Beacon | Firm | Feb-27 | Feb-27 | 580,000 | |
| | | | USGOM | Beacon | Firm | Feb-27 | Jul-27 | 505,000 | |
| | | | USGOM | bp | Firm | Jun-28 | Jun-30 | 635,000 | |
Deepwater Aquila | 1, 2, 3 | 1,400 | 2024 | Brazil | Petrobras | Firm | Apr-26 | Dec-26 | 438,000 | |
| 1, 2, 3 | | | Brazil | Petrobras | Firm | Jan-27 | Jun-28 | 443,000 | |
Deepwater Poseidon | 1 | 1,400 | 2018 | USGOM | Shell | Firm | Sep-18 | Feb-28 | 501,000 | |
Deepwater Pontus | 1 | 1,400 | 2017 | USGOM | Shell | Firm | Oct-17 | Oct-27 | 499,000 | |
Deepwater Conqueror | | 1,400 | 2016 | USGOM | Not Disclosed | Firm | Oct-25 | Jan-27 | 530,000 | |
Deepwater Proteus | | 1,400 | 2016 | USGOM | Not Disclosed | Firm | Jul-26 | Nov-26 | Not Disclosed | |
| | | | USGOM | Not Disclosed | Priced Options | Nov-26 | Jan-27 | Not Disclosed | |
Deepwater Thalassa | 1 | 1,400 | 2016 | Mexico | Woodside | Firm | Mar-26 | Feb-29 | 495,000 | |
Deepwater Asgard | | | | Eastern Med | Not Disclosed | Firm | Dec-26 | Dec-27 | 405,000 | 20 days - Contract Preparation |
Deepwater Invictus | | 1,400 | 2014 | USGOM | bp | Firm | Apr-25 | Apr-28 | 485,000 | |
Deepwater Skyros | 3 | 1,250 | 2013 | Ivory Coast | Murphy | Firm | Dec-25 | Sep-26 | 361,000 | |
| 3 | 1,250 | 2013 | Ivory Coast | Murphy | Priced Option | Sep-26 | Nov-26 | 361,000 | |
| | | | Australia | Not Disclosed | Firm | Apr-27 | Mar-28 | Not Disclosed | |
| | | | Australia | Not Disclosed | Priced Options | Mar-28 | Aug-30 | Not Disclosed | |
Deepwater Corcovado | 1, 2, 3 | 1,000 | 2011 | Brazil | Petrobras | Firm | Apr-26 | Dec-26 | 379,000 | |
| 1, 2, 3 | | | Brazil | Petrobras | Firm | Jan-27 | Nov-30 | 390,000 | |
Deepwater Mykonos | 1, 2 | 1,000 | 2011 | - | - | Out of Service | May-26 | Aug-26 | - | 80 days - Contract Preparation |
| | | | Brazil | bp | Firm | Sep-26 | Jun-27 | 426,000 | |
Deepwater Orion | 1, 2, 3 | 1,000 | 2011 | Brazil | Petrobras | Firm | Apr-26 | Dec-26 | 375,000 | |
| 1, 2, 3 | | | Brazil | Petrobras | Firm | Jan-27 | Mar-30 | 390,000 | |
Dhirubhai Deepwater KG2 | | 1,000 | 2010 | | - | Idle | May-26 | | - | |
Petrobras 10000 | 1, 2 | 1,000 | 2009 | Brazil | Petrobras | Firm | Oct-25 | Oct-26 | 416,000 | |
| | | | Brazil | Petrobras | Firm | Oct-26 | Oct-27 | 428,000 | |
| 1, 2 | | | Brazil | Petrobras | Firm | Oct-27 | Oct-28 | 441,000 | |
| 1, 2 | | | Brazil | Petrobras | Firm | Oct-28 | Aug-29 | 454,000 | |
Dhirubhai Deepwater KG1 | | 1,000 | 2009 | - | - | Out of Service | Jun-26 | Aug-26 | - | 70 days - Contract Preparation |
| | | | India | Reliance Industries | Firm | Aug-26 | Mar-28 | 410,000 | |
| | | | India | Reliance Industries | Priced Options | Mar-28 | Aug-29 | Not Disclosed | |
Ocean Rig Apollo | | 1,250 | 2015 | | | Stacked | | | | Stacked May-16 |
Ocean Rig Athena | | 1,250 | 2014 | | | Stacked | | | | Stacked Mar-17 |
Ocean Rig Mylos | | 1,250 | 2013 | | | Stacked | | | | Stacked Sep-16 |
| | | | | | | | | | |
| | | | Q3 2026 | Q4 2026 | Q1 2027 | Q2 2027 | | | |
| | Estimated Average Contract Dayrates (4) | | $451,000 | $451,000 | $449,000 | $447,000 | | | |
| | | | | | | | | | |
Harsh Environment Semisubmersibles (7) | | | | | | | | | | |
Transocean Norge | 1, 2, 3 | | | Norway | Harbour Energy / OMV | Firm | Jun-26 | Jan-28 | 472,000 | |
| 1, 2 | | | Norway | Harbour Energy | Firm | Jan-28 | Nov-28 | 513,000 | |
| 1, 2 | | | Norway | Harbour Energy | Priced Options | Nov-28 | Mar-29 | Not Disclosed | |
Transocean Spitsbergen | 1, 2, 3 | 1,000 | 2010 | Norway | Equinor | Firm | Jun-26 | Mar-27 | 413,000 | |
| 1, 2, 3 | | | Norway | Equinor | Firm | Mar-27 | Nov-27 | 515,000 | |
Transocean Barents | 1 | 1,000 | 2009 | Romania | OMV Petrom S.A. | Firm | Mar-25 | Sep-26 | 482,000 | |
| 1 | | | Romania | OMV Petrom S.A. | Firm | Sep-26 | Feb-27 | 498,000 | |
| | | | - | - | Out of Service | Feb-27 | Jul-27 | - | 135 days - Mobilization & Contract Preparation |
| 1, 2 | | | Norway | Vår Energi ASA | Firm | Jul-27 | Jul-30 | 467,000 | |
| 1, 2 | | | Norway | Vår Energi ASA | Priced Options | Jul-30 | Jul-34 | Not Disclosed | |
Transocean Enabler | 1, 2, 3 | 750 | 2016 | Norway | Equinor | Firm | May-26 | Jan-27 | 436,000 | |
| | | | Norway | Equinor | Firm | Jan-27 | Mar-28 | 476,000 | |
| 1, 2, 3, 5 | | | Norway | Equinor | Firm | Mar-28 | Mar-31 | 399,000 | |
Transocean Encourage | 1, 2, 3 | 750 | 2016 | Norway | Equinor | Firm | Jan-26 | May-27 | 511,000 | |
| 1, 2, 3 | | | Norway | Equinor | Firm | May-27 | May-28 | 437,000 | |
| 1, 2, 3, 5 | | | Norway | Equinor | Firm | May-28 | May-30 | 399,000 | |
Transocean Endurance | | | | Australia | Woodside | Firm | Jul-26 | Nov-26 | 390,000 | |
| 1, 2, 3, 5 | | | Norway | Equinor | Firm | Jun-27 | Jun-29 | 399,000 | |
Transocean Equinox | | 750 | 2015 | Australia | Not Disclosed | Firm | Apr-26 | Aug-26 | 485,000 | |
| | | | Australia | Not Disclosed | Firm | Aug-26 | Oct-26 | 540,000 | |
| | | | Australia | Not Disclosed | Priced Option | Oct-26 | Nov-26 | Not Disclosed | |
| | | | Australia | Santos Limited | Firm | Apr-27 | Jun-27 | 395,000 | |
| | | | Australia | Santos Limited | Priced Options | Jun-27 | Oct-27 | Not Disclosed | |
| | | | | | | | | | |
| | | | Q3 2026 | Q4 2026 | Q1 2027 | Q2 2027 | | | |
| | Estimated Average Contract Dayrates (4) | | $462,000 | $459,000 | $476,000 | $468,000 | | | |
| Revisions Noted in Bold |
Footnotes | |
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1 | Dayrate could change in the future due to cost escalations or de-escalations. |
2 | Dayrate includes a non-USD currency component. |
3 | The contract has a bonus incentive opportunity that is not reflected in the contract dayrate. |
4 | The average contractual dayrate relative to our contract backlog is defined as the average maximum contractual operating dayrate to be earned per operating day and certain performance-based provisions expected to be achieved in the measurement period |
5 | Conditional upon receipt of approvals from license partners. |
Disclaimers & Definitions | |
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The information contained in this Fleet Status Report (the “Information”) is as of the date of the report only and is subject to change without notice to the recipient. Transocean Ltd. assumes no duty to update any portion of the Information. | |
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DISCLAIMER. NEITHER TRANSOCEAN LTD. NOR ITS AFFILIATES MAKE ANY EXPRESS OR IMPLIED WARRANTIES (INCLUDING, WITHOUT LIMITATION, ANY WARRANTY OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE OR USE) REGARDING THE INFORMATION CONTAINED IN THIS REPORT, WHICH INFORMATION IS PROVIDED “AS IS.” Neither Transocean Ltd. nor its affiliates will be liable to any recipient or anyone else for any inaccuracy, error or omission, regardless of cause, in the information set forth in this report or for any damages (whether direct or indirect, consequential, punitive or exemplary) resulting therefrom. | |
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No Unauthorized Publication or Use. All information provided by Transocean in this report is given for the exclusive use of the recipient and may not be published, redistributed or retransmitted without the prior written consent of Transocean. | |
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Customer Contract Duration, Timing and Dayrates and Risks Associated with Operations. The duration and timing (including both starting and ending dates) of the customer contracts are estimates only, and customer contracts are subject to cancellation, suspension and delays for a variety of reasons, including some beyond the control of Transocean. Also, the dayrates set forth in the report are estimates based upon the full contractual operating dayrate. However, the actual average dayrate earned over the course of any given contract will be lower and could be substantially lower. The actual average dayrate will depend upon a number of factors (rig downtime, suspension of operations, etc.) including some beyond the control of Transocean. Our customer contracts and operations are generally subject to a number of risks and uncertainties, and we urge you to review the description and explanation of such risks and uncertainties in our filings with the Securities and Exchange Commission (SEC), which are available free of charge on the SEC’s website at www.sec.gov. The dayrates do not include revenue for mobilizations, demobilizations, upgrades, shipyards or recharges. | |
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Contract backlog. The maximum contractual operating dayrate multiplied by the number of days remaining in the firm contract period, including certain performance-based provisions for which achievement is probable, excluding provisions for mobilization, demobilization, contract preparation, other incentive provisions or reimbursement revenues, which are not expected to be material to our contract drilling revenues. The contract backlog represents the maximum contract drilling revenues that can be earned considering the reported operating dayrate in effect during the firm contract period. | |
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Out of Service. The time associated with committed shipyards, upgrades, surveys, repairs, regulatory inspections, contract preparation or other committed activity on the rig and is not expected to earn an operating dayrate, Contract preparation refers to periods during which the rig is undergoing modifications or upgrades as a result of contract requirements. | |
• | The references included in this Fleet Status Report may not be firm and could change significantly based on a variety of factors. Any significant changes to our estimates of out of service time will be reflected in subsequent Fleet Status Reports, as applicable. |
• | In some instances such as certain mobilizations, upgrades and shipyards, we are paid compensation by our customers that is generally recognized over the life of the primary contract term of the drilling contract. |
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Forward-Looking Statement. The statements made in the Fleet Status Report that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements made in the Fleet Status Report include, but are not limited to, statements involving the estimated duration of customer contracts, contract dayrate amounts, future contract commencement dates and locations and planned shipyard projects and other out of service time. Such statements are subject to numerous risks, uncertainties and assumptions, including but not limited to, uncertainties relating to the level of activity in offshore oil and gas exploration and development, exploration success by producers, oil and gas prices, competition and market conditions in the contract drilling industry, shipyard delays, actions and approvals of third parties, possible cancellation or suspension of drilling contracts as a result of mechanical difficulties or performance, Transocean’s ability to enter into and the terms of future contracts, the availability of qualified personnel, labor relations and the outcome | |
of negotiations with unions representing workers, operating hazards, factors affecting the duration of contracts including well-in-progress provisions, the actual amount of downtime, factors resulting in reduced applicable dayrates, hurricanes and other weather conditions, terrorism, political and other uncertainties inherent in non-U.S. operations (including the risk of war, civil disturbance, seizure or damage of equipment and exchange and currency fluctuations), the impact of governmental laws and regulations, the adequacy of sources of liquidity, the effect of litigation and contingencies and other factors described above and discussed in Transocean’s most recently filed Form 10-K, in Transocean’s Forms 10-Q for subsequent periods and in Transocean’s other filings with the SEC, which are available free of charge on the SEC’s website at www.sec.gov. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those indicated. You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statements, except as required by law. | |
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Fleet Classifications. Transocean uses classifications for its drillships and semisubmersibles as follows: “Ultra-Deepwater” are the latest generation of drillships and semisubmersible rigs and are capable of drilling in water depths equal to or greater than 7,500 feet; “Harsh Environment” are premium rigs equipped for year-round operations in harsh environments. | |
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Stacking. An "Idle" rig is primarily between contracts, readily available for operations, and operating costs are typically at or near normal levels. A "Stacked" rig, on the other hand, is primarily manned by a reduced crew or unmanned and typically has reduced operating costs and is (i) preparing for an extended period of inactivity, (ii) expected to continue to be inactive for an extended period, or (iii) completing a period of extended inactivity. However, stacked rigs will continue to incur operating costs at or above normal operating costs for approximately 30 days following initiation of stacking. | |