Transocean Ltd. - Annual Report: 2020 (Form 10-K)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

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FORM 10-K

(Mark one)

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

For the fiscal year ended December 31, 2020

OR

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

For the transition period from _____ to _____

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Commission file number 001-38373

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TRANSOCEAN LTD.

(Exact name of registrant as specified in its charter)

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

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

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Securities registered pursuant to Section 12(g) of the Act: None

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Indicate by check mark whether the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.   Yes ☑   No ☐

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.   Yes ☐   No ☑

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 ☑   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 during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).   Yes ☑   No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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 ☑ 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 has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐

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

As of June 30, 2020, 614,612,545 shares were outstanding and the aggregate market value of shares held by non-affiliates was approximately $1.12 billion (based on the reported closing market price of the shares of Transocean Ltd. on June 30, 2020 of $1.83 per share and assuming that all directors and executive officers of the Company are “affiliates,” although the Company does not acknowledge that any such person is actually an “affiliate” within the meaning of the federal securities laws).  As of February 16, 2021, 616,025,144 shares were outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s definitive Proxy Statement to be filed with the United States Securities and Exchange Commission within 120 days of December 31, 2020, for its 2021 annual general meeting of shareholders, are incorporated by reference into Part III of this Form 10-K.

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TRANSOCEAN LTD. AND SUBSIDIARIES

INDEX TO ANNUAL REPORT ON FORM 10-K

FOR THE YEAR ENDED DECEMBER 31, 2020

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Forward-Looking Information

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

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

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

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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PART I

Item 1.Business

Overview

Transocean Ltd. (together with its subsidiaries and predecessors, unless the context requires otherwise, “Transocean,” the “Company,” “we,” “us” or “our”) is a leading international provider of offshore contract drilling services for oil and gas wells.  As of February 16, 2021, we owned or had partial ownership interests in and operated a fleet of 37 mobile offshore drilling units, consisting of 27 ultra-deepwater floaters and 10 harsh environment floaters.  As of February 16, 2021, we were constructing two ultra-deepwater drillships.

Our primary business is to contract our drilling rigs, related equipment and work crews predominantly on a dayrate basis to drill oil and gas wells.  We specialize in technically demanding regions of the global offshore drilling business with a particular focus on ultra-deepwater and harsh environment drilling services.  Our mobile offshore drilling fleet is one of the most versatile fleets in the world, consisting of drillship and semisubmersible floaters used in support of offshore drilling activities and offshore support services on a worldwide basis.

Transocean Ltd. is a Swiss corporation with its registered office in Steinhausen, Canton of Zug and with principal executive offices located at Turmstrasse 30, 6312 Steinhausen, Switzerland.  Our telephone number at that address is +41 41 749-0500.  Our shares are listed on the New York Stock Exchange under the ticker symbol “RIG.”  For information about the revenues, operating income, assets and other information related to our business, our segments and the geographic areas in which we operate, see “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 20—Operating Segments, Geographic Analysis and Major Customers.”

Drilling Fleet

Overview—Our drilling fleet of floaters consists of drillships and semisubmersibles, which are mobile and can be moved to new locations in response to customer demand.  Our drilling equipment is suitable for both exploration and development, and we engage in both types of drilling activity.  Our mobile offshore drilling units are designed to operate in locations away from port for extended periods of time and have living quarters for the crews, a helicopter landing deck and storage space for drill pipe, riser and drilling supplies.

Drillships are generally self-propelled vessels, shaped like conventional ships, and are the most mobile of the major rig types.  Our high-specification drillships are equipped with dynamic positioning thruster systems, which allows them to maintain position without anchors through the use of onboard propulsion and station-keeping systems.  Ultra-deepwater drillships typically have greater deck load and storage capacity than early generation semisubmersible rigs, which provides logistical and resupply efficiency benefits for customers.  Drillships are generally better suited to operations in calmer sea conditions and typically do not operate in areas considered to be harsh environments.  We have 22 ultra-deepwater drillships that are, and two ultra-deepwater drillships under construction that will be, equipped with our patented dual-activity technology.  Dual-activity technology employs structures, equipment and techniques using two drilling stations within a dual derrick to allow these drillships to perform simultaneous drilling tasks in a parallel, rather than a sequential manner, which reduces critical path activity and improves efficiency in both exploration and development drilling.  In addition to dynamic positioning thruster systems, dual-activity technology and industry-leading hoisting capacity, our contracted newbuild drillship under construction will be equipped with two 20,000 pounds per square inch (“psi”) blowout preventers and, if the relevant conditions are satisfied, our newbuild drillship with a conditional agreement will be equipped with one 20,000 psi blowout preventer as required by the conditional agreement and will be equipped to accommodate a second 20,000 psi blowout preventer.

Semisubmersibles are floating vessels that can be partially submerged by means of a water ballast system such that the lower column sections and pontoons are below the water surface during drilling operations.  Semisubmersibles are known for stability, making them well suited for operating in rough sea conditions.  Semisubmersible floaters are capable of maintaining their position over a well either through dynamic positioning or the use of mooring systems.  Although most semisubmersible rigs are relocated with the assistance of tugs, some units are self-propelled and move between locations under their own power when afloat on pontoons.  Four of our 13 semisubmersibles are equipped with dual-activity technology and also have mooring capability.  Two of these four dual-activity units are custom-designed, high capacity semisubmersible drilling rigs, equipped for year-round operations in harsh environments, including those of the Norwegian continental shelf and sub-Arctic waters.

Fleet categories—We further categorize the drilling units of our fleet as follows: (1) “ultra-deepwater floaters” and (2) “harsh environment floaters.”  Ultra-deepwater floaters are equipped with high-pressure mud pumps and are capable of drilling in water depths of 4,500 feet or greater.  Harsh environment floaters are capable of drilling in harsh environments in water depths between 1,500 and 10,000 feet and have greater displacement, which offers larger variable load capacity, more useable deck space and better motion characteristics.

Fleet status—Depending on market conditions, we may idle or stack our non-contracted rigs.  An idle rig is between drilling contracts, readily available for operations, and operating costs are typically at or near normal operating levels.  A stacked rig typically has reduced operating costs, is staffed by a reduced crew or has no crew and is (a) preparing for an extended period of inactivity, (b) expected to continue to be inactive for an extended period, or (c) completing a period of extended inactivity.  Stacked rigs will continue to incur operating

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costs at or above normal operating levels for approximately 30 days following initiation of stacking.  Some idle rigs and all stacked rigs require additional costs to return to service.  The actual cost to return to service, which in many instances could be significant and could fluctuate over time, depends upon various factors, including the availability and cost of shipyard facilities, the cost of equipment and materials, the extent of repairs and maintenance that may ultimately be required and time and cost of assembling and training crew.  We consider these factors, together with market conditions, length of contract, dayrate and other contract terms, when deciding whether to return a stacked rig to service.  We may not return some stacked rigs to work for drilling services.

Drilling units—The following tables, presented as of February 12, 2021, provide certain specifications for our rigs.  Unless otherwise noted, the stated location of each rig indicates either the current drilling location, if the rig is operating, or the next operating location, if the rig is in shipyard with a follow-on contract.  The dates provided represent the expected time of completion, the year placed into service, and, if applicable, the year of the most recent upgrade.  As of February 12, 2021, we owned all of the drilling rigs in our fleet noted in the tables below, except for the following: (1) the harsh environment floater Transocean Norge, which is owned through our 33.0 percent ownership interest in Orion Holdings (Cayman) Limited (together with its subsidiary, “Orion”), and (2) the ultra-deepwater floater Petrobras 10000, which is subject to a finance lease through August 2029.

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Drilling Contracts

Our contracts to provide offshore drilling services are individually negotiated and vary in their terms and conditions.  We obtain most of our drilling contracts through competitive bidding against other contractors and direct negotiations with operators.  Drilling contracts generally provide for payment on a dayrate basis, with higher rates for periods while the drilling unit is operating and lower rates or zero rate for periods of mobilization or when drilling operations are interrupted or restricted by equipment breakdowns, adverse environmental conditions or other conditions beyond our control.  A dayrate drilling contract generally extends over a period of time either covering the drilling of a single well or group of wells or covering a stated term.  At December 31, 2020, our contract backlog was approximately $8.1 billion, representing a decrease of 22 percent and a decrease of 35 percent, respectively, compared to the contract backlog at December 31, 2019 and 2018, which was $10.4 billion and $12.5 billion, respectively.  See “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Performance and Other Key Indicators.”

Certain of our drilling contracts may be cancelable for the convenience of the customer, typically with the payment of an early termination payment.  Such payments, however, may not fully compensate us for the loss of the contract.  Contracts also customarily provide for either automatic termination or termination at the option of the customer, typically without payment of any termination fee, under various circumstances such as non-performance, in the event of extended downtime or impaired performance due to equipment or operational issues or periods of extended downtime due to force majeure events.  Many of these events are beyond our control.  The contract term in some instances may be extended by the customer exercising options for the drilling of additional wells or for an additional term.  Our contracts also typically include a provision that allows the customer to extend the contract to finish drilling a well-in-progress.  During periods of depressed market conditions, our customers may seek to renegotiate firm drilling contracts to reduce the term of their obligations or the average dayrate through term extensions, or may seek to early terminate or repudiate their contracts.  Suspension of drilling contracts will result in the reduction in or loss of dayrate for the period of the suspension.  If our customers cancel some of our contracts and we are unable to secure new contracts on a timely basis and on substantially similar terms, if contracts are suspended for an extended period of time or if a number of our contracts are renegotiated, it could adversely affect our consolidated financial position, results of operations or cash flows.  See “Item 1A. Risk Factors—Risks related to our business—Our drilling contracts may be terminated due to a number of events, and, during depressed market conditions, our customers may seek to repudiate or renegotiate their contracts.”

Under dayrate drilling contracts, consistent with standard industry practice, our customers, as the operators, generally assume, and grant indemnity for, subsurface and well control risks, and their consequential damages.  Under all of our current drilling contracts, our customers, indemnify us for pollution damages in connection with reservoir fluids stemming from operations under the contract, and we indemnify our customers for pollution that originates above the surface of the water from the rig from substances in our control, such as diesel used onboard the rig or other fluids stored onboard the rig.  Also, our customers indemnify us for consequential damages they incur, damage to the well or reservoir, loss of subsurface oil and gas and the cost of bringing the well under control.  However, our drilling contracts are individually negotiated, and the degree of indemnification we receive from our customers for the risks discussed above may vary from contract to contract, based on market conditions and customer requirements existing when the contract was negotiated.  In some instances, we have contractually agreed upon certain limits to our indemnification rights and can be responsible for damages up to a specified maximum dollar amount.  The nature of our liability and the prevailing market conditions, among other factors, can influence such contractual terms.  In most instances in which we are indemnified for damages to the well, we have the responsibility to redrill the well at a reduced dayrate.  Notwithstanding a contractual indemnity from a customer, there can be no assurance that our customers will be financially able to indemnify us or will otherwise honor their contractual indemnity obligations.

The interpretation and enforceability of a contractual indemnity depends upon the specific facts and circumstances involved, as governed by applicable laws, and may ultimately need to be decided by a court or other proceeding, which will need to consider the specific contract language, the facts and applicable laws.  The law generally considers contractual indemnity for criminal fines and penalties to be against public policy.  Courts also restrict indemnification for criminal fines and penalties.  The inability or other failure of our customers to fulfill their indemnification obligations, or unenforceability of our contractual protections could have a material adverse effect on our consolidated financial position, results of operations or cash flows.  See “Item 1A. Risk Factors—Risks related to our business—Our business involves numerous operating hazards, and our insurance and indemnities from our customers may not be adequate to cover potential losses from our operations.”

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Markets

Our operations are geographically dispersed in oil and gas exploration and development areas throughout the world.  We operate in a single, global offshore drilling market, as our drilling rigs are mobile assets and can be moved according to prevailing market conditions.  We may mobilize our drilling rigs between regions for a variety of reasons, including to respond to customer contracting requirements or to capture observed market demand.  Consequently, we cannot predict the future percentage of our revenues that will be derived from particular geographic areas.  As of February 12, 2021, our drilling fleet, including stacked and idle rigs, but excluding rigs under construction, was located in Greece (eight units), the Norwegian North Sea (seven units), the U.S. Gulf of Mexico (seven units), Brazil (three units), Malaysia (three units), the United Kingdom (the “U.K.”) North Sea (two units), Trinidad (two unit), Angola (one unit), Canada (one unit), India (one unit), Myanmar (one unit), and Namibia (one unit).

We categorize the market sectors in which we operate as follows: (1) ultra-deepwater and deepwater, (2) harsh environment, and (3) midwater.  We offer our drilling services across all of these market sectors, collectively known as the floater market, with our drillships and semisubmersibles, 11 of which are suited to work in harsh environments.  We generally view the ultra-deepwater and deepwater market sector as water depths beginning at 4,500 feet and extending to the maximum water depths in which rigs are capable of drilling, which is currently up to 12,000 feet.  The midwater market sector includes water depths from approximately 300 feet to approximately 4,500 feet.  The harsh environment market sector includes regions that are more challenged by lower temperatures, harsher weather conditions and water currents.

The market for offshore drilling rigs and related services reflects oil companies’ demand for equipment for drilling exploration, appraisal and development wells and for performing maintenance on existing production wells.  Activity levels of energy companies, including integrated oil companies, independent oil companies and, to a lesser extent, national oil companies are largely driven by the worldwide demand for energy, including crude oil and natural gas.  Worldwide energy supply and demand drives oil and natural gas prices, which, in turn, impact energy companies’ ability to fund investments in exploration, development and production activities.

Since 2014, the industry has experienced a severe cyclical downturn of considerably longer duration than those previously observed.  Multiple years of volatile and generally weak commodity prices, exacerbated in 2020 by the effects of the COVID-19 pandemic and production disputes among major oil producing countries, have resulted in our customers repeatedly delaying offshore investment decisions and postponing exploration and development programs.  Some of our customers have also recently committed to invest or increase investment in low carbon and renewable energy resources, potentially reducing their expenditures in the development and production of hydrocarbons over the coming decades.  However, even in the context of some diversion of investment away from traditional sources of energy, the structural efficiency gains achieved by the offshore oil and gas segment in the past six years have materially improved the economics of deepwater offshore development projects, making the segment a competitive source of new supply.

We anticipate that the subdued level of contract activity will continue for at least the first half of 2021, although we believe that by the second half of 2021, our customers will again focus on favorable deepwater offshore economics and begin increasing their exploration, production and reserve replacement activities by restarting delayed projects and commencing new campaigns.  This depends on many variables, including global amelioration of the COVID-19 pandemic and the effects of actions by some governments and regulators intended to curtail existing and future drilling activities, and other factors.

Our overall outlook for the offshore drilling sector remains positive, particularly for high-specification assets.  Brazil, the U.S. Gulf of Mexico, and to a lesser extent, West Africa remain key ultra-deepwater market sectors, while Norway represents the largest harsh environment market.  In addition, in 2020, we saw continued strong tendering activity for Asia and Australia.  Licensing activity also indicated an increased interest in these areas as energy companies looked to explore and develop new prospects.

As the economics of offshore development projects have materially improved, we expect deepwater oil and gas production will continue to be a significant part of the long-term strategy for energy companies as they strive to replace reserves to meet global demand for energy sources and hydrocarbons.  .  These projects are technically demanding due to factors such as water depth, complex well designs, deeper drilling depth, high pressure and temperature, sub-salt geological formations, harsh environments, and heightened regulatory standards; therefore, they require high-specification drilling units.

Generally, high-specification rigs are the most modern, technologically advanced class of the offshore fleet and have capabilities that are attractive to energy companies operating in deeper water depths, other challenging environments or with complex well designs.  We have led the industry and made concerted efforts since the beginning of the prolonged downturn to high-grade our fleet profile by acquiring high-specification assets and disposing of lower-specification assets.  In the year ended December 31, 2018, we significantly enhanced our high-specification asset portfolio with our acquisitions of (i) Songa Offshore SE, (ii) Ocean Rig UDW Inc. and (iii) a 33.0 percent ownership interest in Orion.  During the years ended December 31, 2020, 2019 and 2018, we sold for scrap value six, eleven and eight lower-specification drilling units, respectively.

Ultimately, as the hydrocarbon supply-demand balance improves, including as the result of a post-pandemic global economic recovery, we expect a sustained improvement of oil prices, which will result in greater demand for our high-specification fleet of assets, resulting in further improvement of dayrates.  Consequently, when considering the reduced supply of offshore drilling units and expected increase in demand, we expect dayrates for our services should steadily increase over the next several years.  See “Item 1A. Risk Factors—Risks related to our business.”

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Customers

We provide our offshore drilling services to most of the leading integrated oil companies or their affiliates, as well as for many government-owned or government-controlled oil companies and other independent oil companies.  For the year ended December 31, 2020, our most significant customers were Royal Dutch Shell plc (together with its affiliates, “Shell”), Equinor ASA (together with its affiliates, “Equinor”) and Chevron Corporation (together with its affiliates, “Chevron”), representing approximately 28 percent, 27 percent and 14 percent, respectively, of our consolidated operating revenues.  No other customers accounted for 10 percent or more of our consolidated operating revenues in the year ended December 31, 2020.  Additionally, as of February 12, 2021, the customers with the most significant aggregate amount of contract backlog associated with our drilling contracts were Shell, Equinor and Chevron, representing approximately 53 percent, 23 percent and 13 percent, respectively, of our total contract backlog.  See “Item 1A. Risk Factors—Risks related to our business—We rely heavily on a relatively small number of customers and the loss of a significant customer or a dispute that leads to the loss of a customer could have an adverse effect on our business.”

Human Capital Resources

Worldwide workforce—As of December 31, 2020, we had a global workforce of approximately 5,350 individuals, including approximately 530 contractors, representing 56 nationalities.  At December 31, 2020, our global workforce is geographically distributed in 25 countries across five continents as follows: 34 percent in Europe, 32 percent in North America, 18 percent in South America, 11 percent in Asia and 5 percent in Africa.

Approximately 43 percent of our total workforce, working primarily in Norway, Brazil and the U.K., are represented by, and some of our contracted labor work is subject to, collective bargaining agreements, substantially all of which are subject to annual salary negotiation.  Negotiations over annual salary or other labor matters could result in higher personnel or other costs or increased operational restrictions or disruptions.  The outcome of any such negotiation generally affects the market for all offshore employees, not only union members.  Furthermore, a failure to reach an agreement on certain key issues could result in strikes, lockouts or other work stoppages.

FIRST Shared Values and corporate culture—Our FIRST Shared Values guide us to act responsibly as we strive to deliver value for our stakeholders, and they form the foundation of our corporate culture as follows:

Development, attraction and retention—We are committed to being the world’s premier offshore drilling contractor, which requires that we develop, retain and attract the industry’s best workforce.  For that reason, we offer regionally competitive compensation and benefits packages, a technically challenging work environment, global opportunities, and rotational development programs.  In addition, our team remains abreast of industry and technology trends and their transformative effects on our work environment.  These advancements necessitate that we continuously develop our workforce, ensuring that they have the skills and competencies for our organization to realize the full benefits of these advancements and responsibly deliver value to our stakeholders.

Training—We maintain a rigorous competency-based training program.  Our internal training board maintains and regularly updates our training matrix to meet or exceed industry standards, and it oversees our competency assurance management system, which is accredited by the Offshore Petroleum Industry Training Organization.  Offshore training formats include on-the-job, e-learning, customer-specific training, certifications, and leadership and licensing programs.  Unique simulation-based education, augmented by digital twin modeling, enables our workforce to more accurately visualize equipment performance and target efficiencies.  The certifications, skills and competencies needed for each role are clearly articulated to our workforce, and workers are required to successfully complete the relevant training and attain all necessary certifications prior to taking on new roles.

Wellness and benefits—We strive to offer regionally competitive medical and financial benefits, tailored to our workforce demographics, particularly in terms of generational segmentation.  We design our wellness and benefits strategy under four pillars consisting of physical well-being, financial well-being, emotional well-being and social well-being.

Safety—Our safety vision is to conduct our operations in an incident-free workplace, all the time, everywhere.  We prioritize protection of our people, the environment and our property at all work locations and during all operations, and we require compliance with all local regulations and a comprehensive set of internal policies and procedures that govern our operations.  With regular competency and effectiveness assessments, our highly trained crews are equipped to protect our operational integrity with the process-driven management of hazards to prevent and mitigate major hazard accidents.  At the start of the COVID-19 pandemic, we moved quickly to enact additional health and safety protocols for COVID-19 mitigation, and we have keenly focused on enhanced communication and employee support to engage our workforce in a remote work environment.

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We measure our safety performance in terms of widely accepted ratios with the use of industry standards, including (a) the total recorded incidence rate (“TRIR”), which represents the number of work-related injuries or illnesses for every 200,000 hours worked, and (b) the lost time incidence rate (“LTIR”), which measures the number of incidents that result in lost time due to work-related injuries for every 200,000 hours worked.  In the year ended December 31, 2020, our TRIR was 0.24, and our LTIR was 0.0.

Environmental Responsibility

We constantly look for new ways to advance our commitment to safely performing our operations while simultaneously safeguarding the environment in which we operate.  We assess the environmental impacts of our operations, focusing on the reduction of greenhouse gas emissions, operational discharges and water use, through increasing energy efficiency and waste minimization.  Our actions are designed to reduce risk in our current and future operations, to promote sound environmental management practices and to continue to be proactive in managing and reducing our environmental footprint.  Our investments and deployment of capital and technology reflect our commitment to improve the energy and emission efficiency of our operations.

When we have decommissioned older and less capable assets, we have demonstrated our commitment to recycle them according to established environmental regulations and guidelines.  All the rigs that we have sold for scrap value have been safely and responsibly recycled following protocols established under the Basel Convention and by the International Maritime Organization at the Hong Kong International Convention.

Technological Innovation

We have a long history of technological innovation, including the first dynamically positioned drillship, the first rig to drill year-round in the North Sea, the first semisubmersible rig for year-round sub-Arctic operations, the first 10,000-ft. water depth rated ultra-deepwater drillship and numerous water depth world records over the past several decades.  Twenty-two drillships and two semisubmersibles in our existing fleet are, and our two drillships that are under construction will be, equipped with our patented dual-activity technology, which allows our rigs to perform simultaneous drilling tasks in a parallel rather than sequential manner, reducing well construction critical path activities and, thereby, improving efficiency in both exploration and development drilling.

We continue to develop and deploy industry-leading technology in the pursuit of delivering safer, more efficient and environmentally responsible drilling services.  In addition to our patented dual-activity drilling technology, our two drillships under construction will include industry-leading 3.5 million-pound hoisting load capability, hybrid energy storage systems for enhanced drill floor equipment reliability, fuel and emissions savings as well as advanced generator protection for power plant reliability.  Ten drillships in our existing fleet are, and our two drillships that are under construction will be, outfitted with dual blowout preventers and triple liquid mud systems.  Our two drillships under construction will be equipped with 20,000 psi blowout preventers and related equipment.  Five drillships in our existing fleet are designed to accept 20,000 psi blowout preventers in the future.

Seven of our harsh environment semisubmersibles are designed and constructed specifically to provide highly efficient performance in the Norwegian North Sea and in the Barents Sea.  In 2019, we deployed the world’s first hybrid energy storage system aboard a floating drilling unit, the harsh environment floater Transocean Spitsbergen, which is the first solution to reduce fuel consumption and emissions while providing enhanced power management and station keeping reliability.  We also continue to develop and invest in technologies designed to optimize our performance and deliver ever better operational integrity through innovations, such as our proprietary fault-resistant and fault-tolerant blowout preventer control system.  We have installed automated drilling control systems on six harsh environment floaters, which materially improves our ability to safely and efficiently deliver wells to our customers.

We have also deployed our smart equipment analytics tool, which delivers real-time data feeds from equipment and is used to monitor equipment health and inferred emissions and energy consumption.  This technology can also identify trends in performance that allow us to systematically optimize equipment maintenance and achieve higher levels of reliability, operational efficiency and sustainability.  This data-driven approach, augmented by the size of our fleet, is helping us build a knowledge framework for sustainable process optimization.  Additionally, our continued, acute focus on personnel safety has driven the development and deployment of our patented HaloGuard system, which will alarm, notify and, if required, halt equipment to avoid injury to personnel who move into danger zones.

We believe our efforts to continuously improve, and effectively use, innovative technologies to meet or exceed our customers’ requirements is critical to maintaining our competitive position within the contract drilling services industry by drilling more efficient wells, building greater resilience into our critical operating systems, ensuring the safety of our crews, and reducing fuel consumption and emissions.

Governmental Regulations

Our operations are subject to a variety of international, regional, national, state and local government regulations, including environmental regulations.  We monitor our compliance with such government regulations in each country of operation and, while we see an increase in many government regulations, particularly general environmental regulation, we have made and will continue to make the required expenditures to comply with current and future government requirements.  To date, we have not incurred material costs in order to comply with such government regulations, including environmental regulation, and do not expect to make any material capital expenditures in order to comply with such regulations in the year ended December 31, 2021, or any other period contemplated at this time.  We do not believe that

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our compliance with such requirements will have a material adverse effect on our competitive position, consolidated results of operations or cash flows.  We incorporate by reference into this subsection “—Government Relations” the disclosures on government regulations, including environmental regulations, contained in the following sections of this annual report on Form 10-K:

Joint Venture, Agency and Sponsorship Relationships and Other Investments

In some areas of the world, local customs and practice or governmental requirements necessitate the formation of joint ventures with local participation since local laws or customs in those areas effectively mandate the establishment of a relationship with a local agent or sponsor.  When appropriate in these areas, we may enter into agency or sponsorship agreements.  We also invest in certain companies for operational purposes, some of which are involved in researching and developing technology to improve efficiency and reliability and to increase automation, sustainability and safety for our drilling and other activities.  We may or may not control these partially owned companies.  At December 31, 2020, we held partial ownership interests in companies in the Cayman Islands, the U.S., Norway, Canada, Angola, Nigeria and other countries, the most significant of which was our 33.0 percent ownership interest in Orion, an unconsolidated Cayman Islands exempted company formed to construct and own the harsh environment semisubmersible Transocean Norge.  Certain affiliates of Hayfin Capital Management LLP, own the remaining 67.0 percent ownership interest in Orion not owned by us.

Available Information

Our website address is www.deepwater.com.  Information contained on or accessible from our website is not incorporated by reference into this annual report on Form 10-K and should not be considered a part of this report or any other filing that we make with the SEC.  Furthermore, references to our website URLs are intended to be inactive textual references only.  We make available on this website free of charge, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports as soon as reasonably practicable after we electronically file those materials with, or furnish those materials to, the SEC.  You may also find on our website information related to our corporate governance, board committees and company code of business conduct and ethics.  The SEC also maintains a website, www.sec.gov, which contains reports, proxy statements and other information regarding SEC registrants, including us.  We intend to satisfy the requirement under Item 5.05 of Form 8-K to disclose any amendments to our Code of Integrity and any waiver from any provision of our Code of Integrity by posting such information in the Governance page on our website at www.deepwater.com.

Item 1A.Risk Factors

Risks related to our business

Our business depends on the level of activity in the offshore oil and gas industry, which is significantly affected by volatile oil and gas prices and other factors.

Our business depends on the level of activity in oil and gas exploration, development and production in offshore areas worldwide.  Demand for our services depends on oil and natural gas industry activity and expenditure levels that are directly affected by trends in oil and, to a lesser extent, natural gas prices.  Oil and gas prices are extremely volatile and are affected by numerous factors, including the following:

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Demand for our services is particularly sensitive to the level of exploration, development and production activity of, and the corresponding capital spending by, oil and natural gas companies, including national oil companies.  Prolonged reductions in oil and natural gas prices could depress the immediate levels of exploration, development and production activity.  Perceptions of longer-term lower oil and natural gas prices by oil and gas companies could similarly reduce or defer major expenditures given the long-term nature of many large-scale development projects.  Lower levels of activity result in a corresponding decline in the demand for our services, which could have a material adverse effect on our revenue and profitability.  Oil and gas prices and market expectations of potential changes in these prices significantly affect this level of activity.  However, increases in near-term commodity prices do not necessarily translate into increased offshore drilling activity since customers’ expectations of longer-term future commodity prices typically have a greater impact on demand for our rigs.  Consistent with this dynamic, customers may delay or cancel many exploration and development programs, resulting in reduced demand for our services.  Also, increased competition for customers’ drilling budgets could come from, among other areas, land-based energy markets worldwide.  The availability of quality drilling prospects, exploration success, relative production costs, the stage of reservoir development and political and regulatory environments also affect customers’ drilling campaigns.  Worldwide military, political and economic events have often contributed to oil and gas price volatility and are likely to do so in the future.

The offshore drilling industry is highly competitive and cyclical, with intense price competition.

The offshore contract drilling industry is highly competitive with numerous industry participants, none of which has a dominant market share.  Drilling contracts are traditionally awarded on a competitive bid basis.  Although rig availability, service quality and technical capability are drivers of customer contract awards, bid pricing and intense price competition are often key determinants for which a qualified contractor is awarded a job.

The offshore drilling industry is highly cyclical and is impacted by oil and natural gas price levels and volatility.  Periods of high customer demand, limited rig supply and high dayrates have been followed by periods of low customer demand, excess rig supply and low dayrates.  Changes in commodity prices can have a dramatic effect on rig demand, and periods of excess rig supply may intensify competition in the industry and result in the idling of older and less technologically advanced equipment.  We have idled and stacked rigs, and may in the future idle or stack additional rigs or enter into lower dayrate drilling contracts in response to market conditions.  Idled or stacked rigs may remain out of service for extended periods of time.  During prior periods of high dayrates and rig utilization rates, we and other industry participants responded to increased customer demand by increasing the supply of rigs through ordering the construction of new units.  The number of new units delivered without contracts, combined with an increased number of rigs in the global market completing contracts and becoming idle, has increased and may continue to intensify price competition.  In periods of low oil and natural gas price levels, new construction has historically resulted in an oversupply of rigs and has caused a subsequent decline in dayrates and rig utilization rates, sometimes for extended periods of time.  In an oversupplied market, we may have limited bargaining power to negotiate on more favorable terms.  Additionally, lower market dayrates and intense price competition may drive customers to seek to renegotiate existing contracts to lower dayrates in exchange for longer contract terms.  Lower dayrates and rig utilization rates could adversely affect our revenues and profitability.

As of February 12, 2021, we have 16 uncontracted rigs, and these rigs may remain out of service for extended periods of time.  We also have two additional rigs under construction, and while both have secured contracts, one has a contract that is conditional upon a final investment decision of the customer and its partners.  If we are unable to obtain drilling contracts for our uncontracted rigs, whether due to a prolonged offshore drilling market downturn, a delayed or muted recovery of such market or otherwise, it may have an adverse effect on our results of operations and cash flows.

Our current backlog of contract drilling revenues may not be fully realized.

At February 12, 2021, our contract backlog was approximately $7.8 billion.  This amount represents the number of days remaining in the firm term of the drilling contract multiplied by the maximum contractual operating dayrate, excluding revenues for mobilization, demobilization, contract preparation, other incentive provisions or reimbursement revenues, which are generally insignificant to our contract drilling revenues.  Our contract backlog includes amounts associated with our contracted newbuild unit that 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 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 due to a number of factors, including rig downtime or suspension of operations.  Several factors could cause rig downtime or a suspension of operations, including: equipment breakdowns and other unforeseen engineering problems, labor strikes and other work stoppages, shortages of material and skilled labor, surveys by government and maritime authorities, periodic classification surveys, severe weather or harsh operating conditions, and force majeure events.

In certain drilling contracts, the dayrate may be reduced to zero if, for example, repairs extend beyond a stated period of time.  Our contract backlog includes only firm commitments, which are represented by signed drilling contracts or, in some cases, other definitive agreements awaiting contract execution.  We may not be able to realize the full amount of our contract backlog due to events beyond our control.  In addition, some of our customers have experienced liquidity issues in the past, including some recently, and these liquidity issues could be experienced again if commodity prices decline for an extended period of time.  Liquidity issues and other market pressures could lead our customers to seek bankruptcy protection or to seek to repudiate, cancel or renegotiate these agreements for various reasons (see “—Our drilling contracts may be terminated due to a number of events, and, during depressed market conditions, our customers may seek

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to repudiate or renegotiate their contracts”).  Our inability to realize the full amount of our contract backlog may have a material adverse effect on our consolidated financial position, results of operations or cash flows.

We may not be able to renew or obtain new drilling contracts for rigs whose contracts are expiring or obtain drilling contracts for our stacked and idle rigs or our newbuild with a conditional agreement if the conditions thereof are not satisfied.

The offshore drilling markets in which we compete experience fluctuations in the demand for drilling services.  Our ability to renew expiring drilling contracts or obtain new drilling contracts depends on the prevailing or expected market conditions at the time of expiration.  As of February 12, 2021, we have 16 stacked or idle rigs and one rig under construction that has a drilling contract that is subject to a final investment decision by the customer and its partners.  We also have seven existing drilling contracts for our rigs that are currently operating, which are scheduled to expire before December 31, 2021.  We may be unable to obtain drilling contracts for our rigs that are currently operating upon the expiration or termination of such contracts or obtain a drilling contract for our newbuild unit with a conditional agreement in the event the conditions thereof are not satisfied, and there may be a gap in the operation of the rigs between the current contracts and subsequent contracts.  When oil and natural gas prices are low or it is expected that such prices will decrease in the future, we may be unable to obtain drilling contracts at attractive dayrates or at all.  We may not be able to obtain new drilling contracts in direct continuation with existing contracts or for our newbuild unit with a conditional agreement, or depending on prevailing market conditions, we may enter into drilling contracts at dayrates substantially below the existing dayrates or on terms otherwise less favorable compared to existing contract terms, which may have an adverse effect on our consolidated financial position, results of operations or cash flows.

Our drilling contracts may be terminated due to a number of events, and, during depressed market conditions, our customers may seek to repudiate or renegotiate their contracts.

Certain of our drilling contracts with customers may be cancelable at the option of the customer upon payment of an early termination payment.  Such payments may not, however, fully compensate us for the loss of the contract.  Drilling contracts also customarily provide for either automatic termination or termination at the option of the customer, typically without the payment of any termination fee, under various circumstances such as non-performance, as a result of significant downtime or impaired performance caused by equipment or operational issues, or sustained periods of downtime due to force majeure events, many of which are beyond our control.  Certain customers who seek to terminate our drilling contracts may attempt to defeat or circumvent our protections against certain liabilities.  Our customers’ ability to perform their obligations under their drilling contracts, including their ability to fulfill their indemnity obligations to us, may also be negatively impacted by an economic downturn.  Our customers, which include national oil companies, often have significant bargaining leverage over us.  If our customers cancel some of our contracts, and we are unable to secure new contracts on a timely basis and on substantially similar terms, or if contracts are suspended for an extended period of time or if a number of our contracts are renegotiated on terms that are not as favorable as current terms, it could adversely affect our consolidated financial position, results of operations or cash flows.

During periods of depressed market conditions, such as we are currently experiencing, we are subject to an increased counterparty risk, as our customers may seek to repudiate their contracts, including through claims of non-performance in order to reduce their capital expenditures.  Our customers may no longer need a drilling rig that is currently under contract or may be able to obtain a comparable drilling rig at a lower dayrate.  We have experienced, and are at continued risk of experiencing, early contract terminations in a weak commodity price environment as operators look to reduce their capital expenditures.  The ability of each of our counterparties to perform its obligations under a contract with us, including indemnity obligations, will depend on a number of factors that are beyond our control and may include, among other things, general economic conditions, the condition of the offshore drilling industry, prevailing prices for oil and natural gas, the overall financial condition of the counterparty, the dayrates received and the level of expenditures necessary to maintain drilling activities.  Should a counterparty fail to honor its obligations under an agreement with us, we could sustain losses, which could have an adverse effect on our business and on our consolidated financial position, results of operations or cash flows.

We must make substantial capital and operating expenditures to maintain our active fleet or to reactivate our stacked or idle fleet, and we may be required to make significant capital expenditures to maintain our competitiveness, to execute our growth plan and to comply with laws and applicable regulations and standards of governmental authorities and organizations.

We must make substantial capital and operating expenditures to maintain our active fleet or to reactivate our stacked or idle fleet.  These expenditures could increase as a result of changes in the cost of labor and materials, requirements of customers, the size of our fleet, the cost of replacement parts for existing rigs, the geographic location of the rigs and the length of drilling contracts.  Changes in offshore drilling technology, customer requirements for new or upgraded equipment and competition within our industry may require us to make significant capital expenditures in order to maintain our competitiveness and to execute our growth plan.  Changes in governmental regulations, including environmental requirements, and changes in safety or other equipment standards, as well as compliance with standards imposed by maritime self-regulatory organizations, may cause our capital expenditures to increase or require us to make additional unforeseen capital expenditures.  As a result of these factors, we may be required to take our rigs out of service for extended periods of time, with corresponding losses of revenues, in order to make such alterations or to add such equipment.  In the future, market conditions may not justify these expenditures or enable us to operate our older rigs profitably during the remainder of their economic lives.

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If we are unable to fund capital expenditures with our cash flows from operations or proceeds from sales of non-strategic assets, we may be required to either incur additional borrowings or raise capital through the sale of debt or equity securities, or additional financing arrangements with banks or other capital providers.  Our ability to access the capital markets may be limited by our financial condition at the time, perceptions of us or our industry, by changes in laws and regulations or interpretation thereof and by adverse market conditions resulting from, among other things, general economic conditions and contingencies and uncertainties that are beyond our control.  If we raise funds by issuing equity securities or other securities that are convertible into equity securities, existing shareholders may experience dilution.  Our failure to obtain the funds for necessary future capital expenditures could have a material adverse effect on our business and on our consolidated financial position, results of operations and cash flows.

Public health threats, such as COVID-19, have had, and may continue to have, significant adverse consequences for general economic, financial and business conditions, as well as for our business and operations.

Public health threats, pandemics and epidemics, such as the outbreak of a novel strain of COVID-19, severe influenza, other coronaviruses and other highly communicable viruses or diseases, have impacted and may continue to impact our operations directly or indirectly, including by disrupting the operations of our business partners, suppliers and customers in ways that adversely impact our operations.  For instance, the outbreak of COVID-19 and its development into a pandemic in March 2020 resulted in various actions by governmental authorities around the world to prevent or reduce the spread of COVID-19, such as imposing mandatory closures of all non-essential business facilities, seeking voluntary closures of such facilities and imposing restrictions on, or advisories with respect to, travel, business operations and public gatherings or interactions.  In addition, companies and individuals seeking to curtail the spread of COVID-19 have taken certain cautionary measures, such as companies around the world requiring employees to work remotely, suspending all non-essential travel worldwide for employees, and discouraging employee attendance at in-person work-related meetings, as well as individuals voluntarily social distancing and self-quarantining.  While many of these restrictions and measures have since been softened or lifted in varying degrees in different locations around the world, and there have been several COVID-19 vaccines recently approved by many governments that are expected to accelerate a recovery from the pandemic, the ultimate success of such vaccines is currently uncertain and resurgences in the spread of COVID-19 and other rapid developments with respect to the virus have prompted and may in the future prompt, the re-imposition of certain restrictions and measures.

These responses have significantly reduced global economic activity, as there has been a dramatic decrease in the number of businesses open for operation and a substantial reduction in the number of people across the world that have been going to work or leaving their house to purchase goods and services.  This has also resulted in airlines dramatically cutting back on flights and has reduced the number of cars on the road.  As a result, there has also been a sharp reduction in the demand for oil and a decline in oil prices.

We have taken similar precautionary measures intended to help minimize the risk to our business, employees, customers, suppliers and the communities in which we operate.  Our operational employees generally are currently still able to work on site and on our rigs.  We have taken comprehensive and global precautionary measures with respect to such operational employees, such as requiring them to verify they have not either experienced any symptoms consistent with COVID-19 or been in close contact with someone showing such symptoms before they are permitted to travel to the work site or rig, quarantining any operational employee on a rig who has shown signs of COVID-19, regardless of whether such employee has been confirmed to be infected, and imposing social distancing requirements in certain areas of the rig, such as in the dining hall and sleeping quarters, and are incurring incremental costs.  We are also actively assessing and planning for various operational contingencies; however, we cannot guarantee that any actions taken by us, including the precautionary measures noted above, will be effective in preventing either an outbreak of COVID-19 on one or more of our rigs or other adverse effects related to COVID-19.  To the extent an outbreak of COVID-19 develops on one or more of our rigs, we may have to temporarily shut down operations of such rig or rigs, which could result in significant downtime or contract termination and have substantial adverse consequences for our business and results of operations.  In addition, most of our non-operational employees are now working remotely, which increases various operational risks.  For instance, working remotely may increase the risk of security breaches or other cyber incidents or attacks, loss of data, fraud and other disruptions as a consequence of more employees accessing sensitive and critical information from remote locations.

Many governmental authorities across the globe have implemented travel restrictions and mandatory quarantine measures to prevent or reduce the spread of COVID-19, and in complying with such governmental actions, we have experienced, and expect to continue to experience, increased difficulties, delays and costs in moving our personnel in and out of, and to work in, the various jurisdictions in which we operate.  We may be unable to pass along these increased costs to our customers.  Additionally, disruptions to or restrictions on the ability of our suppliers, manufacturers and service providers to supply parts, equipment or services in the jurisdictions in which we operate or to progress the construction of our newbuild projects, whether as a result of government actions, labor shortages, the inability to source parts or equipment from affected locations, or other effects related to the COVID-19 outbreak, may have significant adverse consequences on our ability to meet our commitments to customers, including by increasing our operating costs and increasing the risk of rig downtime and could result in contract terminations.

Concerns over the prolonged negative effects of the COVID-19 outbreak on economic and business prospects across the world have also contributed to increased market and oil price volatility and have diminished expectations for the performance of the global economy.  These factors, coupled with the prospect of decreased business and consumer confidence and increased unemployment resulting from the COVID-19 outbreak and the decline in, and steep increase in the volatility of, oil prices, have precipitated an economic downturn and likely a recession.  The current downturn and period of depressed oil prices has had and may continue to have significant adverse consequences

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for the financial condition of our customers or suppliers.  Such conditions have resulted in, and may continue to result in, reductions to our customers’ drilling and production expenditures and delays or cancellations of projects, thus decreasing demand for our services, and an increased risk that our customers may seek price reductions or more favorable economic terms for our services, terminate our contracts or that we may be required to idle, stack or retire more of our rigs.  Additionally, any early termination payment made in connection with an early contract termination may not fully compensate us for the loss of the contract.  Accordingly, the actual amount of revenues earned may be substantially lower than the reported contract backlog.  To the extent our suppliers experience a deterioration in financial condition or operational capability as a result of such depressed market and industry conditions or we or other suppliers incur delays in moving personnel to and from drilling rigs, we may experience disruptions in supply, which could increase our operating costs and increase rig downtime.  The occurrence of any such events with respect to our customers, contracts or suppliers in certain cases has had, and may continue to have, significant adverse consequences for our business and financial position.

The magnitude and duration of potential social, economic and labor instability resulting from the COVID-19 outbreak, including how quickly national economies can recover once the pandemic subsides, or whether any recovery will ultimately experience a reversal or other setbacks, are uncertain and cannot be estimated at this time as such effects depend on future events that are largely out of our control.  The ultimate extent of the impact of the COVID-19 outbreak on our business and financial position will depend largely on future developments, including the duration, spread or containment of the outbreak, particularly within the geographic locations where we operate, and the related impact on overall economic activity, all of which are highly uncertain at this time.  We are unable to predict the timing or impact of any such restructurings, if completed, on the capital structure and competitive dynamics among offshore drilling companies.

Public and investor sentiment towards climate change, fossil fuels and other esg matters could adversely affect our business, cost of capital and the price of our stock and other securities.

There have been efforts in recent years, based on changing public sentiment concerning fossil fuels, aimed at the investment community, including investment advisors, sovereign wealth funds, public pension funds, universities and other groups, to promote the divestment of shares of energy companies, as well as to pressure lenders and other financial services companies to limit or curtail activities with energy companies.  These efforts have intensified during the COVID-19 pandemic, as seen by the State of New York’s December 2020 announcement that it will be divesting the state’s Common Retirement Fund from fossil fuels.  If this or similar divestment efforts are successful, our stock price and our ability to access capital markets may be negatively impacted.

Members of the investment community are also increasing their focus on environmental, social and governance (“ESG”) practices and disclosures, including practices and disclosures related to greenhouse gases and climate change, in the energy industry in particular, and diversity and inclusion initiatives and governance standards among public companies more generally.  As a result, we may face increasing pressure regarding our ESG disclosures and practices.  Additionally, members of the investment community may screen companies such as ours for ESG sustainability performance before investing in our stock.  Over the past few years there has also been an acceleration in investor demand for ESG investing opportunities, and many large institutional investors have committed to increasing the percentage of their portfolios that are allocated towards ESG investments.  As a result, there has been a proliferation of ESG focused investment funds seeking ESG oriented investment products.  If we or our securities are unable to meet the sustainability ESG standards or investment criteria set by these investors and funds, we may lose investors or investors may allocate a portion of their capital away from us, our cost of capital may increase, our stock price and the price of our publicly traded debt securities may be negatively impacted and our reputation may also be negatively affected.

We rely heavily on a relatively small number of customers and the loss of a significant customer or a dispute that leads to the loss of a customer could have an adverse effect on our business.

We engage in offshore drilling services for most of the leading integrated oil companies or their affiliates, as well as for many government-owned or government-controlled oil companies and other independent oil companies.  For the year ended December 31, 2020, our most significant customers were Shell, Equinor and Chevron, accounting for approximately 28 percent, 27 percent and 14 percent, respectively, of our total contract drilling revenues.  As of February 12, 2021, the customers with the most significant aggregate amount of contract backlog were Shell, Equinor and Chevron, representing approximately 53 percent, 23 percent and 13 percent, respectively, of our total contract backlog.  The loss of any of these customers or another significant customer, or a decline in payments under any of our drilling contracts, could, at least in the short term, have an adverse effect on our business.

Our operating and maintenance costs will not necessarily fluctuate in proportion to changes in our operating revenues.

Our operating and maintenance costs will not necessarily fluctuate in proportion to changes in our operating revenues.  Costs for operating a rig are generally fixed or only semi-variable regardless of the dayrate being earned.  In addition, should our rigs incur unplanned downtime while on contract or idle time between drilling contracts, we will not always reduce the staff on those rigs because we could use the crew to prepare the rig for its next contract.  During times of reduced activity, reductions in costs may not be immediate because portions of the crew may be required to prepare rigs for stacking, after which time the crew members may be reassigned to active rigs or released.  As our rigs are mobilized from one geographic location to another, the labor and other operating and maintenance costs can vary significantly.  In general, labor costs increase primarily due to higher salary levels and inflation.  Equipment maintenance costs fluctuate depending upon the type of activity the unit is performing and the age and condition of the equipment, and these costs could increase for short or extended periods as a result of regulatory or customer requirements that raise maintenance standards above historical levels.  The amount of contract

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preparation and reactivation costs vary based on the scope and length of the contract preparation or reactivation project, and the recognition of such costs varies depending on the duration of the firm contractual period and other contract terms.

Certain of our drilling contracts are partially payable in local currency.  The amounts, if any, of local currency received under these drilling contracts may exceed our local currency needs to pay local operating and maintenance costs, leading to an accumulation of excess local currency balances, which, in certain instances, may be subject to either restrictions or other difficulties in converting to U.S. dollars, our functional currency, or to other currencies of the locations where we operate.  Excess amounts of local currency may also be exposed to the risk of currency exchange losses.

Our business involves numerous operating hazards, and our insurance and indemnities from our customers may not be adequate to cover potential losses from our operations.

Our operations are subject to the usual hazards inherent in the drilling of oil and gas wells, such as, blowouts, reservoir damage, loss of production, loss of well control, lost or stuck drill strings, equipment defects, craterings, fires, explosions and pollution.  Contract drilling requires the use of heavy equipment and exposure to hazardous conditions, which may subject us to liability claims by employees, customers and other parties.  These hazards can cause personal injury or loss of life, severe damage to or destruction of property and equipment, pollution or environmental or natural resource damage, claims by third parties or customers and suspension of operations.  Our offshore fleet is also subject to hazards inherent in marine operations, either while on site or during mobilization, such as capsizing, sinking, grounding, collision, piracy, damage from severe weather and marine life infestations.

The South China Sea, the Northwest Coast of Australia and the U.S. Gulf of Mexico are areas subject to typhoons, hurricanes or other extreme weather conditions on a relatively frequent basis, and our drilling rigs in these regions may be exposed to damage or total loss by these storms, some of which may not be covered by insurance.  The occurrence of these events could result in the suspension of drilling operations, damage to or destruction of the equipment involved and injury to or death of rig personnel.  Some experts believe global climate change could increase the frequency and severity of these extreme weather conditions.  Operations may also be suspended because of machinery breakdowns, abnormal drilling conditions, failure of subcontractors to perform or supply goods or services, or personnel shortages.  We customarily provide contract indemnity to our customers for certain claims that could be asserted by us relating to damage to or loss of our equipment, including rigs, and claims that could be asserted by us or our employees relating to personal injury or loss of life.

Damage to the environment or natural resources could also result from our operations, particularly through spillage of hydrocarbons, fuel, lubricants or other chemicals and substances used in drilling operations, or extensive uncontrolled fires.  We may also be subject to property damage, environmental indemnity and other claims by oil and natural gas companies or other third parties.  Drilling involves certain risks associated with the loss of control of a well, such as blowout, cratering, the cost to regain control of or redrill the well and remediation of associated pollution.  Our customers may be unable or unwilling to indemnify us against such risks.  In addition, a court may decide that certain indemnities in our current or future drilling contracts are not enforceable.  The law generally considers contractual indemnity for criminal fines and penalties to be against public policy, and the enforceability of an indemnity as to other matters may be limited.

Our insurance policies and drilling contracts contain rights to indemnity that may not adequately cover our losses, and we do not have insurance coverage or rights to indemnity for all risks.  We have two main types of insurance coverage: (1) hull and machinery coverage for physical damage to our property and equipment and (2) excess liability coverage, which generally covers offshore risks, such as personal injury, third-party property claims, and third-party non-crew claims, including wreck removal and pollution.  We generally have no hull and machinery insurance coverage for damages caused by named storms in the U.S. Gulf of Mexico.  We maintain per occurrence deductibles that generally range up to $10 million for various third-party liabilities, and we self-insure $50 million of the $750 million excess liability coverage through our wholly owned captive insurance company.  We also retain the risk for any liability that exceeds our excess liability coverage.  However, pollution and environmental risks generally are not completely insurable.

If a significant accident or other event occurs that is not fully covered by our insurance or by an enforceable or recoverable indemnity, the occurrence could adversely affect our consolidated financial position, results of operations or cash flows.  The amount of our insurance may also be less than the related impact on enterprise value after a loss.  Our insurance coverage will not in all situations provide sufficient funds to protect us from all liabilities that could result from our drilling operations.  Our coverage includes annual aggregate policy limits.  As a result, we generally retain the risk for any losses in excess of these limits.  We generally do not carry insurance for loss of revenue, and certain other claims may also not be reimbursed by insurance carriers.  Any such lack of reimbursement may cause us to incur substantial costs.  In addition, we could decide to retain more risk in the future, resulting in higher risk of losses, which could be material.  Moreover, we may not be able to maintain adequate insurance in the future at rates that we consider reasonable or be able to obtain insurance against certain risks.

Failure to recruit and retain key personnel could hurt our operations.

We depend on the continuing efforts of key members of our management, as well as other highly skilled personnel, to operate and provide technical services and support for our business worldwide.  Historically, competition for the personnel required for drilling operations has intensified as the number of rigs activated, added to worldwide fleets or under construction increased, leading to shortages of qualified personnel in the industry and creating upward pressure on wages and higher turnover.  We may experience a reduction in the experience level of our personnel as a result of any increased turnover and ongoing staff reduction initiatives, which could lead to higher downtime and

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more operating incidents, which in turn could decrease revenues and increase costs.  If increased competition for qualified personnel were to intensify in the future we may experience increases in costs or limits on operations.

Our labor costs and the operating restrictions under which we operate could increase as a result of collective bargaining negotiations and additional unionization efforts.

Approximately 43 percent of our total workforce, primarily employed in Norway, Brazil and the U.K., are represented by, and some of our contracted labor work is subject to, collective bargaining agreements, substantially all of which are subject to annual salary negotiation.  Negotiations over annual salary or other labor matters could result in higher personnel or other costs or increased operational restrictions or disruptions.  The outcome of any such negotiation generally affects the market for all offshore employees, not only the union members.  Furthermore, a failure to reach an agreement on certain key issues could result in strikes, lockouts, or other work stoppages.  Legislation has been introduced in the U.S. Congress that could encourage additional unionization efforts in the U.S., as well as increase the chances that such efforts succeed.  Additional unionization efforts, if successful, new collective bargaining agreements or work stoppages could materially increase our labor costs and operating restrictions.

Our shipyard projects and operations are subject to delays and cost overruns.

As of February 12, 2021, we had under construction two ultra-deepwater drillships.  We also have a variety of other more limited shipyard projects at any given time.  These shipyard projects are subject to the risks of delay or cost overruns inherent in any such construction project resulting from numerous factors, including the following:

These factors may contribute to cost variations and delays in the delivery of our newbuild units and other rigs undergoing shipyard projects.  Cost variations may result in, among other things, disputes with the shipyards that construct or service our drilling units.  In addition, delayed delivery of our newbuild units or other rigs undergoing shipyard projects would impact contract commencement, resulting in a loss of revenues we could earn, and may also cause customers to terminate or shorten the term of the drilling contract for the rig pursuant to applicable late delivery clauses.  In the event of termination of any of these drilling contracts, we may not be able to secure a replacement contract on as favorable terms, if at all.

Our operations also rely on a significant supply of capital and consumable spare parts and equipment to maintain and repair our fleet.  We also rely on the supply of ancillary services, including supply boats and helicopters.  Our reliance on our suppliers, manufacturers and service providers to secure equipment, parts, components and sub-systems used in our operations exposes us to volatility in the quality, prices and availability of such items.  Certain parts and equipment that we use in our operations may be available only from a small number of suppliers, manufacturers or service providers, or in some cases must be sourced through a single supplier, manufacturer or service provider.  A disruption in the deliveries from our suppliers, manufacturers or service providers, capacity constraints, production disruptions, price increases, quality control issues, recalls or other decreased availability of parts and equipment or ancillary services could adversely affect our ability to meet our commitments to customers, adversely impact our operations, increase our operating costs and result in increases in rig downtime and delays in the repair and maintenance of our fleet.

Risks related to our indebtedness

We have a substantial amount of debt, including secured debt, and we may lose the ability to obtain future financing and suffer competitive disadvantages.

At December 31, 2020 and 2019, our total debt was $7.8 billion and $9.3 billion, respectively, of which $2.8 billion and $3.3 billion, respectively, was secured.  We have a bank credit agreement, as amended, that established a $1.3 billion secured revolving credit facility

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(the “Secured Credit Facility”), which is currently undrawn, the borrowings under which would be secured.  This substantial level of debt and other obligations could have significant adverse consequences on our business and future prospects, including the following:

See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources and uses of liquidity.”

Credit rating agencies have rated our debt below investment grade, which could limit our access to capital and have an adverse effect on our business and financial condition.

The ratings assigned to our debt securities by credit agencies (our “Debt Rating”) are below investment grade.  Our Debt Ratings could have adverse consequences for our business and future prospects and could cause the following:

Our Debt Ratings have caused some of the effects listed above, and any further downgrades may cause or exacerbate, any of the effects listed above and could have an adverse effect on our business and financial condition.

Worldwide financial, economic and political conditions could restrict our ability to access the capital markets, reduce our flexibility to react to changing economic and business conditions and reduce demand for our services.

Worldwide financial and economic conditions could restrict our ability to access the capital markets 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.  Worldwide economic conditions have in the past impacted, and could in the future impact, the lenders participating in our credit facilities and our customers, causing them to fail to meet their obligations to us.  If economic conditions preclude or limit financing from banking institutions participating in our credit facilities, we may not be able to obtain similar financing from other institutions.  A slowdown in economic activity could further reduce worldwide demand for energy and extend or worsen the recovery from low oil and natural gas prices.  These potential developments, or market perceptions concerning these and related issues, could affect our consolidated financial position, results of operations or cash flows.  In addition, turmoil and hostilities in the Middle East, North Africa and other geographic areas and countries present incremental risk.  An extended period of negative outlook for the world economy could further reduce the overall demand for oil and natural gas and for our services.  A further decline in oil and natural gas prices or an extension of the current low oil and natural gas prices could reduce demand for our drilling services and have a material adverse effect on our consolidated financial position, results of operations or cash flows.

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Risks related to laws, regulations and governmental compliance

Impact of increasingly stringent environmental and safety laws and our compliance with or breach of such laws can be costly, expose us to liability and could limit our operations.

Our business is affected by laws and regulations relating to the energy industry and the environment and safety, including international conventions and treaties, and regional, national, state, and local laws and regulations.  Our business also depends on demand for services from the oil and gas exploration and production industry, and, accordingly, we are directly affected by the adoption of laws and regulations that, for economic, environmental or other policy reasons, curtail, delay or impose additional compliance costs and obligations related to the exploration and development drilling for oil and gas.  Offshore drilling in certain areas has been curtailed and, in certain cases, prohibited because of environmental or safety concerns.  In addition, compliance with environmental and safety laws, regulations and standards, where applicable, may require us to make significant capital expenditures, such as the installation of costly equipment or implementation of operational changes, and may affect the resale values or useful lives of our rigs.  We may also incur additional costs in order to comply with other existing and future regulatory obligations or industry standards, including, but not limited to, costs relating to air emissions, including greenhouse gases, the management of ballast waters, maintenance and inspection, development and implementation of emergency procedures and maintenance of insurance coverage or other financial assurance of our ability to address pollution incidents.  For instance, in the last decade, enhanced governmental safety and environmental requirements applicable to our operations were adopted by U.S. federal agencies for drilling in the U.S. Gulf of Mexico have caused, and may in the future cause, operators to have difficulties obtaining drilling permits in the U.S. Gulf of Mexico.  In addition, the oil and gas industry has adopted new equipment and operating standards, such as the American Petroleum Institute Standard 53, related to the installation and testing of well control equipment.  A failure to comply with applicable laws and regulations may result in administrative and civil penalties, criminal sanctions or the suspension or termination of our operations.  Additionally, our customers may elect to voluntarily comply with any non-mandatory laws, regulations or other standards.

Any such safety, environmental and other regulatory restrictions or standards, including voluntary customer compliance with respect thereto, could decrease, disrupt or delay operations, decrease demand for offshore drilling services, increase operating costs and compliance costs or penalties, increase out-of-service time, decrease dayrates, or reduce the area of operations for drilling rigs in the U.S. and non-U.S. offshore areas.  Any such effects could have a material adverse effect on our consolidated financial position, results of operations or cash flows.

To the extent new laws are enacted, existing laws are changed or other governmental actions are taken that prohibit or restrict offshore drilling or impose additional environmental protection and safety requirements that result in increased costs to the oil and gas industry, in general, or the offshore drilling industry, in particular, our business or prospects could be materially adversely affected.  The operation of our drilling rigs will require certain governmental approvals, some of which may involve public hearings and costly undertakings on our part.  We may not obtain such approvals or such approvals may not be obtained in a timely manner.  If we fail to timely secure the necessary governmental approvals or permits, our customers may have the right to terminate or seek to renegotiate their drilling contracts to our detriment.  The amendment or modification of existing laws and regulations or the adoption of new laws and regulations curtailing or further regulating exploratory or development drilling or production of oil and gas and compliance with any such new or amended legislation or regulations could have an adverse effect on our business or on our consolidated financial position, results of operations or cash flows.

As a contract driller with operations in certain offshore areas, we may be liable for damages and costs incurred in connection with oil spills or disposal of wastes related to those operations, and we may also be subject to significant fines and other liabilities in connection with spills.  For example, an oil spill could result in significant liability, including fines, penalties and criminal liability and remediation, restoration or compensation costs for environmental or natural resource damages, as well as third-party damages, to the extent that the contractual indemnification provisions in our drilling contracts are not enforceable or otherwise sufficient, or if our customers are unwilling or unable to contractually indemnify us against these risks.  Additionally, we may not be able to obtain such indemnities in our future drilling contracts, and our customers may not have the financial capability to fulfill their contractual obligations to us.  Also, these indemnities may be held to be unenforceable in certain jurisdictions, as a result of public policy or for other reasons.  Environmental and safety laws and regulations protecting the environment have become increasingly stringent and may in some cases impose strict liability on facility or vessel owners or operators, rendering a person liable for environmental damage without regard to negligence.  These laws and regulations may expose us to liability for the conduct of, or conditions caused by, others or for acts that were in compliance with all applicable laws at the time they were performed.  The application of these requirements or the adoption of new requirements or measures could have an adverse effect on our consolidated financial position, results of operations or cash flows.

Regulatory and various other risks, including litigation, associated with greenhouse gases and climate change could have an adverse impact on our business and demand for our services.

Scientific studies have suggested that emissions of certain gases, including greenhouse gases, such as carbon dioxide and methane, contribute to warming of the earth’s atmosphere and other climatic changes.  In response to such studies, the issue of climate change and the effect of greenhouse gas emissions, in particular emissions from the fossil fuel industry, has attracted considerable attention worldwide.  The attention to climate change has led, and we expect it to continue to lead, to additional regulations designed to reduce greenhouse gas emissions domestically and internationally.  Such attention could also result in other adverse impacts for the oil and gas industry, including further restrictions or bans imposed by lawmakers, lawsuits by governments or third-parties seeking recoveries for damages resulting from the combustion of fuels that may contribute to climate change effects, or reduced interest from investors if they elect

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in the future to shift some or all of their investments to non-fossil fuel related sectors.  To the extent financial markets view climate change and greenhouse emissions as a financial risk, this could negatively impact our cost of or access to capital.  Because our business depends on the level of activity in the oil and gas industry, existing or future laws, regulations, treaties or international agreements related to greenhouse gases and climate change, or related political, litigation or financial risks, including incentives to conserve energy or use alternative energy sources, could have a negative impact on our business if such laws, regulations, treaties or international agreements reduce the worldwide demand for oil and gas or limit drilling opportunities.  In addition, such laws, regulations, treaties or international agreements or related risks could result in increased compliance costs or additional operating restrictions, which may have an adverse effect on our business.  Further, some experts believe global climate change could increase the frequency and severity of extreme weather conditions, the impacts of which could interfere with our operations, cause damage to our equipment as well as cause other financial and operational impacts, including those that could result from any impact of such conditions on our customers.

We could also face increased climate-related litigation with respect to our operations both in the U.S. and around the world.  Governmental and other entities in various U.S. states, such as California and New York, have filed lawsuits against coal, gas oil and petroleum companies.  These suits allege damages as a result of climate change, and the plaintiffs are seeking unspecified damages and abatement under various tort theories.  Similar lawsuits may be filed in other jurisdictions both in the U.S. and globally.  Though we are not currently a party to any such lawsuit, these suits present a high degree of uncertainty regarding the extent to which energy companies, including offshore drillers, face an increased risk of liability stemming from climate change, which risk would also adversely impact the oil and gas industry and impact demand for our services.

The global nature of our operations involves additional risks.

We operate in various regions throughout the world, which may expose us to political and other uncertainties, including risks of:

Our non-U.S. contract drilling operations are subject to various laws and regulations in certain countries in which we operate, including laws and regulations relating to the import and export, equipment and operation of drilling units, currency conversions and repatriation, oil and gas exploration and development, taxation and social contributions of offshore earnings and earnings of expatriate personnel.  We are also subject to the U.S. Treasury Department’s Office of Foreign Assets Control (“OFAC”) and other U.S. and non-U.S. laws and regulations governing our international operations.  In addition, various state and municipal governments, universities and other investors have proposed or adopted divestment and other initiatives regarding investments including, with respect to state governments, by state retirement systems in companies that do business with countries that have been designated as state sponsors of terrorism by the U.S. State Department.  Failure to comply with applicable laws and regulations, including those relating to sanctions and export restrictions, may subject us to criminal sanctions or civil remedies, including fines, denial of export privileges, injunctions or seizures of assets.  Investors could view any potential violations of OFAC regulations negatively, which could adversely affect our reputation and the market for our shares.

Governments in some countries have become increasingly active in regulating and controlling the ownership of concessions and companies holding concessions, the exploration for oil and gas and other aspects of the oil and gas industries in their countries, including local content requirements for participating in tenders for certain drilling contracts.  Many governments favor or effectively require the awarding of drilling contracts to local contractors or require nonlocal contractors to employ citizens of, or purchase supplies from, a particular jurisdiction or require use of a local agent.  In addition, government action, including initiatives by OPEC, may continue to cause oil or gas price volatility.  In some areas of the world, this governmental activity has adversely affected the amount of exploration and development work by major oil companies and may continue to do so.

The shipment of goods, services and technology across international borders subjects us to extensive trade laws and regulations.  Our import and export activities are governed by unique customs laws and regulations in each of the countries where we operate.  Moreover, many countries, including the U.S., control the import and export of certain goods, services and technology and impose related import and export recordkeeping and reporting obligations.  Governments also may impose economic sanctions against certain countries, persons and other entities that may restrict or prohibit transactions involving such countries, persons and entities, and we are also subject to the U.S. anti-boycott law.

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The laws and regulations concerning import and export activity, recordkeeping and reporting, import and export control and economic sanctions are complex and constantly changing.  These laws and regulations may be enacted, amended, enforced or interpreted in a manner materially impacting our operations.  Ongoing economic challenges may increase some governments’ efforts to enact, enforce, amend or interpret laws and regulations as a method to increase revenue.  Shipments can be delayed and denied import or export for a variety of reasons, some of which are outside our control and some of which may result from failure to comply with existing legal and regulatory regimes.  Shipping delays or denials could cause unscheduled operational downtime.

Our ability to operate worldwide depends on our ability to obtain the necessary visas and work permits for our personnel to travel in and out of, and to work in, the jurisdictions in which we operate.  Governmental actions in some of the jurisdictions in which we operate may make it difficult for us to move our personnel in and out of these jurisdictions by delaying or withholding the approval of these permits.  If we are not able to obtain visas and work permits for the employees we need to conduct our operations on a timely basis, we might not be able to perform our obligations under our drilling contracts, which could allow our customers to cancel the contracts.  If our customers cancel some of our drilling contracts, and we are unable to secure new drilling contracts on a timely basis and on substantially similar terms, it could have a material adverse effect on our business and on our consolidated financial position, results of operations or cash flows.

Failure to comply with anti-bribery statutes, such as the U.S. Foreign Corrupt Practices Act and the U.K. Bribery Act 2010, could result in fines, criminal penalties, drilling contract terminations and an adverse effect on our business.

The U.S. Foreign Corrupt Practices Act (“FCPA”), the U.K. Bribery Act 2010 (“Bribery Act”) and similar anti-bribery laws in other jurisdictions, generally prohibit companies and their intermediaries from making improper payments for the purpose of obtaining or retaining business.  We operate in many parts of the world that have experienced corruption to some degree and, in certain circumstances, strict compliance with anti-bribery laws may conflict with local customs and practices.  If we are found to be liable for violations under the FCPA, the Bribery Act or other similar laws, either due to our acts or omissions or due to the acts or omissions of others, including our partners in our various joint ventures and of the current or former officers, directors or employees of any companies we have acquired, we could suffer from civil and criminal penalties or other sanctions, which could have a material adverse effect on our business or our consolidated financial position and results of operations.  In addition, investors could negatively view potential violations, inquiries or allegations of misconduct under the FCPA, the Bribery Act or similar laws, which could adversely affect our reputation and the market for our shares.

We could also face fines, sanctions and other penalties from authorities in relevant jurisdictions, including prohibition of our participating in or curtailment of business operations in those jurisdictions and the seizure of rigs or other assets.  Additionally, our business and results of operations could be adversely affected as a result of claims by customers, agents, shareholders, debt holders, other interest holders, current or former employees or other constituents of our company who, in connection with alleged or actual noncompliance with antibribery and related laws, may seek to impose penalties, seek remedies, terminate drilling contracts or take other actions adverse to our interests.  Our business and results of operations may be adversely affected if we are required to dedicate significant time and resources to investigate and resolve allegations of misconduct, regardless of the merit of such allegations.  Further, disclosure of the subject matter of any investigation could adversely affect our reputation and our ability to obtain new business with potential customers, to retain existing business with our current customers, to attract and retain employees and to access the capital markets.

We are subject to investigations and litigation that, if not resolved in our favor and not sufficiently insured against, could have a material adverse effect on us.

We are subject to a variety of disputes, investigations and litigation.  Certain of our subsidiaries are subject to and have been involved in litigation with certain of our customers and other constituents.  Certain of our subsidiaries are named as defendants in numerous lawsuits alleging personal grievances or injury, including as a result of exposure to asbestos or toxic fumes or resulting from other occupational diseases, such as silicosis, and various other medical issues that can remain undiscovered for a considerable amount of time.  Some of these subsidiaries that have been put on notice of potential liabilities have no assets.  Certain subsidiaries are subject to litigation relating to environmental damage.  Our patent for dual-activity technology has been successfully challenged in certain jurisdictions.  We are also subject to a number of significant tax disputes.  We cannot predict the outcome of the investigations and cases involving the Company or our subsidiaries or the potential costs to resolve them.  Insurance may not be applicable or sufficient in all cases, insurers may not remain solvent and policies may not be located.  Suits against non-asset-owning subsidiaries have and may in the future give rise to alter ego or successor-in-interest claims against us and our asset-owning subsidiaries to the extent a subsidiary is unable to pay a claim or insurance is not available or sufficient to cover the claims.  To the extent that one or more pending or future investigations or litigation matters is not resolved in our favor and is not covered by insurance, which could have an adverse effect on our financial position, results of operations or cash flows.

We are subject to cybersecurity risks and threats as well as increasing regulation of data privacy and security.

We depend on data and digital technologies to conduct our offshore and onshore operations, to collect payments from customers and to pay vendors and employees.  Our data protection measures and measures taken by our customers and vendors may not prevent unauthorized access of information technology systems.  Threats to our information technology systems, and the systems of our customers and vendors, associated with cybersecurity risks and cyber-incidents or attacks continue to grow.  Threats to our systems and our customers’ and vendors’ systems may derive from human error, fraud or malice, social engineering on the part of employees or third parties, or may

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result from accidental technological failure.  In addition, breaches to our systems and systems of our customers and vendors could go unnoticed for some period of time.  Risks associated with these threats include disruptions of certain systems on our rigs; other impairments of our ability to conduct our operations; loss or ransom of intellectual property, proprietary information or customer and vendor data; disruption of our customers’ and vendors’ operations; misappropriation of assets; loss or damage to our customer and vendor data delivery systems; and increased costs to prevent, respond to or mitigate cybersecurity events.  A breach could also originate from, or compromise, our customers’ and vendors’ or other third-party networks outside of our control.  A breach may also result in legal claims or proceedings against us by our shareholders, employees, customers, vendors and governmental authorities, both U.S. and non-U.S.  If such a cyber-incident were to occur, it could have a material adverse effect on our business or on our consolidated financial position, results of operations or cash flows.

In addition, laws and regulations governing data privacy and the unauthorized disclosure of personal data and confidential information, including the European Union General Data Protection Regulation, the Data Protection Law, as revised, of the Cayman Islands, the General Data Protection Law of Brazil and the California Consumer Privacy Act, pose increasingly complex compliance challenges and potential to elevate our costs.  Any failure by us to comply with these laws and regulations, including as a result of a security or privacy breach, could result in significant penalties, litigation and liabilities for us.  Additionally, if we acquire a company that has violated or is not in compliance with applicable data protection laws, we may incur significant liabilities and penalties as a result.

Acts of terrorism, piracy and political and social unrest could affect the markets for drilling services.

Acts of terrorism and social unrest, brought about by world political events or otherwise, have caused instability in the world’s financial and insurance markets in the past and may occur in the future.  Such acts could be directed against companies such as ours.  In addition, acts of terrorism, piracy and social unrest could lead to increased volatility in prices for crude oil and natural gas and could affect the markets for drilling services.  Insurance premiums could increase and coverage may be unavailable in the future.  Government regulations may effectively preclude us from engaging in business activities in certain countries.  These regulations could be amended to cover countries where we currently operate or where we may wish to operate in the future.  Our drilling contracts do not generally provide indemnification against loss of capital assets or loss of revenues resulting from acts of terrorism, piracy or political or social unrest.  We have limited insurance for our assets providing coverage for physical damage losses resulting from certain risks, such as terrorist acts, piracy, vandalism, sabotage, civil unrest, expropriation and acts of war, and we do not carry insurance for loss of revenues resulting from such risks.

Risks related to taxes

A change in tax laws, treaties or regulations, or their interpretation, of any country in which we have operations, are incorporated or are resident could result in a higher effective tax rate on our consolidated earnings and increase our cash tax payments.

We are subject to changes in applicable tax laws, treaties or regulations in the jurisdictions in which we operate and earn income, and such changes could include laws or policies directed toward companies organized in jurisdictions with low tax rates with the intent to increase the tax burden.  Switzerland, for example, enacted tax reform in response to certain guidance from and demands by the EU and the Organization for Economic Co-operation and Development (the “OECD”) effective January 2022.  Similarly, the OECD issued its action plan of tax reform measures that called for member states to take action to prevent base erosion and profit shifting.  Some of these measures impact transfer pricing, requirements to qualify for tax treaty benefits, and the definition of permanent establishments depending on each jurisdiction’s adoption and interpretation of such proposals.  Respective countries have adopted various measures into their own tax laws.  In addition, the EU issued its Anti-Tax Avoidance Directives in 2016 and 2017 that required its member states to adopt specific tax reform measures starting in 2019.  Other tax jurisdictions in which we operate may consider implementing similar legislation.  Any material change to tax laws, treaties, regulations or policies, their interpretation or application, or the adoption of new interpretations of existing laws and rulings, in any of the jurisdictions in which we operate, are incorporated or resident, could result in a higher effective tax rate on our worldwide earnings and such change could have a significant adverse effect on our consolidated financial position, results of operations or cash flows.

A loss of a major tax dispute or a successful tax challenge to our operating structure, intercompany pricing policies or the taxable presence of our key subsidiaries in certain countries could result in a higher effective tax rate on our consolidated earnings and increase our cash tax payments.

We are subject to tax laws, treaties and regulations in the countries in which we operate and earn income.  Our income taxes are based on the applicable tax laws and tax rates in effect in the countries in which we operate and earn income as well as upon our operating structures in these countries.  Our income tax returns are subject to review and examination in these jurisdictions, and we do not recognize the benefit of income tax positions we believe are more likely than not to be disallowed upon challenge by a tax authority.  If any tax authority successfully challenges our operational structure, intercompany pricing policies or the taxable presence of our key subsidiaries in certain countries; or if the terms of certain income tax treaties are interpreted in a manner that is adverse to our structure; or if we lose a material tax dispute in any country, our effective tax rate on our worldwide earnings could increase substantially and our earnings and cash flows from operations could be materially adversely affected.  For example, we believe that neither we nor our non-U.S. subsidiaries, other than those that report a U.S. trade or business or a U.S. permanent establishment, were or are engaged in a trade or business in the U.S. or, if applicable, maintained or maintain a permanent establishment in the U.S.  The determination of the aforementioned, among other things, involves considerable uncertainty.  If the U.S. Internal Revenue Service (the “IRS”) were to disagree, then we could be subject to additional U.S. corporate income and branch profits taxes on the portion of our earnings effectively connected to such U.S. business or, if applicable,

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attributable to such U.S. permanent establishment during the period in which this was considered to have occurred.  If this occurs, our effective tax rate on worldwide earnings for that period could increase substantially, we could be subject to assessments in previously filed returns that remain open to audit and our earnings and cash flows from operations for that period could be adversely affected.

U.S. tax authorities could treat us as a passive foreign investment company, which would have adverse U.S. federal income tax consequences to U.S. shareholders.

A foreign corporation will be treated as a passive foreign investment company (“PFIC”) for U.S. federal income tax purposes if either (1) at least 75 percent of its gross income for any taxable year consists of certain types of passive income or (2) at least 50 percent of the average value of the corporation's assets produce or are held for the production of those types of passive income.  For purposes of these tests, passive income includes dividends, interest and gains from the sale or exchange of investment property and certain rents and royalties, but does not include income derived from performing services.

We believe that we have not been and will not be a PFIC with respect to any taxable year.  Our income from offshore contract drilling services should be treated as services income for purposes of determining whether we are a PFIC.  Accordingly, we believe that our income from our offshore contract drilling services should not constitute passive income, and the assets that we own and operate in connection with the production of that income should not constitute passive assets.  There is significant legal authority supporting this position, including statutory provisions, legislative history, case law and IRS pronouncements concerning the characterization, for other tax purposes, of income derived from services where a substantial component of such income is attributable to the value of the property or equipment used in connection with providing such services.  However, a prior case and an IRS pronouncement that relies on such case characterize income from time chartering of vessels as rental income rather than services income for other tax purposes.  The IRS has subsequently formally announced that it does not agree with the decision in that case.  Moreover, we believe that the terms of the time charters in the prior case differ in material respects from the terms of our drilling contracts with customers.  However, no assurance can be given that the IRS or a court will accept our position, and there is a risk that the IRS or a court could determine that we are a PFIC.

If we were treated as a PFIC for any taxable year, our U.S. shareholders would face adverse U.S. tax consequences.  Under the PFIC rules, unless a shareholder makes certain elections available under the Internal Revenue Code of 1986, as amended, which elections could themselves have adverse consequences for the shareholder, the shareholder could be required to pay U.S. federal income tax at the highest applicable income tax rates on ordinary income upon the receipt of excess distributions, as defined for U.S. tax purposes, and upon any gain from the disposition of our shares, plus interest on such amounts, as if such excess distribution or gain had been recognized ratably over the shareholder’s holding period of our shares.  Additionally, under applicable statutory provisions, the preferential tax rate on qualified dividend income, which applies to dividends paid to non-corporate shareholders, does not apply to dividends paid by a foreign corporation if the foreign corporation is a PFIC for the taxable year in which the dividend is paid or the preceding taxable year.

Risks related to our jurisdiction of organization and governing documents

As a Swiss corporation, our flexibility may be limited with respect to certain aspects of capital management AND swift implementation of certain initiatives or strategies.

Under Swiss law, our shareholders may approve an authorized share capital that allows the board of directors to issue new shares without additional shareholder approval within a period of up to two years and for up to a maximum of 50 percent of a company’s issued share capital.  The authorized share capital approved by our shareholders at the May 2020 annual general meeting will expire on May 7, 2022.  Our currently available authorized share capital is limited to approximately 29 percent of our issued share capital as of February 16, 2021.  Accordingly, shareholders at our annual general meeting in May 2021 may be requested to approve a renewal and an increase in authorized share capital.  Additionally, subject to certain exceptions, Swiss law grants preemptive rights to existing shareholders to subscribe for new issuances of shares.  Further, Swiss law does not provide as much flexibility in the various terms that can attach to different classes of shares as the laws of some other jurisdictions.  Swiss law also reserves for shareholder approval certain corporate actions over which a board of directors would have authority in some other jurisdictions.  For example, dividends must be approved by shareholders.  These Swiss law requirements relating to our capital management may limit our flexibility, and situations may arise where greater flexibility would have provided substantial benefits to our shareholders.

Distributions to shareholders in the form of a par value reduction and dividend distributions out of qualifying additional paid-in capital are not currently subject to the 35 percent Swiss federal withholding tax.  However, the Swiss withholding tax rules could also be changed in the future, and any such change may adversely affect us or our shareholders.  In addition, over the long term, the amount of par value available for us to use for par value reductions or the amount of qualifying additional paid-in capital available for us to pay out as distributions is limited.  If we are unable to make a distribution through a reduction in par value, or out of qualifying additional paid-in capital as shown on Transocean Ltd.’s standalone Swiss statutory financial statements, we may not be able to make distributions without subjecting our shareholders to Swiss withholding taxes.

Under Swiss tax law, repurchases of shares for the purposes of capital reduction are treated as a partial liquidation subject to a 35 percent Swiss withholding tax based on the difference between the repurchase price and the related amount of par value and the related amount of qualifying additional paid-in capital, if any.  At our 2009 annual general meeting, our shareholders approved the repurchase of up to CHF 3.5 billion of our shares for cancellation under the share repurchase program.  If we repurchase shares, we expect to use an alternative procedure pursuant to which we repurchase shares via a “virtual second trading line” from market players, such as banks and

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institutional investors, who are generally entitled to receive a full refund of the Swiss withholding tax.  The use of such “virtual second trading line” with respect to share repurchase programs is subject to the approval of the competent Swiss tax and other authorities.  We may not be able to repurchase as many shares as we would like to repurchase for purposes of capital reduction on the “virtual second trading line” without subjecting the selling shareholders to Swiss withholding taxes.

We are required, from time to time, to evaluate the carrying amount of our investments in affiliates, as presented on our Swiss standalone balance sheet.  If we determine that the carrying amount of any such investment exceeds its fair value, we may conclude that such investment is impaired.  The recognized loss associated with such a non-cash impairment could result in our net assets no longer covering our statutory share capital and statutory capital reserves.  Under Swiss law, if our net assets cover less than 50 percent of our statutory share capital and statutory capital reserves, the board of directors must convene a general meeting of shareholders and propose measures to remedy such a capital loss.  The appropriate measures depend on the relevant circumstances and the magnitude of the recognized loss and may include seeking shareholder approval for offsetting the aggregate loss, or a portion thereof, with our statutory capital reserves, including qualifying additional paid-in capital otherwise available for distributions to shareholders, or raising new equity.  Depending on the circumstances, we may also need to use qualifying additional paid-in capital available for distributions in order to reduce our accumulated net loss and such use might reduce our ability to make distributions without subjecting our shareholders to Swiss withholding tax.

These Swiss law requirements could limit our flexibility to swiftly implement certain initiatives or strategies.

We are subject to anti-takeover provisions.

Our articles of association and Swiss law contain provisions that could prevent or delay an acquisition of the company by means of a tender offer, a proxy contest or otherwise.  Actions taken under such provisions may adversely affect prevailing market prices for our shares, and could, among other things:

Item 1B.Unresolved Staff Comments

None.

Item 2.Properties

The description of our property included under “Item 1. Business” is incorporated by reference herein.  We maintain offices, land bases and other facilities worldwide, most of which we lease, including principal executive offices in Steinhausen, Switzerland, and corporate offices in Houston, Texas, and the Cayman Islands.  Our remaining offices and bases are located in various countries in North America, Europe, South America, Asia and Africa.

Item 3.Legal Proceedings

We have 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—Commitments and Contingencies” and “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Other Matters—Regulatory Matters” in this annual report on Form 10-K.  We are also involved in various tax matters as described in “Part II. Item 8. Financial Statements and Supplementary

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Data—Notes to Consolidated Financial Statements—Note 10—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 this annual report on Form 10-K.  All such actions, claims, tax and other matters disclosed therein are incorporated herein by reference.

As of December 31, 2020, we were 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 consolidated financial position, results of operations or cash flows.  We cannot predict with certainty the outcome or effect of any of the matters referred to above or of any such other pending or threatened litigation or legal proceedings.  There can be no assurance that our beliefs or expectations as to the outcome or effect of any lawsuit or 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 4.Mine Safety Disclosures

Not applicable.

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Information About Our Executive Officers

We have included the following information, presented as of February 16, 2021, on our executive officers for purposes of U.S. securities laws in Part I of this report in reliance on General Instruction G(3) to Form 10-K.  The board of directors elects the officers of the Company, generally on an annual basis.  There is no family relationship between any of our executive officers.

Jeremy D. Thigpen is President and Chief Executive Officer and a member of the Company’s board of directors.  Before joining the Company in this position in April 2015, Mr. Thigpen served as Senior Vice President and Chief Financial Officer at National Oilwell Varco, Inc. from December 2012 to April 2015.  At National Oilwell Varco, Inc., Mr. Thigpen also served as President, Downhole and Pumping Solutions from August 2007 to December 2012, as President of the Downhole Tools Group from May 2003 to August 2007 and as manager of the Downhole Tools Group from April 2002 to May 2003.  From 2000 to 2002, Mr. Thigpen served as the Director of Business Development and Special Assistant to the Chairman for National Oilwell Varco, Inc.  Mr. Thigpen earned a Bachelor of Arts degree in Economics and Managerial Studies from Rice University in 1997, and he completed the Program for Management Development at Harvard Business School in 2001.

Keelan Adamson is Executive Vice President and Chief Operations Officer of the Company.  Before being named to his current position in August 2018, Mr. Adamson served as Senior Vice President, Operations from October 2017 to July 2018 and as Senior Vice President, Operations Integrity and HSE, from June 2015 to October 2017.  Since 2010, Mr. Adamson served in multiple executive positions with responsibilities spanning Engineering and Technical Services, Major Capital Projects, Human Resources, and more recently, Operations Integrity and HSE.  Mr. Adamson started his career as a drilling engineer with BP Exploration in 1991 and joined Transocean in July 1995.  In addition to several management assignments in the U.K., Asia, and Africa, he also held leadership roles in Sales and Marketing, Well Construction and Technology, and as Managing Director for operations in North America, Canada and Trinidad.  Mr. Adamson earned a Bachelor's degree in Aeronautical Engineering from The Queens University of Belfast and completed the Advanced Management program at Harvard Business School in 2016.  Mr. Adamson also currently serves on the board of the National Ocean Industries Association.

Howard E. Davis is Executive Vice President, Chief Administrative Officer and Chief Information Officer of the Company.  Before joining the Company in this position in August 2015, Mr. Davis served as Senior Vice President, Chief Administrative Officer and Chief Information Officer of National Oilwell Varco, Inc. from March 2005 to April 2015 and as Vice President, Chief Administrative Officer and Chief Information Officer from August 2002 to March 2005.  Mr. Davis earned a Bachelor’s degree from University of Kentucky in 1980, and he completed the Advanced Management Program at Harvard Business School in 2005.

Brady K. Long is Executive Vice President and General Counsel of the Company.  Before being named to his current position in March 2018, Mr. Long served as Senior Vice President and General Counsel from November 2015 to March 2018.  From 2011 to November 2015, when Mr. Long joined the Company, he served as Vice President—General Counsel and Secretary of Ensco plc, which acquired Pride International, Inc. where he had served as Vice President, General Counsel and Secretary since August 2009.  Mr. Long joined Pride International, Inc. in June 2005 as Assistant General Counsel and served as Chief Compliance Officer from June 2006 to February 2009.  He was director of Transocean Partners LLC from May 2016 until December 2016.  Mr. Long previously practiced corporate and securities law with the law firm of Bracewell LLP.  Mr. Long earned a Bachelor of Arts degree from Brigham Young University in 1996, a Juris Doctorate degree from the University of Texas School of Law in 1999 and an Executive LLM in Taxation from New York University in 2019.

Mark L. Mey is Executive Vice President and Chief Financial Officer of the Company.  Before joining the Company in this position in May 2015, Mr. Mey served as Executive Vice President and Chief Financial Officer of Atwood Oceanics, Inc. from January 2015 to May 2015, prior to which he served as Senior Vice President and Chief Financial Officer from August 2010.  Mr. Mey was director of Transocean Partners LLC from June 2015 until December 2016.  He served as Director, Senior Vice President and Chief Financial Officer of Scorpion Offshore Ltd. from August 2005 to July 2010.  Prior to 2005, Mr. Mey held various senior financial and other roles in the drilling and financial services industries, including 12 years with Noble Corporation.  He earned an Advanced Diploma in Accounting and a Bachelor of Commerce degree from the University of Port Elizabeth in South Africa in 1985, and he is a chartered accountant.  Additionally, Mr. Mey completed the Harvard Business School Executive Advanced Management Program in 1998.

David Tonnel is Senior Vice President and Chief Accounting Officer.  Before being named to his current position in April 2017, he served as Senior Vice President, Supply Chain and Corporate Controller from October 2015 to April 2017, as Senior Vice President, Finance and Controller from March 2012 to October 2015 and as Senior Vice President of the Europe and Africa Unit from June 2009 to March 2012.  Mr. Tonnel served as Vice President of Global Supply Chain from November 2008 to June 2009, as Vice President of Integration and Process Improvement from November 2007 to November 2008, and as Vice President and Controller from February 2005 to November 2007.  Prior to February 2005, he served in various financial roles, including Assistant Controller; Finance Manager, Asia Australia Region; and Controller, Nigeria.  Mr. Tonnel joined the Company in 1996 after working for Ernst & Young in France as Senior Auditor.  Mr. Tonnel earned a Master of Science degree in Management from HEC in Paris, France in 1991.

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PART II

Item 5.Market for Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities

Market for Shares of Our Common Equity

Our shares are listed on the New York Stock Exchange under the ticker symbol “RIG.”  On February 16, 2021, we had 616,025,144 shares outstanding and 5,266 holders of record of our shares.

Shareholder Matters

Swiss tax consequences to our shareholders

Overview—The tax consequences discussed below are not a complete analysis or listing of all the possible tax consequences that may be relevant to our shareholders.  Shareholders should consult their own tax advisors in respect of the tax consequences related to receipt, ownership, purchase or sale or other disposition of our shares and the procedures for claiming a refund of withholding tax.

Swiss income tax on dividends and similar distributions—A non-Swiss holder is not subject to Swiss income taxes on dividend income and similar distributions in respect of our shares, unless the shares are attributable to a permanent establishment or a fixed place of business maintained in Switzerland by such non-Swiss holder.  However, dividends and similar distributions are subject to Swiss withholding tax, subject to certain exceptions.  See “—Swiss withholding tax on dividends and similar distributions to shareholders.”

Swiss wealth tax—A non-Swiss holder is not subject to Swiss wealth taxes unless the holder’s shares are attributable to a permanent establishment or a fixed place of business maintained in Switzerland by such non-Swiss holder.

Swiss capital gains tax upon disposal of shares—A non-Swiss holder is not subject to Swiss income taxes for capital gains unless the holder’s shares are attributable to a permanent establishment or a fixed place of business maintained in Switzerland by such non-Swiss holder.  In such case, the non-Swiss holder is required to recognize capital gains or losses on the sale of such shares, which are subject to cantonal, communal and federal income tax.

Swiss withholding tax on dividends and similar distributions to shareholders—A Swiss withholding tax of 35 percent is due on dividends and similar distributions to our shareholders from us, regardless of the place of residency of the shareholder, subject to the exceptions discussed under “—Exemption” below.  We will be required to withhold at such rate and remit on a net basis any payments made to a holder of our shares and pay such withheld amounts to the Swiss federal tax authorities.

Exemption—Distributions to shareholders in the form of a par value reduction or out of qualifying additional paid-in capital for Swiss statutory purposes are exempt from Swiss withholding tax.  On December 31, 2020, the aggregate amount of par value of our outstanding shares was CHF 61.5 million, equivalent to approximately $69.5 million, and the aggregate amount of qualifying additional paid-in capital of our outstanding shares was CHF 13.5 billion, equivalent to approximately $15.3 billion.  Consequently, we expect that a substantial amount of any potential future distributions may be exempt from Swiss withholding tax.

Refund available to Swiss holders—A Swiss tax resident, corporate or individual, can recover the withholding tax in full if such resident is the beneficial owner of our shares at the time the dividend or other distribution becomes due and provided that such resident reports the gross distribution received on such resident’s income tax return, or in the case of an entity, includes the taxable income in such resident’s income statement.

Refund available to non-Swiss holders—If the shareholder that receives a distribution from us is not a Swiss tax resident, does not hold our shares in connection with a permanent establishment or a fixed place of business maintained in Switzerland, and resides in a country that has concluded a treaty for the avoidance of double taxation with Switzerland for which the conditions for the application and protection of and by the treaty are met, then the shareholder may be entitled to a full or partial refund of the withholding tax described above.  Switzerland has entered into bilateral treaties for the avoidance of double taxation with respect to income taxes with numerous countries, including the United States (“U.S.”), whereby under certain circumstances all or part of the withholding tax may be refunded.  The procedures for claiming treaty refunds, and the time frame required for obtaining a refund, may differ from country to country.

Refund available to U.S. residents—The Swiss-U.S. tax treaty provides that U.S. residents eligible for benefits under the treaty can seek a refund of the Swiss withholding tax on dividends for the portion exceeding 15 percent, leading to a refund of 20 percent, or a 100 percent refund in the case of qualified pension funds.  As a general rule, the refund will be granted under the treaty if the U.S. resident can show evidence of the following: (a) beneficial ownership, (b) U.S. residency and (c) meeting the U.S.-Swiss tax treaty’s limitation on benefits requirements.

The claim for refund must be filed with the Swiss federal tax authorities (Eigerstrasse 65, 3003 Bern, Switzerland), not later than December 31 of the third year following the year in which the dividend payments became due.  The relevant Swiss tax form is Form 82C for companies, 82E for other entities and 82I for individuals.  These forms can be obtained from any Swiss Consulate General in the U.S. or from the Swiss federal tax authorities at the above address or can be downloaded from the webpage of the Swiss federal tax administration.  

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Each form must be completed in triplicate, with each copy duly completed and signed before a notary public in the U.S.  Evidence that the withholding tax was withheld at the source must also be included.

Stamp duties in relation to the transfer of shares—The purchase or sale of our shares may be subject to Swiss federal stamp taxes on the transfer of securities irrespective of the place of residency of the purchaser or seller if the transaction takes place through or with a Swiss bank or other Swiss securities dealer, as those terms are defined in the Swiss Federal Stamp Tax Act and no exemption applies in the specific case.  If a purchase or sale is not entered into through or with a Swiss bank or other Swiss securities dealer, then no stamp tax will be due.  The applicable stamp tax rate is 0.075 percent for each of the two parties to a transaction and is calculated based on the purchase price or sale proceeds.  If the transaction does not involve cash consideration, the transfer stamp duty is computed on the basis of the market value of the consideration.

Share repurchases

Shares repurchased for the purpose of capital reduction are treated as a partial liquidation subject to a 35 percent Swiss withholding tax based on the difference between the repurchase price and the related amount of par value and the related amount of qualifying additional paid-in capital, if any.  We would be required to remit on a net basis the purchase price with the Swiss withholding tax deducted to a holder of our shares and pay the withholding tax to the Swiss federal tax authorities.  However, for such repurchased shares, the portions of the repurchase price that are attributable to the par value and the qualifying additional paid-in capital for Swiss statutory reporting purposes are not subject to the Swiss withholding tax.

If we repurchase shares, we expect to use an alternative procedure pursuant to which we repurchase our shares via a "virtual second trading line" from market players, such as banks and institutional investors, who are generally entitled to receive a full refund of the Swiss withholding tax.  The use of such “virtual second trading line” with respect to share repurchase programs is subject to approval of the competent Swiss tax and other authorities.  We may not be able to repurchase as many shares as we would like to repurchase for purposes of capital reduction on the “virtual second trading line” without subjecting the selling shareholders to Swiss withholding taxes.  The repurchase of shares for purposes other than for cancellation, such as to retain as treasury shares for use in connection with stock incentive plans, convertible debt or other instruments within certain periods, are not generally subject to Swiss withholding tax.

Under Swiss corporate law, the right of a company and its subsidiaries to repurchase and hold its own shares is limited.  A company may repurchase its shares to the extent it has freely distributable reserves as shown on its Swiss statutory balance sheet in the amount of the purchase price and if the aggregate par value of all shares held by the company as treasury shares does not exceed 10 percent of the company’s share capital recorded in the Swiss Commercial Register, whereby for purposes of determining whether the 10 percent threshold has been reached, shares repurchased under a share repurchase program for cancellation purposes authorized by the company’s shareholders are disregarded.  As of February 16, 2021, Transocean Inc., our wholly owned subsidiary, held as treasury shares four percent of our issued and outstanding shares as of such date.  Our board of directors could, to the extent freely distributable reserves are available, authorize the repurchase of additional shares for purposes other than cancellation, such as to retain treasury shares for use in satisfying our obligations in connection with incentive plans or other rights to acquire our shares.  Based on the number of shares held as treasury shares as of February 16, 2021, approximately six percent of our issued and outstanding shares could be repurchased for purposes of retention as additional treasury shares.  Although our board of directors has not approved such a share repurchase program for the purpose of retaining repurchased shares as treasury shares, if it did so, any such shares repurchased would be in addition to any shares repurchased under the currently approved program.

Issuer Purchases of Equity Securities

Item 6.Selected Financial Data

Part II, Item 6 is no longer required as we have adopted certain provisions within the amendments to Regulation S-K that eliminate Item 301.

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Item 7.Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following information should be read in conjunction with the information contained in “Part I. Item 1. Business,” “Part I. Item 1A. Risk Factors” and the audited consolidated financial statements and the notes thereto included under “Item 8. Financial Statements and Supplementary Data” elsewhere in this annual report on Form 10-K.  The following discussion of our results of operations and liquidity and capital resources includes comparisons for the years ended December 31, 2020 and 2019.  For a discussion, including comparisons, of our results of operations and liquidity and capital resources for the years ended December 31, 2019 and 2018, see “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our annual report on Form 10-K for the year ended December 31, 2019, filed with the United States (“U.S.”) Securities and Exchange Commission on February 18, 2020.

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 February 16, 2021, we owned or had partial ownership interests in and operated 37 mobile offshore drilling units, including 27 ultra-deepwater floaters and 10 harsh environment floaters.  As of February 16, 2021, 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.  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 exchanges—On August 14, 2020, we issued $238 million aggregate principal amount of 2.50% senior guaranteed exchangeable bonds due January 2027 (the “Senior Guaranteed Exchangeable Bonds”) in non-cash private exchanges for $397 million aggregate principal amount of the 0.50% exchangeable senior bonds due January 2023 (the “Exchangeable Senior Bonds”) (collectively, the “Private Exchange”).  In the year ended December 31, 2020, as a result of the Private Exchange, we recognized a gain of $72 million associated with the restructuring of debt.  See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

On September 11, 2020, we issued $687 million aggregate principal amount of 11.50% senior guaranteed notes due January 2027 (the “11.50% Senior Guaranteed Notes”) in non-cash exchange transactions with the respective holders for $1.5 billion aggregate principal amount of several series of our existing debt securities that were validly tendered and accepted for purchase (the “Exchange Offers” and, together with the Private Exchange, the “Exchange Transactions”), associated with the restructuring of debt.  In the year ended December 31, 2020, as a result of the Exchange Offers, we recognized a gain of $355 million associated with the restructuring of debt.  See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

On February 26, 2021, we completed privately negotiated transactions to exchange $323 million aggregate principal amount of outstanding Exchangeable Senior Bonds for $294 million aggregate principal amount of new 4.00% Senior Guaranteed Exchangeable Bonds due 2025 (the “New Senior Guaranteed Exchangeable Bonds”) and an aggregate cash payment of $11 million.  See “—Liquidity and Capital Resources—Sources and uses of liquidity.”

Early debt retirement—On February 18, 2020, we made an aggregate cash payment of $767 million, including the make-whole premium, to redeem the outstanding 9.00% senior notes due July 2023 (the “9.00% Senior Notes”).  In the year ended December 31, 2020, we recognized a loss of $65 million associated with the retirement of redeemed debt.  See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

During the year ended December 31, 2020, we repurchased in the open market $147 million aggregate principal amount of certain of our debt securities and made an aggregate cash payment of $110 million.  In the year ended December 31, 2020, we recognized an aggregate net gain of $36 million, associated with the retirement of repurchased debt.  See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

On November 9, 2020, we completed cash tender offers (the “2020 Tender Offers”) to purchase (i) any and all of the outstanding 6.50% senior notes due November 2020 and (ii) up to $200 million in aggregate purchase price of the 6.375% senior notes due December 2021, 3.80% senior notes due October 2022, the 5.375% senior secured notes due May 2023 (“5.375% Senior Secured Notes”) and the 7.25% senior notes due November 2025 (the “7.25% Guaranteed Notes”), subject to certain conditions specified in the related offer

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to purchase.  In the year ended December 31, 2020, as a result of the 2020 Tender Offers, we made an aggregate cash payment of $222 million and recognized a gain of $135 million associated with the retirement of such notes.  See “—Operating Results” and “—Liquidity and Capital Resources—Sources and uses of liquidity.”

Debt issuances—On January 17, 2020, we issued $750 million aggregate principal amount of 8.00% senior notes due February 2027 (the “8.00% Guaranteed Notes”), and we received aggregate cash proceeds of $743 million, net of issue costs.  See “—Liquidity and Capital Resources—Sources and uses of liquidity.”

Debt exchange litigation and purported notice of default—In September 2020, funds managed by, or affiliated with, Whitebox Advisors LLC (“Whitebox”) as holders of certain series of our notes subject to the Exchange Offers, filed a claim (the “Claim”) in the U.S. District Court for the Southern District of New York (the “Court”) related to certain internal reorganization transactions (the “Internal Reorganization”) and the Exchange Offers.  Additionally, in September and October 2020, Whitebox and funds managed by, or affiliated with, Pacific Investment Management Company LLC (“PIMCO”) as debtholders, together with certain other advisors and debtholders, provided purported notices of alleged default with respect to the indentures governing, respectively, the 8.00% Guaranteed Notes and the 7.25% Guaranteed Notes.  Following our amendment of certain of our financing documents and certain internal reorganization transactions, we do not expect the liability, if any, resulting from these matters to have a material adverse effect on our consolidated financial statements.  See “—Liquidity and Capital Resources—Sources and uses of liquidity.”

Customer 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 year ended December 31, 2020, we recognized an aggregate loss of $556 million primarily associated with the impairment of one ultra-deepwater floater, two harsh environment floaters and three midwater floaters, along with related assets, which we determined were impaired at the time we classified the assets as held for sale.  In the year ended December 31, 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 Holdings (Cayman) Limited (together with its subsidiary, “Orion”).  In the year ended December 31, 2020, we recognized a loss of $31 million associated with the impairment of our midwater asset group.  See “—Operating Results.”

Dispositions—During the year ended December 31, 2020, we completed the sale of one ultra-deepwater floater, three harsh environment floaters and three midwater floaters, along with related assets, and we received $20 million in aggregate net cash proceeds.  See “—Operating Results” and “—Liquidity and Capital Resources.”

Outlook

Drilling market—Since 2014, the industry has experienced a severe cyclical downturn of considerably longer duration than those previously observed.  Multiple years of volatile and generally weak commodity prices, exacerbated in 2020 by the effects of the coronavirus (“COVID-19”) pandemic and production disputes among major oil producing countries, have resulted in our customers repeatedly delaying offshore investment decisions and postponing exploration and development programs. Some of our customers have also recently committed to invest or increase investment in low carbon and renewable energy resources, potentially reducing their expenditures in the development and production of hydrocarbons over the coming decades.  However, even in the context of some diversion of investment away from traditional sources of energy, the structural efficiency gains achieved by the offshore oil and gas segment in the past six years have materially improved the economics of deepwater offshore development projects, making the segment a competitive source of new supply.

We anticipate that the subdued level of contract activity will continue for at least the first half of 2021, although we believe that by the second half of 2021, our customers will again focus on favorable deepwater offshore economics and begin increasing their exploration, production and reserve replacement activities by restarting delayed projects and commencing new campaigns.  This depends on many variables, including global amelioration of the COVID-19 pandemic, and the effects of actions by some governments and regulators intended to curtail existing and future drilling activities, and other factors.  Ultimately, as the hydrocarbon supply-demand balance improves, including as the result of a post-pandemic global economic recovery, we expect a sustained improvement of oil prices, which will result in greater demand for our high-specification fleet of assets, resulting in further improvement of dayrates.

In markets requiring harsh environment floating drilling rigs, the limited supply of these specialized high-specification rigs has continued to result in strong utilization and dayrates.  In the ultra-deepwater markets, we have seen accelerated retirement of idle rigs, and with the anticipated consolidation of distressed drilling contractors, we expect additional retirements will reduce supply and improve utilization and dayrate metrics for high-specification assets.

As of February 12, 2021, our contract backlog was $7.8 billion compared to $8.2 billion as of October 14, 2020.  The risks of drilling project delays, contract renegotiations and contract terminations and cancellations have diminished as oil prices have improved and stabilized.

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 or is not committed to

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a shipyard.  The uncommitted fleet rates exclude the effect of priced options.  As of February 12, 2021, uncommitted fleet rates for each of the five years in the period ending December 31, 2025 were as follows:

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:

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.  It does not include conditional agreements and options to extend firm commitments.  Our contract backlog includes amounts associated with our contracted newbuild unit that 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 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.

Average contractual dayrate relative to our contract backlog is defined as the average maximum contractual operating dayrate to be earned per operating day in the measurement period.  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.

At February 12, 2021, the contract backlog and average contractual dayrates for our fleet were as follows:

The actual amounts of revenues earned and the actual periods during which revenues are earned will differ from the amounts and periods shown in the tables above due to various factors, including shipyard and maintenance projects, unplanned downtime and other factors that result in lower applicable dayrates than the full contractual operating dayrate.  Additional factors that could affect the amount and timing of actual revenue to be recognized include customer liquidity issues and contract terminations, which may be available to our customers under certain circumstances.

The COVID-19 pandemic and the volatility in oil prices in the year ended December 31, 2020, which have included precipitous drops in oil prices, could have significant adverse consequences for the financial condition of our customers.  This could 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.  See “Part I. Item 1A. Risk Factors—Risks related to our business—Our current backlog of contract drilling revenues may not be fully realized.”

Average daily revenue—Average daily revenue is defined as contract drilling revenues, excluding revenues for contract terminations, reimbursements and contract intangible amortization, earned per operating day.  An operating day is defined as a calendar day

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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:

Our average daily revenue fluctuates relative to market conditions and our revenue efficiency.  The average daily revenue may 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:

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 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:

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, 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

Year ended December 31, 2020 compared to the year ended December 31, 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.

“nm” means not meaningful.

Contract drilling revenues—Contract drilling revenues increased for the year ended December 31, 2020, compared to the year ended December 31, 2019, primarily due to the following: (a) $177 million resulting from the settlement of disputes in the year ended December 31, 2020, (b) approximately $110 million resulting from the reactivations of two ultra-deepwater floaters in Brazil in the year ended December 31, 2019, (c) approximately $55 million resulting from higher dayrates on our comparable active fleet, (d) approximately $50 million resulting from the operations of the harsh environment floater that we operate under a bareboat charter that commenced in August 2019, (e) approximately $37 million resulting from reimbursement revenues related to COVID-19, (f) approximately $30 million resulting from the early termination of a contract for the convenience of our customers and (g) approximately $25 million resulting from higher revenue efficiency on the comparable active fleet.  These increases were partially offset by the following decreases: (a) approximately $170 million resulting from rigs stacked, (b) approximately $140 million resulting from decreased activity on the comparable active fleet, (c) approximately $60 million resulting from rigs sold or classified as held for sale and (d) approximately $45 million resulting from lower reimbursement revenues unrelated to COVID-19.

Costs and expenses—Operating and maintenance costs and expenses decreased for the year ended December 31, 2020, compared to the year ended December 31, 2019, primarily due to the following: (a) approximately $80 million resulting from rigs stacked, (b) approximately $75 million resulting from reduced shipyard, personnel and in-service maintenance costs on the comparable active fleet, (c) approximately $65 million resulting from rigs sold or classified as held for sale, (d) approximately $45 million resulting from resulting from lower customer reimbursable costs unrelated to COVID-19 and (e) approximately $40 million resulting from optimized onshore personnel costs.  These decreases were partially offset by the following increases: (a) approximately $70 million resulting from the operations of the harsh environment floater that we operate under a bareboat charter that commenced in August 2019, (b) approximately $65 million resulting from personnel and related costs associated with mitigating the effect of the COVID-19 pandemic and (c) approximately $30 million resulting from the reactivations of two ultra-deepwater floaters in Brazil in the year ended December 31, 2019.

Depreciation and amortization expense decreased for the year ended December 31, 2020, compared to the year ended December 31, 2019, primarily due to approximately $65 million resulting from rigs sold or classified as held for sale and approximately $20 million resulting from assets that had reached the end of their useful lives or had been retired, partially offset by approximately $20 million resulting from assets placed into service.

General and administrative expense decreased for the year ended December 31, 2020, compared to the year ended December 31, 2019, primarily due to the following: (a) approximately $7 million resulting from personnel and other costs related to the integration of Ocean Rig UDW Inc. (“Ocean Rig”) in the year ended December 31, 2019, (b) approximately $5 million resulting from reduced legal and professional fees and (c) approximately $5 million resulting from reduced office rent expense.  These decreases were partially offset by the following

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increases: (a) approximately $5 million resulting from increased insurance costs and (b) approximately $3 million resulting from increased software licensing and subscription arrangements.

Loss on impairment or disposal of assets—In the year ended December 31, 2020, we recognized a loss on the impairment of assets, including an aggregate net loss of $556 million associated with assets that we determined were impaired at the time we classified them as held for sale, a loss of $31 million associated with the impairment of our midwater floater asset group and a loss of $10 million associated with the impairment of other assets .  In the year ended December 31, 2019, we recognized an aggregate loss of $583 million, primarily associated with certain assets that we determined were impaired at the time we classified them as held for sale, and an aggregate loss of $26 million associated with the impairment of right-of-use assets and leasehold improvements.

In the year ended December 31, 2020, we recognized an aggregate loss of $61 million associated with the sale of one ultra-deepwater floater, three harsh environment floaters and three midwater floaters, along with related assets.  In the year ended December 31, 2019, we recognized an aggregate gain of $4 million associated with the sale of six ultra-deepwater floaters, one harsh environment floater, two deepwater floaters and two midwater floaters, along with related assets.  In the years ended December 31, 2020 and 2019, we recognized an aggregate loss of $23 million and $16 million, respectively, associated with the disposal of assets unrelated to rig sales.

Other income and expense—Interest expense, net of amounts capitalized, decreased in the year ended December 31, 2020, compared to the year ended December 31, 2019, primarily due to a decrease of $155 million resulting from the debt retired, repaid or restructured, partially offset by an increase of $78 million primarily resulting from debt issued.

In the year ended December 31, 2020, we recognized a net gain on restructuring and retirement of debt, primarily due to the following: (a) an aggregate gain of $427 million associated with the restructuring of debt in the Exchange Transactions, (b) an aggregate gain of $135 million associated with the retirement of $360 million aggregate principal amount of our debt securities in the 2020 Tender Offers, (c) an aggregate gain of $36 million associated with the retirement of $147 million aggregate principal amount of our debt securities repurchased in the open market, partially offset by (d) a loss of $65 million associated with the full redemption of the 9.00% Senior Notes due July 2023.  In the year ended December 31, 2019, we recognized a net loss on retirement of debt, including a loss of $23 million resulting from the retirement of $434 million aggregate principal amount of our debt securities repurchased in the open market and a loss of $18 million resulting from retirement of validly tendered notes (the “2019 Tendered Notes”).

Other expense, net, increased in the year ended December 31, 2020, compared to the year ended December 31, 2019, primarily due to the following: (a) a gain of $132 million recognized in the prior year resulting from the termination of construction contracts, (b) a loss of $59 million recognized in the year ended December 31, 2020, associated with the impairment of our equity-method investment in Orion, (c) increased net periodic benefit costs of $14 million primarily from settlement of certain defined benefit plans in Norway, (d) increased loss of $10 million resulting from net changes in currency exchange rates and (e) a gain of $11 million recognized in the prior year resulting from the bargain purchase of Ocean Rig completed in the year ended December 31, 2018, partially offset by (f) increased income of $9 million related to our investment in Orion and (g) increased income of $5 million related to our dual-activity patent.

Income tax expense—In the years ended December 31, 2020 and 2019, our effective tax rate was (5.1) percent and (4.9) percent, respectively, based on loss before income tax expense.  In the years ended December 31, 2020 and 2019, discrete period tax items represented a net tax benefit of $91 million and $150 million, respectively.  In the year ended December 31, 2020, we identified certain discrete items, such as losses on impairment and disposal of assets, gain on restructuring and retirement of debt, 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, settlements and expirations of various uncertain tax positions and accruals for withholding taxes.  In the year ended December 31, 2019, we identified certain discrete items, such as losses on impairment and disposal of assets, settlements and expirations of various uncertain tax positions and adjustments to our deferred taxes for operating structural changes made in the U.S.  In the years ended December 31, 2020 and 2019, our effective tax rate, excluding discrete items, was (23.4) percent and (30.7) percent, respectively, based on loss before income tax expense.  Our effective tax rate increased in the year ended December 31, 2020 compared to the year ended December 31, 2019, primarily due to a decreased loss before income taxes, partially offset by tax benefits for 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 previously recorded valuation allowances, settlements and expirations of uncertain tax positions, and adjustments to our deferred taxes for operating structural changes in the U.S., offset by tax expense for an increase in the withholding tax rate in Angola and an increase in loss before income tax expense.

Due 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 year ended December 31, 2020, a significant portion of our income tax expense was generated in countries in which income taxes are imposed on gross revenues, with the most significant of these countries being Angola 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 the U.S., Switzerland, Brazil, the United Kingdom and Norway.  Our rig operating structures further

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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.

Liquidity and Capital Resources

Sources and uses of cash

At December 31, 2020, we had $1.2 billion in unrestricted cash and cash equivalents and $406 million in restricted cash and cash equivalents.  In the year ended December 31, 2020, our primary sources of cash were net cash proceeds from the issuance of debt and net cash provided by operating activities.  Our primary uses of cash were repayments of debt and capital expenditures.