Transocean Ltd. - Annual Report: 2016 (Form 10-K)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

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, 2016

OR

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

For the transition period from _____ to _____

 

 

Commission file number 000-53533

 

 

 

TRANSOCEAN LTD.

(Exact name of registrant as specified in its charter)

 

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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S‑T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).   Yes ☑   No ◻

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S‑K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10‑K or any amendment to this Form 10‑K.   ☐

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

Large accelerated filer ☑   Accelerated filer ☐   Non‑accelerated filer (do not check if a smaller reporting company) ☐   Smaller reporting company ☐

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

As of June 30, 2016, 365,353,527 shares were outstanding and the aggregate market value of shares held by non‑affiliates was approximately $4.3 billion (based on the reported closing market price of the shares of Transocean Ltd. on June 30, 2016 of $11.89 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 28, 2017, 389,597,755 shares were outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s definitive Proxy Statement to be filed with the U.S. Securities and Exchange Commission within 120 days of December 31, 2016, for its 2017 annual general meeting of shareholders, are incorporated by reference into Part III of this Form 10‑K.

 

TRANSOCEAN LTD. AND SUBSIDIARIES

INDEX TO ANNUAL REPORT ON FORM 10‑K

FOR THE YEAR ENDED DECEMBER 31, 2016

 

 

 

 

 

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.

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 9, 2017, we owned or had partial ownership interests in and operated 56 mobile offshore drilling units.  As of February 9, 2017, our fleet consisted of 30 ultra‑deepwater floaters, seven harsh environment floaters, three deepwater floaters, six midwater floaters and 10 high‑specification jackups.  At February 9, 2017, we also had four ultra‑deepwater drillships and five high‑specification jackups under construction or under contract to be constructed.

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 deepwater and harsh environment drilling services.  We believe our mobile offshore drilling fleet is one of the most versatile fleets in the world, consisting of floaters and high‑specification jackups 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 Chemin de Blandonnet 10, 1214 Vernier, Switzerland.  Our telephone number at that address is +41 22 930‑9000.  Our shares are listed on the New York Stock Exchange under the symbol “RIG” (see “—Recent Developments”).  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 21—Operating Segments, Geographic Analysis and Major Customers.”

Recent Developments

Transocean Partners—On December 9, 2016, Transocean Partners LLC (“Transocean Partners”) completed a merger with one of our subsidiaries as contemplated under the Agreement and Plan of Merger (the “Merger Agreement”), dated July 31, 2016, and as amended on November 21, 2016.  Following the completion of the merger, Transocean Partners became a wholly owned indirect subsidiary of Transocean Ltd.  Each Transocean Partners common unit that was issued and outstanding immediately prior to the closing, other than the units held by Transocean and its subsidiaries, was converted into the right to receive 1.20 of our shares.  To complete the merger, we issued 23.8 million shares from conditional capital.

Markets for our shares—Our shares were previously listed on the SIX Swiss Exchange (“SIX”) under the symbol “RIGN”.  Effective March 31, 2016, at our request, our shares were delisted from the SIX.

Drilling Fleet

Fleet overview—Our drilling fleet can be generally characterized as follows: (1) floaters, including drillships and semisubmersibles, and (2) jackups.  Most of our drilling equipment is suitable for both exploration and development, and we normally engage in both types of drilling activity.  All of our drilling rigs are mobile and can be moved to new locations in response to customer demand.  All of 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.  All of our drillships are ultra‑deepwater capable and equipped with a computer‑controlled dynamic positioning thruster system, which allows them to maintain position without anchors through the use of their onboard propulsion and station‑keeping systems.  These rigs 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 15 ultra‑deepwater drillships that are, and four 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, reducing critical path activity, to improve efficiency in both exploration and development drilling.  In addition to dynamic positioning thruster systems, dual‑activity technology, industry‑leading hoisting capacity and a second blowout preventer system, our four newbuild drillships under construction will be outfitted to accommodate a future upgrade to a 20,000 pounds per square inch (“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.  These rigs are capable of maintaining their position over a well through the use of an anchoring system or a computer‑controlled dynamic positioning thruster system.  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.  Typically, semisubmersibles are capable of operating in rougher sea conditions than drillships.  We have

two custom‑designed, high‑capacity, dual‑activity semisubmersible drilling rigs, equipped for year‑round operations in harsh environments, including those of the Norwegian continental shelf and sub‑Arctic waters.  We have three semisubmersibles that are designed for mild environments and are equipped with the tri‑act derrick.  The tri‑act derrick, which was designed to reduce overall well construction costs since it allows offline tubular and riser handling operations to occur at two sides of the derrick while the center portion of the derrick is being used for normal drilling operations through the rotary table.  Five of our 23 semisubmersibles are equipped with our patented dual‑activity technology.

Jackup rigs are mobile self‑elevating drilling platforms equipped with legs that can be lowered to the ocean floor until a foundation is established to support the drilling platform.  Once a foundation is established, the drilling platform is then jacked further up the legs so that the platform is above the highest expected waves.  These rigs are generally suited for water depths of 400 feet or less.  We have five newbuild high‑specification jackups under construction that are expected to be capable of constructing wells up to 35,000 feet deep and feature advanced offshore drilling technology, including offline tubular handling features and simultaneous operations support.

Fleet categories—We further categorize the drilling units of our fleet as follows: (1) “ultra‑deepwater floaters,” (2) “harsh environment floaters,” (3) “deepwater floaters,” (4) “midwater floaters” and (5) “high‑specification jackups.”

Ultra‑deepwater floaters are equipped with high‑pressure mud pumps and are capable of drilling in water depths of 7,500 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.  Deepwater floaters are generally those other semisubmersible rigs and drillships capable of drilling in water depths between 4,500 and 7,500 feet.  Midwater floaters are generally comprised of those non‑high‑specification semisubmersibles that have a water depth capacity of less than 4,500 feet.  High‑specification jackups have high capacity derricks, drawworks, mud systems and storage and generally have a water depth capacity of between 350 and 400 feet.

As of February 9, 2017, we owned and operated a fleet of 56 rigs, excluding rigs under construction, as follows:

Fleet status—Depending on market conditions, we may idle or stack non‑contracted rigs.  An idle rig is between drilling contracts, readily available for operations, and operating costs are typically at or near normal 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 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, cost of equipment and materials and the extent of repairs and maintenance that may ultimately be required.  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, from time to time, consider marketing stacked rigs as accommodation units or for other alternative uses until drilling activity increases and we obtain drilling contracts for these units.  We may not return some stacked rigs to work for drilling services or for these alternative uses.

Drilling units—The following tables, presented as of February 9, 2017, 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.  As of February 9, 2017, we owned all of the drilling rigs in our fleet noted in the tables below, except for the following: (1) those specifically described as being owned through our interests in consolidated entities that were less than wholly owned and (2) Petrobras 10000, which is subject to a capital lease through August 2029.

Rigs under construction (9)

“HSD” means high‑specification drillship.

(a)To be dynamically positioned.

(b)To be equipped with dual‑activity.

(c)To be an Enterprise‑class or Enhanced Enterprise‑class rig.

(d)Designed to accommodate a future upgrade to a 20,000 pounds psi blowout preventer.

(e)To be equipped with two blowout preventers.

Ultra‑deepwater floaters (30)

“HSD” means high‑specification drillship.

“HSS” means high‑specification semisubmersible.

Harsh environment floaters (7)

“HSS” means high‑specification semisubmersible.

Deepwater floaters (3)

“HSS” means high‑specification semisubmersible.

Midwater floaters (6)

“OS” means other semisubmersible.

High‑specification jackups (10)

 

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 are able to 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 capture demand in another locale.  Consequently, we cannot predict the percentage of our revenues that will be derived from particular geographic or political areas in future periods.

As of February 9, 2017, our drilling fleet was located in the U.K. North Sea (11 units), U.S. Gulf of Mexico (nine units), Trinidad (nine units), Spain (four units), Brazil (three units), Malaysia (three units), Norway (three units). Thailand (three units), Canada (two units), Congo (two units), India (two units), Angola (one unit), Myanmar (one unit), Romania (one unit), South Africa (one unit) and United Arab Emirates (one unit).

We categorize the market sectors in which we operate as follows: (1) ultra-deepwater, (2) deepwater, (3) midwater and (4) jackup.  The ultra‑deepwater, deepwater and midwater market sectors, collectively known as the floater market, are serviced by our drillships and semisubmersibles, seven of which are suited to work in harsh environments.  We generally view the ultra-deepwater market sector as water depths beginning at 7,500 feet and extending to the maximum water depths in which rigs are capable of drilling, which is currently up to 12,000 feet.  The deepwater market sector services water depths beginning at approximately 4,500 feet to approximately 7,500 feet, and the midwater market sector services water depths from approximately 300 feet to approximately 4,500 feet.  The jackup market sector begins at the outer limit of the transition zone, which is characterized by coastal and state water areas, extending to water depths of approximately 400 feet.

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 exploration and production (“E&P”) companies and their associated capital expenditures 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 E&P companies’ ability to fund investments in exploration, development and production activities.

The industry is presently experiencing a cyclical downturn.  Sustained weak commodity pricing has resulted in our customers delaying investment decisions and postponing exploration and production programs.  Although oil and natural gas prices have improved recently, such prices do not currently support sustained demand for drilling rigs across all asset classes and regions.  As a result of this reduced demand, we have observed a sharp decline in the execution of drilling contracts for the global offshore drilling fleet and an unprecedented level of drilling contract early terminations and cancellations.  We currently expect few drilling contracts to be awarded in 2017, exacerbating the excess rig capacity and resulting in continued downward pressure on dayrates.  In this environment, older and less capable assets are more likely to be permanently retired, ultimately reducing the available supply of drilling rigs.  During the years ended December 31, 2016, 2015 and 2014, we sold for scrap value 11, 17 and two drilling units, respectively, and at December 31, 2016, we had one additional rig classified as held for sale for scrap value.

Despite current market conditions, our long‑term outlook for the offshore drilling sector remains positive, particularly for high‑specification assets.  Prior to the downturn, Brazil, the U.S. Gulf of Mexico, and West Africa emerged as key ultra‑deepwater market sectors, and licensing activity demonstrated an increased interest in deepwater fields as E&P companies looked to explore new prospects.  We expect deepwater oil and gas production will continue to be a part of the long‑term strategy for E&P companies as they strive to replace reserves to meet global demand for hydrocarbons.  A number of new deepwater and ultra‑deepwater development opportunities have been identified globally.  If commodity prices stabilize and rebound to sustainable levels, we anticipate that many of the projects will receive approval to move forward.  Typically, these projects are technically demanding due to factors such as water depth, complex well designs, deeper drilling depth, high pressure and temperature, sub‑salt, harsh environments, and heightened regulatory standards; therefore, they require sophisticated drilling units.  Generally, ultra‑deepwater rigs are the most modern, technologically advanced class of the offshore fleet and have capabilities that are attractive to E&P companies operating in deeper water depths, other challenging environments or with complex well designs.

Financial Information about Geographic Areas

The following table presents the geographic areas in which our operating revenues were earned (in millions):

The following table presents the geographic areas in which our long‑lived assets were located (in millions):

Contract Drilling Services

Our contracts to provide offshore drilling services are individually negotiated and vary in their terms and provisions.  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 rates 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 covering either the drilling of a single well or group of wells or covering a stated term.  At December 31, 2016, the contract backlog was approximately $11.7 billion, representing a decrease of 27 percent and 48 percent, respectively, compared to the contract backlog at December 31, 2015 and 2014, which was $16.0 billion and $22.5 billion, respectively.  See “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Outlook—Drilling market” and “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Outlook—Performance and Other Key Indicators.”

Certain of our drilling contracts may be cancelable for the convenience of the customer upon 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 the payment of any termination fee, under various circumstances such as non‑performance, in the event of extended downtime or impaired performance caused by 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 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, or 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 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.”

Consistent with standard industry practice, our customers generally assume, and indemnify us against, well control and subsurface risks under dayrate drilling contracts.  Under all of our current drilling contracts, our customers, as the operators, indemnify us for pollution damages in connection with reservoir fluids stemming from operations under the contract and we indemnify the operator for pollution from substances in our control that originate from the rig, such as diesel used onboard the rig or other fluids stored onboard the rig and above the

water surface.  Also, under all of our current drilling contracts, the operator indemnifies us against damage to the well or reservoir and 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 the operator against the liabilities discussed above can 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, which is, in any case, immaterial to us.  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.  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.”

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 statement of financial position, results of operations or cash flows.  See “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 13—Commitments and Contingencies.”

Significant Customers

We engage in offshore drilling services for most of the leading international oil companies or their affiliates, as well as for many government‑controlled oil companies and independent oil companies.  For the year ended December 31, 2016, our most significant customers were Chevron Corporation (together with its affiliates, “Chevron”), BP plc. (together with its affiliates, “BP”), Royal Dutch Shell plc (together with its affiliates, “Shell”) and Petróleo Brasileiro S.A. (“Petrobras”), representing approximately 24 percent, 12 percent, 12 percent and 11 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, 2016.  Additionally, as of February 9, 2017, the customers with the most significant aggregate amount of contract backlog associated with our drilling contracts were Shell and Chevron, representing approximately 63 percent and 20 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 a material adverse impact on our consolidated statement of financial position, results of operations or cash flows.”

Employees

We require highly skilled personnel to operate our drilling units.  Consequently, we conduct extensive personnel recruiting, training and safety programs.  At December 31, 2016, we had approximately 5,400 employees, including approximately 400 persons engaged through contract labor providers.  Approximately 28 percent of our total workforce, working primarily in Angola, Brazil, Norway and the U.K. are represented by, and some of our contracted labor work under, collective bargaining agreements, substantially all of which are subject to annual salary negotiation.  These negotiations could result in higher personnel expenses, other increased costs or increased operational restrictions, as the outcome of such negotiations apply to all offshore employees not just the union members.  Additionally, failure to reach agreement on certain key issues may result in strikes, lockouts or other work stoppages that may materially impact our operations.

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.  We may or may not control these joint ventures.  We are an active participant in several joint venture drilling companies, principally in Angola, Indonesia, Malaysia and Nigeria.  Local laws or customs in some areas of the world also effectively mandate establishment of a relationship with a local agent or sponsor.  When appropriate in these areas, we enter into agency or sponsorship agreements.  At December 31, 2016, joint ventures in which we participate were as follows:

We hold a 65 percent interest in ADDCL, a consolidated Cayman Islands joint venture company formed to own Discoverer Luanda, which operates in Angola.  Our local partner, Angco Cayman Limited, a Cayman Islands company, holds the remaining 35 percent interest in ADDCL.  Angco Cayman Limited has the right to exchange its interest in the joint venture for cash at an amount based on an appraisal of the fair value of the drillship, subject to certain adjustments.

We hold a 24 percent direct interest and a 36 percent indirect interest in Indigo Drilling Limited (“Indigo”), a consolidated Nigerian joint venture company formed to engage in drilling operations offshore Nigeria.  Our local partners, Mr. Fidelis Oditah and Mr. Chima Ibeneche, each hold a 12.5 percent direct interest, and our other partners, Mr. Joseph Obi and Mr. Ben Osuno, together own a 15 percent indirect interest, in Indigo.

Additionally, we hold interests in certain joint venture companies in Angola, Indonesia, Malaysia, Nigeria and other countries that have been formed to perform certain management services and other onshore support services for our operations.

Technological Innovation

Since launching the offshore industry’s first jackup drilling rig in 1954, we have achieved a long history of technological innovations, including the first dynamically positioned drillship, the first rig to drill year‑round in the North Sea and the first semisubmersible rig for year‑round sub‑Arctic operations.  We have repeatedly achieved water depth world records in the past.  Twenty drillships and semisubmersibles in our existing fleet are, and our four 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 and reduces critical path activity while improving efficiency in both exploration and development drilling.  Additionally, three rigs in our existing fleet are equipped with the tri‑act derrick, which allows offline tubular and riser activities during normal drilling operations and is patented in certain market sectors in which we operate.

We continue to develop and deploy industry‑leading technology.  In addition to our patented dual‑activity drilling technology, some of our most recent newbuild drillships include industry‑leading hookload capability, compensated cranes for performing subsea installations, hybrid power systems and reduced emissions and advanced generator protection.  Seven drillships in our existing fleet are, and our four drillships that are under construction will be, outfitted with two blowout preventers and triple liquid mud systems.  Three drillships in our existing fleet are, and our four drillships that are under construction will be, designed to accept 20,000 psi blowout preventers in the future.  The effective use of and continued improvements in technology to address our customers’ requirements are critical to maintaining our competitive position within the contract drilling services industry.  We continue to develop technology internally, such as the digital transformation program focused on utilizing analytics and data science to continuously improve operational integrity and efficiency while optimizing cost.  In addition, we are focused on a breakthrough drilling innovation program that includes a fault‑resistant and fault‑tolerant blowout preventer control system.

Environmental Compliance

Our operations are subject to a variety of global environmental regulations.  We monitor our compliance with environmental regulation in each country of operation and, while we see an increase in general environmental regulation, we have made and will continue to make the required expenditures to comply with current and future environmental requirements.  We make expenditures to further our commitment to environmental improvement and the setting of a global environmental standard.  We assess the environmental impacts of our business, focusing on the areas of greenhouse gas emissions, climate change, discharges and waste management.  Our actions are designed to reduce risk in our current and future operations, to promote sound environmental management and to create a proactive environmental program.  To date, we have not incurred material costs in order to comply with recent environmental legislation, and we do not believe that our compliance with such requirements will have a material adverse effect on our competitive position, consolidated results of operations or cash flows.  For a discussion of the effects of environmental regulation, see “Item 1A. Risk Factors—Risks related to our business—Compliance with or breach of environmental laws can be costly, expose us to liability and could limit our operations.”

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.  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 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:

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.  Any prolonged reduction 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 drive demand for our rigs.  The current commodity pricing environment has had a negative impact on demand for our services, and it could continue.  The price of crude oil as reported on the New York Mercantile Exchange has weakened significantly and, despite recent price improvements, has not returned to the higher levels experienced prior to December 31, 2014.  Consequently, customers have delayed or cancelled 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 contributed to oil and gas price volatility and are likely to do so in the future.

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 has historically been cyclical and is impacted by oil and natural gas price levels and volatility.  There have been periods of high customer demand, limited rig supply and high dayrates, 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.  We cannot predict when or if any idled or stacked rigs will return to service.

During prior periods of high dayrates and rig utilization rates, we and other industry participants have responded to increased customer demand by increasing the supply of rigs through ordering the construction of new units.  In periods of low oil and natural gas price levels, growth in 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.  Presently, there are numerous recently constructed high‑specification floaters and other drilling units capable of competing with our rigs that have entered the global market, and there are more that are under construction. 

The entry into service of these new units has increased and will continue to increase supply.  The increased supply has contributed to and may continue to contribute to a reduction in dayrates as rigs are absorbed into the active fleet and has led to accelerated stacking of the existing fleet.

Two of our four ultra‑deepwater drillships and our five high‑specification jackups currently under construction have not been contracted for work.  Combined with the rapid increase in the number of rigs in the global market completing contracts and becoming idle, the number of new units expected to be delivered without contracts has intensified and may further intensify price competition.  Any further increase in construction of new units would likely exacerbate the negative impact of increased supply on dayrates and utilization rates.  Additionally, lower market dayrates and intense price competition may drive customers to demand renegotiation of existing contracts to lower dayrates in exchange for longer contract terms.  In an oversupplied market, we may have limited bargaining power to negotiate on more favorable terms.  Lower dayrates and rig utilization rates could adversely affect our revenues and profitability.

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 these events are beyond our control.  During periods of depressed market conditions, we are subject to an increased risk of our customers seeking to repudiate their contracts, including through claims of non‑performance.  We are at continued risk of experiencing early contract terminations in the current weak commodity price environment as operators look to reduce their capital expenditures.  During the years ended December 31, 2016 and 2015, our customers early terminated or cancelled contracts for eight and five of our rigs, respectively, and these rigs currently remain idle.  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, it could adversely affect our consolidated statement of financial position, results of operations or cash flows.  See “Item 1. Business—Contract Drilling Services.”

At February 9, 2017, our contract backlog was approximately $11.3 billion.  This amount represents the firm term of the drilling contract multiplied by the contractual operating rate, which may be higher than the actual dayrate we receive or we may receive other dayrates included in the contract, such as waiting on weather rate, repair rate, standby rate or force majeure rate.  The contractual operating dayrate may also be higher than the actual dayrate we receive because of a number of factors, including rig downtime or suspension of operations.

Several factors could cause rig downtime or a suspension of operations, including:

In certain drilling contracts, the dayrate may be reduced to zero or result in customer credit against future dayrate if, for example, repairs extend beyond a stated period of time.  Our contract backlog includes signed drilling contracts and, 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 and these liquidity issues could be experienced again if commodity prices decline to lower levels for an extended period of time.  Liquidity issues and other market pressures could lead our customers to go into bankruptcy or could encourage our customers 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 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 statement of financial position, results of operations or cash flows.

Our ability to renew expiring drilling contracts or obtain new drilling contracts will depend on the prevailing market conditions at the time.  If we are unable to obtain new drilling contracts in direct continuation with existing contracts or for our uncontracted newbuild units, or if new drilling contracts are entered into at dayrates substantially below the existing dayrates or on terms otherwise less favorable compared to existing contract terms, our revenues and profitability could be adversely affected.

The offshore drilling markets in which we compete experience fluctuations in the demand for drilling services.  A number of existing drilling contracts for our drilling rigs that are currently operating are scheduled to expire before December 31, 2017.  Seven of the units we currently have under construction as part of our newbuild program, two ultra‑deepwater drillships and our five high‑specification jackups, are being constructed without customer drilling contracts.  We will attempt to secure drilling contracts for these units prior to their completion.  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 drilling contracts for our newbuilds, and there may be a gap in the operation of the rigs between the current contracts and subsequent contracts.  In particular, if oil and natural gas prices remain low, as is currently the case, or it is expected that such prices will decrease in the future, at a time when we are seeking drilling contracts for our rigs, we may be unable to obtain drilling contracts at attractive dayrates or at all.

We must make substantial capital and operating expenditures to maintain our fleet.  These expenditures could increase as a result of changes in the following:

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.  In addition, changes in governmental regulations, safety or other equipment standards, as well as compliance with standards imposed by maritime self-regulatory organizations, may require us to make additional unforeseen capital expenditures.  As a result, 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.

In addition, we may require additional capital in the future.  If we are unable to fund capital expenditures with our cash flow from operations or 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.  Our ability to access the capital markets may be limited by our financial condition at the time, 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, 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 statements of financial condition, results of operations and cash flows.

During the year ended December 31, 2015, three credit rating agencies downgraded their credit ratings of our non‑credit enhanced senior unsecured long‑term debt (“Debt Rating”) to Debt Ratings that are below investment grade.  During the year ended December 31, 2016 and in January 2017, the same three credit rating agencies further downgraded our Debt Rating.  Our Debt Rating levels could have material adverse consequences on our business and future prospects and could:

The downgrades have caused some of the effects listed above, and any further downgrades may cause or exacerbate, any of the effects listed above.

At December 31, 2016 and 2015, our total consolidated debt was $8.5 billion.  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 Conditions and Results of Operations—Liquidity and Captial Resources—Sources and Uses of Liquidity—Debt Issuances.”

We engage in offshore drilling services for most of the leading international oil companies or their affiliates, as well as for many government‑controlled oil companies and independent oil companies.  For the year ended December 31, 2016, our most significant customers were Chevron, BP, Shell and Petrobras, accounting for approximately 24 percent, 12 percent, 12 percent and 11 percent, respectively, of our consolidated operating revenues.  As of February 9, 2017, the customers with the most significant aggregate amount of contract backlog were Shell and Chevron, representing approximately 63 percent and 20 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 a material adverse effect on our results of operations and cash flows.

In addition, our drilling contracts subject us to counterparty risks.  The ability of each of our counterparties to perform its obligations under a contract with us 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 expenses necessary to maintain drilling activities.  In addition, in depressed market conditions, such as we are currently experiencing, 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.  Should a counterparty fail to honor its obligations under an agreement with us, we could sustain losses, which could have a material adverse effect on our business and on our consolidated statement of financial condition results of operations or cash flows.

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 current period of low oil and natural gas prices.  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 statement of financial position, results of operations or cash flows.

The world economy is currently facing a number of challenges.  An extended period of negative outlook for the world economy could reduce the overall demand for oil and natural gas and for our services.  These potential developments, or market perceptions concerning these and related issues, could affect our consolidated statement of 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 are adding to overall 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.  Such changes could adversely affect our business and our consolidated statement of financial position, results of operations or cash flows.

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 assigned 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.  Contract preparation costs vary based on the scope and length of contract preparation required and the duration of the firm contractual period over which such expenditures are amortized.

As of February 9, 2017, we had four ultra‑deepwater floater and five high‑specification jackup newbuild rigs under construction.  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.  Delays in the delivery of these units would impact contract commencement, resulting in a loss of revenue to us, 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.  Shortages in materials, manufacturing defects, delays in the delivery of necessary spare parts, equipment or other materials, or the unavailability of ancillary services could negatively impact our future operations and result in increases in rig downtime and delays in the repair and maintenance of our fleet.

The combined response team to the Macondo well incident was unable to stem the flow of hydrocarbons from the well prior to the sinking of Deepwater Horizon.  The resulting spill of hydrocarbons was the most extensive in U.S. history.  Under the Deepwater Horizon drilling contract and in accordance with our settlement agreement with the operator, BP agreed to indemnify us with respect to certain matters, and we agreed to indemnify BP with respect to certain matters (see “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 13—Commitments and Contingencies—Macondo well incident commitments and contingencies—BP Settlement Agreement”).  We could experience a material adverse effect on our consolidated statement of financial position, results of operations or cash flows to the extent that BP fails to fully satisfy its indemnification obligations, including by reason of financial or legal restrictions, or our insurance policies do not fully cover these amounts.  In addition, in connection with our settlement with the Department of Justice (the “DOJ”), we agreed that we will not use payments pursuant to a civil consent decree by and among the DOJ and certain of our affiliates (the “Consent Decree”) as a basis for indemnity or reimbursement from non‑insurer defendants named in the complaint by the U.S. or their affiliates.

On February 25, 2013, we and the U.S. Environmental Protection Agency (the “EPA”) entered into an administrative agreement (the “EPA Agreement”) related to the Macondo well incident, which has a five‑year term.  In the EPA Agreement, we agreed to, among other things, continue the implementation of certain programs and systems; comply with certain employment and contracting procedures; engage independent compliance auditors and a process safety consultant; and give reports and notices with respect to various matters.  Subject to certain exceptions, the EPA Agreement prohibits us from entering into, extending or engaging in certain business relationships with individuals or entities that are debarred, suspended, proposed for debarment or similarly restricted.  In addition, if we fail to comply with the terms of the EPA Agreement, we may be subject to suspension, debarment or statutory disqualification.

Following the Macondo well incident, enhanced governmental safety and environmental requirements applicable to both deepwater and shallow water operations were adopted for drilling in the U.S. Gulf of Mexico.  In order to obtain drilling permits, operators must submit applications that demonstrate compliance with the enhanced regulations, which require independent third‑party inspections, certification of well design and well control equipment and emergency response plans in the event of a blowout, among other requirements.  Operators have previously had, and may in the future 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.  These new safety and environmental guidelines and standards and any further new guidelines or standards the U.S. government or industry may issue or any other steps the U.S. government or industry may take, could disrupt or delay operations, increase the cost of operations, increase out‑of‑service time or reduce the area of operations for drilling rigs in the U.S. and non‑U.S. offshore areas.

Other governments could take similar actions related to implementing new safety and environmental regulations in the future.  Additionally, some of our customers have elected to voluntarily comply with some or all of the new inspections, certification requirements and safety and environmental guidelines on rigs operating outside of the U.S. Gulf of Mexico.  Additional governmental regulations and requirements concerning licensing, taxation, equipment specifications and training requirements or the voluntary adoption of such requirements or guidelines by our customers could increase the costs of our operations, increase certification and permitting requirements, increase review periods and impose increased liability on offshore operations.  The requirements applicable to us under the Consent Decree and the EPA Agreement cover safety, environmental, reporting, operational and other matters and are in addition to the regulations applicable to other industry participants and may require additional agreements and corporate compliance resources that, together with our cooperation guilty plea agreement by and among the DOJ and certain of our affiliates (the “Plea Agreement”), could cause us to incur additional costs and liabilities.  The continuing effects of the enhanced regulations may also decrease the demand for drilling services, negatively affect dayrates and increase out‑of‑service time, which could ultimately have a material adverse effect on our revenues and profitability.

Our business in the offshore drilling industry is affected by laws and regulations relating to the energy industry and the environment, including international conventions and treaties, and regional, national, state, and local laws and regulations.  The offshore drilling industry 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 exploration and development drilling for oil and gas.  Compliance with such laws, regulations and standards, where applicable, may require us to make significant capital expenditures, such as the installation of costly equipment or 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, 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 insurance coverage or other financial assurance of our ability to address pollution incidents.  Offshore drilling in certain areas has been curtailed and, in certain cases, prohibited because of concerns over protection of the environment.  These costs could have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  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.

To the extent new laws are enacted or other governmental actions are taken that prohibit or restrict offshore drilling or impose additional environmental protection 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.  These governmental approvals 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 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 and production of oil and gas could have a material adverse effect on our business, operating results or financial condition.  Compliance with any such new legislation or regulations could have an adverse effect on our statements of operations and cash flows.

As an operator of mobile offshore drilling units in some offshore areas, we may be liable for damages and costs incurred in connection with oil spills or waste disposals related to those operations, and we may also be subject to significant fines in connection with spills.  For example, an oil spill could result in significant liability, including fines, penalties and criminal liability and remediation costs for 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 from 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.  For example, one of the courts in the litigation related to the Macondo well incident has refused to enforce aspects of our indemnity with respect to certain environmental‑related liabilities.  Laws and regulations protecting the environment have become more stringent in recent years, and may in some cases impose strict liability, 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 a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.  In addition, our Consent Decree, the EPA Agreement and probation arising out of our Plea Agreement add to these regulations, requirements and liabilities.  Our guilty plea to negligently discharging oil into the U.S. Gulf of Mexico in connection with the Macondo well incident caused us to incur liabilities under the environmental laws relating to the Macondo well incident.  We may be subject to additional liabilities and penalties.

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. 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.

A substantial portion of our drilling contracts are partially payable in local currency.  Those amounts may exceed our local currency needs, leading to the accumulation of excess local currency, which, in certain instances, may be subject to either temporary blocking or other difficulties converting to U.S. dollars, our functional currency, or to other currencies in which we operate.  Excess amounts of local currency may be exposed to the risk of currency exchange losses.

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.

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.

An inability to obtain visas and work permits for our employees on a timely basis could impact our operations and have an adverse effect on our business.  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 operate our rigs 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 adversely affect our consolidated statement of financial position, results of operations or cash flows.

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 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 area are 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 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.  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 an additional aggregate annual deductible of $50 million, which is self-insured through our wholly‑owned captive insurance company.  We also retain the risk for any liability in excess of our $750 million 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 statement of 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.

On January 1, 2014, subject to certain transitional provisions, the Swiss Federal Council Ordinance Against Excessive Compensation at Public Companies (the “Ordinance”) became effective.  The Ordinance, among other things, (a) requires a binding shareholder “say on pay” vote with respect to the compensation of members of our executive management and board of directors (b) generally prohibits the making of severance, advance, transaction premiums and similar payments to members of our executive management and board of directors, and (c) requires the declassification of our board of directors and the amendment of our articles of association to specify various compensation‑related matters.  At the 2014 annual general meeting, our shareholders approved amendments to our articles of association that implement the requirements of the Ordinance, and at each of our 2015 and 2016 annual general meetings our shareholders approved in a binding “say on pay” vote the compensation of members of our executive management and board of directors.  At the 2017 annual general meeting, our shareholders will be required to approve the maximum aggregate compensation of (1) our board of directors for the period between the 2017 annual general meeting and the 2018 annual general meeting and (2) our executive management team for the year ending December 31, 2018.  Our shareholders will be asked to approve such matters for successive one‑year periods at subsequent annual general meetings.  The Ordinance further provides for criminal penalties against directors and members of executive management in case of noncompliance with certain of its requirements.  The Ordinance may negatively affect our ability to attract and retain executive management and members of our board of directors.

We have undertaken and continue to seek appropriate opportunities for restructuring our organization, engaging in strategic acquisitions, divestitures and other business combinations in order to optimize our fleet and strengthen our competitiveness.  We face risks arising from these activities, which could adversely affect our ability to achieve our strategic goals.  For example:

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 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 reliance on third‑party 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.  Recent industry developments have reduced the number of available suppliers.  A disruption in the deliveries from such third‑party suppliers, manufacturers or service providers, capacity constraints, production disruptions, price increases, quality control issues, recalls or other decreased availability of parts and equipment could adversely affect our ability to meet our commitments to customers, adversely impact our operations and revenues or increase our operating costs.

Approximately 28 percent of our total workforce, working primarily in Angola, Brazil, Norway and the U.K. are represented by, and some of our contracted labor work under, collective bargaining agreements, substantially all of which are subject to annual salary negotiation.  These negotiations could result in higher personnel expenses, other increased costs or increased operational restrictions as the outcome of such negotiations apply to all offshore employees not just the union members.  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.

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, we could suffer from civil and criminal penalties or other sanctions, which could have a material adverse effect on our business, financial condition 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 the 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, we could also face other third‑party claims by agents, shareholders, debt holders, or other interest holders or constituents of our company.  Further, disclosure of the subject matter of any investigation could adversely affect our reputation and our ability to obtain new business from potential customers or retain existing business from our current customers, to attract and retain employees and to access the capital markets.  Our customers in relevant jurisdictions could seek to impose penalties or take other actions adverse to our interests, and we may be required to dedicate significant time and resources to investigate and resolve allegations of misconduct, regardless of the merit of such allegations.

Some scientific studies have suggested that emissions of certain gases, including greenhouse gases, carbon dioxide and methane, may be contributing 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 fossil fuels, is attracting increasing attention worldwide.

In the U.S., the EPA has begun adopting and implementing a comprehensive suite of regulations to restrict emissions of greenhouse gases under existing provisions of the Clean Air Act.  In addition, a number of other federal, state and regional efforts have focused on tracking or reducing greenhouse gas emissions.  Efforts have also been made and continue to be made in the international community toward the adoption of international treaties or protocols that would address global climate change issues.  In December 2015, the U.S. joined the international community at the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change in Paris, France.  The resulting Paris Agreement calls for the parties to undertake “ambitious efforts” to limit the average global temperature and to conserve and enhance sinks and reservoirs of greenhouse gases.  The Paris Agreement, if ratified, establishes a framework for the parties to cooperate and report actions to reduce greenhouse gas emissions.

Because our business depends on the level of activity in the offshore oil and gas industry, existing or future laws, regulations, treaties or international agreements related to greenhouse gases and climate change, 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 could result in increased compliance costs or additional operating restrictions, which may have a negative impact on our business.

We are subject to a variety of disputes, investigations and litigation.  Certain of our subsidiaries are named as defendants in numerous lawsuits alleging personal injury 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.  Further, our patent for dual‑activity technology has been successfully challenged in certain jurisdictions, and we have been accused of infringing other patents.  Other subsidiaries are subject to litigation relating to environmental damage.  We cannot predict the outcome of the cases involving those subsidiaries or the potential costs to resolve them.  Insurance may not be applicable or sufficient in all cases, insurers may not remain solvent, policies may not be located, and liabilities associated with the Macondo well incident may exhaust some or all of the insurance available to cover certain claims.  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.  We are subject to litigation with certain of our customers.  We are also subject to a number of significant tax disputes.  To the extent that one or more pending or future litigation matters is not resolved in our favor and is not covered by insurance, a material adverse effect on our financial results and condition could result.

We depend on digital technologies to conduct our offshore and onshore operations, to collect payments from customers and to pay vendors and employees.  Threats to our information technology systems associated with cybersecurity risks and cyber‑incidents or attacks continue to grow.  In addition, breaches to our systems 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 of intellectual property, proprietary information or customer data; disruption of our customers’ operations; loss or damage to our customer data delivery systems; and increased costs to prevent, respond to or mitigate cybersecurity events.  If such a cyber‑incident were to occur, it could have a material adverse effect on our business, financial condition, cash flows and results of operations.

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 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.

Public health threats, such as Severe Acute Respiratory Syndrome, severe influenza and other highly communicable viruses or diseases, outbreaks of which have already occurred in various parts of the world in which we operate, could adversely impact our operations, the operations of our customers and the global economy, including the worldwide demand for oil and natural gas and the level of demand for our services.  Quarantine of personnel or inability to access our offices or rigs could adversely affect our operations.  Travel restrictions or operational problems in any part of the world in which we operate, or any reduction in the demand for drilling services caused by public health threats in the future, may materially impact operations and adversely affect our financial results.

Other risks

Under Section 404 of the Sarbanes‑Oxley Act of 2002 and rules promulgated by the SEC, we are required to conduct a comprehensive evaluation of our internal control over financial reporting.  To complete this evaluation, we are required to document and test our internal control over financial reporting; management is required to assess and issue a report concerning our internal control over financial reporting; and our independent registered public accounting firm is required to attest to the effectiveness of our internal control over financial reporting.  Our internal control over financial reporting may not prevent or detect misstatements because of its inherent limitations, including the possibility of human error, the circumvention or overriding of controls, or fraud.  Over time, controls may become inadequate because of changes in conditions or deterioration in the degree of compliance with policies or procedures.  Because of the inherent limitations in a cost‑effective control system, misstatements due to error or fraud may occur and may not be prevented or detected timely.  Even effective internal control over financial reporting can provide only reasonable assurance with respect to the preparation and fair presentation of financial statements.

In the course of the external audit of the consolidated financial statements for the year ended December 31, 2016 we identified a material weakness in our controls over income tax accounting.  A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.  A more complete description of the recently identified errors and the resulting material weakness is included in “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 4—Correction of Errors in previously Reported Consolidated Financial Statements” and “Part II. Item 9A. Controls and Procedures” in this annual report on Form 10‑K.  Although we are evaluating certain measures in order to remediate this material weakness, we can provide no assurance that our remediation efforts will be effective or that additional material weaknesses in our internal control over financial reporting will not be identified in the future.

The existence of a material weakness could result in errors in our financial statements that could result in a restatement of financial statements, which could cause us to fail to meet our reporting obligations, lead to a loss of investor confidence and have a negative impact on the trading price of our common stock.

At December 31, 2016, the carrying amount of our property and equipment was $21.1 billion, representing 78 percent of our total assets.  In accordance with our critical accounting policies, we review our property and equipment for impairment when events or changes in circumstances indicate that carrying amounts of our assets held and used may not be recoverable.  In the year ended December 31, 2016, we recognized an aggregate loss of $52 million associated with the impairment of our deepwater floater asset group.  In the year ended December 31, 2015, we recognized an aggregate loss of $1.2 billion associated with the impairment of our deepwater floater and midwater floater asset groups.  Future expectations of lower dayrates or rig utilization rates or a significant change to the composition of one or more of our asset groups or to our contract drilling services reporting unit could result in the recognition of additional losses on impairment of our long‑lived asset groups if future cash flow expectations, based upon information available to management at the time of measurement, indicate that the carrying amount of our asset groups may be impaired.

We operate worldwide through our various subsidiaries.  Consequently, we are subject to changes in applicable tax laws, treaties or regulations in the jurisdictions in which we operate, which could include laws or policies directed toward companies organized in jurisdictions with low tax rates.  A material change in the tax laws, treaties or regulations, or their interpretation or application, of any country in which we have significant operations, or in which we are incorporated or resident, could result in a higher effective tax rate on our worldwide earnings and such change could be significant to our financial results.

In the U.S., major tax reform is under consideration.  One proposal by the U.S. House of Representatives would impose a border adjustment on goods and services imported into the U.S.  Although no bill or statutory language has to date been introduced, it is expected that such border adjustment would have the direct or indirect effect of taxing goods and services sourced from outside the U.S.  Such a border adjustment, if implemented, could result in a higher effective tax rate on our worldwide earnings and have a material adverse effect on our consolidated statements of financial position, results of operations or cash flows.  Further, tax legislative proposals intending to eliminate some perceived tax advantages of companies that have legal domiciles outside the U.S., but have certain U.S. connections, have repeatedly been introduced in the U.S. Congress.  Recent examples include, but are not limited to, legislative proposals that would broaden the circumstances in which a non‑U.S. company would be considered a U.S. resident, including the use of “management and control” provisions to determine corporate residency, and proposals that could override certain tax treaties and limit treaty benefits on certain payments by U.S. subsidiaries to non‑U.S. affiliates.  Any material change in tax laws or policies, or their interpretation, resulting from such

legislative proposals or inquiries could result in a higher effective tax rate on our worldwide earnings and such change could have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

In a referendum held on February 12, 2017, Swiss voters rejected a corporate tax legislative proposal that would have abolished certain cantonal tax privileges as well as implement other significant changes to existing tax laws and practices starting in 2019.  These legislative proposals were in response to certain guidance from and demands by the European Union and the Organization for Economic Co‑operation and Development (the “OECD”).  Switzerland must now give consideration to a revised corporate tax reform proposal.  Switzerland’s implementation of any material change in tax laws or policies or its adoption of new interpretations of existing tax laws and rulings could result in a higher effective tax rate on our worldwide earnings and such change could have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Similarly, in October 2015, 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.    The European Union issued its Anti‑Tax Avoidance Directive in 2016 that required its member states to adopt specific tax reform measures by 2019.  Any material change in tax laws or policies, or their interpretation, resulting from such legislative proposals or inquiries could result in a higher effective tax rate on our worldwide earnings and such change could have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

Other tax jurisdictions in which we operate may consider implementing similar legislation.  The implementation of such legislation, any other material changes in tax laws or policies or the adoption of new interpretations of existing tax laws and rulings could result in a higher effective tax rate on our worldwide earnings and any such change could have a material adverse effect on our consolidated statement of financial position, results of operations or cash flows.

We are a Swiss corporation that operates through our various subsidiaries in a number of countries throughout the world.  Consequently, we are subject to tax laws, treaties and regulations in and between the countries in which we operate.  Our income taxes are based upon 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.  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, particularly in the U.S., Norway, India or Brazil, 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 cannot be certain that the U.S. Internal Revenue Service (“IRS”) will not successfully contend that we or any of our key subsidiaries were or are engaged in a trade or business in the U.S. or, when applicable, that we or any of our key subsidiaries maintained or maintain a permanent establishment in the U.S., since, among other things, such determination involves considerable uncertainty.  If we or any of our key subsidiaries were considered to have been engaged in a trade or business in the U.S., when applicable, through a permanent establishment, we could be subject to U.S. corporate income and additional branch profits taxes on the portion of our earnings effectively connected to such U.S. business during the period in which this was considered to have occurred, in which case our effective tax rate on worldwide earnings for that period could increase substantially, and our earnings and cash flows from operations for that period could be adversely affected.

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 the performance of 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.  It should be noted, however, that a prior case and an IRS pronouncement which relies on the case characterize income from time chartering of vessels as rental income rather than services income for other tax purposes.  However, the IRS subsequently has 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 recent case differ in material respects from the terms of our drilling contracts with customers.  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 to be 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, and such elections could themselves have adverse consequences for such shareholder, such shareholder generally would be liable 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.  In addition, 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.

Our ability to benefit from our deferred tax assets depends on us having sufficient future earnings to utilize our net operating loss and tax credit carryforwards before they expire.  We have established a valuation allowance against the future tax benefit for a number of our U.S. and non U.S. net operating losses and tax credit carryforwards, and we could be required to record an additional valuation allowance against other U.S. or non‑U.S. deferred tax assets if market conditions change materially and, as a result, our future earnings are, or are projected to be, significantly less than we currently estimate.  Our net operating loss and tax credit carryforwards are subject to review and potential disallowance upon audit by the tax authorities of the jurisdictions where these tax attributes are incurred.

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.  As a matter of Swiss law, authorized share capital is limited to a maximum of 50 percent of a company’s registered share capital and is subject to re‑approval by shareholders every two years.  At our 2016 annual general meeting, our shareholders approved an authorized share capital, which will expire on May 12, 2018.  Our current authorized share capital is limited to approximately six percent of our registered share capital.  Additionally, subject to specified 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 present 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 on the repurchase price less the par value, and since January 1, 2011, to the extent attributable to 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.  We may repurchase shares under the share repurchase program using a procedure pursuant to which we can repurchase shares under the share repurchase program via a “virtual second trading line” from market players, in particular, banks and institutional investors, who are generally entitled to receive a full refund of the Swiss withholding tax.  Our ability to use the “virtual second trading line” is limited to the share repurchase program currently approved by our shareholders, and any use of the “virtual second trading line” with respect to future share repurchase programs will require the approval of the competent Swiss tax 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 in these circumstances 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.

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.  These provisions may also adversely affect prevailing market prices for our shares.  These provisions, among other things:

In June 2016, a majority of voters in the U.K. elected to withdraw from the European Union in a national referendum.  The referendum was advisory, and the terms of any withdrawal are subject to a negotiation period that could last at least two years after the government of the U.K. formally initiates a withdrawal process.  Nevertheless, the referendum has created significant uncertainty about the future relationship between the U.K. and the European Union, including with respect to the laws and regulations that will apply as the U.K. determines which European Union‑derived laws to replace or replicate in the event of a withdrawal.  The referendum has also given rise to calls for the governments of other European Union member states to consider withdrawal.  These developments, or the perception that any of them could occur, have had and may continue to have a material adverse effect on global economic conditions and the stability of global financial markets, and may significantly reduce global market liquidity and restrict the ability of key market participants to operate in certain financial markets.  Any of these factors could depress economic activity and restrict our access to capital, which could have a material adverse effect on our business and on our consolidated statement of financial position, results of operations or cash flows.

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, including the following:

Our remaining offices and bases are located in various countries in North America, South America, Europe, Africa, India and the Far East.  We lease most of these facilities.

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—Contingencies and Uncertainties—” in this annual report on Form 10‑K for the year ended December 31, 2016.  We are also involved in various tax matters as described in “Part II. Item 8. Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 7—Income Taxes” and in “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contingencies and Uncertainties—Tax matters” in this annual report on Form 10‑K for the year ended December 31, 2016.  All such actions, claims, tax and other matters are incorporated herein by reference.

As of December 31, 2016, we were also involved in a number of other lawsuits, claims and disputes, which have arisen in the ordinary course of our business and for which we do not expect the liability, if any, to have a material adverse effect on our current consolidated statement of financial position, results of operations or cash flows.  We cannot predict with certainty the outcome or effect of any of the matters referred to above or of any such other pending or threatened litigation or legal proceedings.  There can be no assurance that our beliefs or expectations as to the outcome or effect of any lawsuit or claim or dispute will prove correct and the eventual outcome of these matters could materially differ from management’s current estimates.

In addition to the legal proceedings described above, we may from time to time identify other matters that we monitor through our compliance program and in response to events arising generally within our industry and in the markets where we do business.  For example, in the year ended December 31, 2015, we began investigating statements made by a former employee of Petróleo Brasileiro S.A. (“Petrobras”) related to the award to us of a drilling services contract in Brazil.  These statements were made in connection with an ongoing criminal investigation by the Brazilian authorities into Petrobras and certain other companies and individuals.  We have completed our internal investigation, and we have not identified any wrongdoing by any of our employees or agents in connection with our business.  We have voluntarily met with governmental authorities in the U.S. to discuss the statements made by the former Petrobras employee and our internal investigation as well as our findings.  We will continue to investigate these types of allegations and cooperate with 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.