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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_________________________________________________________________________________________________
FORM 10-K
☑ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended: December 31, 2020
OR
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from             to             
_____________________________________________________________________________________________________
Commission file number: 001-36211

Noble Corporation
(Exact name of registrant as specified in its charter)
Cayman Islands   98-1575532
(State or other jurisdiction of incorporation or organization) (I.R.S. employer identification number)
13135 Dairy Ashford, Suite 800, Sugar Land, Texas, 77478
(Address of principal executive offices) (Zip Code)
Registrant’s Telephone Number, Including Area Code: (281) 276-6100
Noble Holding Corporation plc
(Former name or former address, if changed since last report)
_____________________________________________________________________________________________________
Commission file number: 001-31306

Noble Finance Company
(Exact name of registrant as specified in its charter)
Cayman Islands   98-0366361
(State or other jurisdiction of incorporation or organization) (I.R.S. employer identification number)
13135 Dairy Ashford, Suite 800, Sugar Land, Texas 77478
(Address of principal executive offices) (Zip Code)
Registrant’s Telephone Number, Including Area Code: (281) 276-6100
Noble Corporation
Suite 3D Landmark Square, 64 Earth Close, P.O. Box 31327 George Town, Grand Cayman, Cayman Islands, KY1-1206
(Address of principal executive offices) (Zip Code)
Registrant’s Telephone Number, Including Area Code: (345) 938-0293
(Former name or former address, if changed since last report)
_____________________________________________________________________________________________________

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

Securities registered pursuant to Section 12(g) of the Act: None 
_____________________________________________________________________________________________________
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes  ¨   No  þ
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.    Yes  ¨    No  þ
Indicate by check mark whether each registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  þ    No  ¨
Indicate by check mark whether each registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  þ    No  ¨
Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):
Noble Corporation Large accelerated filer ☐ Accelerated filer
☑
Non-accelerated filer ☐ Smaller reporting company ☑ Emerging growth company ☐
Noble Finance Company Large accelerated filer ☐ Accelerated filer ☐ Non-accelerated filer
☑
Smaller reporting company ☐ Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.    ¨
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☑
Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ☐    No  þ
As of June 30, 2020, the aggregate market value of the registered shares of Noble Holding Corporation plc (the Exchange Act predecessor to the registrant Noble Corporation) held by non-affiliates was $79.5 million based on the closing price of such shares on such date as reported on the New York Stock Exchange.
Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes þ No ☐
Number of shares outstanding at March 10, 2021: Noble Corporation — 43,536,636
Number of shares outstanding: Noble Finance Company — 261,246,093

DOCUMENTS INCORPORATED BY REFERENCE
Items 10, 11, 12, 13 and 14 of Part III of this Annual Report on Form 10-K will be incorporated by reference from an amendment to this Annual Report on Form 10-K to be filed with the Securities and Exchange Commission.

This Form 10-K is a combined annual report being filed separately by two registrants: Noble Corporation, a Cayman Islands company, and its wholly-owned subsidiary, Noble Finance Company, a Cayman Islands company.
1

TABLE OF CONTENTS
 
        Page
PART I    
Item 1.  
5
Item 1A.  
14
Item 1B.  
31
Item 2.  
31
Item 3.  
31
Item 4.  
31
   
PART II      
Item 5.  
32
Item 6.  
34
Item 7.  
34
Item 7A.  
51
Item 8.  
53
Item 9.  
110
Item 9A.  
110
Item 9B.  
112
       
PART III  
Item 10.  
113
Item 11.  
113
Item 12.  
113
Item 13.  
113
Item 14.
113
   
PART IV  
Item 15.
114
Item 16.
114
     
121
This combined Annual Report on Form 10-K is separately filed by Noble Corporation, an exempted company incorporated in the Cayman Islands with limited liability (“Noble” or “Successor”), and Noble Finance Company (formerly known as Noble Corporation), an exempted company incorporated in the Cayman Islands with limited liability and a wholly-owned subsidiary of Noble (“Finco”). Information in this filing relating to Finco is filed by Noble and separately by Finco on its own behalf. Finco makes no representation as to information relating to Noble (except as it may relate to Finco) or any other affiliate or subsidiary of Noble.
This report should be read in its entirety as it pertains to each Registrant. Except where indicated, the Consolidated Financial Statements and the Notes to the Consolidated Financial Statements are combined. References in this Annual Report on Form 10-K to “Noble,” the “Company,” “we,” “us,” “our” and words of similar meaning refer collectively to Noble and its consolidated subsidiaries, including Finco.
2

Forward-Looking Statements
This Annual Report on Form 10-K (“Annual Report”) includes “forward-looking statements” within the meaning of Section 27A of the US Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the US Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements other than statements of historical facts included in this report or in the documents incorporated by reference, including those regarding the impact of our emergence from bankruptcy on our business and relationships, our plan to list our equity on a national securities exchange, the global novel strain of coronavirus (“COVID-19”) pandemic and agreements regarding production levels among members of the Organization of Petroleum Exporting Countries (“OPEC”) and other oil and gas producing nations (together with OPEC, “OPEC+”), and any expectations we may have with respect thereto, and those regarding rig demand, peak oil, the offshore drilling market, oil prices, contract backlog, fleet status, our future financial position, business strategy (including our business strategy post-emergence from bankruptcy), impairments, repayment of debt, credit ratings, liquidity, borrowings under any credit facilities or other instruments, sources of funds, future capital expenditures, contract commitments, dayrates, contract commencements, extension or renewals, contract tenders, the outcome of any dispute, litigation, audit or investigation, plans and objectives of management for future operations, foreign currency requirements, results of joint ventures, indemnity and other contract claims, reactivation, refurbishment, conversion and upgrade of rigs, industry conditions, access to financing, impact of competition, governmental regulations and permitting, availability of labor, worldwide economic conditions, taxes and tax rates, indebtedness covenant compliance, dividends and distributable reserves, timing or results of acquisitions or dispositions, and timing for compliance with any new regulations are forward-looking statements. When used in this report or in the documents incorporated by reference, the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “might,” “plan,” “project,” “should” “shall,” “will” and similar expressions are intended to be among the statements that identify forward-looking statements. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we cannot assure you that such expectations will prove to be correct. These forward-looking statements speak only as of the date of this Annual Report on Form 10-K and we undertake no obligation to revise or update any forward-looking statement for any reason, except as required by law. We have identified factors, including but not limited to risks and uncertainties relating to our emergence from bankruptcy (including but not limited to our ability to improve our operating structure, financial results and profitability and to maintain relationships with suppliers, customers, employees and other third parties following emergence from bankruptcy), the effects of public health threats, pandemics and epidemics, such as the ongoing outbreak of COVID-19, and the adverse impact thereof on our business, financial condition and results of operations (including but not limited to our growth, operating costs, supply chain, availability of labor, logistical capabilities, customer demand for our services and industry demand generally, our liquidity, the price of our securities and trading markets with respect thereto, our ability to access capital markets, and the global economy and financial markets generally), the effects of actions by or disputes among OPEC+ members with respect to production levels or other matters related to the price of oil, market conditions, factors affecting the level of activity in the oil and gas industry, supply and demand of drilling rigs, factors affecting the duration of contracts, the actual amount of downtime, factors that reduce applicable dayrates, operating hazards and delays, risks associated with operations outside the US, actions by regulatory authorities, credit rating agencies, customers, joint venture partners, contractors, lenders and other third parties, legislation and regulations affecting drilling operations (including as a result of the change in the US presidential administration), compliance with or changes in regulatory requirements, violations of anti-corruption laws, shipyard risk and timing, delays in mobilization of rigs, hurricanes and other weather conditions, and the future price of oil and gas, that could cause actual plans or results to differ materially from those included in any forward-looking statements. Actual results could differ materially from those expressed as a result of various factors. These factors include those referenced or described under “Risk Factors” included in this report, or in our other filings with the US Securities and Exchange Commission (“SEC”). We cannot control such risk factors and other uncertainties, 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. You should consider these risks and uncertainties when you are evaluating us.
3

PART I
Item 1. Business.
Overview
Noble is a leading offshore drilling contractor for the oil and gas industry. We provide contract drilling services to the international oil and gas industry with our global fleet of mobile offshore drilling units. We focus on a balanced, high-specification fleet of floating and jackup rigs and the deployment of our drilling rigs in oil and gas basins around the world. Noble and its predecessors have been engaged in the contract drilling of oil and gas wells since 1921.
On July 31, 2020 (the “Petition Date”), our former parent company, Noble Holding Corporation plc (formerly known as Noble Corporation plc), a public limited company incorporated under the laws of England and Wales (“Legacy Noble” or the “Predecessor”), and certain of its subsidiaries, including Finco, filed voluntary petitions in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”) seeking relief under chapter 11 of title 11 of the United States Code (the “Bankruptcy Code”). On September 4, 2020, the Debtors filed with the Bankruptcy Court the Joint Plan of Reorganization of Noble Corporation plc and its Debtor Affiliates, which was subsequently amended on October 8, 2020 and October 13, 2020 and modified on November 18, 2020 (as amended, modified or supplemented, the “Plan”), and the related disclosure statement (the “Disclosure Statement”). On September 24, 2020, six additional subsidiaries of Legacy Noble (together with Legacy Noble and its subsidiaries that filed on the Petition Date, as the context requires, the “Debtors”) filed voluntary petitions in the Bankruptcy Court. The chapter 11 proceedings were jointly administered under the caption Noble Corporation plc, et al. (Case No. 20-33826) (the “Chapter 11 Cases”). On November 20, 2020, the Bankruptcy Court entered an order confirming the Plan. In connection with the Chapter 11 Cases and the Plan, on and prior to the Effective Date (as defined herein), Legacy Noble and certain of its subsidiaries effectuated certain restructuring transactions pursuant to which Legacy Noble formed Noble as an indirect wholly-owned subsidiary of Legacy Noble and transferred to Noble substantially all of the subsidiaries and other assets of Legacy Noble. On February 5, 2021 (the “Effective Date”), the Plan became effective in accordance with its terms and the Debtors emerged from the Chapter 11 Cases. See Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations— Chapter 11 Proceedings and Going Concern” for a description of the events that occurred on the Effective Date, including the issuance of the ordinary shares of Noble (“New Shares”), the Tranche 1 Warrants, the Tranche 2 Warrants and the Tranche 3 Warrants (each as defined herein). In accordance with the Plan, Legacy Noble and its remaining subsidiary will in due course be wound down and dissolved in accordance with applicable law.
Finco was an indirect, wholly-owned subsidiary of Legacy Noble prior to the Effective Date and has been a direct, wholly-owned subsidiary of Noble, our parent company, since the Effective Date. Noble’s principal asset is all of the shares of Finco. Finco has no public equity outstanding. The consolidated financial statements of Noble include the accounts of Finco, and Noble conducts substantially all its business through Finco and its subsidiaries.
Noble is the successor issuer to Legacy Noble for purposes of and pursuant to Rule 15d-5 of the Exchange Act. References to the “Company,” “we,” “us” or “our” in this Annual Report are to Noble, together with its consolidated subsidiaries, when referring to periods following the Effective Date, and to Legacy Noble, together with its consolidated subsidiaries, when referring to periods prior to the Effective Date.
Contract Drilling Services
We report our contract drilling operations as a single reportable segment, Contract Drilling Services, which reflects how we manage our business. The mobile offshore drilling units comprising our offshore rig fleet operate in a global market for contract drilling services and are often redeployed to different regions due to changing demands of our customers, which consist primarily of large, integrated, independent and government-owned or controlled oil and gas companies throughout the world.
We typically provide contract drilling services under an individual contract, on a dayrate basis. Although the final terms of the contracts result from negotiations with our customers, many contracts are awarded based upon a competitive bidding process. Our drilling contracts generally contain the following terms:
•contract duration extending over a specific period of time or a period necessary to drill a defined number of wells;
•payment of compensation to us (generally in US Dollars although some customers, typically national oil companies, require a part of the compensation to be paid in local currency) on a “daywork” basis, so that we receive a fixed amount for each day (“dayrate”) that the drilling unit is operating under contract (a lower rate or no compensation is payable during periods of equipment breakdown and repair or adverse weather or in the event operations are interrupted by other conditions, some of which may be beyond our control);
•provisions permitting early termination of the contract by the customer (i) if the unit is lost or destroyed, (ii) if operations are suspended for a specified period of time due to breakdown of equipment or breach of contract or (iii) for convenience;
4

•provisions allowing the impacted party to terminate the contract if specified “force majeure” events beyond the contracting parties’ control occur for a defined period of time;
•payment by us of the operating expenses of the drilling unit, including labor costs and the cost of incidental supplies;
•provisions that allow us to recover certain cost increases from our customers in certain long-term contracts; and
•provisions that require us to lower dayrates for documented cost decreases in certain long-term contracts.
Generally, our contracts allow us to recover our mobilization and demobilization costs associated with moving a drilling unit from one regional location to another. When market conditions require us to assume these costs, our operating margins are reduced accordingly. For shorter moves, such as “field moves,” our customers have generally agreed to assume the costs of moving the unit in the form of a reduced dayrate or “move rate” while the unit is being moved. Under current market conditions, we are much less likely to receive full reimbursement of our mobilization and demobilization costs.
Contracts often contain early termination provisions permitting the customer to terminate the contract if the unit is lost or destroyed or if operations are suspended for a specified period of time due to breakdown of equipment or breach of contract. In addition, the terms of our drilling contracts permit the customer to terminate the contract after specified notice periods by tendering contractually specified termination amounts and, in often cases, without any payment or a modest payment.
During periods of depressed market conditions, such as the one we experienced for a number of years, our customers may attempt to renegotiate or repudiate their contracts with us although we seek to enforce our rights under our contracts. The renegotiations may include changes to key contract terms, such as pricing, termination and risk allocation. 
For a discussion of our backlog of commitments for contract drilling services, please read Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations— Contract Drilling Services Backlog.”
Drilling Fleet
Noble is a leading offshore drilling contractor for the oil and gas sector. Noble owns and operates one of the most modern, versatile and technically advanced fleets of mobile offshore drilling units in the offshore drilling industry. Noble provides, through its subsidiaries, contract drilling services with a fleet of 19 offshore drilling units, consisting of seven floaters and 12 jackups at the date of this report, focused largely on ultra-deepwater and high-specification drilling opportunities in both established and emerging regions worldwide. Each type of drilling rig is described further below. Several factors determine the type of unit most suitable for a particular job, the most significant of which include the water depth and the environment of the intended drilling location, whether the drilling is being done over a platform or other structure, and the intended well depth. At December 31, 2020, our fleet was located in Far East Asia, the Middle East, the North Sea, Oceania, South America and the US Gulf of Mexico.
Floaters
Our floating fleet consists of the following:
    A drillship is a type of floating drilling unit that is based on the ship-based hull of the vessel and equipped with modern drilling equipment that gives it the capability of easily transitioning from various worldwide locations and carrying high capacities of equipment while being able to drill ultra-deepwater oil and gas wells in up to 12,000 feet of water. Drillships can stay directly over the drilling location without anchors in open seas using a dynamic positioning system (“DPS”), which coordinates position references from satellite signals and acoustic seabed transponders with the drillship's six to eight thrusters to keep the ship directly over the well that is being drilled. Drillships are selected to drill oil and gas wells for programs that require a high level of simultaneous operations, where drilling loads are expected to be high, or where there are occurrences of high ocean currents, where the drillship's hull shape is the most efficient. Noble's fleet consists of six drillships capable of water depths from 10,000 feet to 12,000 feet.
    Semisubmersible drilling units are designed as a floating drilling platform incorporating one or several pontoon hulls, which are submerged in the water to lower the center of gravity and make this type of drilling unit exceptionally stable in the open sea. Semisubmersible drilling units are generally categorized in terms of the water depth in which they are capable of operating, from the mid-water range of 300 feet to 4,000 feet, the deepwater range of 4,000 feet to 7,500 feet, to the ultra-deepwater range of 7,500 feet to 12,000 feet as well as by their generation, or date of construction. This type of drilling unit typically exhibits excellent stability characteristics, providing a stable platform for drilling in even rough seas. Semisubmersible drilling units hold their position over the drilling location using either an anchored mooring system or a DPS and may be self-propelled. Noble’s fleet consists of one moored ultra-deepwater semisubmersible drilling unit.
5

Jackups
Noble’s fleet of modern, high-specification jackup drilling units gives us the flexibility to provide drilling solutions to our customers who have drilling requirements in the shallower waters of the continental shelf, in depths ranging from less than 100 feet to as deep as 500 feet of water with drilling hookloads up to 2,500,000. Jackup rigs can be used in open water exploration locations, as well as over fixed, bottom-supported platforms. A jackup drilling unit is a towed mobile vessel consisting of a floating hull equipped with three or four legs, which are lowered to the seabed at the drilling location. The hull is then elevated out of the water by the jacking system using the legs to support weight of the hull and drilling equipment against the seabed. Once the hull is elevated to the desired level, or jacked up, the drilling package can be extended out over an existing production platform or the open water location and drilling can commence. Noble’s fleet of 12 jackups varies from two units capable of drilling in up to 375 feet of water to premium and high-specification units capable of drilling in up to 500 feet of water.
The following table presents certain information concerning our offshore fleet at March 10, 2021. We own and operate all of the units included in the table.
Name Make
Year Built or Rebuilt (1)
Water Depth Rating (feet) (2)
Drilling Depth Capacity (feet) Location
Status (3)
Floaters—7
Drillships—6          
Noble Bob Douglas GustoMSC P10000 2013 N 12,000 40,000 Guyana Active
Noble Don Taylor GustoMSC P10000 2013 N 12,000 40,000 Guyana Active
Noble Globetrotter I Globetrotter Class 2011 N 10,000 30,000 US Gulf of Mexico Active
Noble Globetrotter II Globetrotter Class 2013 N 10,000 30,000 US Gulf of Mexico Active
Noble Sam Croft GustoMSC P10000 2014 N 12,000 40,000 Suriname Active
Noble Tom Madden GustoMSC P10000 2014 N 12,000 40,000 Guyana Active
Semisubmersibles—1            
Noble Clyde Boudreaux F&G 9500 Enhanced Pacesetter 2007 R 10,000 35,000 Malaysia Active
Independent Leg Cantilevered Jackups—12        
Noble Hans Deul (4)
F&G JU-2000E 2009 N 400 30,000 UK Active
Noble Houston Colbert (4)
F&G JU-3000N 2014 N 400 30,000 UK Available
Noble Joe Knight GustoMSC CJ46-x100-D 2018 N 375 30,000 Saudi Arabia Active
Noble Johnny Whitstine GustoMSC CJ46-x100-D 2018 N 375 30,000 Saudi Arabia Active
Noble Lloyd Noble (4)
GustoMSC CJ70-x150-ST 2016 N 500 32,000 Norway Shipyard
Noble Mick O’Brien (4)
F&G JU-3000N 2013 N 400 30,000 Qatar Active
Noble Regina Allen (4)
F&G JU-3000N 2013 N 400 30,000
Trinidad and Tobago
Active
Noble Roger Lewis (4)
F&G JU-2000E 2007 N 400 30,000 Saudi Arabia Active
Noble Sam Hartley (4)
F&G JU-3000N 2014 N 400 30,000 UK Active
Noble Sam Turner (4)
F&G JU-3000N 2014 N 400 30,000 Denmark Active
Noble Scott Marks (4)
F&G JU-2000E 2009 N 400 30,000 Saudi Arabia Active
Noble Tom Prosser (4)
F&G JU-3000N 2014 N 400 30,000 Australia Active
(1)    Rigs designated with an “R” were modified, refurbished or otherwise upgraded in the year indicated by capital expenditures of an amount deemed material by management. Rigs designated with an “N” are newbuilds.
(2)    Rated water depth for drillships and semisubmersibles reflects the maximum water depth for which a floating rig has been designed for drilling operations.
(3)    Rigs listed as “active” are operating, preparing to operate or under contract; rigs listed as “available” are actively seeking contracts and may include those that are idle or warm stacked; rigs listed as “shipyard” are in a shipyard for construction, repair, refurbishment or upgrade; rigs listed as “stacked” are idle without a contract and have reduced or no crew and are not actively marketed in present market conditions.
(4)    Harsh environment capability.
6

Market
The offshore contract drilling industry is a highly competitive and cyclical business. Demand for offshore drilling services is driven by the offshore exploration and development programs of oil and gas operators, which in turn are influenced by many factors, including, but not limited to, the price and price stability of oil and gas, the availability and relative cost of offshore oil and gas resources within the oil and gas portfolio of each operator, general global economic conditions, energy demand, the operator’s strategy toward renewable energy sources, environmental considerations and national oil and gas policy.
In the provision of offshore contract drilling services, competition is largely governed by price but involves numerous other factors as well. Rig availability, location, suitability and technical specifications are the primary factors in determining which rig is qualified for a job, and additional factors are considered when determining which contractor is awarded a job, including experience of the workforce, efficiency, safety performance record, condition of equipment, operating integrity, reputation, industry standing and client relations. In addition to having one of the newest fleets in the industry among our peer companies, we strive to keep our assets well-maintained and technologically competitive.
We maintain a global operational presence and compete in many of the major offshore oil and gas basins worldwide. All our drilling rigs are mobile, and we may mobilize our drilling rigs among regions for a variety of reasons, including to respond to customer requirements. We compete in both the jackup and floating rig market segments, each of which may have different supply and demand dynamics at a given period in time or in different regions.
Since late 2014, the offshore drilling industry has experienced a severe and prolonged downturn driven by a combination of an oversupply of drilling rigs, weak and volatile crude oil prices exacerbated in early 2020 by production level disagreements by OPEC+, reductions in global offshore exploration and development activities, and the impacts of COVID-19.
The global mitigation efforts associated with preventing the spread of COVID-19 have significantly slowed global economic activity, leading to a precipitous drop in oil demand in 2020. As the year progressed, some countries began to ease lock-down restrictions, resulting in an increase in oil demand; however, current demand and near-term demand forecasts still lag pre-COVID-19 demand levels. As the demand imbalance played out during the year, crude price volatility lessened as OPEC+ agreed to production level cuts through early 2021. In early 2021, Brent crude averaged $55-$60 per barrel, up from an average of approximately $40 per barrel in 2020. Despite the current price recovery, uncertainty remains around the current level of oil prices as a result of the on-going effects of COVID-19 and the early stage of global vaccine efforts, as well as the uncertainty surrounding the longevity of the OPEC+ production agreements. Finally, a growing number of the major oil companies, including some of our customers, have signaled increased commitments toward the transition to renewable energy sources. As international majors commit to these renewable energy sources, capital investments could be diverted from longer-term fossil fuel projects, creating even more competition among premium offshore drilling assets.
We believe the convergence of events in 2020 and early 2021 have lengthened an already challenging and slow recovery in our industry. Despite these challenges and demand projections, we believe that oil and gas demand will rebalance and oil and gas will remain an important portion of the world’s energy mix. We expect that the return of stable oil demand and prices coupled with the continued attrition of rigs in the global offshore fleet will bring improved market conditions for our services. Our young and technologically advanced fleet is well positioned to compete as market dynamics improve.
Significant Customers
Offshore contract drilling operations accounted for approximately 94 percent, 95 percent and 96 percent of our operating revenues for the years ended December 31, 2020, 2019 and 2018, respectively. During the three years ended December 31, 2020, we principally conducted our contract drilling operations in Canada, Far East Asia, the Middle East, the North Sea, Oceania, the Black Sea, Africa, South America and the US Gulf of Mexico. Revenues from Exxon Mobil Corporation (“ExxonMobil”), Royal Dutch Shell plc (“Shell”), Equinor ASA (“Equinor”) and Saudi Arabian Oil Company (“Saudi Aramco”) accounted for approximately 26.6 percent, 21.7 percent, 14.3 percent and 13.8 percent, respectively, of our consolidated operating revenues for the year ended December 31, 2020. Revenues from Shell, ExxonMobil, Equinor and Saudi Aramco accounted for approximately 36.5 percent, 13.7 percent, 13.1 percent and 11.9 percent, respectively, of our consolidated operating revenues, which includes the Noble Bully II contract buyout, for the year ended December 31, 2019. Excluding the Noble Bully II contract buyout, revenues from Shell, ExxonMobil, Equinor and Saudi Aramco accounted for approximately 27.1 percent, 15.7 percent, 15.1 percent and 13.6 percent, respectively, of our consolidated operating revenues for the year ended December 31, 2019. Revenues from Shell, Equinor and Saudi Aramco accounted for approximately 38.8 percent, 15.5 percent and 14.5 percent, respectively, of our consolidated operating revenues for the year ended December 31, 2018. No other customer accounted for more than 10 percent of our consolidated operating revenues in 2020, 2019 or 2018.
7

Human Capital
At December 31, 2020, we had approximately 1,500 employees, excluding approximately 800 persons we engaged through labor contractors or agencies. Approximately 88 percent of our workforce is located offshore. We are not a party to any material collective bargaining agreements, and we consider our employee relations to be satisfactory.
We are fully committed to operating our business with honesty and integrity. Our reputation depends on our directors, officers, employees, and others working on our behalf assuming a personal responsibility for our business conduct. Our compliance program is focused on ensuring adherence with the highest ethical standards and applicable laws and setting the tone for an ethical work environment. Noble’s commitment to a strong compliance culture is fundamental to who we are as a leading offshore drilling contractor. Noble’s Code of Business Conduct and Ethics provides the foundation for our culture and underscores our commitment to our core values of safety, environmental stewardship, honesty and integrity, respect and performance. It also includes our responsibility and commitment to follow all applicable laws as well as our own internal policies, and requires any supplier or third party who works with Noble to comply with similar fundamental principles.
Operating our business in a socially responsible way is integral to who we are. Internally, our employee-focused programs such as recruitment and promotion opportunities, safety and environmental stewardship, and training and continuing education are key to our commitment to the personal and professional growth of our workforce. Externally, our dedication is evidenced by our affiliations and how we contribute to and invest in the communities where we operate.
Recruitment and Promotions. We value a healthy culture of ingenuity and adaptability where everyone has an equal opportunity to thrive. We recognize that an inclusive and diverse workforce is key to the advancement and retention of the best qualified people leading to strong innovation and our continued success. We are committed to a policy of recruitment and promotion based upon job qualifications, performance and merit without discrimination.
Safety and Environmental Stewardship. Noble is committed to delivering excellent health, safety and environmental (“HSE”) performance as part of our business strategy in order to add further value for employees, customers, and shareholders. Safety and environmental stewardship are the cornerstone of who we are, what we stand for and what we do every day to deliver a high-quality operation. All personnel, regardless of job or position onboard our vessels or at any Noble facility, has the authorization and obligation to immediately stop any unsafe act, practice or job that that poses any risk or danger to people or the environment. Noble’s pursuit of exceptional HSE performance begins with our strong corporate culture and by starting SAFE every day: one tour, one task and one person at a time. SAFE is an acronym for the phrase: follow Standards, be Accountable, stay Focused, achieve Excellence. Daily, the crew onboard each rig work together to achieve specific safety and environmental objectives and if all objectives are met, then the day is counted as a SAFE Day. Under our SAFE Day program, in 2020, our rigs achieved the SAFE objectives 98.6% of available days, which is an increase over 2019 performance, and our total recordable incident rate for 2020 decreased 38% from the prior year.
Training and Continuing Education. We place considerable value on the training and development of our employees and maintain a practice of keeping them informed on matters affecting them, as well as on the performance of the Company. Accordingly, we conduct formal and informal meetings with employees, maintain a Company intranet website with matters of interest, issue periodic publications of Company activities and other matters of interest, and offer a variety of in-house training, including through NobleAdvances, our state-of-the-art training facility in Sugar Land, Texas. When travel became a challenge, we developed and enhanced virtual and worksite training courses, some of which are facilitated through our rig-based leadership and are accredited through the International Association of Drilling Contractors.
In consideration of the negative impact of COVID-19 on our employees, customers, suppliers and the communities in which we operate, as well as associated human rights concerns that may exist in the areas in which we operate, we have taken, and will continue to take, incremental measures to monitor, identify and manage risks associated with the COVID-19 pandemic. Throughout the pandemic, we have continued operations in support of essential infrastructure in the energy industry while carefully ensuring worker safety. We have been able to maintain operation of our rigs by implementing several mitigations, such as extending crew schedules to offset travel delays due to limitations or restrictions, implementing quarantine measures in advance of persons boarding our rigs to prevent the spread of COVID-19 on board and enhancing crew health monitoring and response measures to prevent an outbreak on board any of our vessels. We have also continued the operation of our shore-side offices by implementing social distancing programs and implementing staggered rotational schedules for facility employees to reduce the number of persons on site. In addition, we have increased internal contingency planning, protective measures and employee communications and reinforced our employee wellness programs with all offshore and shore-side employees to offset the potential impact on employees both personally and professionally.
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Governmental Regulations and Environmental Matters
Political developments and numerous governmental regulations, which may relate directly or indirectly to the contract drilling industry, affect many aspects of our operations. Our contract drilling operations are subject to various laws and regulations in countries in which we operate, including laws and regulations relating to the equipping, supplying and operation of drilling units, environmental protection and related recordkeeping, health and safety of personnel, safety management systems, the reduction of atmospheric emissions that contribute to a cumulative effect on the overall air quality and environment (commonly referred to as greenhouse gases), currency conversions and repatriation, oil and gas exploration and development, taxation of capital equipment, taxation of offshore earnings and earnings of expatriate personnel, employee benefits and use of local employees, content and suppliers by foreign contractors. A number of countries actively regulate and control the ownership of concessions and companies holding concessions, the exportation of oil and gas and other aspects of the oil and gas industries in their countries. In addition, government actions, including initiatives by OPEC, may continue to contribute to oil price volatility. In some areas of the world, this government activity has adversely affected the amount of exploration and development work done by oil and gas companies and influenced their need for offshore drilling services, and likely will continue to do so.
The regulations applicable to our operations include provisions that regulate the discharge of materials into the environment or require remediation of contamination under certain circumstances. Many of the countries in whose waters we operate from time to time regulate the discharge of oil and other contaminants in connection with drilling and marine operations. Failure to comply with these laws and regulations, or failure to obtain or comply with permits, may result in the assessment of administrative, civil and criminal penalties, imposition of remedial requirements and the imposition of injunctions to force future compliance. Although these requirements impact the oil and gas and energy services industries, generally they do not appear to affect us in any material respect that is different, or to any materially greater or lesser extent, than other companies in the energy services industry. However, our business and prospects could be adversely affected by regulatory activity that prohibits or restricts our customers’ exploration and production activities, resulting in reduced demand for our services or imposing environmental protection requirements that result in increased costs to us, our customers or the oil and natural gas industry in general.
The following is a summary of some of the existing laws and regulations that apply in the United States and Europe, which serves as an example of the various laws and regulations to which we are subject. While laws vary widely in each jurisdiction, each of the laws and regulations below addresses regulatory issues similar to those in most of the other jurisdictions in which we operate.
Offshore Regulation and Safety. In response to the Macondo well blowout incident in April 2010, the United States Congress, the US Department of Interior, through the Bureau of Ocean Energy Management (“BOEM”) and the Bureau of Safety and Environmental Enforcement (“BSEE”), and the US Department of Homeland Security, through the United States Coast Guard (“USCG”), have undertaken an aggressive overhaul of the offshore oil and natural gas related regulatory processes, which has significantly impacted oil and gas development and operational requirements in the US Gulf of Mexico. Such actions by the US government has, on occasion, served as a leading indicator for similar regulatory developments or requirements by other countries where, from time to time, new rules, regulations and requirements in the United States and in other countries have been proposed and implemented that materially limit or prohibit, and increase the cost of, offshore drilling and related operations. Other similar regulations impact certain operational requirements on rigs and govern liability for vessel or cargo loss, or damage to life, property, or the marine environment. See Part I, Item 1A, “Risk Factors —Regulatory and Legal Risks—Changes in, compliance with, or our failure to comply with the certain laws and regulations may negatively impact our operations and could have a material adverse effect on our results of operations” and “Risk Factors—Regulatory and Legal Risks— Governmental laws and regulations may add to our costs, result in delays, or limit our drilling activity” for additional information.
Spills and Releases. The US Oil Pollution Act of 1990 (“OPA”), the Comprehensive Environmental Response, Compensation, and Liability Act in the United States (“CERCLA”), and similar regulations, including but not limited to the International Convention for the Prevention of Pollution from Ships (“MARPOL”), adopted by the International Maritime Organization (“IMO”), as enforced in the United States through the domestic implementing law called the Act to Prevent Pollution from Ships, impose certain operational requirements on offshore rigs operating in the United States and govern liability for leaks, spills and blowouts involving pollutants. OPA imposes strict, joint and several liabilities on “responsible parties” for damages, including natural resource damages, resulting from oil spills into or upon navigable waters, adjoining shorelines or in the exclusive economic zone of the United States. A “responsible party” includes the owner or operator of an onshore facility and the lessee or permit holder of the area in which an offshore facility is located. CERCLA and similar state and foreign laws and regulations, impose joint and several liabilities, without regard to fault or the legality of the original act, on certain classes of persons that contributed to the release of a “hazardous substance” into the environment. In the course of our ordinary operations, we may generate waste that may fall within the scope of CERCLA's definition of a “hazardous substance.” However, we have to-date not received any notification that we are, or may be, potentially responsible for cleanup costs under CERCLA.
Regulations under OPA require owners and operators of rigs in United States waters to maintain certain levels of financial responsibility. The failure to comply with OPA’s requirements may subject a responsible party to civil, criminal, or administrative enforcement actions. We are not aware of any action or event that would subject us to liability under OPA, and we believe that compliance with OPA’s financial assurance and other operating requirements will not have a material impact on our operations or financial condition.
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Waste Handling. The US Resource Conservation and Recovery Act (“RCRA”), and similar state, local and foreign laws and regulations govern the management of wastes, including the treatment, storage and disposal of hazardous wastes. RCRA imposes stringent operating requirements, and liability for failure to meet such requirements, on a person who is either a “generator” or “transporter” of hazardous waste or an “owner” or “operator” of a hazardous waste treatment, storage or disposal facility. RCRA and many state counterparts specifically exclude from the definition of hazardous waste drilling fluids, produced waters, and other wastes associated with the exploration, development, or production of crude oil and natural gas. As a result, our operations generate minimal quantities of RCRA hazardous wastes. We do not believe the current costs of managing our wastes, as they are presently classified, to be significant. However, any repeal or modification of this or similar exemption in similar state statutes, would increase the volume of hazardous waste we are required to manage and dispose of, and would cause us, as well as our competitors, to incur increased operating expenses with respect to our US operations.
Water Discharges. The US Federal Water Pollution Control Act of 1972, as amended, also known as the “Clean Water Act,” and similar state laws and regulations impose restrictions and controls on the discharge of pollutants into federal and state waters. These laws also regulate the discharge of storm water in process areas. Pursuant to these laws and regulations, we are required to obtain and maintain approvals or permits for the discharge of wastewater and storm water. In addition, the USCG has promulgated requirements for ballast water management as well as supplemental ballast water requirements, which includes limits and, in some cases, water treatment requirements applicable to specific discharge streams, such as deck runoff, bilge water and gray water. Further, in October 2020, the United States Environmental Protection Agency (“EPA”) published proposed national standards of performance for incidental discharges pursuant to the Vessel Incidental Discharge Act. The proposed rule would establish discharge standards for a range of vessels, including mobile offshore drilling units. We do not anticipate that compliance with these laws and regulations will cause a material impact on our operations or financial condition.
Air Emissions. The US Federal Clean Air Act and associated state laws and regulations restrict the emission of air pollutants from many sources, including oil and natural gas operations. New facilities may be required to obtain permits before operations can commence, and existing facilities may be required to obtain additional permits, and incur capital costs, in order to remain in compliance. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with air permits or other requirements of the Clean Air Act and associated state laws and regulations. In general, we believe that compliance with the Clean Air Act and similar state laws and regulations will not have a material impact on our operations or financial condition.
Climate Change. Climate change is an environmental, social and economic challenge facing everyone today. We are committed to continuous improvement and a sustainable energy future, supported by our efforts to protect the environment throughout our operations and safely provide reliable and efficient services to allow access to resources essential for human and economic prosperity. There is increasing attention concerning the issue of climate change and the effect of greenhouse gas (“GHG”) emissions. The EPA regulates the permitting of GHG emissions from stationary sources under the Clean Air Act’s Prevention of Significant Deterioration and Title V permitting programs, which require the use of “best available control technology” for GHG emissions from new and modified major stationary sources, which can sometimes include our rigs. The EPA has also adopted rules requiring the monitoring and reporting of GHG emissions from specified sources in the United States, including, among other things, certain onshore and offshore oil and natural gas production facilities, on an annual basis.
Moreover, in 2005, the Kyoto Protocol to the 1992 United Nations Framework Convention on Climate Change, which establishes a binding set of emission targets for GHGs, became binding on all countries that had ratified it. In 2015, the United Nations (“U.N.”) Climate Change Conference in Paris resulted in the creation of the Paris Agreement. In September 2016, the US deposited its instrument of acceptance of the Paris Agreement, which later entered into force on November 4, 2016. The Paris Agreement requires countries to review and “represent a progression” in their nationally determined contributions, which set emissions reduction goals, every five years beginning in 2020. In November 2019, the US submitted formal notification to the U.N. of its decision to withdraw from the Paris Agreement, which took effect on November 4, 2020. However, in January 2021, shortly after Joseph Biden was sworn into office as the President of the United States, a series of executive orders were issued regarding climate change, which in part led to the US again depositing an instrument of acceptance of the Paris Agreement, which thereafter re-entered into force for the US on February 19, 2021. The terms of the Paris Agreement and the executive orders are expected to result in additional regulations or changes to existing regulations, which could have a material adverse effect on our business in the US and that of our customers. In addition, incentives to conserve energy or use alternative energy sources in many of the countries where we currently operate or may operate in the future, could have a negative impact on our business in those countries and worldwide. See Part I, Item1A, “Risk Factors—Regulatory and Legal Risks— Governmental laws and regulations may add to our costs, result in delays, or limit our drilling activity” for additional information.
Countries in the European Union (“EU”) implement the U.N.’s Kyoto Protocol on GHG emissions through the Emissions Trading System (“ETS”). The ETS program establishes a GHG “cap and trade” system for certain industry sectors, including power generation at some offshore facilities. Total GHG from these sectors is capped, and the cap is reduced over time to achieve GHG reductions from these sectors. In September 2020, the European Commission presented a plan to increase the EU’s GHG reduction target to at least 55% by 2030 in accordance with the European Green Deal. In order to reach this goal, the European Commission has proposed potential revisions and expansions of the EU ETS.
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In addition, the United Kingdom (“UK”) government implemented its own ETS in January 2021 to replace the UK’s participation in the EU ETS. The UK has also introduced an auction price floor to prevent carbon prices from dropping below a set level during the initial implementation of the UK ETS. The cost of compliance with the UK ETS and the EU ETS can be expected to increase over time. Additional member state climate change legislation may result in potentially material capital expenditures.
We have determined that combustion of ultra-low sulfur fuel oil aboard all of our vessels worldwide (Scope 1) is the Company’s primary source of GHG emissions, which includes carbon dioxide, methane and nitrous oxide. Based upon the emissions calculation factor provided by the original equipment manufacturer for each engine type utilized on our vessels, for the year ended December 31, 2020, our estimated carbon dioxide equivalent (“C02e”) gas emissions were 960,593 tons as compared to 1,063,925 tons for the year ended December 31, 2019. When expressed as an intensity measure of tons of C02e gas emissions per contract day for our vessels worldwide, the intensity measure for December 31, 2020 and 2019 was 174.58 and 156.85, respectively.
The increase of our C02e intensity average from 2019 to 2020 is largely attributed to fewer contracted days in 2020 for several of our vessels that have lower operating energy demands, while our larger vessels that require more energy collectively operated for more contracted days during the same period.
Noble utilizes emission coefficient factors directly from the OEM engine manufacturers carefully calculated per engine type and fuel usage to determine emissions generated from our direct operations throughout the year. While OEM provided coefficients are one method of calculation, there are other relevant industry and regulatory approved standards for calculating GHG production that lead us to a broader understanding of our GHG impact. Each of these methods of calculation vary in assumptions made during the calculation process. By providing these additional calculations such as the Environmental Emissions Monitoring System (EEMS), we feel we are more prepared to compare our emissions data to those relevant industry standards and accurately compare to peer performance with a higher degree of transparency.
Our Scope 1 C02e gas emissions reporting has been prepared with reference to the requirements set out in the UK Companies Act 2006 Regulations 2013, the Environmental Reporting Guidelines (June 2013) issued by the Department for Environment Food & Rural Affairs, the World Resources Institute and World Business Council for Sustainable Development GHG Protocol Corporate Accounting and Reporting Standard Revised and the International Organization for Standardization (“ISO”) 14064-1, “Specification with guidance at the organizational level for quantification and reporting of greenhouse gas emissions and removals (2006).”
Worker Safety. The US Occupational Safety and Health Act (“OSHA”) and other similar laws and regulations govern the protection of the health and safety of employees. The OSHA hazard communication standard, EPA community right-to-know regulations under Title III of CERCLA and similar state statutes require that information be maintained about hazardous materials used or produced in our operations and that this information be provided to employees, state and local governments and citizens. EU member states have also adopted regulations pursuant to EU Directive 2013/30/EU, on the safety of offshore oil and gas operations within the exclusive economic zone (which can extend up to 200 nautical miles from a coast) or the continental shelf. We believe that we are in substantial compliance with OSHA requirements and EU directive 2013/30/EU (as well as the extensive current health and safety regimes implemented in the member states in which we operate), but future developments could require the Company to incur significant costs to comply with the directive's implementation.
International Regulatory Regime. The IMO provides international regulations governing shipping and international maritime trade. IMO regulations have been widely adopted by U.N. member countries, and in some jurisdictions in which we operate, these regulations have been expanded upon. The requirements contained in the International Management Code for the Safe Operation of Ships and for Pollution Prevention, or ISM Code, promulgated by the IMO, govern much of our drilling operations. Among other requirements, the ISM Code requires the party with operational control of a vessel to develop an extensive safety management system that includes, among other things, the adoption of a safety and environmental protection policy setting forth instructions and procedures for operating its vessels safely and describing procedures for responding to emergencies.
The IMO has also adopted and revised MARPOL, including Annex VI to MARPOL, which limits the main air pollutants contained in exhaust gas from ships, including sulfur oxides (“SOx”) and nitrous oxides (“NOx”), prohibits deliberate emissions of ozone depleting substances (“ODS”), regulates shipboard incineration and the emissions of volatile organic compounds (“VOC”) from tankers, sets a progressive reduction globally in emissions of SOx, NOx and particulate matter, introduces emission control areas (“ECAs”) to reduce emissions of those air pollutants further in designated sea areas, and effective from January 1, 2020, reduces the global sulfur limit in fuel oil from the current 3.50% to 0.50% m/m (mass by mass) sulfur content. Prior to January 1, 2020, our rigs were operating and continue to operate with low sulfur fuel oil at or below the global limits of 0.50%.
The IMO has also negotiated international conventions that impose liability for oil pollution in international waters and the territorial waters of the signatory to such conventions such as the Ballast Water Management Convention, (the “BWM Convention”) and the International Convention for Civil Liability for Bunker Oil Pollution Damage of 2001 (the “Bunker Convention”). The BWM Convention's implementing regulations call for a phased introduction of mandatory ballast of water exchange requirements, to be replaced in time with a requirement for
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mandatory ballast water treatment. The Bunker Convention provides a liability, compensation and compulsory insurance system for the victims of oil pollution damage caused by spills of bunker oil. We believe that all of our drilling rigs are currently compliant in all material respects with these regulations. However, the IMO continues to review and introduce new regulations. It is impossible to predict what additional regulations, if any, may be passed by the IMO and what effect, if any, such regulation may have on our operations.
Insurance and Indemnification Matters
Our operations are subject to many hazards inherent in the drilling business, including blowouts, fires, collisions, groundings, punch-throughs, and damage or loss from adverse weather and sea conditions. These hazards could cause personal injury or loss of life, loss of revenues, pollution and other environmental damage, damage to or destruction of property and equipment and oil and natural gas producing formations, and could result in claims by employees, customers or third parties and fines and penalties.
Our drilling contracts provide for varying levels of indemnification from our customers and in most cases also require us to indemnify our customers for certain losses. Under our drilling contracts, liability with respect to personnel and property is typically assigned on a “knock-for-knock” basis, which means that we and our customers assume liability for our respective personnel and property, generally irrespective of the fault or negligence of the party indemnified. In addition, our customers may indemnify us in certain instances for damage to our down-hole equipment and, in some cases, our subsea equipment. Also, we generally obtain a mutual waiver of consequential losses in our drilling contracts.
Our customers typically assume responsibility for and indemnify us from loss or liability resulting from pollution or contamination, including third-party damages and clean-up and removal, arising from operations under the contract and originating below the surface of the water. We are generally responsible for pollution originating above the surface of the water and emanating from our drilling units. Additionally, our customers typically indemnify us for liabilities incurred as a result of a blow-out or cratering of the well and underground reservoir loss or damage. In the current market, we are under increasing pressure to accept exceptions to the above-described allocations of risk and, as a result, take on more risk. In such cases where we agree, we generally limit the exposure with a monetary cap and other restrictions.
In addition to the contractual indemnities described above, we also carry Protection and Indemnity (“P&I”) insurance, which is a comprehensive general liability insurance program covering liability resulting from offshore operations. Our P&I insurance includes coverage for liability resulting from personal injury or death of third parties and our offshore employees, third-party property damage, pollution, spill clean-up and containment and removal of wrecks or debris. Our P&I insurance program is renewed in April of each year and currently has a standard deductible of $10.0 million per occurrence, with maximum liability coverage of $750.0 million. We also carry hull and machinery insurance that protects us against physical loss or damage to our drilling rigs, subject to a deductible that is currently $5.0 million.
Our insurance policies and contractual rights to indemnity may not adequately cover our losses and liabilities in all cases. For additional information, please read “We may have difficulty obtaining or maintaining insurance in the future and our insurance coverage and contractual indemnity rights may not protect us against all the risks and hazards we face” included in Part I, Item 1A, “Risk Factors” of this Annual Report on Form 10-K.
The above description of our insurance program and the indemnification provisions of our drilling contracts is only a summary as of the time of preparation of this report, and is general in nature. Our insurance program and the terms of our drilling contracts may change in the future. In addition, the indemnification provisions of our drilling contracts may be subject to differing interpretations, and enforcement of those provisions may be limited by public policy and other considerations.
Available Information
Our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act are available free of charge at our website. The US Securities and Exchange Commission (the “SEC”) maintains an internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC at http://www.sec.gov.
You may also find information related to our corporate governance, board committees and company code of ethics (and any amendments or waivers of compliance) at our website. Among the documents you can find there are the following:
•Articles of Association;
•Code of Business Conduct and Ethics;
•Corporate Governance Guidelines;
•Audit Committee Charter;
•Compensation Committee Charter;
•Nominating, Governance and Sustainability Committee Charter; and
•Finance Committee Charter.
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Our website address is http://www.noblecorp.com. Investors should also note that we announce material financial information in SEC filings, press releases and public conference calls. Based on guidance from the SEC, we may use the investor relations section of our website to communicate with our investors. It is possible that the financial and other information posted there could be deemed to be material information. Except to the extent explicitly stated herein, documents and information on our website are not incorporated by reference herein.
Item 1A. Risk Factors.
You should carefully consider the following risk factors in addition to the other information included in this Annual Report on Form 10-K. Each of these risk factors could affect our business, operating results and financial condition, as well as affect an investment in our shares.
Risk Factors Summary
The following is a summary of the principal risks that could adversely affect our business, operating results and financial condition.
Risks Related to Our Emergence from Bankruptcy
•the effect of our recent emergence from bankruptcy on our business and relationships;
•our actual financial results after emergence from bankruptcy may not be comparable to filed projections;
•our historical financial information will not be indicative of future financial performance;
•Legacy Noble’s ordinary shares were cancelled upon our emergence from bankruptcy;
•the warrants we issued pursuant to the Plan are exercisable for New Shares;
Risks Related to Our Business and Operations
•the impact of the COVID-19 pandemic;
•our business depends on the level of activity in the oil and gas industry;
•the offshore contract drilling industry is a highly competitive and cyclical business;
•the over-supply of offshore rigs;
•our ability to renew or replace existing contracts;
•our current backlog of contract drilling revenue may not be ultimately realized;
•our substantial dependence on several of our customers;
•risks relating to operations in international locations;
•our and our service providers’ failure to adequately protect sensitive information technology systems and critical data;
•our failure to attract and retain skilled personnel;
•supplier capacity constraints or shortages in parts or equipment or price increases;
•risks associated with future acquisitions of other businesses or assets;
•future sales or the availability for sale of substantial amounts of the New Shares could, if the New Shares are listed on a national securities exchange. adversely affect the trading price of the New Shares;
•we are a holding company, and we are dependent upon cash flow from subsidiaries to meet our obligations;
Financial and Tax Risks
•we may record impairment charges on property and equipment;
•the Exit Credit Agreement (as defined herein) contains various restrictive covenants limiting the discretion of our management in operating our business;
•the impact of a loss of a major tax dispute or a successful tax challenge to our operating structure, intercompany pricing policies or the taxable presence of our subsidiaries in certain countries on our tax rate on our worldwide earnings;
Regulatory and Legal Risks
•the impact of governmental laws and regulations on our costs and drilling activity;
•increasing attention to environmental, social and governance matters;
•changes in, compliance with, or our failure to comply with certain laws and regulations;
•compliance with laws and regulations relating to the protection of the environment and of human health and safety; and
•we are subject to litigation.
For a more complete discussion of the material risks facing our business, see below.
Risks Related to Our Emergence from Bankruptcy
We recently emerged from bankruptcy, which may adversely affect our business and relationships.
It is possible that our having filed for bankruptcy and our recent emergence from the Chapter 11 Cases may adversely affect our business and relationships with our vendors, suppliers, service providers, customers, employees and other third parties. Many risks exist as a result of the Chapter 11 Cases and our emergence, including the following:
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•we may have difficulty obtaining acceptable and sufficient financing to execute our business plan;
•key suppliers, vendors and customers, may among other things, renegotiate the terms of our agreements, attempt to terminate their relationship with us or require financial assurances from us;
•our ability to renew existing contracts and obtain new contracts on reasonably acceptable terms and conditions may be adversely affected;
•our ability to attract, motivate and retain key employees and executives may be adversely affected; and
•competitors may take business away from us, and our ability to compete for new business and attract and retain customers may be negatively impacted.
The occurrence of one or more of these events could have a material and adverse effect on our operations, financial condition and reputation. We cannot assure you that having been subject to bankruptcy protection will not adversely affect our operations in the future.
Our actual financial results after emergence from bankruptcy may not be comparable to our projections filed with the Bankruptcy Court in the course of the Chapter 11 Cases.
In connection with the Disclosure Statement we filed with the Bankruptcy Court, and the hearing to consider confirmation of the Plan, we prepared projected financial information to demonstrate to the Bankruptcy Court the feasibility of the Plan and our ability to continue operations upon our emergence from the Chapter 11 Cases. Those projections were prepared solely for the purpose of the Chapter 11 Cases and have not been and will not be updated and should not be relied upon by investors. At the time they were prepared, the projections reflected numerous assumptions concerning our anticipated future performance with respect to then prevailing and anticipated market and economic conditions that were and remain beyond our control and that may not materialize. We have not reviewed the projections or the assumptions on which they were based after our emergence. Projections are inherently subject to substantial and numerous uncertainties and to a wide variety of significant business, economic and competitive risks, and the assumptions underlying the projections or valuation estimates may prove to be wrong in material respects. Actual results may vary significantly from those contemplated by the projections. As a result, investors should not rely on these projections.
Our historical financial information will not be indicative of future financial performance as a result of the implementation of the Plan and the transactions contemplated thereby, as well as our adoption of fresh start accounting following emergence.
Our capital structure was significantly impacted by the Plan. Under fresh start accounting rules that became applicable to us upon the Effective Date, assets and liabilities will be adjusted to fair values and our accumulated deficit will be reset to zero. Accordingly, because fresh start accounting rules apply, our financial condition and results of operations following emergence from the Chapter 11 Cases will not be comparable to the financial condition and results of operations reflected in our historical financial statements from before February 5, 2021.
Legacy Noble’s ordinary shares were cancelled upon our emergence from bankruptcy.
Upon our emergence from the Chapter 11 Cases, Legacy Noble’s ordinary shares were cancelled and we issued the New Shares. We intend to apply for a listing of the New Shares on a national securities exchange. However, we can provide no assurance when we will apply for listing of the New Shares, whether the New Shares will be approved for listing, whether an active trading market will develop for the New Shares or as to the liquidity of such trading market for the New Shares.
The warrants we issued pursuant to the Plan are exercisable for New Shares, and the exercise of such equity instruments would have a dilutive effect to shareholders of the Company.
On the Effective Date and pursuant to the Plan, we issued 8,333,081 Tranche 1 Warrants and 8,333,081 Tranche 2 Warrants to the holders of Legacy Notes (as defined herein) and 2,777,698 Tranche 3 Warrants to the holders of Legacy Noble’s ordinary shares outstanding prior to the Effective Date. The warrants are exercisable for one New Share per warrant at initial exercise price of $19.27 per Tranche 1 Warrant, $23.13 per Tranche 2 Warrant and $124.40 per Tranche 3 Warrant, in each case as may be adjusted from time to time pursuant to the applicable warrant agreements. The Tranche 1 Warrants and the Tranche 2 Warrants are exercisable until 5:00 p.m., Eastern time, on February 4, 2028 and the Tranche 3 Warrants are exercisable until 5:00 p.m., Eastern time, on February 4, 2026. The Tranche 1 and Tranche 2 Warrants have Black-Scholes protections. The exercise of these warrants into New Shares would have a dilutive effect to the holdings of our existing shareholders.

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Risks Related to Our Business and Operations
Public health issues, including epidemics or pandemics such as COVID-19 have resulted in, and may in the future cause, significant adverse consequences for our business and financial position.
Public health issues, such as the COVID-19 pandemic, our mitigation efforts necessitated by COVID-19, and the effect from the actual and potential disruption of operations of our business partners, suppliers and customers, have had, and may in the future have, a material negative impact on our business and results of operations. In addition, if new strains of COVID-19 develop or sufficient amounts of approved vaccines or new vaccines do not become available, are not widely administered for a significant period of time, or otherwise prove ineffective, the negative impact of COVID-19 on the global economy, and, in turn, on our business and results of operations, could be material.
In response to COVID-19, governmental authorities around the world took various actions over time to mitigate the spread of COVID-19, such as imposing mandatory closures of non-essential business facilities, seeking voluntary closures of certain businesses, and imposing restrictions on, or advisories with respect to, travel, business operations and public gatherings or interactions. In addition, individuals and entities implemented measures in response to the pandemic and the governmental actions, as well as made changes to personal behaviors, such as requiring employees to work remotely, suspending non-essential travel worldwide for employees, discouraging or canceling employee attendance at in-person work-related meetings, and social distancing and isolating from others.
We have taken and will continue to take precautionary measures intended to mitigate the risk to our business, employees, customers, suppliers and the communities in which we operate. Our operational employees have been, and currently are, able to work on site and on our rigs, due in part to various precautionary measures with little or no material negative impact on the business and results of operations, such as requiring individuals to verify they have not experienced any COVID-19 related symptoms, or been in close contact with someone showing such symptoms or having recently tested positive for COVID-19, before they are permitted to travel to the work site or rig; quarantining any operational employees on a rig who have shown signs of COVID-19 (regardless of whether such employee has been confirmed to be infected); and imposing social distancing requirements in various areas of the rig, such as in the dining hall, work and meeting spaces, and sleeping quarters. Other precautionary measures that have contributed to our ability to continue operations have nonetheless had a material negative impact on the business and results of operations, such as requiring individuals to isolate in a designated facility or repurposed hotel for up to 14 days and test negative for COVID-19 prior to being permitted to travel to our rigs, which has resulted in an increase in the cost of operations. We are also actively assessing and planning for various operational contingencies; however, we cannot guarantee that any actions taken by us, including the precautionary measures noted above, will be effective in preventing an interruption of operations from an outbreak of COVID-19 or absence due to COVID-19 infection resulting in the vacancy of essential positions on one or more of our rigs. To the extent there is an outbreak of COVID-19 or vacancy of essential positions on one or more of our rigs, we may have to temporarily shut down operations thereof, which could result in significant downtime and have significant adverse consequences for our business and results of operations. In addition, most of our non-operational employees are now working remotely, which increases various logistical challenges, inefficiencies and operational risks. For instance, working remotely may increase the risk of security breaches or other cyber-incidents or attacks, loss of data, fraud and other disruptions as a consequence of more employees accessing sensitive and critical information from remote locations via network infrastructure and internet services not arranged, established or secured by the Company.
Governmental authorities have implemented and continue to develop policies with the goal of re-opening various sectors of the economy. However, certain jurisdictions have returned, or may in the future return, to restrictions based upon increases in new COVID-19 cases. The COVID-19 pandemic may continue unabated or worsen during the upcoming months, which may cause governmental authorities to implement restrictions on businesses and society, resulting in the re-opening of the economy being further curtailed. In complying with travel restrictions and mandatory quarantine measures imposed by governmental authorities and navigating surges in COVID-19 cases in various jurisdictions, we have experienced, and may continue to experience, increased difficulties, delays and expenses in moving our personnel to and from our operating locations. We have been unable, and may in the future be unable, to pass along these increased expenses to our customers. Additionally, disruptions to the ability of our suppliers, manufacturers and service providers to supply labor, parts, equipment or services in the jurisdictions in which we operate, whether as a result of government actions, labor shortages, travel restrictions, or the inability to source labor, parts or equipment from affected locations or other effects related to COVID-19, have increased our operating costs, increased the risk of rig downtime and negatively impacted our ability to meet our commitments to customers and may continue to do so in the future.
These conditions have had significant adverse consequences for the financial condition of many of our customers and resulted in, and may in the future result in, reductions to their drilling and production expenditures and delays or cancellations of projects, thereby decreasing demand for our services. We have experienced customers seeking price reductions for our services, payment deferrals and termination of our contracts; customers seeking to not perform under our contracts based on a force majeure claim; and customers that are unable or unwilling to timely pay outstanding receivables owed to us, all of which present liquidity challenges for us. In addition, we have experienced, and may in the future experience, pressure to reduce dayrates on existing contracts and idle or suspend existing operations. Any early termination payment made in connection with an early contract termination may not fully compensate us for the loss of the contract or may result in a negative
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impact to our projected future earnings due to the accounting treatment of such a termination payment under applicable accounting requirements. Accordingly, the actual amount of revenues earned may be substantially lower than the backlog reported.
The factors described above, including the ultimate duration and scope of the COVID-19 pandemic (including any potential future outbreaks and the success of vaccination programs), the impact on customers, suppliers, manufacturers and service providers, the timing to return to normal economic conditions, the impact on our operations, the demand for our services, and any permanent behavioral changes that the pandemic may cause, have had, and may continue to have, a material negative impact on our business, results of operations and financial condition, have previously contributed to our ability to continue as a going concern, and could in the future raise substantial doubt about our ability to continue as a going concern. We cannot predict when this negative impact will end, or whether it may worsen.
Our business and results of operations have been materially and negatively impacted and our market value has substantially declined due to depressed market conditions which are the result of, in part, the dramatic drop in the oil price, the development of additional onshore oil and gas resources and the oversupply of offshore drilling rigs.
Crude oil prices have been in a steep decline since late 2014 and dropped to as low as approximately $30 per barrel in January 2016. Oil prices have partially recovered to a price of approximately $68 per barrel on March 10, 2021, but have been volatile and have not recovered to 2014 levels. As a result of the oil price environment prior to the significant drop in 2014, the offshore drilling business flourished with high utilization and high dayrates, and a large number of offshore drilling rigs were constructed to take advantage of the market. Also, many in our industry extended the lives of older rigs rather than retiring these rigs. These factors have led to a significant oversupply of drilling rigs while our customers have greatly reduced their planned offshore exploration and development spending in response to the depressed price of oil.
During the same period, onshore crude oil production in the United States rose sharply. While the cost of production onshore varies, in some cases it may be less than the cost of production in offshore fields where our rigs are designed to operate, especially deepwater fields. Additionally, onshore production is perceived as yielding more consistent results and posing lower regulatory risk than offshore production. This increase in onshore US production has had a negative impact on the price of oil and the demand for our services. Further, given the reduced oil price and often the lower operating costs onshore, many of our customers have allocated more of their capital budgets to onshore exploration activities than offshore exploration activities, particularly deepwater exploration activities, which has also led to a decrease in the demand for offshore drilling services since 2014.
These factors have affected market conditions and led to a material decline in the demand for our services since 2014, the dayrates we are paid by our customers and the level of utilization of our drilling rigs. These poor market conditions, which may continue into the foreseeable future, in turn, have led to a material deterioration in our results of operations. There can be no assurance as to if, when or to what extent the current depressed market conditions, and our business, results of operations or enterprise value, will improve. Further, even if the price of oil and gas were to increase dramatically, we cannot assure you that there would be any increase in demand for our services.
Our business depends on the level of activity in the oil and gas industry. Adverse developments affecting the industry, including a decline in the price of oil or gas, reduced demand for oil and gas products and increased regulation of drilling and production, could have a material adverse effect on our business, financial condition and results of operations.
Demand for drilling services depends on a variety of economic and political factors and the level of activity in offshore oil and gas exploration and development and production markets worldwide. As noted above, the price of oil and gas, and market expectations of potential changes in the price, significantly affect this level of activity, as well as dayrates that we can charge customers for our services. However, higher prices do not necessarily translate into increased drilling activity because our clients take into account a number of considerations when they decide to invest in offshore oil and gas resources, including expectations regarding future commodity prices. The price of oil and gas and the level of activity in offshore oil and gas exploration and development are extremely volatile and are affected by numerous factors beyond our control, including:
•the cost of exploring for, developing, producing and delivering oil and gas;
•the ability of OPEC to set and maintain production levels and pricing;
•expectations regarding future energy prices;
•increased supply of oil and gas resulting from onshore hydraulic fracturing activity and shale development;
•the relative cost of offshore oil and gas exploration versus onshore oil and gas production;
•worldwide production and demand for oil and gas (including the over-supply of oil and gas as a result of the COVID-19 pandemic and actions by OPEC+ members), which are impacted by changes in the rate of economic growth in the global economy;
•potential acceleration in the development, and the price and availability, of alternative fuels or energy sources;
•the level of production in non-OPEC countries;
•worldwide financial instability or recessions;
•regulatory restrictions or any moratorium on offshore drilling;
•the discovery rate of new oil and gas reserves either onshore or offshore;
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•the rate of decline of existing and new oil and gas reserves;
•available pipeline and other oil and gas transportation capacity;
•oil refining capacity;
•the ability of oil and gas companies to raise capital;
•limitations on liquidity and available credit;
•advances in exploration, development and production technology either onshore or offshore;
•technical advances affecting energy consumption, including the displacement of hydrocarbons through increasing transportation fuel efficiencies;
•merger and divestiture activity among oil and gas producers;
•the availability of, and access to, suitable locations from which our customers can produce hydrocarbons;
•adverse weather conditions, including hurricanes, typhoons, cyclones, winter storms and rough seas, the frequency and severity of which may be increased due to climate change;
•the occurrence or threat of epidemic or pandemic diseases or any governmental response to such occurrence or threat;
•tax laws, regulations and policies;
•laws and regulations related to environmental matters, including those addressing alternative energy sources, the phase-out of fossil fuel vehicles and the risks of global climate change;
•the political environment of oil-producing regions, including uncertainty or instability resulting from civil disorder, an outbreak or escalation of armed hostilities or acts of war or terrorism; and
•the laws and regulations of governments regarding exploration and development of their oil and gas reserves or speculation regarding future laws or regulations.
Adverse developments affecting the industry as a result of one or more of these factors, including any further decline in the price of oil and gas from their current levels or the failure of the price of oil and gas to recover to a level that encourages our clients to expand their capital spending, the inability of our customers to access capital on economically advantageous terms, including as a result of the increasing focus on climate change by investors, a global recession, reduced demand for oil and gas products, increased supply due to the development of new onshore drilling and production technologies, and increased regulation of drilling and production, particularly if several developments were to occur in a short period of time, would have a material adverse effect on our business, financial condition and results of operations. The current level of oil and gas prices has had a material adverse effect on demand for our services since 2014 and is expected to continue to have a material adverse effect on our business and results of operations.
The offshore contract drilling industry is a highly competitive and cyclical business with intense price competition. We have competitors who are larger and have more financial resources than us. If we are unable to compete successfully, our profitability may be materially reduced.
The offshore contract drilling industry is a highly competitive and cyclical business characterized by high capital and operating costs and evolving capability of newer rigs. Drilling contracts are traditionally awarded on a competitive bid basis. Price competition, rig availability, location and rig suitability and technical specifications are the primary factors in determining which rig is qualified for a job, and additional factors are considered when determining which contractor is awarded a job, including experience of the workforce, efficiency, safety performance record, condition of equipment, operating integrity, reputation, industry standing and client relations. Our future success and profitability will partly depend upon our ability to keep pace with our customers’ demands with respect to these factors. In the past several years, the pace of consolidation in our industry has increased, leading to the creation of a number of larger and financially stronger competitors. If we are unable, or our customers believe that we are unable, to compete with the scale and financial strength of these larger competitors, it could harm our competitiveness and our ability to secure new drilling contracts. Moreover, certain of our competitors have engaged, or may in the future engage, in bankruptcy proceedings, debt refinancing transactions, management changes or other strategic initiatives in an attempt to reduce operating costs to maintain a position in the market, which could result in such competitors emerging with stronger or healthier balance sheets and, in turn, an improved ability to compete with us in the future. Further, if current competitors, or new market entrants, implement new technical capabilities, services or standards that are more attractive to our customers or price their product offerings more competitively, it could have a material adverse effect on our business, financial condition and results of operations.
In addition to intense competition, our industry has historically been cyclical. The offshore contract drilling industry is currently in a period characterized by low demand for drilling services and excess rig supply. Periods of low demand or excess rig supply intensify the competition in the industry and have resulted in, and are expected to continue to result in, many of our rigs earning substantially lower dayrates or being idle for long periods of time. We cannot provide you with any assurances as to when such period will end, and when there will be higher demand for contract drilling services or a meaningful reduction in the number of drilling rigs.
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The over-supply of offshore rigs continues to contribute to depressed dayrates and demand for our rigs, which may remain unchanged for some time and, therefore, is expected to further adversely impact our revenues and profitability.
Prior to the current downturn, we experienced an extended period of high utilization and high dayrates, and industry participants materially increased the supply of drilling rigs by building new drilling rigs, including some that have not yet entered service. This increase in supply, combined with the decrease in demand for drilling rigs resulting from the substantial decline in the price of oil that began in 2014, has resulted in an oversupply of drilling rigs, which has contributed to the decline in utilization and dayrates.
We are currently experiencing competition from newbuild rigs that have either already entered the market or are available to enter the market. The entry of these rigs into the market has resulted in lower dayrates for both newbuilds and existing rigs rolling off their current contracts. Lower utilization and dayrates have adversely affected our revenues and profitability and may continue to do so for some time in the future. In addition, our competitors may relocate rigs to geographic markets in which we operate, which could exacerbate excess rig supply and result in lower dayrates and utilization in those markets. To the extent that the drilling rigs currently under construction or on order do not have contracts upon their completion, there may be increased price competition as such vessels become operational, which could lead to a further reduction in dayrates and in utilization, and we may be required to idle additional drilling rigs. Rig operators may take lower dayrates and shorter contract durations on older rigs to keep their rigs operational and avoid scrapping or retiring them. As a result, our business, financial condition and results of operations would be materially adversely affected.
We may not be able to renew or replace expiring contracts, and our customers may terminate or seek to renegotiate or repudiate our drilling contracts or may have financial difficulties that prevent them from meeting their obligations under our drilling contracts.
Since the market downturn began at the end of 2014, the new customer contracts we have entered into have generally had less favorable terms, including dayrates, than contracts entered into prior to the downturn. In addition, for some of our older rigs we were unable to find any replacement contracts. Our ability to renew contracts that expire or obtain new contracts and the terms of any such contracts will depend on market conditions and our customers' expectations and assumptions of future oil prices and other factors.
Our customers may generally terminate our drilling contracts if a drilling rig is destroyed or lost or if we have to suspend drilling operations for a specified period of time as a result of a breakdown of major equipment or, in some cases, due to other events beyond the control of either party. In the case of nonperformance and under certain other conditions, our drilling contracts generally allow our customers to terminate without any payment to us. The terms of some of our drilling contracts permit the customer to terminate the contract after a specified notice period by tendering contractually specified termination amounts and, in some cases, without any payment. These termination payments, if any, may not fully compensate us for the loss of a contract. The early termination of a contract may result in a rig being idle for an extended period of time and a reduction in our contract backlog and associated revenue, which could have a material adverse effect on our business, financial condition and results of operations. Moreover, if any of our long-term contracts were to be terminated early, such termination could affect our future earnings flow and could have material adverse effect on our future financial condition and results of operations, even if we were to receive the contractually specified termination amount.
In addition, during periods of depressed market conditions, such as the one we are currently experiencing, we are subject to an increased risk of our customers seeking to renegotiate or repudiate their contracts. The ability of our customers to perform their obligations under drilling contracts with us may also be adversely affected by the financial condition of the customer, restricted credit markets, economic downturns and industry downturns. We may elect to renegotiate the rates we receive under our drilling contracts downward if we determine that to be a reasonable business solution. If our customers cancel or are unable to perform their obligations under their drilling contracts, including their payment obligations, and we are unable to secure new contracts on a timely basis on substantially similar terms or if we elect to renegotiate our drilling contracts and accept terms that are less favorable to us, it could have a material adverse effect on our business, financial condition and results of operations.
Our current backlog of contract drilling revenue may not be ultimately realized.
Generally, contract backlog only includes future revenues under firm commitments; however, from time to time, we may report anticipated commitments under letters of intent or award for which definitive agreements have not yet been, but are expected to be, executed. We may not be able to perform under these contracts as a result of operational or other breaches or due to events beyond our control, and we may not be able to ultimately execute a definitive agreement in cases where one does not currently exist. Moreover, we can provide no assurance that our customers will be able to or willing to fulfill their contractual commitments to us or that they will not seek to renegotiate or repudiate their contracts, especially during the current industry downturn. The terms of some of our drilling contracts permit the customer to terminate the contract after specified notice periods by tendering contractually specified termination amounts and, in certain cases, without any payment. In estimating backlog, we make certain assumptions about applicable dayrates for our longer-term contracts with dayrate adjustment mechanisms (like certain of our contracts with Shell). We cannot assure you that actual results will mirror these assumptions. Our inability to perform under our contractual obligations or to execute definitive agreements, our customers’ inability or unwillingness to fulfill their contractual commitments to us, including as a result of contract repudiations or our decision to accept less favorable terms on our drilling
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contracts, or the failure of actual results to reflect the assumptions we use to estimate backlog for certain contracts, may have a material adverse effect on our business, financial condition and results of operations.
We are substantially dependent on several of our customers, including Equinor, ExxonMobil, Saudi Aramco and Shell, and the loss of any of these customers would have a material adverse effect on our financial condition and results of operations.
Any concentration of customers increases the risks associated with any possible termination or nonperformance of drilling contracts, failure to renew contracts or award new contracts or reduction of their drilling programs. Equinor, ExxonMobil, Saudi Aramco and Shell accounted for approximately 14.3 percent, 26.6 percent, 13.8 percent and 21.7 percent, respectively, of our consolidated operating revenues and approximately 3.6 percent, 44.2 percent, 17.0 percent and 26.3 percent, respectively, of our backlog for the year ended December 31, 2020. This concentration of customers increases the risks associated with any possible termination or nonperformance of contracts, in addition to our exposure to credit risk. If any of these customers were to terminate or fail to perform their obligations under their contracts and we were not able to find other customers for the affected drilling units promptly, our financial condition and results of operations could be materially adversely affected.
Our business involves numerous operating hazards.
Our operations are subject to many hazards inherent in the drilling business, including:
•well blowouts;
•fires;
•collisions or groundings of offshore equipment and helicopter accidents;
•punch-throughs;
•mechanical or technological failures;
•failure of our employees or third-party contractors to comply with our internal environmental, health and safety guidelines;
•pipe or cement failures and casing collapses, which could release oil, gas or drilling fluids;
•geological formations with abnormal pressures;
•loop currents or eddies;
•failure of critical equipment;
•toxic gas emanating from the well;
•spillage handling and disposing of materials; and
•adverse weather conditions, including hurricanes, typhoons, tsunamis, cyclones, winter storms and rough seas, the frequency and severity of which may be increased due to climate change.
These hazards could cause personal injury or loss of life, suspend drilling operations, result in regulatory investigation or penalties, seriously damage or destroy property and equipment, result in claims by employees, customers or third parties, cause environmental damage and cause substantial damage to oil and gas producing formations or facilities. Operations also may be suspended because of machinery breakdowns, abnormal drilling conditions, and failure of subcontractors to perform or supply goods or services or personnel shortages. The occurrence of any of the hazards we face could have a material adverse effect on our business, financial condition and results of operations.
We are exposed to risks relating to operations in international locations.
We operate in various regions throughout the world that may expose us to political and other uncertainties, including risks of:
•seizure, nationalization or expropriation of property or equipment;
•monetary policies, government credit rating downgrades and potential defaults, and foreign currency fluctuations and devaluations;
•limitations on the ability to repatriate income or capital;
•complications associated with repairing and replacing equipment in remote locations;
•repudiation, nullification, modification or renegotiation of contracts;
•limitations on insurance coverage, such as war risk coverage, in certain areas;
•import-export quotas, wage and price controls and imposition of trade barriers;
•delays in implementing private commercial arrangements as a result of government oversight;
•compliance with and changes in taxation rules or policies;
•compliance with and changes in various jurisdictional regulatory or financial requirements, including rig flagging and local ownership requirements;
•other forms of government regulation and economic conditions that are beyond our control and that create operational uncertainty;
•governmental corruption;
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•the occurrence or threat of epidemic or pandemic diseases or any government response to such occurrence or threat;
•piracy; and
•terrorist acts, war, revolution and civil disturbances.
Further, we operate or have operated in certain less-developed countries with legal systems that are not as mature or predictable as those in more developed countries, which can lead to greater uncertainty in legal matters and proceedings. Examples of challenges of operating in these countries include:
•procedural requirements for temporary import permits, which may be difficult to obtain; and
•the effect of certain temporary import permit regimes, where the duration of the permit does not coincide with the general term of the drilling contract.
Our ability to do business in a number of jurisdictions is subject to maintaining required licenses and permits and complying with applicable laws and regulations. For example, all of our drilling units are subject to regulatory requirements of the flag state where the drilling unit is registered. The flag state requirements are international maritime requirements and, in some cases, further interpolated by the flag state itself. In addition, each of our drilling units must be “classed” by a classification society, signifying that such drilling rig has been built and maintained in accordance with the rules of the classification society and complies with applicable rules and regulations of the flag state. If any drilling unit loses its flag, does not maintain its class or fails any periodical survey or special survey, the drilling unit will be unable to carry on operations and will be unemployable and uninsurable.
Jurisdictions where we operate may attempt to impose requirements that our drilling units operating in such a jurisdiction have some local ownership or be registered under the flag of that jurisdiction, or both. If our debt agreements do not permit us to change the flag of a rig to a certain jurisdiction or register a rig under the flag of that jurisdiction (and consequently comply with local ownership requirements), and if we are otherwise unable to successfully object to registration, we may no longer be able to operate in that country. Any such inability to carry on operations in jurisdictions where we operate or desire to operate, or our failure to comply with any other laws and regulations of the countries where we operate, could have a material adverse effect on our results of operations.
In addition, OPEC initiatives, as well as other governmental actions, may continue to cause oil price volatility. In some areas of the world, this governmental activity has adversely affected the amount of exploration and development work done by major oil companies, which may continue. In addition, some governments favor or effectively require the awarding of drilling contracts to local contractors, require use of a local agent, require partial local ownership or require foreign contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. These practices may adversely affect our ability to compete and our results of operations.
In June 2016, the UK held a referendum in which voters approved an exit from the EU (“Brexit”). The UK exited the EU on January 31, 2020, consistent with the terms of the EU-UK Withdrawal Agreement, with a transition period that ended on December 31, 2020. On January 1, 2021, the UK left the EU Single Market and Customs Union as well as all EU policies and international agreements. As a result, the free movement of persons, goods, services and capital between the UK and the EU ended, and the EU and the UK formed two separate markets and two distinct regulatory and legal spaces. On December 24, 2020, the European Commission reached a trade agreement with the UK on the terms of its future cooperation with the EU. The trade agreement offers UK and EU companies preferential access to each other’s markets, ensuring imported goods will be free of tariffs and quotas (subject to rules of origin requirements). Uncertainty exists regarding the ultimate impact of this trade agreement, as well as the extent of possible financial, trade, regulatory and legal implications of Brexit. Brexit also contributes to global political and economic uncertainty, which may cause, among other consequences, volatility in exchange rates and interest rates, and changes in regulations. The Company provides contract drilling services to the international oil and gas industry and our fleet operates globally across multiple locations. Based on our global operating model and the versatility and marketability of our fleet, we do not expect the impact of Brexit to be significant to the Company.
Operating and maintenance costs of our rigs may be significant and may not correspond to revenue earned.
Our operating expenses and maintenance costs depend on a variety of factors including: crew costs, costs of provisions, equipment, insurance, maintenance and repairs, and shipyard costs, many of which are beyond our control. Our total operating costs are generally related to the number of drilling rigs in operation and the cost level in each country or region where such drilling rigs are located. Equipment maintenance costs fluctuate depending upon the type of activity that the drilling rig is performing and the age and condition of the equipment. Operating and maintenance costs will not necessarily fluctuate in proportion to changes in operating revenues. While operating revenues may fluctuate as a function of changes in dayrate, costs for operating a rig may not be proportional to the dayrate received and may vary based on a variety of factors, including the scope and length of required rig preparations and the duration of the contractual period over which such expenditures are amortized. Any investments in our rigs may not result in an increased dayrate for or income from such rigs. A disproportionate amount of operating and maintenance costs in comparison to dayrates could have a material adverse effect on our business, financial condition and results of operations.
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Drilling contracts with national oil companies may expose us to greater risks than we normally assume in drilling contracts with non-governmental clients.
Contracts with national oil companies are often non-negotiable and may expose us to greater commercial, political and operational risks than we assume in other contracts, such as exposure to materially greater environmental liability and other claims for damages (including consequential damages) and personal injury related to our operations, or the risk that the contract may be terminated by our client without cause on short-term notice, contractually or by governmental action, under certain conditions that may not provide us an early termination payment, collection risks and political risks. In addition, our ability to resolve disputes or enforce contractual provisions may be negatively impacted with these contracts. We can provide no assurance that the increased risk exposure will not have an adverse impact on our future operations or that we will not increase the number of rigs contracted to national oil companies with commensurate additional contractual risks.
Operational interruptions or maintenance or repair work may cause our customers to suspend or reduce payment of dayrates until operation of the respective drilling rig is resumed, which may lead to loss of revenue or termination or renegotiation of the drilling contract.
If our drilling rigs are idle for reasons that are not related to the ability of the rig to operate, our customers are entitled to pay a waiting, or standby, rate that is lower than the full operational rate. In addition, if our drilling rigs are taken out of service for maintenance and repair for a period of time that exceeds the scheduled maintenance periods set forth in our drilling contracts, we will not be entitled to payment of dayrates until the rig is able to work. Several factors could cause operational interruptions, including:
•breakdowns of equipment and other unforeseen engineering problems;
•work stoppages, including labor strikes;
•shortages of material and skilled labor;
•delays in repairs by suppliers;
•surveys by government and maritime authorities;
•periodic classification surveys;
•inability to obtain permits;
•severe weather, strong ocean currents or harsh operating conditions;
•force majeure events; and
•the occurrence or threat of epidemic or pandemic diseases or any government response to such occurrence or threat.
If the interruption of operations exceeds a determined period due to an event of force majeure, our customers have the right to pay a rate that is significantly lower than the waiting rate for a period of time and, thereafter, may terminate the drilling contracts related to the subject rig. Suspension of drilling contract payments, prolonged payment of reduced rates or termination of any drilling contract as a result of an interruption of operations as described herein could materially adversely affect our business, financial condition and results of operations.
We may have difficulty obtaining or maintaining insurance in the future and our insurance coverage and contractual indemnity rights may not protect us against all the risks and hazards we face.
We do not procure insurance coverage for all of the potential risks and hazards we may face. Furthermore, no assurance can be given that we will be able to obtain insurance against all of the risks and hazards we face or that we will be able to obtain or maintain adequate insurance at rates and with deductibles or retention amounts that we consider commercially reasonable. In addition, our insurance carriers may interpret our insurance policies such that they do not cover losses for which we make claims.
Although we maintain insurance in the geographic areas in which we operate, pollution, reservoir damage and environmental risks generally are not fully insurable. Our insurance policies may not adequately cover our losses or may have exclusions of coverage for some losses. We do not have insurance coverage or for all risks, including loss of hire insurance on most of the rigs in our fleet. Uninsured exposures may include expatriate activities prohibited by US laws and regulations, radiation hazards, cyber risks, certain loss or damage to property onboard our rigs and losses relating to shore-based terrorist acts or strikes. In addition, our insurance may not cover losses associated with pandemics such as the COVID-19 pandemic. Furthermore, the damage sustained to offshore oil and gas assets in the United States as a result of hurricanes has negatively impacted certain aspects of the energy insurance market, resulting in more restrictive and expensive coverage for US named windstorm perils due to the price or lack of availability of coverage. Accordingly, we have in the past self-insured the rigs in the US Gulf of Mexico for named windstorm perils. We currently have US windstorm coverage for most of our US fleet subject to certain limits, but will continue to monitor the insurance market conditions in the future and may decide not to, or be unable to, purchase named windstorm coverage for some or all of the rigs operating in the US Gulf of Mexico.
Under our drilling contracts, liability with respect to personnel and property is customarily assigned on a “knock-for-knock” basis, which means that we and our customers assume liability for our respective personnel and property, irrespective of the fault or negligence of the party indemnified. Although our drilling contracts generally provide for indemnification from our customers for certain liabilities, including liabilities resulting from pollution or contamination originating below the surface of the water, enforcement of these contractual rights to indemnity may be limited by public policy and other considerations and, in any event, may not adequately cover our losses from such incidents. There can also be no assurance that those parties with contractual obligations to indemnify us will necessarily be in a financial position to do
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so. During depressed market periods such as the one in which we currently operate, the contractual indemnity provisions we are able to negotiate in our drilling contracts may require us to assume more risk than we would during normal market periods.
If a significant accident or other event occurs and is not fully covered by insurance or contractual indemnity, it could adversely affect our business, financial condition and results of operations.
Our failure to adequately protect our sensitive information technology systems and critical data and our service providers’ failure to protect their systems and data could have a material adverse effect on our business, results of operations and financial condition.
We increasingly depend on information technology systems that we manage, and others that are managed by our third-party service and equipment providers, to conduct our day-to-day operations, including critical systems on our drilling units, and these systems are subject to risks associated with cyber incidents or attacks. It has been reported that unknown entities or groups have mounted cyber-attacks on businesses and other organizations solely to disable or disrupt computer systems, disrupt operations and, in some cases, steal data. In addition, the US government has issued public warnings that indicate that energy assets might be specific targets of cybersecurity threats. Also, in response to the COVID-19 pandemic, many of our non-operational employees are working remotely, which increases logistical challenges, inefficiencies and operational risks. Working remotely has significantly increased the use of online conferencing services and remote networking, which enable employees to work outside of our corporate infrastructure and, in some cases, use their own personal devices. This remote work model has resulted in an increased demand for information technology resources and may expose us to additional risks of security breaches or other cyber-incidents or attacks, loss of data, fraud and other disruptions as a consequence of more employees accessing sensitive and critical information from remote locations. Due to the nature of cyber-attacks, breaches to our systems or our service or equipment providers’ systems could go undetected for a prolonged period of time. While the Company has a cybersecurity program, a significant cyber-attack could disrupt our operations and result in downtime, loss of revenue, harm to the Company's reputation, or the loss, theft, corruption or unauthorized release of critical data of us or those with whom we do business as well as result in higher costs to correct and remedy the effects of such incidents. If our or our service or equipment providers’ systems for protecting against cyber incidents or attacks prove to be insufficient and an incident were to occur, it could have a material adverse effect on our business, financial condition and results of operations, along with our reputation. Even though we carry cyber insurance that may provide insurance coverage under certain circumstances, we might suffer losses as a result of a security breach that exceeds the coverage available under our policy or for which we do not have coverage.
In addition, laws and regulations governing data privacy and the unauthorized disclosure of confidential or protected information, including the European Union General Data Protection Regulation and recent legislation in various US states, pose increasingly complex compliance challenges and potentially elevate costs, and any failure to comply with these laws and regulations could result in significant penalties and legal liability.
Upgrades, refurbishment and repair of rigs are subject to risks, including delays and cost overruns, that could have an adverse impact on our available cash resources and results of operations.
We will continue to make upgrades, refurbishment and repair expenditures to our fleet from time to time, some of which may be unplanned. In addition, we may reactivate rigs that have been cold or warm stacked and make selective acquisitions of rigs. Our customers may also require certain shipyard reliability upgrade projects for our rigs. These projects and other efforts of this type are subject to risks of cost overruns or delays inherent in any large construction project as a result of numerous factors, including the following:
•shortages of equipment, materials or skilled labor;
•work stoppages and labor disputes;
•unscheduled delays in the delivery of ordered materials and equipment;
•local customs strikes or related work slowdowns that could delay importation of equipment or materials;
•weather interferences;
•difficulties in obtaining necessary permits or approvals or in meeting permit or approval conditions;
•design and engineering problems;
•inadequate regulatory support infrastructure in the local jurisdiction;
•latent damages or deterioration to hull, equipment and machinery in excess of engineering estimates and assumptions;
•unforeseen increases in the cost of equipment, labor and raw materials, particularly steel;
•unanticipated actual or purported change orders;
•client acceptance delays;
•disputes with shipyards and suppliers;
•delays in, or inability to obtain, access to funding;
•shipyard availability, failures and difficulties, including as a result of financial problems of shipyards or their subcontractors; and
•failure or delay of third-party equipment vendors or service providers.
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The failure to complete a rig upgrade, refurbishment or repair on time, or at all, may result in related loss of revenues, penalties, or delay, renegotiation or cancellation of a drilling contract or the recognition of an asset impairment. Additionally, capital expenditures could materially exceed our planned capital expenditures. Moreover, when our rigs are undergoing upgrade, refurbishment and repair, they may not earn a dayrate during the period they are out of service. If we experience substantial delays and cost overruns in our shipyard projects, it could have a material adverse effect on our business, financial condition and results of operations. We currently have no new rigs under construction.
Failure to attract and retain skilled personnel or an increase in personnel costs could adversely affect our operations.
We require skilled personnel to operate and provide technical services and support for our drilling units. In the past, during periods of high demand for drilling services and increasing worldwide industry fleet size, shortages of qualified personnel have occurred. During the last few years of reduced demand, there were layoffs of qualified personnel, who often find work with competitors or leave the industry. As a result, if market conditions improve and we seek to reactivate warm or cold stacked rigs, upgrade our working rigs or purchase additional rigs, we may face shortages of qualified personnel, which would impair our ability to attract qualified personnel for our new or existing drilling units, impair the timeliness and quality of our work and create upward pressure on personnel costs, any of which could adversely affect our operations.
Supplier capacity constraints or shortages in parts or equipment, supplier production disruptions, supplier quality and sourcing issues or price increases could increase our operating costs, decrease our revenues and adversely impact our operations.
Our reliance on third-party suppliers, manufacturers and service providers to secure equipment used in our drilling operations exposes us to volatility in the quality, price and availability of such items. Certain specialized parts and equipment we use in our operations may be available only from a single or small number of suppliers. During the last few years of reduced demand, many of these third-party suppliers reduced their inventories of parts and equipment and, in some cases, reduced their production capacity. If the market for our services improves and we seek to reactivate warm or cold stacked rigs, upgrade our working rigs or purchase additional rigs, these reductions could make it more difficult for us to find equipment and parts for our rigs. A disruption or delay in the deliveries from such third-party suppliers, capacity constraints, production disruptions, price increases, defects or quality-control issues, recalls or other decreased availability or servicing of parts and equipment could adversely affect our ability to reactivate rigs, upgrade working rigs, purchase additional rigs or meet our commitments to customers on a timely basis, adversely impact our operations and revenues by resulting in uncompensated downtime, reduced dayrates, the incurrence of liquidated damages or other penalties or the cancellation or termination of contracts, or increase our operating costs.
We may contemplate future mergers or acquisitions as part of our business strategy. Acquisitions of other businesses or assets present various risks and uncertainties.
We may pursue growth through the mergers or acquisition of businesses or assets that we believe will enable us to strengthen or broaden our business. We may be unable to implement this element of our strategy if we cannot identify suitable companies, businesses or assets, reach agreement on potential strategic acquisitions on acceptable terms or for other reasons. Moreover, merges and acquisitions involve various risks, including, among other things, (i) difficulties relating to integrating an acquired business and unanticipated changes in customer and other third-party relationships subsequent to acquisition, (ii) diversion of management's attention from day-to-day operations, (iii) failure to realize anticipated benefits, such as cost savings and revenue enhancements, (iv) potentially substantial transaction costs associated with acquisitions, and (v) potential impairment resulting from the overpayment for an acquisition.
Future mergers or acquisitions may require us to obtain additional equity or debt financing, which may not be available on attractive terms. Moreover, to the extent a transaction financed by non-equity consideration results in goodwill, it will reduce our tangible net worth, which might have an adverse effect on credit availability.
Acts of terrorism, piracy and political and social unrest could affect the markets for drilling services, which may have a material adverse effect on our 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.
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Fluctuations in exchange rates and nonconvertibility of currencies could result in losses to us.
We may experience currency exchange losses when revenues are received or expenses are paid in nonconvertible currencies, when we do not hedge an exposure to a foreign currency, when the result of a hedge is a loss or if any counterparty to our hedge were to experience financial difficulties. We may also incur losses as a result of an inability to collect revenues due to a shortage of convertible currency available to the country of operation, controls over currency exchange or controls over the repatriation of income or capital.
We are a holding company, and we are dependent upon cash flow from subsidiaries to meet our obligations.
We currently conduct our operations through our subsidiaries, and our operating income and cash flow are generated by our subsidiaries. As a result, cash we obtain from our subsidiaries is the principal source of funds necessary to meet our debt service obligations. Unless they are guarantors of our indebtedness, our subsidiaries do not have any obligation to pay amounts due on our indebtedness or to make funds available for that purpose. Contractual provisions or laws, as well as our subsidiaries’ financial condition and operating requirements, may also limit our ability to obtain the cash that we require from our subsidiaries to pay our debt service obligations. Applicable tax laws may also subject such payments to us by our subsidiaries to further taxation.
Future sales or the availability for sale of substantial amounts of the New Shares, or the perception that these sales may occur, could, if the New Shares are listed on a national securities exchange, adversely affect the trading price of the New Shares and could impair our ability to raise capital through future sales of equity securities.
Pursuant to the Memorandum of Association of Noble Corporation, the share capital of Noble is $6,000 divided into 500,000,000 ordinary shares of a par value of $0.00001 each and 100,000,000 shares of a par value of $0.00001, each of such class or classes having the rights as our Board of Directors may determine from time to time. On March 10, 2021, there were 43,536,636 New Shares outstanding and 6,463,182 Penny Warrants (as defined herein) issued and outstanding. In addition, as of March 10, 2021, 8,332,910 Tranche 1 Warrants, 8,332,910 Tranche 2 Warrants and 2,777,698 Tranche 3 Warrants are outstanding and exercisable. We also have 7,716,049 New Shares authorized and initially reserved for issuance pursuant to equity awards under the Noble Corporation 2021 Long-Term Incentive Plan.
A large percentage of the New Shares are held by a relatively small number of investors. We entered into the Equity Registration Rights Agreement (as defined herein) with certain of those investors pursuant to which we have agreed to file a registration statement with the SEC to facilitate potential future sales of such New Shares by them. We intend to apply for a listing of the New Shares on a national securities exchange. If the New Shares are listed on a national securities exchange, sales of a substantial number of the New Shares in the public markets, or even the perception that these sales might occur (such as upon the filing of the aforementioned registration statement), could impair our ability to raise capital through a future sale of, or pay for acquisitions using, our equity securities.
We may issue New Shares or other securities from time to time as consideration for future acquisitions and investments. If any such acquisition or investment is significant, the number of New Shares, or the number or aggregate principal amount, as the case may be, of other securities that we may issue may in turn be substantial. We may also grant registration rights covering those New Shares or other securities in connection with any such acquisitions and investments.
If the New Shares are listed on a national securities exchange, we cannot predict the effect that future sales of New Shares will have on the price at which the New Shares trades or the size of future issuances of New Shares or the effect, if any, that future issuances will have on the market price of the New Shares. Sales of substantial amounts of the New Shares, or the perception that such sales could occur, may, if the New Shares are listed on a national securities exchange, adversely affect the trading price of the New Shares.
Certain shareholders own a significant portion of our outstanding equity securities, and their interests may not always coincide with the interests of other holders of the New Shares.
As noted above, a large percentage of the New Shares are held by a relatively small number of investors. As a result, these investors could have significant influence over all matters presented to our shareholders for approval, including election and removal of our directors, change in control transactions and the outcome of all actions requiring a majority shareholder approval.
The interests of these investors may not always coincide with the interests of the other holders of the New Shares, and the concentration of control in these investors may limit other shareholders’ ability to influence corporate matters. The concentration of ownership and voting power of these investors may also delay, defer or even prevent an acquisition by a third party or other change of control of our Company and may make some transactions more difficult or impossible without their support, even if such events are in the bests interests of our other shareholders. If the New Shares are listed on a national securities exchange, this concentration and voting power may adversely affect the trading price of the New Shares.
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Financial and Tax Risks
We may record impairment charges on property and equipment, including rigs and related capital spares.
We evaluate the impairment of property and equipment, which include rigs and related capital spares, whenever events or changes in circumstances (including a decision to cold stack, retire or sell rigs) indicate that the carrying amount of an asset may not be recoverable. An impairment loss on our property and equipment may exist when the estimated undiscounted cash flows expected to result from the use of the asset and its eventual disposition are less than its carrying amount. Any impairment loss recognized represents the excess of the asset’s carrying value over the estimated fair value. As part of this analysis, we make assumptions and estimates regarding future market conditions. To the extent actual results do not meet our estimated assumptions, for a given rig or piece of equipment, we may take an impairment loss in the future. In addition, we may also take an impairment loss on capital spares and other capital equipment when we deem the value of those items has declined due to factors like obsolescence, deterioration or damage. Based upon our impairment analyses for the years ended December 31, 2020 and 2019, we recorded impairment charges of $3.9 billion and $615.3 million, respectively, on various rigs and certain capital spares during those periods. There can be no assurance that we will not have to take additional impairment charges in the future if current depressed market conditions persist, or that we will be able to return cold stacked rigs to service in the time frame and at the reactivation costs or at the dayrates that we projected. It is reasonably possible that the estimate of undiscounted cash flows may change in the near term, resulting in the need to write down the affected assets to their corresponding estimated fair values.
The Exit Credit Agreement contains various restrictive covenants limiting the discretion of our management in operating our business.
The Exit Credit Agreement contains various restrictive covenants that may limit our management’s discretion in certain respects. In particular, the Exit Credit Agreement limits Finco’s ability and the ability of its restricted subsidiaries to, among other things and subject to certain limitations and exceptions, (i) incur, assume or guarantee additional indebtedness; (ii) pay dividends or distributions on capital stock or redeem or repurchase capital stock; (iii) make investments; (iv) repay, redeem or amend certain indebtedness; (v) sell stock of its subsidiaries; (vi) transfer or sell assets; (vii) create, incur or assume liens; (viii) enter into transactions with certain affiliates; (ix) merge or consolidate with or into any other person or undergo certain other fundamental changes; and (x) enter into certain burdensome agreements. In addition, the Exit Credit Agreement obligates Finco and its restricted subsidiaries to comply with certain financial maintenance covenants and, under certain conditions, to make mandatory prepayments and reduce the amount of credit available under the Exit Credit Facility, all as described in Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations— Liquidity and Capital Resources— Post-emergence Debt—Senior Secured Exit Revolving Credit Facility.” Such mandatory prepayments and commitment reductions may affect cash available for use in the Company’s business. Our failure to comply with these covenants could result in an event of default which, if not cured or waived, could result in all obligations under the Exit Credit Facility to be declared due and payable immediately and all commitments thereunder to be terminated.
Changes in the method of determining the London Interbank Offered Rate, or the replacement of the London Interbank Offered Rate with an alternative reference rate, may adversely affect interest expense related to outstanding debt.
The loans outstanding under the Exit Credit Facility (as defined herein) bear interest at a rate per annum equal to the applicable margin plus, at Finco’s option, either: (i) the reserve-adjusted London Interbank Offered Rate (“LIBOR”) or (ii) a base rate. On July 27, 2017, the Financial Conduct Authority in the UK, which regulates LIBOR, announced that it intends to phase out LIBOR as a benchmark by the end of 2021. It is unclear if LIBOR will cease to exist at the end of 2021, when it is intended to be phased out or if new methods of calculating LIBOR will be established such that it continues to exist after 2021. While the Exit Credit Facility, which has a term that extends beyond 2021, contains “fallback” provisions providing for alternative rate calculations upon the occurrence of certain events related to the phase-out of LIBOR, these “fallback” provisions may not adequately address the actual changes to LIBOR or successor rates. Although the Secured Overnight Financing Rate is expected to be the alternative rate that replaces LIBOR, we cannot predict what margin adjustments and related terms would be negotiated in connection with the “fallback” provisions. As a result, our interest expense could increase. In addition, the overall financial markets may be disrupted as a result of the phase-out or replacement of LIBOR. Uncertainty as to the nature of such potential phase-out and alternative reference rates or disruption in the financial market could have a material adverse effect on our financial condition, results of operations and cash flows.
A loss of a major tax dispute or a successful tax challenge to our operating structure, intercompany pricing policies or the taxable presence of our subsidiaries in certain countries could result in a higher tax rate on our worldwide earnings, which could result in a material adverse effect on our financial condition and results of operations.
Income tax returns that we file will be subject to review and examination. We recognize the benefit of income tax positions we believe are more likely than not to be sustained upon challenge by a tax authority. If any tax authority successfully challenges our operational structure, intercompany pricing policies or the taxable presence of our subsidiaries in certain countries, if the terms of certain income tax treaties are
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interpreted in a manner that is adverse to our structure, or if we lose a material tax dispute in any country, our effective tax rate on our worldwide earnings could increase substantially and result in a material adverse effect on our financial condition.
Our consolidated effective income tax rate may vary substantially from one reporting period to another.
We cannot provide any assurances as to what our consolidated effective income tax rate will be because of, among other matters, uncertainty regarding the nature and extent of our business activities in any particular jurisdiction in the future and the tax laws of such jurisdictions, as well as potential changes in the UK, US, Switzerland and other tax laws, regulations or treaties or the interpretation or enforcement thereof, changes in the administrative practices and precedents of tax authorities or any reclassification or other matter (such as changes in applicable accounting rules) that increases the amounts we have provided for income taxes or deferred tax assets and liabilities in our consolidated financial statements. For example, the Organization for Economic Cooperation and Development (“OECD”) has issued its final reports on Base Erosion and Profit Shifting, which generally focus on situations where profits are earned in low-tax jurisdictions, or payments are made between affiliates from jurisdictions with high tax rates to jurisdictions with lower tax rates. Certain countries within which we operate have recently enacted changes to their tax laws in response to the OECD recommendations or otherwise and these and other countries may enact changes to their tax laws or practices in the future (prospectively or retroactively), which may have a material adverse effect on our financial position, operating results and/or cash flows.
In addition, as a result of frequent changes in the taxing jurisdictions in which our drilling rigs are operated and/or owned, changes in the overall level of our income and changes in tax laws, our consolidated effective income tax rate may vary substantially from one reporting period to another. Income tax rates imposed in the tax jurisdictions in which our subsidiaries conduct operations vary, as does the tax base to which the rates are applied. In some cases, tax rates may be applicable to gross revenues, statutory or negotiated deemed profits or other bases utilized under local tax laws, rather than to net income. Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the movement of drilling rigs among taxing jurisdictions will involve the transfer of ownership of the drilling rigs among our subsidiaries. If we are unable to mitigate the negative consequences of any change in law, audit, business activity or other matter, this could cause our consolidated effective income tax rate to increase and cause a material adverse effect on our financial position, operating results and/or cash flows.
Pension expenses associated with our retirement benefit plans may fluctuate significantly depending upon changes in actuarial assumptions, future investment performance of plan assets and legislative or other regulatory actions.
A portion of our current and retired employee population is covered by pension and other post-retirement benefit plans, the costs of which are dependent upon various assumptions, including estimates of rates of return on benefit plan assets, discount rates for future payment obligations, mortality assumptions, rates of future cost growth and trends for future costs. In addition, funding requirements for benefit obligations of our pension and other post-retirement benefit plans are subject to legislative and other government regulatory actions. Future changes in estimates and assumptions associated with our pension and other post-retirement benefit plans could have a material adverse effect on our financial condition, results of operations, cash flows and/or financial disclosures.
Regulatory and Legal Risks
Governmental laws and regulations may add to our costs, result in delays, or limit our drilling activity.
Our business is affected by public policy and laws and regulations relating to the energy industry in the geographic areas where we operate.
The drilling industry is dependent 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. We may be required to make significant capital expenditures to comply with governmental laws and regulations. Governments in some foreign countries are increasingly active in regulating and controlling the ownership of concessions, the exploration for oil and gas, and other aspects of the oil and gas industries. There is increasing attention in the United States and worldwide concerning the issue of climate change and the effect of greenhouse gases, or GHGs, and other sustainability and energy transition matters. This increased attention may result in new environmental laws or regulations that may unfavorably impact us, our suppliers and our customers.
The modification of existing laws or regulations or the adoption of new laws or regulations that result in the curtailment of exploratory or developmental drilling for oil and gas could materially and adversely affect our operations by limiting drilling opportunities increasing our cost of doing business, discouraging our customers from drilling for hydrocarbons, disrupting revenue through permitting or similar delays, or subjecting us to liability. For example, on January 20, 2021, the Acting Secretary for the Department of the Interior signed an order effectively suspending new fossil fuel leasing and permitting on federal lands, including in the US Gulf of Mexico, for 60 days. Then on January 27, 2021, President Biden issued an executive order indefinitely suspending new oil and natural gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of federal oil and gas permitting and leasing practices. Demand for our services could be diminished during this review period. Further, to the extent that the review results in the development of additional restrictions on
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offshore drilling, limitations on the availability of offshore leases, or restrictions on the ability to obtain required permits, it could have a material adverse impact on our operations by reducing drilling opportunities and the demand for our services.
Increasing attention to environmental, social and governance matters may impact our business and financial results.
In recent years, increasing attention has been given to corporate activities related to environmental, social and governance (“ESG”) matters in public discourse and the investment community. A number of advocacy groups, both domestically and internationally, have campaigned for governmental and private action to promote change at public companies related to ESG matters, including through the investment and voting practices of investment advisers, public pension funds, universities and other members of the investing community. These activities include increasing attention and demands for action related to climate change and energy transition matters, such as promoting the use of substitutes to fossil fuel products and encouraging the divestment of fossil fuel equities, as well as pressuring lenders and other financial services companies to limit or curtail activities with fossil fuel companies. If this were to continue, it could have a material adverse effect on our ability to access equity capital markets. Members of the investment community have begun to screen companies such as ours for sustainability performance, including practices related to GHGs and climate change. If we are unable to find economically viable, as well as publicly acceptable, solutions that reduce our GHG emissions and/or GHG intensity for new and existing projects, we could experience additional costs or financial penalties, delayed or cancelled projects, and/or reduced production and reduced demand for hydrocarbons, which could have a material adverse effect on our earnings, cash flows and financial condition.
Any violation of anti-bribery or anti-corruption laws, including the Foreign Corrupt Practices Act, the United Kingdom Bribery Act, or similar laws and regulations could result in significant expenses, divert management attention, and otherwise have a negative impact on us.
We operate in countries known to have a reputation for corruption. We are subject to the risk that we, our affiliated entities or their respective officers, directors, employees and agents may take action determined to be in violation of such anti-corruption laws, including the US Foreign Corrupt Practices Act of 1977 (the “FCPA”), the United Kingdom Bribery Act 2010 (the “UK Bribery Act”) and similar laws in other countries. Any violation of the FCPA, UK Bribery Act or other applicable anti-corruption laws could result in substantial fines, sanctions, civil and/or criminal penalties and curtailment of operations in certain jurisdictions and might adversely affect our business, financial condition and results of operations. In addition, actual or alleged violations could damage our reputation and ability to do business. Further, detecting, investigating and resolving actual or alleged violations is expensive and can consume significant time and attention of our senior management.
Changes in, compliance with, or our failure to comply with the certain laws and regulations may negatively impact our operations and could have a material adverse effect on our results of operations.
Our operations are subject to various laws and regulations in countries in which we operate, including laws and regulations relating to:
•the environment and the health and safety of personnel;
•the importing, exporting, equipping and operation of drilling rigs;
•currency exchange controls;
•oil and gas exploration and development;
•taxation of offshore earnings and earnings of expatriate personnel; and
•use and compensation of local employees and suppliers by foreign contractors.
Public and governmental scrutiny of the energy industry has resulted in increased regulations being proposed and often implemented. In addition, existing regulations might be revised or reinterpreted, new laws, regulations and permitting requirements might be adopted or become applicable to us, our rigs, our customers, our vendors or our service providers, and future changes in laws and regulations could significantly increase our costs and could have a material adverse effect on our business, financial condition and results of operations. In addition, we may be required to post additional surety bonds to secure performance, tax, customs and other obligations relating to our rigs in jurisdictions where bonding requirements are already in effect and in other jurisdictions where we may operate in the future. These requirements would increase the cost of operating in these countries, which could materially adversely affect our business, financial condition and results of operations.
From time to time, new rules, regulations and requirements regarding oil and gas development have been proposed and implemented by BOEM, BSEE or the United States Congress, as well as other jurisdictions outside the United States, that could materially limit or prohibit, and increase the cost of, offshore drilling. For example, in July 2016, BOEM and BSEE finalized a rule revising and adding requirements for drilling on the US Arctic Outer Continental Shelf. Similarly, in April 2016, BSEE announced a final blowout preventer systems and well control rule. BSEE also finalized a rule in September 2016 concerning production safety systems for oil and natural gas operations on the Outer Continental Shelf. BSEE issued final rules amending both the September 2016 production safety systems rule and the April 2016 blowout preventer systems and well control rule in September 2018 and May 2019, respectively. BSEE also published a proposed rule in December 2020 that would revise the 2016 rule concerning drilling on the US Arctic Outer Continental Shelf. In addition, BOEM released a Notice to Lessees and Operators in the Outer Continental Shelf (“NTL”) in September 2016 that updated offshore bonding requirements. The NTL was only partially implemented before being rescinded and replaced by a proposed rule addressing offshore bonding published in October 2020. However, on January 20, 2021, President Biden issued executive orders freezing the issuance of new rules pending further review and directing
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all executive departments and agencies to review and consider suspending, revising, or rescinding all regulations issued between January 20, 2017 and January 20, 2021 determined to be inconsistent with President Biden’s environmental and climate goals. To the extent these recent proposed and final rules are reviewed and determined to be inconsistent under the executive orders, BOEM and BSEE could issue new rules reinstating the requirements of the 2016 rules and/or reimplement the NTL.
We are also subject to increasing regulatory requirements and scrutiny in the North Sea jurisdictions and other countries. New rules, regulations and requirements, or a return to the requirements of the 2016 versions of the BSEE and BOEM regulations, including the adoption of new safety requirements and policies relating to the approval of drilling permits, restrictions on oil and gas development and production activities in the US Gulf of Mexico and elsewhere, implementation of safety and environmental management systems, mandatory third party compliance audits, and the promulgation of numerous Notices to Lessees or similar new regulatory requirements outside of the United States, may impact our operations by causing increased costs, delays and operational restrictions. If new regulations, policies, operating procedures and the possibility of increased legal liability resulting from the adoption or amendment of rules and regulations applicable to our operations in the United States or other jurisdictions are viewed by our current or future customers as a significant impairment to expected profitability on projects, then they could discontinue or curtail their offshore operations in the impacted region, thereby adversely affecting our operations by limiting drilling opportunities or imposing materially increased costs.
We could also be affected by challenges and restrictions to offshore operations by environmental groups, costal states and the federal government. For example, in December 2018, environmental groups challenged incidental harassment authorizations issued by the National Marine Fisheries Service that allow companies to conduct air gun seismic surveys for oil and gas exploration off the Atlantic coast. The attorney generals for ten US coastal states also intervened as plaintiffs. The litigation concluded in October 2020 and the authorizations expired in November 2020. Restrictions on authorizations needed to conduct seismic surveys could impact our customers’ ability to identify oil and gas reserves, thereby reducing demand for our services. Several coastal states have also taken steps to prohibit offshore drilling. For example, California passed laws in September 2018 barring the construction of new oil drilling-related infrastructure in state waters. Similarly, in November 2018, voters in Florida approved an amendment to the state constitution that would ban oil and gas drilling in offshore state waters. Such initiatives could reduce opportunities for our customers and thereby reduce demand for our services. In addition, the federal government has taken steps to restrict offshore drilling opportunities. For example, on January 20, 2021, the Acting Secretary for the Department of the Interior signed an order effectively suspending new fossil fuel leasing and permitting on federal lands, including in the US Gulf of Mexico, for 60 days. Then on January 27, 2021, President Biden issued an executive order indefinitely suspending new oil and natural gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of federal oil and gas permitting and leasing practices. Demand for our services could be diminished during this review period. Further, to the extent that the review results in the development of additional restrictions on offshore drilling, limitations on the availability of offshore leases, or restrictions on the ability to obtain required permits, it could have a material adverse impact on our operations by reducing drilling opportunities and the demand for our services.
Adverse effects may continue as a result of the uncertainty of ongoing inquiries, investigations and court proceedings, or additional inquiries and proceedings by federal or state regulatory agencies or private plaintiffs. In addition, we cannot predict the outcome of any of these inquiries or whether these inquiries will lead to additional legal proceedings against us, civil or criminal fines or penalties, or other regulatory action, including legislation or increased permitting requirements. Legal proceedings or other matters against us, including environmental matters, suits, regulatory appeals, challenges to our permits by citizen groups and similar matters, might result in adverse decisions against us. The result of such adverse decisions, both individually or in the aggregate, could be material and may not be covered fully or at all by insurance.
Our operations are subject to numerous laws and regulations relating to the protection of the environment and of human health and safety, and compliance with these laws and regulations could impose significant costs and liabilities that exceed our current expectations.
Substantial costs, liabilities, delays and other significant issues could arise from environmental, health and safety laws and regulations covering our operations, and we may incur substantial costs and liabilities in maintaining compliance with such laws and regulations. Our operations are subject to extensive international conventions and treaties, and national or federal, state and local laws and regulations, governing environmental protection, including with respect to the discharge of materials into the environment and the security of chemical and industrial facilities. These laws govern a wide range of environmental issues, including:
•the release of oil, drilling fluids, natural gas or other materials into the environment;
•air emissions from our drilling rigs or our facilities;
•handling, cleanup and remediation of solid and hazardous wastes at our drilling rigs or our facilities or at locations to which we have sent wastes for disposal;
•restrictions on chemicals and other hazardous substances; and
•wildlife protection, including regulations that ensure our activities do not jeopardize endangered or threatened animals, fish and plant species, nor destroy or modify the critical habitat of such species.
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Various governmental authorities have the power to enforce compliance with these laws and regulations and the permits issued under them, oftentimes requiring difficult and costly actions. Failure to comply with these laws, regulations and permits, or the release of oil or other materials into the environment, may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations, the imposition of stricter conditions on or revocation of permits, the issuance of moratoria or injunctions limiting or preventing some or all of our operations, delays in granting permits and cancellation of leases, or could affect our relationship with certain consumers.
There is an inherent risk of the incurrence of environmental costs and liabilities in our business, some of which may be material, due to the handling of our customers’ hydrocarbon products as they are gathered, transported, processed and stored, air emissions related to our operations, historical industry operations, and water and waste disposal practices. For example, we, as an operator of mobile offshore drilling units in navigable US waters and certain offshore areas, including the US Outer Continental Shelf, are liable for damages and for the cost of removing oil spills for which we may be held responsible, subject to certain limitations. Our operations may involve the use or handling of materials that are classified as environmentally hazardous. Environmental 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. Joint, several or strict liability may be incurred without regard to fault under certain environmental laws and regulations for the remediation of contaminated areas and in connection with past, present or future spills or releases of natural gas, oil and wastes on, under, or from past, present or future facilities. Private parties may have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage arising from our operations. In addition, increasingly strict laws, regulations and enforcement policies could materially increase our compliance costs and the cost of any remediation that may become necessary. Our insurance may not cover all environmental risks and costs or may not provide sufficient coverage if an environmental claim is made against us.
Our business may be adversely affected by increased costs due to stricter pollution control equipment requirements or liabilities resulting from non-compliance with required operating or other regulatory permits. Also, we might not be able to obtain or maintain from time to time all required environmental regulatory approvals for our operations. If there is a delay in obtaining any required environmental regulatory approvals, or if we fail to obtain and comply with them, the operation or construction of our facilities could be prevented or become subject to additional costs. In addition, the steps we could be required to take to bring certain facilities into regulatory compliance could be prohibitively expensive, and we might be required to shut down, divest or alter the operation of those facilities, which might cause us to incur losses.
We make assumptions and develop expectations about possible expenditures related to environmental conditions based on current laws and regulations and current interpretations of those laws and regulations. If the interpretation of laws or regulations, or the laws and regulations themselves, change, our assumptions may change, and new capital costs may be incurred to comply with such changes. In addition, new environmental laws and regulations might adversely affect our operations, as well as waste management and air emissions. For instance, governmental agencies could impose additional safety requirements, which could affect our profitability. Further, new environmental laws and regulations might adversely affect our customers, which in turn could affect our profitability.
Finally, although some of our drilling rigs will be separately owned by our subsidiaries, under certain circumstances a parent company and all of the unit-owning affiliates in a group under common control engaged in a joint venture could be held liable for damages or debts owed by one of the affiliates, including liabilities for oil spills under environmental laws. Therefore, it is possible that we could be subject to liability upon a judgment against us or any one of our subsidiaries.
Unionization efforts and labor regulations in certain countries in which we operate could materially increase our costs or limit our flexibility.
Certain of our employees and contractors in international markets are represented by labor unions or work under collective bargaining or similar agreements, which are subject to periodic renegotiation. Efforts may be made from time to time to unionize portions of our workforce. In addition, we may be subject to strikes or work stoppages and other labor disruptions in the future. Additional unionization efforts, new collective bargaining agreements or work stoppages could materially increase our costs, reduce our revenues or limit our operational flexibility.
Any failure to comply with the complex laws and regulations governing international trade could adversely affect our operations.
The shipment of goods, services and technology across international borders subjects our business to extensive trade laws and regulations. Import activities are governed by unique customs laws and regulations in each of the countries of operation. Moreover, many countries, including the United States, control the export and re-export of certain goods, services and technology and impose related 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. US sanctions, in particular, are targeted against certain countries that are heavily involved in the petroleum and petrochemical industries, which includes drilling activities.
The laws and regulations concerning import activity, export recordkeeping and reporting, 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. Shipments can be delayed and denied export or entry for a variety of reasons, some of which are outside our control
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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. Any failure to comply with applicable legal and regulatory trading obligations could also result in criminal and civil penalties and sanctions, such as fines, imprisonment, debarment from government contracts, seizure of shipments and loss of import and export privileges.
Currently, we do not, nor do we intend to, operate in countries that are subject to significant sanctions and embargoes imposed by the US government or identified by the US government as state sponsors of terrorism, such as the Crimean region of the Ukraine, Cuba, Iran, North Korea, Sudan and Syria. The US sanctions and embargo laws and regulations vary in their application, as they do not all apply to the same covered persons or proscribe the same activities, and such sanctions and embargo laws and regulations may be amended or strengthened over time. There can be no assurance that we will be in compliance in the future, particularly as the scope of certain laws may be unclear and may be subject to changing interpretations. Any such violation could result in fines or other penalties and could result in some investors deciding, or being required, to divest their interest, or not to invest, in us. In addition, certain institutional investors may have investment policies or restrictions that prevent them from holding securities of companies that have contracts with countries identified by the US government as state sponsors of terrorism. In addition, our reputation and the market for our securities may be adversely affected if we engage in certain other activities, such as entering into drilling contracts with individuals or entities in countries subject to significant US sanctions and embargo laws that are not controlled by the governments of those countries, or engaging in operations associated with those countries pursuant to contracts with third parties that are unrelated to those countries or entities controlled by their governments.
We are subject to litigation that could have an adverse effect on us.
We are, from time to time, involved in various litigation matters. These matters may include, among other things, contract disputes, personal injury claims, asbestos and other toxic tort claims, environmental claims or proceedings, employment matters, issues related to employee or representative conduct, governmental claims for taxes or duties, and other litigation that arises in the ordinary course of our business. Although we intend to defend or pursue such matters vigorously, we cannot predict with certainty the outcome or effect of any claim or other litigation matter, and there can be no assurance as to the ultimate outcome of any litigation. Litigation may have an adverse effect on us because of potential negative outcomes, legal fees, the allocation of management’s time and attention, and other factors.
Item 1B. Unresolved Staff Comments.
None.
Item 2. Properties.
The description of our rig fleet included under “Part I, Item 1, Business” is incorporated by reference herein. We lease office space in Sugar Land, Texas, where our corporate headquarters are located. In addition, we own and lease operational, administrative and marketing offices, as well as other sites used primarily for operations, storage and maintenance and repairs for drilling rigs and equipment in various locations worldwide.
Item 3. Legal Proceedings.
Information regarding legal proceedings is presented in “Note 16— Commitments and Contingencies” to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K.
Item 4. Mine Safety Disclosures.
Not applicable.
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PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.
Market for Shares and Related Shareholder Information
Legacy Noble’s ordinary shares were previously listed and traded on the New York Stock Exchange (the “NYSE”) under the symbol “NE.” As a consequence of the Chapter 11 Cases, on July 31, 2020, the NYSE suspended trading in Legacy Noble’s ordinary shares at the market opening. On August 17, 2020, the NYSE filed a Form 25 with the SEC to delist Legacy Noble’s ordinary shares. The delisting was effective 10 days after the Form 25 was filed. From August 4, 2020 to the Effective Date, Legacy Noble’s ordinary shares were trading on the OTC Pink Open Market under the symbol “NEBLQ.” On the Effective Date, Legacy Noble’s ordinary shares were cancelled and we issued the New Shares, which are not listed or traded on an established trading or other public market. In accordance with the Plan, Legacy Noble and its remaining subsidiary will in due course be wound down and dissolved in accordance with applicable law.
On March 10, 2021, there were 43,536,636 New Shares outstanding held by two shareholder accounts of record, and there were 6,463,182 Penny Warrants issued and outstanding.
Dividends
The declaration and payment of dividends required the authorization of the Board of Directors of Legacy Noble, provided that such dividends on issued share capital may be paid only out of Legacy Noble’s “distributable reserves” on its statutory balance sheet in accordance with UK law. Therefore, Legacy Noble was not permitted to pay dividends out of share capital, which includes share premium. Legacy Noble had not paid dividends since the third quarter of 2016. The payment of future dividends will depend on our results of operations, financial condition, cash requirements, future business prospects, contractual and indenture restrictions and other factors deemed relevant by our Board of Directors.
UK Tax Consequences to Shareholders of Legacy Noble
Legacy Noble's shares were cancelled on the Effective Date and relevant Forms 8937 will be published on the Company’s website within 45 days following the Effective Date. Shareholders should review such Forms 8937 with their own tax advisors to determine the tax consequences of such cancellation to such shareholders. The tax consequences discussed below may be relevant prior to such cancellation and do not reflect a complete analysis or listing of all the possible tax consequences that may be relevant to shareholders of Legacy Noble. Shareholders should consult their own tax advisors in respect of the tax consequences related to receipt, ownership, purchase or sale or other disposition of our shares.    
UK Income Tax on Dividends and Similar Distributions
A non-UK tax resident holder will not be subject to UK income taxes on dividend income and similar distributions in respect of their Legacy Noble shares, unless the shares are attributable to a permanent establishment or a fixed place of business maintained in the UK by such non-UK holder.
Disposition of Legacy Noble Shares
Shareholders who are neither UK tax residents nor holding their Legacy Noble shares in connection with a trade carried on through a permanent establishment in the UK will not be subject to any UK taxes on chargeable gains as a result of any disposals of their shares. Legacy Noble shares held outside the facilities of The Depository Trust Company (“DTC”) should be treated as UK situs assets for the purpose of UK inheritance tax.
UK Withholding Tax—Dividends to Shareholders
Payments of dividends by Legacy Noble will not be subject to any withholding in respect of UK taxation, regardless of the tax residence of the recipient shareholder.
Stamp Duty and Stamp Duty Reserve Tax in Relation to the Transfer of Shares
Stamp duty and/or stamp duty reserve tax (“SDRT”) are imposed by the UK on certain transfers of chargeable securities (which include shares in companies incorporated in the UK) at a rate of 0.5 percent of the consideration paid for the transfers in question. Certain transfers of shares to depositaries or into clearance systems are charged at a higher rate of 1.5 percent. Her Majesty’s Revenue and Customs (“HMRC”) regard DTC as a clearance system for these purposes.
Transfers of the ordinary shares through the facilities of DTC will not attract a charge to stamp duty or SDRT in the UK. Any transfer of title to ordinary shares from within those facilities to a holder outside those facilities, and any subsequent transfers that occur entirely outside
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those facilities, will ordinarily attract stamp duty or SDRT at a rate of 0.5 percent. This duty must be paid (and, where relevant, the transfer document stamped by HMRC) before the transfer can be registered in the books of Legacy Noble. However, if those ordinary shares of Legacy Noble are redeposited into the facilities of DTC, that redeposit will attract stamp duty or SDRT at the rate of 1.5 percent.
Share Repurchases
Under UK law, Legacy Noble was only permitted to purchase its own shares by way of an “off-market purchase” in a plan approved by shareholders. We did not have shareholder authority to repurchase shares of Legacy Noble and there is currently no share repurchase plan in place for the Successor. During the years ended December 31, 2020, 2019 and 2018, we did not repurchase any of our shares.
Stock Performance Graph
The chart below presents a comparison of the five-year cumulative total return, assuming $100 was invested on December 31, 2015 for Legacy Noble, the Standard & Poor's 500 Index, Dow Jones US Oil Equipment and Services and a self-determined offshore drillers peer group. Total return assumes the reinvestment of dividends, if any, in the security on the ex-dividend date. This graph depicts the past performance of Legacy Noble’s ordinary shares through December 31, 2020, and in no way should be used to predict future share performance. All common stock and equity-based compensation awards that were outstanding immediately prior to the Effective Date of our emergence from the Chapter 11 Cases were terminated and cancelled.
NE-20201231_G1.JPG
INDEXED RETURNS
Year Ended December 31,
Company / Index 2016 2017 2018 2019 2020
Legacy Noble $ 57.50  $ 43.90  $ 25.45  $ 11.85  $ 0.24 
S&P 500 Index 111.96  136.40  130.42  171.49  203.04 
Dow Jones US Oil Equipment & Services 127.31  106.03  61.11  66.12  40.11 
Offshore Drillers Peer Group (1)
94.73  73.61  43.27  38.72  8.62 
(1)Our self-determined peer group is weighted according to market capitalization and consists of the Company and the following peer companies: Diamond Offshore Drilling Inc., Rowan Companies plc (through April 10, 2019), Transocean Ltd and Valaris (formerly known as Ensco plc).
The above graph and related information shall not be deemed “soliciting material” or to be “filed” with the SEC, nor shall such information be incorporated by reference into any future filing under the Securities Act or the Exchange Act, except to the extent that we specifically incorporate it by reference into such filing.
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Item 6. Selected Financial Data.
The following table presents selected financial data of us and our consolidated subsidiaries over the five-year period ended December 31, 2020, which information is derived from our audited financial statements. This information should be read in conjunction with, and is qualified in its entirety by, the more detailed information in our financial statements included in Part II, Item 8, “Financial Statements and Supplementary Data” in this Annual Report on Form 10-K.
Year Ended December 31,
2020 2019 2018 2017 2016
(In thousands, except per share amounts)
Statement of Income Data
Operating revenues from continuing operations $ 964,272  $ 1,305,438  $ 1,082,826  $ 1,236,915  $ 2,302,065 
Net income (loss) from continuing operations attributable to Noble (1)
(3,978,459) (696,769) (885,050) (515,025) (929,580)
Net income (loss) from continuing operations per share attributable to Noble:
Basic (15.86) (2.79) (3.59) (2.10) (3.82)
Diluted (15.86) (2.79) (3.59) (2.10) (3.82)
Balance Sheet Data (at end of period)
Cash and cash equivalents 343,332  104,621  375,232  662,829  725,722 
Property and equipment, net 3,577,069  7,733,924  8,480,718  9,489,240  10,061,948 
Total assets 4,263,937  8,284,498  9,264,923  10,794,659  11,440,117 
Long-term debt —  3,779,499  3,877,402  3,795,867  4,040,229 
Total debt (2)
—  3,842,004  3,877,402  4,045,710  4,340,111 
Total equity (311,388) 3,658,972  4,654,574  5,950,628  6,467,445 
Other Data
Net cash provided by operating activities 273,197  186,771  171,851  416,675  1,142,740 
Net cash used in investing activities (121,520) (256,030) (189,377) (118,325) (686,595)
Net cash provided by (used in) financing activities 107,440  (200,724) (269,396) (361,243) (242,668)
Net cash used for capital expenditures 148,886  268,783  194,779  120,707  711,403 
Working capital (3)
383,933  (94,821) 293,599  445,951  559,321 
Cash distributions declared per share —  —  —  —  0.20 
(1)    Results for 2020, 2019, 2018, 2017 and 2016 include impairment charges of $3.9 billion, $615.3 million, $802.1 million, $121.6 million and $1.5 billion, respectively. Results for 2020 and 2019 include a gain of $15.0 million and loss of $100.0 million respectively, related to the final disposition of the Paragon Offshore litigation matter.
(2)    Consists of long-term debt and current maturities of long-term debt. All of our Long-term debt as of December 31, 2020 has been presented as “Liabilities subject to compromise.”
(3)    Working capital is calculated as current assets less current liabilities.
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
The following discussion is intended to assist you in understanding our financial position at December 31, 2020 and 2019, and our results of operations for each of the years in the three-year period ended December 31, 2020. The following discussion should be read in conjunction with the consolidated financial statements and related notes contained in this Annual Report on Form 10-K for the year ended December 31, 2020 filed by Noble and Finco.
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Executive Overview
We provide contract drilling services to the international oil and gas industry with our global fleet of mobile offshore drilling units. Our business strategy focuses on a balanced, high-specification fleet of both floating and jackup rigs, and the deployment of our drilling rigs in established and emerging offshore oil and gas basins around the world.
We emphasize safe operations, environmental stewardship, social responsibility, and robust governance to sustain the superior performance and maximize stakeholder value achieved through our qualified and well-trained crews, the care of our surroundings and local communities, an effective management system, and a superior fleet. We also carefully manage rig operating costs through innovative systems and processes, including the use of data analytics and predictive maintenance technology.
As of the filing date of this Annual Report on Form 10-K, our fleet of 19 drilling rigs consisted of seven floaters and 12 jackups strategically deployed worldwide. We typically employ each drilling unit under an individual contract, and many contracts are awarded based upon a competitive bidding process.
Our 2020 financial and operating results from continuing operations include:
•operating revenues totaling $1.0 billion, a decrease of 26% from prior year;
•net loss attributable to Noble Corporation of $4.0 billion, or $15.86 per diluted share, which includes a $3.9 billion before-tax impairment charge recognized on 16 of our rigs and certain capital spare equipment; and
•net cash provided by operating activities totaling $273.2 million, an increase of 46% from prior year.
Demand for our services is highly competitive and, in significant part, a function of the worldwide demand for oil and gas and the global supply of mobile offshore drilling units. Since late 2014, the offshore drilling industry has experienced a severe and prolonged downturn stemming from the combination of an oversupply of competing drilling rigs that resulted from the new build rig influx of the 2010s, weak and volatile crude oil prices, and the advancement of onshore opportunities and technology. The Company entered 2020 cautiously optimistic with the prospects for the offshore drilling market continuing to improve; however, the combined effects of the pandemic and the steep decline in the demand for oil have resulted in significantly reduced global economic activity. These factors in concert led to heightened competition for opportunities to re-contract our rigs upon the expiration of existing contracts.
Recent Events
Emergence from Chapter 11. In connection with the Chapter 11 Cases (as defined below) and the Plan, on and prior to the Effective Date, Legacy Noble and certain of its subsidiaries effectuated certain restructuring transactions, pursuant to which Legacy Noble transferred to Noble substantially all of the subsidiaries, and other assets, of Legacy Noble. On the Effective Date, Legacy Noble successfully completed its financial restructuring and Legacy Noble and its debtor affiliates emerged from the Chapter 11 Cases. For additional information regarding the Chapter 11 Cases, see “—Chapter 11 Proceedings and Going Concern” below
As a result of the financial restructuring, Noble emerged from bankruptcy on the Effective Date with a substantially delevered balance sheet and less than $400.0 million of debt. Noble’s capital structure as of the Effective Date includes a $675.0 million revolving credit facility, of which $177.5 million is drawn as of March 10, 2021, and $216.0 million Second Lien Notes (as defined herein). On the Effective Date, Legacy Noble’s ordinary shares were cancelled and New Shares were issued to Legacy Noble’s former bondholders. Certain former bondholders and former equity holders of Legacy Noble were also issued warrants to purchase shares of the Company.
Paragon Matter. In August 2014, Legacy Noble completed the Spin-off through a pro rata distribution of all of the ordinary shares of its wholly-owned subsidiary, Paragon Offshore, to the holders of Legacy Noble’s ordinary shares. Paragon Offshore filed for protection under chapter 11 of the Bankruptcy Code in February 2016, and in connection with Paragon Offshore’s emergence from bankruptcy in July 2017, all claims it may have had against Legacy Noble were transferred to a litigation trust. In December 2017, a litigation trust filed fraudulent conveyance and related claims relating to the Spin-off in an action (the “Action”) against Legacy Noble and certain of its subsidiaries (the “Noble Defendants”), as well as certain of Legacy Noble’s and then current and former officers and directors (the “Individual Defendants”). The litigation trust sought total damages of approximately $2.6 billion and unspecified amounts against the Individual Defendants. On September 23, 2020, the Noble Defendants entered into a settlement agreement (the “Settlement Agreement”) with the litigation trust to fully and finally settle the disputes among them in the Action on the terms set forth in the Settlement Agreement and, subject to certain terms and conditions, to allow the litigation trust’s claims to proceed against the Individual Defendants in the Delaware Court. The Settlement Agreement further provided that it was a compromise settlement that is not in any respect, for any purpose, to be deemed or construed to be an express or implied admission of any liability or wrongdoing or otherwise. On October 9, 2020, the Bankruptcy Court (as defined below) entered an order approving the Debtors' (as defined below) entry into the Settlement Agreement, which also contemplated a potential global settlement including the Individual Defendants.
On February 3, 2021, the Noble Defendants, the Individual Defendants and the litigation trust entered into a global settlement. Pursuant to the global settlement, among other things, the Debtors made a $7.7 million payment to the litigation trust, and all claims brought against all
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defendants, including the Noble Defendants and Individual Defendants were settled and released. The global settlement was subject to approval by the Delaware Court, which approval was granted on February 24, 2021. See “Note 16— Commitments and Contingencies” to our consolidated financial statements included in Part II, Item 8 of this Annual Report on Form 10-K for more information.
Outlook
The offshore drilling industry remains highly competitive. We believe the convergence of events in 2020 and early 2021 have lengthened an already challenging and slow recovery in our industry. Despite these challenges and demand projections, we believe that oil and gas demand will rebalance and oil and gas will remain an important portion of the world’s energy mix. We expect that the return of stable oil demand and prices coupled with the continued attrition of rigs in the global offshore fleet will bring improved market conditions for our services.
Noble emerged from the Chapter 11 Cases with a high-specification fleet of 19 rigs, balanced across jackups and floaters. Our floating and jackup drilling fleet is among the youngest, most modern and versatile in the industry, with the majority of our rigs having been delivered since 2011, and is well positioned to compete as market dynamics improve. Our fleet consists predominately of technologically advanced units, equipped with sophisticated systems and components prepared to execute our customers’ increasingly complicated offshore drilling programs safely and with greater efficiency, contributing to an overall reduction of our carbon footprint. We remain committed to safely and efficiently serving the needs of our customers globally and we set several company safety records during 2020.
At December 31, 2020, we had a total contract drilling services backlog of approximately $1.6 billion, which includes a commitment of approximately 67 percent of available days for 2021. For additional information regarding our backlog, see “—Contract Drilling Services Backlog” below.
Chapter 11 Proceedings and Going Concern
On July 31, 2020 (the “Petition Date”), Legacy Noble and certain of its subsidiaries, including Finco, filed voluntary petitions in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”) seeking relief under chapter 11 of title 11 of the United States Code (the “Bankruptcy Code”). On September 4, 2020, the Debtors filed with the Bankruptcy Court the Joint Plan of Reorganization of Noble Corporation plc and its Debtor Affiliates, which was subsequently amended on October 8, 2020 and October 13, 2020 and modified on November 18, 2020 (as amended, modified or supplemented, the “Plan”), and the related disclosure statement (the “Disclosure Statement”). On September 24, 2020, six additional subsidiaries of Legacy Noble (together with Legacy Noble and its subsidiaries that filed on the Petition Date, as the context requires, the “Debtors”) filed voluntary petitions in the Bankruptcy Court. The chapter 11 proceedings were jointly administered under the caption Noble Corporation plc, et al. (Case No. 20-33826) (the “Chapter 11 Cases”). As a result of the filing of the Chapter 11 Cases, Legacy Noble’s Board of Directors determined to cancel Legacy Noble’s share ownership policy applicable to the officers and directors. Noble is currently considering an appropriate policy subsequent to its emergence from bankruptcy.
The filing of the Chapter 11 Cases constituted events of default that accelerated the Company’s obligations under the indentures governing our outstanding senior notes and under our 2017 Credit Facility (as defined herein). In addition, the unpaid principal and interest due under our then outstanding senior notes and 2017 Credit Facility became immediately due and payable. However, any efforts to enforce such payment obligations with respect to such senior notes and 2017 Credit Facility were automatically stayed as a result of the filing of the Chapter 11 Cases, and the creditors’ rights of enforcement were subject to the applicable provisions of the Bankruptcy Code. We elected not to make the semiannual interest payment due in respect of the Senior Notes due 2024 (the “2024 Notes”), which was due on July 15, 2020, and did not made any additional interest payments due on any senior notes through the Effective Date.
On the Petition Date, the Debtors entered into a Restructuring Support Agreement (together with all exhibits and schedules thereto, and as amended by the First Amendment thereto dated as of August 20, 2020, the “Restructuring Support Agreement”) with an ad hoc group of certain holders of approximately 70% of the aggregate outstanding principal amount of the Senior Notes due 2026 (the “Guaranteed Notes”) and an ad hoc group of certain holders of approximately 45% of the aggregate outstanding principal amount of our other then outstanding senior notes, taken as a whole (the “Legacy Notes”). Legacy Noble entered into a Backstop Commitment Agreement (the “Backstop Commitment Agreement”) with the backstop parties thereto (the “Backstop Parties”) on October 12, 2020, pursuant to which the issuance of the senior secured second lien notes (the “Second Lien Notes”) were fully backstopped by the Ad Hoc Guaranteed Group and the Ad Hoc Legacy Group (each as defined in the Restructuring Support Agreement). Participation in the rights offering of Second Lien Notes (the “Rights Offering”) was offered to the holders of the Guaranteed Notes and the Legacy Notes. On November 20, 2020, the Bankruptcy Court entered an order confirming the Plan. On the Effective Date, the Plan became effective in accordance with its terms and the Debtors emerged from the Chapter 11 Cases.
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On the Effective Date, and pursuant to the terms of the Plan, the Company:
•Appointed five new members to the Successor’s board of directors to replace all of the directors of the Predecessor, other than the director also serving as President and Chief Executive Officer, who was re-appointed pursuant to the Plan;
•Terminated and cancelled all common stock and equity-based awards of Legacy Noble that were outstanding immediately prior to the Effective Date;
•Transferred 31.7 million New Shares with a nominal value of $0.00001 per share to holders of the Guaranteed Notes in the cancellation of the Guaranteed Notes;
•Transferred 2.1 million New Shares, approximately 8.3 million seven-year warrants with Black-Scholes protection (the “Tranche 1 Warrants”) with an exercise price of $19.27 and approximately 8.3 million seven-year warrants with Black-Scholes protection (the “Tranche 2 Warrants”) with an exercise price of $23.13 to holders of the Legacy Notes in cancellation of the Legacy Notes;
•Issued approximately 7.7 million New Shares and Second Lien Notes to participants in the Rights Offering at an aggregate subscription price of $200 million;
•Issued approximately 5.6 million New Shares to the Backstop Parties as Holdback Securities (as defined in the Backstop Commitment Agreement);
•Issued approximately 1.7 million New Shares to the Backstop Parties in respect of their backstop commitment to subscribe for Unsubscribed Securities (as defined in the Backstop Commitment Agreement);
•Issued approximately 1.2 million New Shares to the Backstop Parties in connection with the payment of the Backstop Premiums (as defined in the Backstop Commitment Agreement);
•Issued 2.8 million five-year warrants with no Black-Sholes protection (the “Tranche 3 Warrants”) with an exercise price of $124.40 to the holders of Legacy Noble’s ordinary shares outstanding prior to the Effective Date;
•Entered into a senior secured revolving credit agreement (the “Exit Credit Agreement”) providing for a $675.0 million senior secured revolving credit facility (with a $67.5 million sublimit for the issuance of letters of credit thereunder) (the “Exit Credit Facility”);
•Entered into an exchange agreement with certain Backstop Parties which provided that, as soon as reasonably practicable after the Effective Date, the other parties to such agreement would deliver to the Company an aggregate of approximately 6.5 million New Shares issued pursuant to the Plan in exchange for the issuance of penny warrants to purchase up to approximately 6.5 million New Shares, with an exercise price of $0.01 per share (“Penny Warrants”) which were exchanged on a one-for-one basis for New Shares issued to certain initial holders of New Shares;
•Entered into an indenture governing the Second Lien Notes;
•Entered into a registration rights agreement with certain parties who received New Shares under the Plan (the “Equity Registration Rights Agreement”); and
•Entered into a registration rights agreement with certain parties who received Second Lien Notes under the Plan.
Management Incentive Plan. The Plan contemplated that on or after the Effective Date, (i) the Company would adopt a long-term incentive plan and authorize and reserve 7.7 million New Shares for issuance pursuant to equity incentive awards to be granted under such plan, and (ii) the initial awards under such plan would consist of at least 40% of such shares and be made as soon as practicable after the Effective Date on the terms and conditions as determined by Noble’s Board of Directors; provided that at least 40% of such initial awards would be in the form of time-based vesting awards vesting over a period of no shorter than three years and no longer than four years. As contemplated by the Plan, on February 18, 2021, the Company adopted a long-term incentive plan and authorized and reserved 7.7 million New Shares for issuance pursuant to equity incentive awards to be granted under such plan.
Sources of Cash for Plan Distribution. All cash required for payments made by the Company under the Plan on the Effective Date was obtained from cash on hand, proceeds of the Rights Offering, and proceeds of the Exit Credit Facility.
Going Concern. Legacy Noble performed the required assessments in conjunction with the filing of its Form 10-Q for the three months ended March 31, 2020 and determined, at that time, that substantial doubt about its ability to continue as a going concern existed. Subsequent to emergence from the Chapter 11 Cases, Noble performed a reassessment and concluded there was no longer substantial doubt regarding the Noble’s ability to continue as a going concern one year from the date of filing the Noble's Form 10-K for the year ended December 31, 2020. This was primarily due to the cancellation of Legacy Noble’s outstanding debt obligations and increased liquidity with the Exit Credit Agreement (as defined herein). Management’s assessment was based on the relevant conditions that were known and reasonably knowable at the issuance date and included the Noble’s post-emergence financial condition and liquidity sources, forecasted future cash flows, contractual obligations and commitments and other conditions that could adversely affect the Noble’s ability to meet its obligations through one year from the issuance date of the Form 10-K.
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Impairment
As more thoroughly described in Part II, Item 8, “Financial Statements and Supplementary Data, Note 6— Loss on Impairment” we evaluate our property and equipment for impairment whenever there are changes in facts that suggest that the value of the asset is not recoverable. An impairment loss is recognized when and to the extent that an asset's carrying value exceeds its estimated fair value. As part of this analysis, we make assumptions and estimates regarding future market conditions. To the extent actual results do not meet our estimated assumptions for a given rig or piece of equipment, we may take an impairment loss in the future.
During the years ended December 31, 2020, 2019 and 2018, we recognized non-cash, before-tax impairment charges of $3.9 billion, $615.3 million and $802.1 million, respectively, related to certain rigs and related capital spares. These impairments were driven by factors such as customer suspensions of drilling programs, contract cancellations, a further reduction in the number of new contract opportunities, capital spare equipment obsolescence, and our belief that a drilling unit is no longer marketable and is unlikely to return to service.
There can be no assurance that we will not have to take additional impairment charges in the future if current depressed market conditions persist, or that we will be able to return cold stacked rigs to service in the time frame and at the reactivation costs or at the dayrates that we projected. It is reasonably possible that the estimate of undiscounted cash flows may change in the near term, resulting in the need to write down the affected assets to their corresponding estimated fair values.
Contract Drilling Services Backlog
We maintain a backlog of commitments for contract drilling services. Our contract drilling services backlog reflects estimated future revenues attributable to signed drilling contracts. While backlog did not include any letters of intent as of December 31, 2020, in the past we have included in backlog certain letters of intent that we expect to result in binding drilling contracts.
We calculate backlog for any given unit and period by multiplying the full contractual operating dayrate for such unit by the number of days remaining in the period, and include certain assumptions based on the terms of certain contractual arrangements, discussed in the notes to the table below. For the four rigs contracted with Exxon Mobil Corporation (“ExxonMobil”) mentioned below, we utilize the current market rate, adjusted for a moderate discount rate, as described in footnote (3) to the backlog table below. The reported contract drilling services backlog does not include amounts representing revenues for mobilization, demobilization and contract preparation, which are not expected to be significant to our contract drilling services revenues, amounts constituting reimbursables from customers or amounts attributable to uncommitted option periods under drilling contracts or letters of intent.
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The table below presents the amount of our contract drilling services backlog and the percent of available operating days committed for the periods indicated:
Year Ending December 31, (1)
Total 2021 2022 2023 2024 2025 - 2027
(In thousands)
Contract Drilling Services Backlog
Floaters (2) (3)
$ 1,143,849  $ 433,614  $ 337,359  $ 130,603  $ 61,195  $ 181,078 
Jackups (4)
468,204  241,998  181,110  45,096  —  — 
Total $ 1,612,053  $ 675,612  $ 518,469  $ 175,699  $ 61,195  $ 181,078 
Percent of Available Days Committed (5)
Floaters (3)
84  % 65  % 24  % 14  % 14  %
Jackups 57  % 37  % 7  % —  % —  %
Total 67  % 47  % 13  % 5  % 5  %

(1)Represents a twelve-month period beginning January 1. Some of our drilling contracts provide customers with certain early termination rights and, in limited cases, those termination rights require minimal or no notice and minimal financial penalties.
(2)Two of our long-term drilling contracts with Royal Dutch Shell plc (“Shell”), the Noble Globetrotter I and Noble Globetrotter II, contain a dayrate adjustment mechanism that utilizes an average of market rates that match a set of distinct technical attributes and is subject to a modest discount, beginning on the fifth-year anniversary of the contract and continuing every six months thereafter. On December 12, 2016, we amended those drilling contracts with Shell. As a result of the amendments, each of the contracts now has a contractual dayrate floor of $275,000 per day. Once the dayrate adjustment mechanism becomes effective and following any idle periods, the dayrate for these rigs will not be lower than the higher of (i) the contractual dayrate floor or (ii) the market rate as calculated under the adjustment mechanism. The impact to contract backlog from these amendments has been reflected in the table above and the backlog calculation assumes that, after any idle period at the contractual stacking rate, each rig will work at its respective dayrate floor for the remaining contract term.
(3)Noble entered into a multi-year Commercial Enabling Agreement (the “CEA”) with ExxonMobil in February 2020. Under the CEA, dayrates earned by each rig will be updated at least twice per year to the prevailing market rate, subject to a scale-based discount and a performance bonus that appropriately aligns the interests of Noble and ExxonMobil. Under the CEA, the table above includes awarded and remaining term of nine and a half years related to the Noble Tom Madden, six months to each of the Noble Bob Douglas and Noble Sam Croft, and one year to the Noble Don Taylor. Under the CEA, ExxonMobil may reassign term among rigs. The aforementioned additional backlog included in the table above was estimated using the current market rate, adjusted for a moderate discount rate.
(4)In April 2020, we received notice from Saudi Arabian Oil Company (“Saudi Aramco”) to suspend operations on the Noble Scott Marks for a period of up to 12 months. Beginning in early May 2020, we idled the Noble Scott Marks at a rate of $0 per day. The impact to contract backlog has been reflected in the table above and the backlog calculation assumes that, upon completion of the suspension period, the rig will resume operations at the contracted dayrate for the remaining contract term.
(5)Percent of available days committed is calculated by dividing the total number of days our rigs are operating under contract for such period by the product of the number of our rigs and the number of calendar days in such period.
The amount of actual revenues earned and the actual periods during which revenues are earned may be materially different than the backlog amounts and backlog periods presented in the table above due to various factors, including, but not limited to, the impact of the COVID-19 pandemic and related mitigation efforts on the demand for oil, current oversupply of oil, shipyard and maintenance projects, unplanned downtime, the operation of market benchmarks for dayrate resets, achievement of bonuses, weather conditions, reduced standby or mobilization rates and other factors that result in applicable dayrates lower than the full contractual operating dayrate. In addition, amounts included in the backlog may change because drilling contracts may be varied or modified by mutual consent or customers may exercise early termination rights contained in some of our drilling contracts or decline to enter into a drilling contract after executing a letter of intent. As a result, our backlog as of any particular date may not be indicative of our actual operating results for the periods for which the backlog is calculated. See Part I, Item 1A, “Risk Factors—Risks Related to Our Business and Operations—Our current backlog of contract drilling revenue may not be ultimately realized.”
For the year ended December 31, 2020, ExxonMobil, Shell, Saudi Aramco and Equinor ASA represented approximately 44.2 percent, 26.3 percent, 17.0 percent and 3.6 percent of our backlog, respectively.
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Results of Operations
During 2020, the global mitigation efforts associated with preventing the spread of COVID-19 and production level disputes among OPEC+ members had significant adverse consequences for the financial condition of our customers, and uncertainty about the financial viability of offshore projects, resulting in contract delays, suspension and terminations as well as customers seeking to re-negotiate contracts to secure price reductions. Preliminary demand data compiled by the International Energy Agency (the “IEA”) indicates global liquid fuels consumption declined by 9 million barrels per day in 2020, the largest decline in IEA data since 1980. As a consequence, throughout 2020, we were under pressure to reduce dayrates on existing contracts and idle or suspend existing operations, and market dayrates for new contracts were lower compared to the end of 2019.
2020 Compared to 2019
Net loss from continuing operations attributable to Noble for the year ended December 31, 2020 was $4.0 billion, or $15.86 per diluted share, on operating revenues of $1.0 billion, compared to a net loss from continuing operations for the year ended December 31, 2019 of $696.8 million, or $2.79 per diluted share, on operating revenues of $1.3 billion.
As a result of Noble conducting substantially all of its business through Finco and its subsidiaries, the financial position and results of operations for Finco, and the reasons for material changes in the amount of revenue and expense items between December 31, 2020 and December 31, 2019, would be the same as the information presented below regarding Noble in all material respects, with the exception of operating income (loss). During the years ended December 31, 2020 and 2019, Finco's operating loss was $100.6 million and $138.8 million lower, respectively, than that of Noble. The operating loss difference is primarily a result of expenses related to ongoing litigation, administration, and Chapter 11 bankruptcy charges directly attributable to Noble for operations support and stewardship-related services. In the years ended December 31, 2020 and 2019, Noble recorded a $15.0 million gain and a $100.0 million expense related to ongoing litigation, which was not recognized by Finco.
Key Operating Metrics
Operating results for our contract drilling services segment are dependent on three primary metrics: operating days, dayrates and operating costs. We also track rig utilization, which is a function of operating days and the number of rigs in our fleet. For more information on operating costs, see “—Contract Drilling Services” below.
The following table presents the average rig utilization, operating days and average dayrates for our rig fleet for the years ended December 31, 2020 and 2019:
Average Rig Utilization (1)
Operating Days (2)
Average Dayrates (2)
December 31, December 31, December 31,
2020 2019 2020 2019 % Change 2020 2019 % Change
Jackups 71  % 93  % 3,147  4,054  (22) % $ 132,722  $ 128,002  4  %
Floaters 60  % 62  % 2,354  2,729  (14) % 208,723  266,442  (3) (22) %
Total 66  % 78  % 5,501  6,783  (19) % $ 165,276  $ 183,706  (3) (10) %
(1)We define utilization for a specific period as the total number of days our rigs are operating under contract, divided by the product of the total number of our rigs, including cold stacked rigs, and the number of calendar days in such period. Information reflects our policy of reporting on the basis of the number of available rigs in our fleet, excluding newbuild rigs under construction.
(2)An operating day is defined as a calendar day during which a rig operated under a drilling contract.  We define average dayrates as revenue from contract drilling services earned per operating day. Operating days include standby days which typically have a lower dayrate. 
(3)Includes the impact of the Noble Bully II contract buyout during the year ended December 31, 2019. Exclusive of this item, the average dayrate for the year ended December 31, 2019 would have been $205,304 for floaters and $159,106 for total rigs.
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Contract Drilling Services
The following table presents the operating results for our contract drilling services segment for the years ended December 31, 2020 and 2019 (dollars in thousands):
Year Ended December 31, Change
2020 2019 $ %
Operating revenues:
Contract drilling services $ 909,236  $ 1,246,058  $ (336,822) (27) %
Reimbursables and other (1)
55,036  59,380  (4,344) (7) %
$ 964,272  $ 1,305,438  $ (341,166) (26) %
Operating costs and expenses:
Contract drilling services $ 567,487  $ 698,343  $ (130,856) (19) %
Reimbursables (1)
48,188  49,061  (873) (2) %
Depreciation and amortization 374,129  440,221  (66,092) (15) %
General and administrative 121,196  168,792  (47,596) (28) %
Loss on impairment 3,915,408  615,294  $ 3,300,114  536  %
5,026,408  1,971,711  3,054,697  155  %
Operating loss $ (4,062,136) $ (666,273) $ (3,395,863) 510  %
(1)We record reimbursements from customers for out-of-pocket expenses as operating revenues and the related direct costs as operating expenses. Changes in the amount of these reimbursables generally do not have a material effect on our financial position, results of operations or cash flows.
Operating Revenues. The $336.8 million decrease in contract drilling services revenues for the year ended December 31, 2020 as compared to the same period of 2019 was composed of a $330.1 million decrease due to a decreased number of operating days and a $6.7 million decrease from lower dayrates. The revenue decrease was due to decreases in both floater fleet revenues and jackup fleet revenues of $235.8 million and $101.0 million, respectively.
The $235.8 million revenue decrease in our floater fleet for the year ended December 31, 2020 is attributable to a $276.0 million decrease mainly due to fewer operating days on two rigs, the Noble Bully II, which completed its contract in late 2019, and the Noble Clyde Boudreaux, which completed its contract in the middle of 2020. These decreases were partially offset by an increase of $30.4 million primarily due to the Noble Sam Croft returning to service following its reactivation near the end of the three months ended March 31, 2019 and the Noble Don Taylor, which had time between contracts in 2019 related to contract preparation. Floater fleet revenue was also impacted by a decline in dayrates of $32.2 million as the legacy contract for the Noble Don Taylor and the legacy assignment for the Noble Globetrotter I were completed in early 2019. These revenue reductions were partially offset by a $42.0 million increase in revenues associated with an increase in dayrates on various other rigs, including a $17.1 million increase in revenue on the Noble Sam Croft as a result of starting a new contract at a higher dayrate in 2020.
The $101.0 million revenue decrease in our jackup fleet for the year ended December 31, 2020 is attributable to a $118.5 million decrease due to fewer operating days on the Noble Regina Allen mainly due to the rig relocating to Trinidad & Tobago from Canada to start a new contract, the Noble Sam Hartley which had downtime in between contracts in 2020 during which it was warm-stacked, the Noble Scott Marks contract being suspended in May 2020 for a period of up to 12 months, the Noble Houston Colbert which was warm-stacked for five months in 2019 as compared to eight months in 2020, the Noble Joe Beall which completed its final contract in early 2020 and was subsequently sold later in 2020, and the Noble Sam Turner and the Noble Hans Deul which were warm-stacked in early 2020 after their contract completions. This decrease was partially offset by an increase in revenue of $34.0 million primarily due to increased operating days on the Noble Tom Prosser, as well as the Noble Johnny Whitstine and the Noble Joe Knight being placed into service in 2019. Adjusting for the effect of operating days on the average dayrates, there was also a net decrease of revenue of $16.5 million due to a decline in dayrates across the jackup fleet.
Operating Costs and Expenses. Contract drilling services costs decreased $130.9 million for the year ended December 31, 2020 as compared to the same period of 2019. The primary cost decreases were due to: (i) a $52.5 million decrease due to rigs that had fewer operating days or were idled, (ii) a $37.3 million decrease across our active fleet in 2020 compared to 2019 mainly due to reductions in repair and maintenance activity, transportation costs and personnel-related expenses, (iii) a $35.6 million decrease due to the retirement of the Noble Bully I, Noble Bully II, Noble Danny Adkins, Noble Joe Beall, Noble Jim Day and Noble Paul Romano during 2020 and (iv) a $23.4 million decrease
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in overhead across our fleet from lower personnel-related expenses in 2020 compared to 2019. These decreases were partially offset by: (i) a $9.9 million increase in expenses due to the Noble Joe Knight commencing operations in September 2019. Due to the effects of the ongoing COVID-19 pandemic, we experienced a $9.8 million increase primarily in labor expenses across our fleet in 2020.
Depreciation and amortization decreased $66.1 million for the year ended December 31, 2020 as compared to the same period of 2019. The decline was due to the effect of rig impairments recorded during 2019 and 2020.
Loss on Impairments. We recorded a loss on impairment of $3.9 billion for the year ended December 31, 2020 as compared to a loss on impairment of $615.3 million for the same period of 2019. We impaired the carrying value to estimated fair value for seven floaters and nine jackups and certain capital spare equipment during 2020 and two floaters and certain capital spare equipment during 2019. We impaired the carrying value to estimated fair value for the Noble Bully II during 2019, of which $265.0 million was attributable to our former joint venture partner. For additional information, see Part II, Item 8, “Financial Statements and Supplementary Data, Note 6— Loss on Impairment.”
Other Income and Expenses
General and Administrative Expenses. General and administrative expenses decreased $47.6 million during the year ended December 31, 2020 as compared to the same period of 2019, primarily as a result of a reduction to Noble’s ongoing litigation charge of $53.5 million, partially offset by an increase in Finco’s litigation charge of $7.5 million.
Pre-Petition Charges. Noble incurred $14.4 million of pre-petition charges during the year ended December 31, 2020 as compared to no charges for the same period of 2019. These costs relate to attorneys’ and financial advisors’ fees and other professional fees incurred in connection with the Chapter 11 Cases, prior to the Petition Date.
Reorganization Items, Net. Noble incurred net charges of $23.9 million for reorganization items during the year ended December 31, 2020 as compared to no charges for the same period of 2019. Finco incurred net charges of $50.8 million for reorganization items during the year ended December 31, 2020 as compared to no charges for the same period of 2019. These costs relate to attorneys’ and financial advisors’ fees, write-off of deferred financing costs and debt discounts, revisions of estimated claims, adjustments to legal contingencies and other professional fees incurred in connection with the Chapter 11 Cases.
Interest Expense. Interest expense decreased $114.8 million during the year ended December 31, 2020 as compared to the same period of 2019. This decrease was primarily due to the Bankruptcy Court ordering a stay on all interest expense starting on the Petition Date; therefore, we did not incur any interest expense after July 31, 2020 and the retirement of our 2015 Credit Facility in December 2019. For additional information, see Part II, Item 8, “Financial Statements and Supplementary Data, Note 7— Debt.”
Income Tax Benefit. Our income tax benefit increased by $221.9 million for the year ended December 31, 2020 as compared to the same period of 2019.
Significant items included in the income tax benefit in the same period of 2019 are as follows:
•Tax benefits related to the following:
•release of reserves related to the closure of the 2010-2011 US tax audit of $33.7 million; and
•reversal of UK valuation allowance of $19.2 million.
•Tax expense related to an internal restructuring of $36.8 million.
Significant items included in the income tax benefit in the current period of 2020 are as follows:
•Tax benefits related to the following:
•gross benefit of $192.4 million related to the impairment of rigs and certain capital spares partially offset by a corresponding increase in valuation allowance of $92.7 million;
•the application of the CARES Act of $39.0 million;
•release of reserves related to the closure of the 2012- 2017 US tax audit of $111.9 million; and
•tax impact of an internal restructuring net of resulting adjustment to the valuation allowance of $17.9 million.
•Tax expenses related to the following:
•a 2019 US return-to-provision adjustment and resulting adjustment to the valuation allowance of $21.2 million;
•an increase in UK valuation allowance of $31.1 million; and
•an increase in non-US tax reserves of $7.8 million.
Excluding the tax impact of the significant items as outlined above and other immaterial items, our income tax benefit increased by $25.0 million. This increase is primarily a result of an increase in US taxable losses partially offset by non-US recurring tax expense.
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2019 Compared to 2018
    Information related to a comparison of our results of operations for our fiscal year ended December 31, 2019 compared to our fiscal year ended December 31, 2018 is included in Part II, Item 7, “Management's Discussion and Analysis of Financial Condition and Results of Operations” of our Annual Report on Form 10-K for the fiscal year ended December 31, 2019, filed with the SEC on February 20, 2020.
Liquidity and Capital Resources
As a result of the financial restructuring through the Chapter 11 Cases, Noble emerged with a new $675.0 million revolving credit facility and $216.0 million of Second Lien Notes (as defined herein). At emergence, Legacy Noble’s ordinary shares were cancelled and New Shares were issued to Legacy Noble’s former bondholders. Certain former bondholders and former equity holders of Legacy Noble were also issued warrants to purchase shares of the Company.
Post-emergence Debt
Senior Secured Exit Revolving Credit Facility
On the Effective Date, Finco and Noble International Finance Company (“NIFCO”) entered into the Exit Credit Agreement providing for the $675.0 million Exit Credit Facility and canceled all debt that existed immediately prior to the Effective Date. The Exit Credit Facility matures on July 31, 2025. Subject to the satisfaction of certain conditions, Finco may from time to time designate one or more of Finco’s other wholly-owned subsidiaries as additional borrowers under the Exit Credit Agreement (collectively with Finco and NIFCO, the “Borrowers”). As of the Effective Date, $177.5 million of loans were outstanding, and $8.8 million of letters of credit were issued, under the Exit Credit Facility.
All obligations of the Borrowers under the Exit Credit Agreement, certain cash management obligations and certain swap obligations are unconditionally guaranteed, on a joint and several basis, by Finco and certain of its direct and indirect subsidiaries (collectively with the Borrowers, the “Credit Parties”), including a guarantee by each Borrower of the obligations of each other Borrower under the Exit Credit Agreement. All such obligations, including the guarantees of the Exit Credit Facility, are secured by senior priority liens on substantially all assets of, and the equity interests in, each Credit Party, including all of the rigs owned by the Company as of the Effective Date or acquired thereafter and certain assets related thereto, in each case, subject to certain exceptions and limitations described in the Exit Credit Agreement.
The loans outstanding under the Exit Credit Facility bear interest at a rate per annum equal to the applicable margin plus, at Finco’s option, either: (i) the reserve-adjusted LIBOR or (ii) a base rate, determined as the greatest of (x) the prime loan rate as published in the Wall Street Journal, (y) the federal funds effective rate plus 1⁄2 of 1%, and (z) the reserve-adjusted one-month LIBOR plus 1%. The applicable margin is initially 4.75% per annum for LIBOR loans and 3.75% per annum for base rate loans and will be increased by 50 basis points after July 31, 2024, and may be increased by an additional 50 basis points under certain conditions described in the Exit Credit Agreement.
The Borrowers are required to pay a quarterly commitment fee to each lender under the Exit Credit Agreement, which accrues at a rate per annum equal to 0.50% on the average daily unused portion of such lender’s commitments under the Exit Credit Facility. The Borrowers are also required to pay customary letter of credit and fronting fees.
Borrowings under the Exit Credit Agreement may be used for working capital and other general corporate purposes. Availability of borrowings under the Exit Credit Agreement is subject to the satisfaction of certain conditions, including restrictions on borrowings if, after giving effect to any such borrowings and the application of the proceeds thereof, (i) the aggregate amount of Available Cash (as defined in the Exit Credit Agreement) would exceed $100 million, (ii) the Consolidated First Lien Net Leverage Ratio (as defined in the Exit Credit Agreement) would be greater than 5.50 to 1.00 and the aggregate principal amount outstanding under the Exit Credit Facility would exceed $610 million, or (iii) the Asset Coverage Ratio (as described below) would be less than 2.00 to 1.00.
Mandatory prepayments and, under certain circumstances, commitment reductions are required under the Exit Credit Facility in connection with (i) certain asset sales, asset swaps and events of loss (subject to reinvestment rights if no event of default exists) and (ii) certain debt issuances. Available Cash in excess of $150 million is also required to be applied periodically to prepay loans (without a commitment reduction). The loans under the Exit Credit Facility may be voluntarily prepaid, and the commitments thereunder voluntarily terminated or reduced, by the Borrowers at any time without premium or penalty, other than customary breakage costs.
The Exit Credit Agreement obligates Finco and its restricted subsidiaries to comply with the following financial maintenance covenants:
•as of the last day of each fiscal quarter in 2021, Adjusted EBITDA (as defined in the Exit Credit Agreement) is not permitted to be lower than (i) $70 million for the four fiscal quarter period ending March 31, 2021, (ii) $40 million for the four fiscal quarter period ending June 30, 2021 and (iii) $25 million for the four fiscal quarter periods ending on each of September 30, 2021 and December 31, 2021;
•as of the last day of each fiscal quarter ending on or after March 31, 2022, the ratio of Adjusted EBITDA to Cash Interest Expense (as defined in the Exit Credit Agreement) is not permitted to be less than (i) 2.00 to 1.00 for each four fiscal quarter
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period ending on or after March 31, 2022 until June 30, 2024, and (ii) 2.25 to 1.00 for each four fiscal quarter period ending thereafter; and
•for each fiscal quarter ending on or after June 30, 2021, the ratio of (x) Asset Coverage Aggregate Rig Value (as defined in the Exit Credit Agreement) to (y) the aggregate principal amount of loans and letters of credit outstanding under the Exit Credit Facility (the “Asset Coverage Ratio”) as of the last day of any such fiscal quarter is not permitted to be less than 2.00 to 1.00.
The Exit Credit Facility contains affirmative and negative covenants, representations and warranties and events of default that the Company considers customary for facilities of this type.
Second Lien Notes Indenture
On the Effective Date, pursuant to the Backstop Commitment Agreement and in accordance with the Plan, Noble and Finco consummated the Rights Offering of Second Lien Notes and associated New Shares at an aggregate subscription price of $200 million.
On the Effective Date, Finco issued an aggregate principal amount of $216 million of Second Lien Notes, which includes the aggregate subscription price of $200.0 million plus a backstop fee of $16.0 million which was paid in kind. The Second Lien Notes mature on February 15, 2028.The Second Lien Notes are fully and unconditionally guaranteed, jointly and severally, on a senior secured second-priority basis, by the direct and indirect subsidiaries of Finco that are Credit Parties under the Exit Credit Facility. The Second Lien Notes and such guarantees are secured by senior priority liens on the assets subject to liens securing the Exit Credit Facility, including the equity interests in Finco and each guarantor of the Second Lien Notes, all of the rigs owned by the Company as of the Effective Date or acquired thereafter, certain assets related thereto, and substantially all other assets of Finco and such guarantors, in each case, subject to certain exceptions and limitations.
Interest on the Second Lien Notes accrues, at Finco’s option, at a rate of: (i) 11% per annum, payable in cash; (ii) 13% per annum, with 50% of such interest to be payable in cash and 50% of such interest to be payable by issuing additional Second Lien Notes (“PIK Notes”); or (iii) 15% per annum, with the entirety of such interest to be payable by issuing PIK Notes. Finco shall pay interest semi-annually in arrears on February 15 and August 15 of each year, commencing August 15, 2021.
On or after February 15, 2024, Finco may redeem all or part of the Second Lien Notes at fixed redemption prices (expressed as percentages of the principal amount), plus accrued and unpaid interest, if any, to, but excluding, the redemption date. Finco may also redeem the Second Lien Notes, in whole or in part, at any time and from time to time on or before February 14, 2025 at a redemption price equal to 106% of the principal amount plus accrued and unpaid interest, if any, to, but excluding, the applicable redemption date, plus a “make-whole” premium. Notwithstanding the foregoing, if a Change of Control (as defined in the Second Lien Notes Indenture) occurs prior to (but not including) February 15, 2024, then, within 120 days of such Change of Control, Finco may elect to purchase all remaining outstanding Second Lien Notes at a redemption price equal to 106% of the principal amount, plus accrued and unpaid interest, if any, to, but excluding, the applicable redemption date.
The Second Lien Notes contain covenants and events of default that the Company considers customary for notes of this type.
Sources and Uses of Cash
Our principal sources of capital in 2020 were cash generated from operating activities, funding from our 2017 Credit Facility and the CARES Act. Cash on hand during 2020 was primarily used for the following:
•normal recurring operating expenses;
•fees and expenses related to the Chapter 11 Cases; and
•capital expenditures.
Our currently anticipated cash flow needs, both in the short-term and long-term, may include the following:
•normal recurring operating expenses;
•planned and discretionary capital expenditures; and
•repayments of debt and interest.
We currently expect to fund these cash flow needs with cash generated by our operations, cash on hand, borrowings under our Exit Credit Facility and potential issuances of equity or long-term debt.
On March 27, 2020, the 45th President of the United States signed the CARES Act into law. The CARES Act makes significant changes to various areas of US federal income tax law by, among other things, allowing a five-year carryback period for 2018, 2019 and 2020 NOLs, accelerating the realization of remaining alternative minimum tax credits, and increasing the interest expense limitation under Section 163(j) for years 2019 and 2020. The Company recognized an income tax benefit of $39.0 million as a result of the application of the CARES Act in its 2020 financial statements. Such $39.0 million tax benefit was comprised primarily of a current income tax receivable of $151.4 million, partially offset by non-cash deferred tax expense of $112.4 million related to NOL utilization. As of December 31, 2020, we had
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received $134.0 million of the income tax receivable related to the CARES Act, along with an additional receipt of $4.4 million of related interest.
Net cash provided by operating activities was $273.2 million for the year ended December 31, 2020 as compared to $186.8 million for the year ended December 31, 2019. The increase in net cash provided by operating activities for the year ended December 31, 2020 was primarily attributable to $151.2 million in tax refunds received offset by a reduction in cash flows from operating activity. We had working capital of $383.9 million and negative working capital of $94.8 million at December 31, 2020 and December 31, 2019, respectively.
Net cash used in investing activities for the year ended December 31, 2020 was $121.5 million as compared to $256.0 million for the year ended December 31, 2019. The variance primarily relates to the purchase and preparation of the Noble Joe Knight and the preparation of the Noble Johnny Whitstine to commence operations for their contracts in the fourth quarter and the second quarter of 2019, respectively.
Net cash provided by financing activities for the year ended December 31, 2020 was $107.4 million as compared to net cash used in financing activities of $200.7 million for the year ended December 31, 2019. The variance primarily relates to higher net borrowings of $108.9 million in the current period as compared to net repayments of only $65.0 million in the year ended December 31, 2019 and the $106.7 million purchase of Shell's non-controlling interest in the Bully I and Bully II joint ventures in the year ended December 31, 2019.
In March 2019, we completed cash tender offers for our Senior Notes due 2020 (the “2020 Notes”), our Senior Notes due 2021 (the “2021 Notes”), our Senior Notes due 2022 (the “2022 Notes”)and the 2024 Notes. Pursuant to such tender offers, we purchased $440.9 million aggregate principal amount of these senior notes for $400.0 million, plus accrued interest, using borrowings under the 2015 Credit Facility (as defined herein) and cash on hand.
At December 31, 2020, we had a total contract drilling services backlog of approximately $1.6 billion, which includes a commitment of 67.0 percent of available days for 2021. For additional information regarding our backlog, see “—Contract Drilling Services Backlog.”
Capital Expenditures
Capital expenditures totaled $148.2 million, $306.4 million and $281.3 million for the years ended December 31, 2020, 2019 and 2018, respectively. Capital expenditures during 2020 consisted of the following:
•$65.8 million for sustaining capital;
•$23.9 million in major projects, including subsea and other related projects; and
•$58.5 million for rebillable capital modifications.
Our total capital expenditure estimate for 2021 is expected to range between $170.0 million and $190.0 million, of which approximately $80.0 to $90.0 million is currently anticipated to be spent for sustaining capital.
From time to time we consider possible projects that would require expenditures that are not included in our capital budget, and such unbudgeted expenditures could be significant. In addition, while liquidity and preservation of capital remains our top priority, we will continue to evaluate acquisitions of drilling units from time to time.
Pre-emergence Debt
2017 Credit Facility
In December 2017, Noble Cayman Limited, a Cayman Islands company and a wholly-owned indirect subsidiary of Finco; Noble International Finance Company, a Cayman Islands company and a wholly-owned indirect subsidiary of Finco; and Noble Holding UK Limited, a company incorporated under the laws of England and Wales and a wholly-owned direct subsidiary of Legacy Noble (“NHUK”), as parent guarantor, entered into a senior unsecured credit agreement (as amended, the “2017 Credit Facility”). In July 2019, we executed a first amendment to our 2017 Credit Facility, which, among other things, reduced the maximum aggregate amount of commitments thereunder from $1.5 billion to $1.3 billion. As a result of such reduction in the maximum aggregate amount of commitments, we recognized a net loss of approximately $0.7 million in the year ended December 31, 2019.
Prior to the filing of the Chapter 11 Cases, the 2017 Credit Facility was scheduled to mature in January 2023. Borrowings were available for working capital and other general corporate purposes. The 2017 Credit Facility provided for a letter of credit sub-facility in the amount of $15.0 million, with the ability to increase such amount up to $500.0 million with the approval of the lenders. The 2017 Credit Facility had provisions that varied the applicable interest rates for borrowings based upon our debt ratings. Borrowings under the 2017 Credit Facility bore interest at LIBOR plus an applicable margin. NHUK guaranteed the obligations of the borrowers under the 2017 Credit Facility. In addition, certain indirect subsidiaries of Legacy Noble that owned rigs were guarantors under the 2017 Credit Facility.
In April 2020, we borrowed $100.0 million under the 2017 Credit Facility to pay down our indebtedness under the Seller Loans (as defined herein) as further described below. At December 31, 2020, we had $545.0 million of borrowings outstanding under the 2017 Credit
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Facility. At December 31, 2020, we had $8.8 million of letters of credit issued under the 2017 Credit Facility and an additional $6.0 million in letters of credit and surety bonds issued under unsecured or cash collateralized bilateral arrangements.
The filing of the Chapter 11 Cases constituted events of default that accelerated the Company’s obligations under the indentures governing our outstanding senior notes and under our 2017 Credit Facility. In addition, the unpaid principal and interest due under our indentures and the 2017 Credit Facility became immediately due and payable. However, any efforts to enforce such payment obligations with respect to our senior notes and 2017 Credit Facility were automatically stayed as a result of the filing of the Chapter 11 Cases, and the creditors’ rights of enforcement were subject to the applicable provisions of the Bankruptcy Code. See “Note 1— Organization and Basis of Presentation” to our consolidated financial statements for additional information.
On the Effective Date, all outstanding obligations under the 2017 Credit Facility were terminated and the holders of claims under the 2017 Credit Facility had such obligations refinanced through the Exit Credit Facility. On the Effective Date, all liens and security interests granted to secure such obligations were terminated and are of no further force and effect.
2015 Credit Facility
Effective January 2018, in connection with entering into the 2017 Credit Facility, we amended our $300.0 million senior unsecured credit facility that would have matured in January 2020 and was guaranteed by our indirect, wholly-owned subsidiaries, Noble Holding (U.S.) LLC and Noble Holding International Limited (“NHIL”), a finance subsidiary of Finco, (as amended, the “2015 Credit Facility”). As a result of the 2015 Credit Facility's reduction in the aggregate principal amount of commitments, we recognized a net loss of approximately $2.3 million in the year ended December 31, 2018. On December 20, 2019, we repaid $300.0 million of outstanding borrowings and terminated the 2015 Credit Facility.
Seller Loans
In February 2019, we purchased the Noble Joe Knight for $83.8 million with a $53.6 million seller-financed secured loan (the “2019 Seller Loan”). The 2019 Seller Loan had a term of four years and required a 5% principal payment at the end of the third year with the remaining 95% of the principal due at the end of the term. The 2019 Seller Loan bore a cash interest rate of 4.25% and the equivalent of a 1.25% interest rate paid-in-kind over the four-year term of the 2019 Seller Loan. Based on the terms of the 2019 Seller Loan, the 1.25% paid-in-kind interest rate was accelerated into the first year, resulting in an overall first year interest rate of 8.91%, of which only 4.25% was payable in cash. Thereafter, the paid-in-kind interest ended and the cash interest rate of 4.25% was payable for the remainder of the term.
In September 2018, we purchased the Noble Johnny Whitstine for $93.8 million with a $60.0 million seller-financed secured loan (the “2018 Seller Loan” and, together with the 2019 Seller Loan, the “Seller Loans”). The 2018 Seller Loan had a term of four years and required a 5% principal payment at the end of the third year with the remaining 95% of the principal due at the end of the term. The 2018 Seller Loan bore a cash interest rate of 4.25% and the equivalent of a 1.25% interest rate paid-in-kind over the four-year term of the 2018 Seller Loan. Based on the terms of the 2018 Seller Loan, the 1.25% paid-in-kind interest rate was accelerated into the first year, resulting in an overall first year interest rate of 8.91%, of which only 4.25% was payable in cash. Thereafter, the paid-in-kind interest ended and the cash interest rate of 4.25% was payable for the remainder of the term.
Both of the Seller Loans were guaranteed by Finco and each was secured by a mortgage on the applicable rig and by the pledge of the shares of the applicable single-purpose entity that owned the relevant rig. Each Seller Loan contained a debt to total capitalization ratio requirement that such ratio not exceed 0.55 at the end of each fiscal quarter, a $300.0 million minimum liquidity financial covenant and an asset and revenue covenant substantially similar to the Guaranteed Notes, as well as other covenants and provisions customarily found in secured transactions, including a cross default provision. Each Seller Loan required immediate repayment on the occurrence of certain events, including the termination of the drilling contract associated with the relevant rig or circumstances in connection with a material adverse effect.
In April 2020, the Company agreed with the lender under the Seller Loans to pay off 85% of the outstanding principal amount of the Seller Loans in exchange for a discount to the outstanding loan balance. On April 20, 2020, the Company made a payment of $48.1 million under the 2019 Seller Loan and $53.6 million under the 2018 Seller Loan, and, upon the lender’s receipt of such payment, interest ceased accruing, and the financial covenants set forth in the agreements relating to the Seller Loans ceased to apply. On July 20, 2020, at the conclusion of the 90-day period following the payment date, all outstanding amounts were reduced to zero, all security was released, and the Seller Loans were terminated.
As a result of the early repayment of the Seller Loans and the conclusion of the 90-day period following the payment date, we recognized gains of approximately $17.3 million in the year ended December 31, 2020.
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Senior Notes
In March 2019, we completed cash tender offers for the 2020 Notes, the 2021 Notes, the 2022 Notes, and the 2024 Notes. Pursuant to such tender offers, we purchased $440.9 million aggregate principal amount of these senior notes for $400.0 million, plus accrued interest, using cash on hand and borrowings under the 2015 Credit Facility. As a result of these transactions, we recognized a net gain of approximately $31.3 million.
On the Effective Date, in accordance with the Plan, all outstanding obligations under our senior notes were cancelled and the indentures governing such obligations were cancelled, except to the limited extent expressly set forth in the Plan.
Share Capital
The declaration and payment of dividends required the authorization of the Board of Directors of Legacy Noble, provided that such dividends on issued share capital may be paid only out of Legacy Noble’s “distributable reserves” on its statutory balance sheet in accordance with UK law. Therefore, Legacy Noble was not permitted to pay dividends out of share capital, which includes share premium. Legacy Noble had not paid dividends since the third quarter of 2016. The payment of future dividends will depend on our results of operations, financial condition, cash requirements, future business prospects, contractual and indenture restrictions and other factors deemed relevant by our Board of Directors; however, at this time, we do not expect to pay any dividends in the foreseeable future.
At Legacy Noble’s 2020 Annual General Meeting, Legacy Noble’s shareholders authorized its Board of Directors to increase share capital through the issuance of up to approximately 8.7 million ordinary shares (at then current nominal value of $0.01 per share). That authority to allot shares has expired on the Effective Date. Other than shares issued to Legacy Noble’s directors under the Noble Corporation 2017 Director Omnibus Plan, the authority was not used to allot shares during the year ended December 31, 2020. Pursuant to the Memorandum of Association of Noble Corporation, the share capital of Noble is $6,000 divided into 500,000,000 ordinary shares of a par value of $0.00001 each and 100,000,000 shares of a par value of $0.00001, each of such class or classes having the rights as the Board may determine from time to time.
In accordance with the Plan, all agreements, instruments and other documents evidencing, relating to or otherwise connected with any of Legacy Noble’s equity interests outstanding prior to the Effective Date, including all equity-based awards, were cancelled and all such equity interests have no further force or effect after the Effective Date. Pursuant to the Plan, the holders of Legacy Noble’s ordinary shares, par value $0.01 per share, outstanding prior to the Effective Date received their pro rata share of the Tranche 3 Warrants to acquire New Shares.
Share Repurchases
Under UK law, Legacy Noble was only permitted to purchase its own shares by way of an “off-market purchase” in a plan approved by shareholders. We did not have shareholder authority to repurchase shares of Legacy Noble and there is currently no share repurchase plan in place for the Successor. During the years ended December 31, 2020, 2019 and 2018, we did not repurchase any of our shares.
Summary of Contractual Cash Obligations and Commitments
The following table summarizes our contractual cash obligations and commitments (in thousands):
    Payments Due by Period  
For the Years Ending December 31,
Total 2021 2022 2023 2024 2025 Thereafter Other
Contractual Cash Obligations
Debt obligations (1)
$ 3,997,926  $ 3,997,926  $ —  $ —  $ —  $ —  $ —  $ — 
Interest payments (1)
110,301  110,301  —  —  —  —  —  — 
Operating leases 42,040  8,594  5,545  3,567  3,629  3,687  17,018  — 
Pension plan contributions 140,046  19,390  11,791  12,375  12,663  13,200  70,627  — 
Tax reserves (2)
42,501  —  —  —  —  —  —  42,501 
Total contractual cash obligations
$ 4,332,814  $ 4,136,211  $ 17,336  $ 15,942  $ 16,292  $ 16,887  $ 87,645  $ 42,501 
(1)    Debt obligations and interest payments are included in “Liabilities subject to compromise.” Since the Petition Date, the Company operated as a debtor-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with provisions of the Bankruptcy Code. On the Effective Date, the Plan became effective in accordance with its terms and the Debtors emerged from the Chapter 11 Cases. See Part II, Item 8, “Financial Statements and Supplementary Data, Note 2— Chapter 11 Proceedings.”
(2)    Tax reserves are included in “Other” due to the difficulty in making reasonably reliable estimates of the timing of cash settlements to taxing authorities. See Part II, Item 8, “Financial Statements and Supplementary Data, Note 12— Income Taxes.”
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At December 31, 2020, we had other commitments that we are contractually obligated to fulfill with cash if the obligations are called. These obligations include letters of credit that guarantee our performance as it relates to our drilling contracts, tax and other obligations in various jurisdictions. These letters of credit obligations are not normally called, as we typically comply with the underlying performance requirement.
The following table summarizes our other commercial commitments at December 31, 2020 (in thousands):
    Amount of Commitment Expiration Per Period
Total 2021 2022 2023 2024 2025 Thereafter
Total letters of credit and commercial
commitments 		$ 14,840  $ 9,184  $ —  $ —  $ —  $ —  $ 5,656 
Guarantees of Registered Securities
NHIL is a finance subsidiary of Finco and prior to our emergence from the Chapter 11 Cases on the Effective Date, had issued the following registered securities, which, together with the indentures governing such registered securities, were cancelled on the Effective Date in accordance with the Plan: the 2020 Notes, the 2021 Notes, the 2022 Notes, the 2024 Notes, the Senior Notes due 2025, the Senior Notes due 2040, the Senior Notes due 2041, the Senior Notes due 2042 and the Senior Notes due 2045. Finco had fully and unconditionally guaranteed these registered securities and no other subsidiary of Finco had guaranteed these registered securities. Due to this fact pattern, separate financial information about NHIL and Finco will not be disclosed.
Critical Accounting Policies
We consider the following to be our critical accounting policies and estimates since they are very important to the understanding of our financial condition and results and require our most subjective and complex judgments. We have discussed the development, selection and disclosure of such policies and estimates with the Audit Committee of our Board of Directors. For a discussion of our significant accounting policies, refer to Part II, Item 8, “Financial Statements and Supplementary Data, Note 1— Organization and Significant Accounting Policies.”
We prepare our consolidated financial statements in accordance with accounting principles generally accepted in the United States (“GAAP”), which require us to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosures of contingent assets and liabilities. These estimates require significant judgments and assumptions. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying amounts of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates.
Principles of Consolidation
The consolidated financial statements include our accounts and those of our wholly-owned subsidiaries and entities in which we hold a controlling financial interest. Until December 3, 2019, our consolidated financial statements included the accounts of two joint ventures, in each of which we owned a 50 percent interest. On December 3, 2019, we acquired the remaining 50 percent interest not owned by us and as a result the two joint ventures became our wholly-owned subsidiaries. Our historical ownership interest in the joint ventures met the definition of variable interest under Financial Accounting Standards Board (“FASB”) codification and we determined that we were the primary beneficiary. Intercompany balances and transactions have been eliminated in consolidation.
Basis of Presentation-UK Companies Act 2006 Section 435 Statement
The accompanying consolidated financial statements have been prepared in accordance with GAAP, which the Board of Directors considers to be the most meaningful presentation of our results of operations and financial position. The accompanying consolidated financial statements do not constitute statutory accounts required by the UK Companies Act 2006 (“Companies Act”), which will be prepared in accordance with International Financial Reporting Standards, as adopted by the European Union and delivered to the Registrar of Companies in the UK following the annual general meeting of shareholders.
Property and Equipment
Property and equipment is stated at cost, reduced by provisions to recognize economic impairment in value whenever events or changes in circumstances indicate an asset’s carrying value may not be recoverable. At December 31, 2020 and 2019, we had $99.8 million and $88.9 million of construction-in-progress, respectively. Such amounts are included in “Property and equipment, at cost” in the accompanying
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Consolidated Balance Sheets. Major replacements and improvements are capitalized. When assets are sold, retired or otherwise disposed of, the cost and related accumulated depreciation are eliminated from the accounts and the gain or loss is recognized. Drilling equipment and facilities are depreciated using the straight-line method over their estimated useful lives as of the date placed in service or date of major refurbishment. Estimated useful lives of our drilling equipment range from three to thirty years. Other property and equipment is depreciated using the straight-line method over useful lives ranging from two to forty years.
Interest is capitalized on construction-in-progress using the weighted average cost of debt outstanding during the period of construction. During the years ended December 31, 2020, 2019 and 2018, there was zero, $9.6 million and $2.9 million capitalized interest, respectively.
Scheduled maintenance of equipment is performed based on the number of hours operated in accordance with our preventative maintenance program. Routine repair and maintenance costs are charged to expense as incurred; however, the costs of the overhauls and asset replacement projects that benefit future periods and which typically occur every three to five years are capitalized when incurred and depreciated over an equivalent period. These overhauls and asset replacement projects are included in “Property and equipment, at cost” in the Consolidated Balance Sheets. Such amounts, net of accumulated depreciation, totaled $129.6 million and $143.4 million at December 31, 2020 and 2019, respectively. Depreciation expense from continuing operations related to overhauls and asset replacement totaled $55.4 million, $61.3 million and $66.9 million for the years ended December 31, 2020, 2019 and 2018, respectively.
We evaluate the impairment of property and equipment whenever events or changes in circumstances (including the decision to cold stack, retire or sell a rig) indicate that the carrying amount of an asset may not be recoverable. An impairment loss on our property and equipment may exist when the estimated undiscounted cash flows expected to result from the use of the asset and its eventual disposition are less than its carrying amount. Any impairment loss recognized represents the excess of the asset's carrying value over the estimated fair value. As part of this analysis, we make assumptions and estimates regarding future market conditions. To the extent actual results do not meet our estimated assumptions, for a given rig or piece of equipment, we may take an impairment loss in the future.
During the years ended December 31, 2020, 2019 and 2018, we recognized a non-cash loss on impairment of $3.9 billion, $615.3 million and $802.1 million, respectively, related to our long-lived assets. See Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations— Executive Overview,” and Part II, Item 8, “Financial Statements and Supplementary Data, Note 6— Loss on Impairment” for additional information.
Revenue Recognition
The activities that primarily drive the revenue earned in our drilling contracts include (i) providing a drilling rig and the crew and supplies necessary to operate the rig, (ii) mobilizing and demobilizing the rig to and from the drill site, and (iii) performing rig preparation activities and/or modifications required for the contract. Consideration received for performing these activities may consist of dayrate drilling revenue, mobilization and demobilization revenue, contract preparation revenue and reimbursement revenue. We account for these integrated services provided within our drilling contracts as a single performance obligation satisfied over time and comprised of a series of distinct time increments in which we provide drilling services.
Our standard drilling contracts require that we operate the rig at the direction of the customer throughout the contract term (which is the period we estimate to benefit from the corresponding activities and generally ranges from two to 60 months). The activities performed and the level of service provided can vary hour to hour. Our obligation under a standard contract is to provide whatever level of service is required by the operator, or customer, over the term of the contract. We are, therefore, under a stand-ready obligation throughout the entire contract duration. Consideration for our stand-ready obligation corresponds to distinct time increments, though the rate may be variable depending on various factors, and is recognized in the period in which the services are performed. The total transaction price is determined for each individual contract by estimating both fixed and variable consideration expected to be earned over the term of the contract. We have elected to exclude from the transaction price measurement all taxes assessed by a governmental authority. See further discussion regarding the allocation of the transaction price to the remaining performance obligations below.
The amount estimated for variable consideration may be subject to interrupted or restricted rates and is only included in the transaction price to the extent that it is probable that a significant reversal of previously recognized revenue will not occur throughout the term of the contract (“constrained revenue”). When determining if variable consideration should be constrained, management considers whether there are factors outside the Company’s control that could result in a significant reversal of revenue as well as the likelihood and magnitude of a potential reversal of revenue. These estimates are re-assessed each reporting period as required.
Dayrate Drilling Revenue. Our drilling contracts generally provide for payment on a dayrate basis, with higher rates for periods when the drilling unit is operating and lower rates or zero rates for periods when drilling operations are interrupted or restricted. The dayrate invoices billed to the customer are typically determined based on the varying rates applicable to the specific activities performed on an hourly basis. Such dayrate consideration is allocated to the distinct hourly increment it relates to within the contract term, and therefore, recognized in line with the contractual rate billed for the services provided for any given hour.
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Mobilization/Demobilization Revenue. We may receive fees (on either a fixed lump-sum or variable dayrate basis) for the mobilization and demobilization of our rigs. These activities are not considered to be distinct within the context of the contract and, therefore, the associated revenue is allocated to the overall performance obligation and the associated pre-operating costs are deferred. We record a contract liability for mobilization fees received and a deferred asset for costs. Both revenue and pre-operating costs are recognized ratably over the initial term of the related drilling contract.
In most contracts, there is uncertainty as to the amount of expected demobilization revenue due to contractual provisions that stipulate that certain conditions must be present at contract completion for such revenue to be received and as to the amount thereof, if any. For example, contractual provisions may require that a rig demobilize a certain distance before the demobilization revenue is payable or the amount may vary dependent upon whether or not the rig has additional contracted work within a certain distance from the wellsite. Therefore, the estimate for such revenue may be constrained, as described earlier, depending on the facts and circumstances pertaining to the specific contract. We assess the likelihood of receiving such revenue based on past experience and knowledge of the market conditions. In cases where demobilization revenue is expected to be received upon contract completion, it is estimated as part of the overall transaction price at contract inception and recognized in earnings ratably over the initial term of the contract with an offset to an accretive contract asset.
Contract Preparation Revenue. Some of our drilling contracts require downtime before the start of the contract to prepare the rig to meet customer requirements. At times, we may be compensated by the customer for such work (on either a fixed lump-sum or variable dayrate basis). These activities are not considered to be distinct within the context of the contract and, therefore, the related revenue is allocated to the overall performance obligation and recognized ratably over the initial term of the related drilling contract. We record a contract liability for contract preparation fees received, which is amortized ratably to contract drilling revenue over the initial term of the related drilling contract.
Bonuses, Penalties and Other Variable Consideration. We may receive bonus increases to revenue or penalty decreases to revenue. Based on historical data and ongoing communication with the operator/customer, we are able to reasonably estimate this variable consideration. We will record such estimated variable consideration and re-measure our estimates at each reporting date. For revenue estimated, but not received, we will record to “Prepaid expenses and other current assets” on our Consolidated Balance Sheets.
Capital Modification Revenue. From time to time, we may receive fees from our customers for capital improvements to our rigs to meet contractual requirements (on either a fixed lump-sum or variable dayrate basis). Such revenue is allocated to the overall performance obligation and recognized ratably over the initial term of the related drilling contract as these activities are integral to our drilling activities and are not considered to be a stand-alone service provided to the customer within the context of our contracts. We record a contract liability for such fees and recognize them ratably as contract drilling revenue over the initial term of the related drilling contract.
Revenues Related to Reimbursable Expenses. We generally receive reimbursements from our customers for the purchase of supplies, equipment, personnel services and other services provided at their request in accordance with a drilling contract or other agreement. Such reimbursable revenue is variable and subject to uncertainty, as the amounts received and timing thereof is highly dependent on factors outside of our influence. Accordingly, reimbursable revenue is constrained revenue and not included in the total transaction price until the uncertainty is resolved, which typically occurs when the related costs are incurred on behalf of a customer. We are generally considered a principal in such transactions and record the associated revenue at the gross amount billed to the customer as “Reimbursables and other” in our Consolidated Statements of Operations. Such amounts are recognized ratably over the period within the contract term during which the corresponding goods and services are to be consumed.
Deferred revenues from drilling contracts totaled $59.9 million and $65.1 million at December 31, 2020 and 2019, respectively. Such amounts are included in either “Other current liabilities” or “Other liabilities” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition. Related expenses deferred under drilling contracts totaled $13.9 million at December 31, 2020 as compared to $30.8 million at December 31, 2019 and are included in either “Prepaid expenses and other current assets,” “Other assets,” or “Property and equipment, net” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition.
We record reimbursements from customers for “out-of-pocket” expenses as revenues and the related direct cost as operating expenses.
Income Taxes
We currently operate, and have in the past operated, in a number of countries throughout the world and our tax returns filed in those jurisdictions are subject to review and examination by tax authorities within those jurisdictions. We recognize uncertain tax positions that we believe have a greater than 50 percent likelihood of being sustained upon challenge by a tax authority. We cannot predict or provide assurance as to the ultimate outcome of any existing or future assessments. Our gross deferred tax asset balance at year-end reflects the application of our income tax accounting policies and is based on management’s estimates, judgments and assumptions regarding realizability. If it is more likely than not that a portion of the deferred tax assets will not be realized in a future period, the deferred tax assets will be reduced by a valuation allowance based on management’s estimates. The Company has adopted an accounting policy to look through the outside basis of partnerships and all other flow-through entities and exclude these from the computation of deferred taxes.
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The Internal Revenue Service (“IRS”) has completed its examination procedures, including all appeals and administrative reviews, for the taxable years ended December 31, 2012 through December 31,2017. In May 2020, the IRS examination team notified us that it was no longer proposing any adjustments with respect to our tax reporting for the taxable years ended December 31, 2012 through December 31, 2017. Subsequent to our filing of an Application for Tentative Refund with the IRS under the CARES Act in the months of April and August 2020, the IRS informed us that it would be conducting a limited scope examination of the taxable years ended December 31, 2012, 2013, 2014, 2018 and 2019. In the first quarter of 2020, we filed a foreign tax credit refund claim for taxable year 2009. The IRS is currently auditing taxable year 2009 in relation to our refund claim. We believe that we have accurately reported all amounts in our returns.
Audit claims of approximately $96.1 million attributable to income and other business taxes were assessed against Noble entities in Mexico related to tax years 2007, 2009 and 2010, in Australia related to tax years 2013 to 2016, in Guyana related to tax years 2019 and 2020 and in Saudi Arabia related to tax years 2015 to 2018. We intend to vigorously defend our reported positions, and believe the ultimate resolution of the audit claims will not have a material adverse effect on our consolidated financial statements.
Insurance Reserves
We maintain various levels of self-insured retention for certain losses including property damage, loss of hire, employment practices liability, employers’ liability and general liability, among others. We accrue for property damage and loss of hire charges on a per event basis.
Employment practices liability claims are accrued based on actual claims during the year. Maritime employer’s liability claims are generally estimated using actuarial determinations. General liability claims are estimated by our internal claims department by evaluating the facts and circumstances of each claim (including incurred but not reported claims) and making estimates based upon historical experience with similar claims. At December 31, 2020 and 2019, loss reserves for personal injury and protection claims totaled $30.9 million and $27.9 million, respectively, and such amounts are included in “Other liabilities” and “Liabilities subject compromise” in the accompanying Consolidated Balance Sheets.
Certain Significant Estimates and Contingent Liabilities
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our consolidated financial statements. We follow FASB standards regarding contingent liabilities, which are discussed in Part II, Item 8, “Financial Statements and Supplementary Data, Note 16— Commitments and Contingencies.”
Off-Balance Sheet Arrangements
We have no off-balance sheet arrangements as that term is defined in Item 303(a)(4)(ii) of Regulation S-K.
New Accounting Pronouncements
See Part II, Item 8, “Financial Statements and Supplementary Data, Note 1— Organization and Significant Accounting Policies” for a description of the recent accounting pronouncements.
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.
Market risk is the potential for loss due to a change in the value of a financial instrument as a result of fluctuations currency exchange rates or equity prices, as further described below.
Foreign Currency Risk
Although we are a Cayman Islands company, we define foreign currency as any non-US denominated currency. Our functional currency is the US Dollar. However, outside the United States, a portion of our expenses are incurred in local currencies. Therefore, when the US Dollar weakens (strengthens) in relation to the currencies of the countries in which we operate, our expenses reported in US Dollars will increase (decrease).
We are exposed to risks on future cash flows to the extent that local currency expenses exceed revenues denominated in local currency that are other than the functional currency. To help manage this potential risk, we periodically enter into derivative instruments to manage our
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exposure to fluctuations in currency exchange rates, and we may conduct hedging activities in future periods to mitigate such exposure. These contracts are primarily accounted for as cash flow hedges, with the effective portion of changes in the fair value of the hedge recorded on the Consolidated Balance Sheets and in “Accumulated other comprehensive income (loss)” (“AOCI”). Amounts recorded in AOCI are reclassified into earnings in the same period or periods that the hedged item is recognized in earnings. The ineffective portion of changes in the fair value of the hedged item is recorded directly to earnings. We have documented policies and procedures to monitor and control the use of derivative instruments. We do not engage in derivative transactions for speculative or trading purposes, nor are we a party to leveraged derivatives.
Several of our regional shorebases have a significant amount of their cash operating expenses payable in local currencies. To limit the potential risk of currency fluctuations, we periodically enter into forward contracts, which have historically settled monthly in the operations’ respective local currencies. All of these contracts had a maturity of less than 12 months. During 2020, we did not enter into any forward contracts. During 2019, we entered into forward contracts of approximately $15.8 million, all of which settled during 2019. At both December 31, 2020 and 2019, we had no outstanding derivative contracts. Based on current projections, a 10% increase in the average exchange rates of all foreign currencies would hypothetically increase our future estimated operating expenses by approximately $11.0 million.
Market Risk
We have a US noncontributory defined benefit pension plan that covers certain salaried employees and a US noncontributory defined benefit pension plan that covers certain hourly employees, whose initial date of employment is prior to August 1, 2004 (collectively referred to as our “qualified US plans”). These plans are governed by the Noble Drilling Employees’ Retirement Trust. The benefits from these plans are based primarily on years of service and, for the salaried plan, employees’ compensation near retirement. These plans are designed to qualify under the Employee Retirement Income Security Act of 1974 (“ERISA”), and our funding policy is consistent with funding requirements of ERISA and other applicable laws and regulations. We make cash contributions, or utilize credits available to us, for the qualified US plans when required. The benefit amount that can be covered by the qualified US plans is limited under ERISA and the Internal Revenue Code of 1986. Therefore, we maintain an unfunded, nonqualified excess benefit plan designed to maintain benefits for specified employees at the formula level in the qualified salary US plan. We refer to the qualified US plans and the excess benefit plan collectively as the “US plans.”
In addition to the US plans, Noble Drilling (Land Support) Limited, an indirect, wholly-owned subsidiary of Noble, maintains a pension plan that covers all of its salaried, non-union employees, whose most recent date of employment is prior to April 1, 2014 (referred to as our “non-US plan”). Benefits are based on credited service and employees’ compensation, as defined by the non-US plan.
The Company’s pension plan assets are exposed to the market prices of debt and equity securities. Changes to the pension plan asset values can impact the Company’s pension expense, funded status and future minimum funding requirements. The Company aims to reduce risk through asset diversification and by investing in long duration fixed-income securities that have a duration similar to that of its pension liabilities. At December 31, 2020, the value of the investments in the pension funds was $306.2 million, and a hypothetical 10.0% percent decrease in the value of the investments in the fund would have reduced the value of the fund by approximately $30.6 million. A significant decline in the value of pension assets could require Noble to increase funding of its pension plans in future periods, which could adversely affect cash flows in those periods. In addition, a decline in the fair value of these plan assets, in the absence of additional cash contributions to the plans by Noble, could increase the amount of pension cost required to be recorded in future periods by Noble.

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Item 8. Financial Statements and Supplementary Data.
The following financial statements are filed in this Item 8: 
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Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders of Noble Corporation:

Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Noble Corporation (formerly known as Noble Holding Corporation plc) and its subsidiaries (the “Company”) as of December 31, 2020 and 2019, and the related consolidated statements of operations, of comprehensive income (loss), of equity and of cash flows for each of the three years in the period ended December 31, 2020, including the related notes (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Basis for Opinions
The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Annual Report on Internal Control Over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

53

Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Impairment Assessment – Certain Rigs Within Drilling Equipment and Facilities Assets
As described in Notes 1, 5 and 6 to the consolidated financial statements, the balance of drilling equipment and facilities was $4.5 billion as of December 31, 2020, which included a $2.8 billion impairment related to certain rigs for the year ended December 31, 2020. Management evaluates property and equipment for impairment whenever there are changes in facts that suggest that the carrying value of the asset is not recoverable. As part of this analysis, management makes assumptions and estimates regarding future market conditions. When circumstances indicate that the carrying value of the assets may not be recoverable, management compares the carrying value to the expected undiscounted pre-tax future cash flows (estimated using an undiscounted cash flow model) for the associated rig for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows are lower than the carrying value, the capitalized costs are reduced to fair value. An impairment loss is recognized to the extent that an asset's carrying value exceeds its estimated fair value. Management estimated the fair values of these units using a weighting between an income valuation approach and a market approach, utilizing significant unobservable inputs, representative of a Level 3 fair value measurement. Assumptions used in the assessment included, but were not limited to, future marketability of each unit in light of the current market conditions and its current technical specifications, timing of future contract awards and expected operating dayrates, operating costs, utilization rates, discount rates, capital expenditures, market values, weighting of market values, reactivation costs, estimated economic useful lives and, in certain cases, the belief that a drilling unit is no longer marketable and is unlikely to return to service in the near to medium term.
The principal considerations for our determination that performing procedures relating to the impairment assessment of certain rigs within drilling equipment and facilities assets is a critical audit matter are (i) the significant judgment by management when developing the undiscounted pre-tax future cash flows and estimated fair values of the drilling equipment and facilities assets; (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management’s significant assumptions related to the expected operating dayrates, operating costs, utilization rates, and the discount rate; and (iii) the audit effort involved the use of professionals with specialized skill and knowledge.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the drilling equipment and facilities assets impairment assessment. These procedures also included, among others (i) testing management’s process for developing the undiscounted pre-tax future cash flows and fair value estimates; (ii) evaluating the appropriateness of the undiscounted pre-tax cash flow and discounted cash flow model; (iii) testing the completeness and accuracy of underlying data used in the model; and (iv) evaluating the significant assumptions used by management related to the expected operating dayrates, operating costs, utilization rates, and the discount rate. Evaluating management’s assumptions related to the expected operating day rates, operating costs and utilization rates involved evaluating whether the assumptions used by management were reasonable considering (i) the current and past performance of the assets; (ii) the consistency with external market and industry data; and (iii) whether these assumptions were consistent with evidence obtained in other areas of the audit. Professionals with specialized skill and knowledge were used to assist in the evaluation of the discounted cash flow model and the discount rate.

/s/ PricewaterhouseCoopers LLP
 
Houston, Texas
March 12, 2021

We have served as the Company’s auditor since 1994.

54


NOBLE CORPORATION (formerly known as Noble Holding Corporation plc)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED BALANCE SHEETS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands, except per share data)

December 31,
2020 		December 31,
2019
ASSETS
Current assets
Cash and cash equivalents $ 343,332  $ 104,621 
Accounts receivable, net of allowance for credit losses of $1,069 and $1,939, respectively
147,863  198,665 
Taxes receivable 30,767  59,771 
Prepaid expenses and other current assets 80,322  59,050 
Total current assets 602,284  422,107 
Property and equipment, at cost 4,777,697  10,306,625 
Accumulated depreciation (1,200,628) (2,572,701)
Property and equipment, net 3,577,069  7,733,924 
Other assets 84,584  128,467 
Total assets $ 4,263,937  $ 8,284,498 
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt $ —  $ 62,505 
Accounts payable 95,159  108,208 
Accrued payroll and related costs 36,553  56,056 
Taxes payable 36,819  30,715 
Interest payable —  88,047 
Other current liabilities 49,820  171,397 
Total current liabilities 218,351  516,928 
Long-term debt —  3,779,499 
Deferred income taxes 9,292  68,201 
Other liabilities 108,039  260,898 
Liabilities subject to compromise 4,239,643  — 
Total liabilities 4,575,325  4,625,526 
Commitments and contingencies (Note 16)
Shareholders' equity
Common stock, $0.01 par value, ordinary shares; 251,084 and 249,200 shares outstanding as of December 31, 2020 and December 31, 2019, respectively.
2,511  2,492 
Additional paid-in capital 814,796  807,093 
Retained earnings (accumulated deficit) (1,070,683) 2,907,776 
Accumulated other comprehensive loss (58,012) (58,389)
Total shareholders' equity (311,388) 3,658,972 
Total liabilities and equity $ 4,263,937  $ 8,284,498 
See accompanying notes to the consolidated financial statements.
55

NOBLE CORPORATION (formerly known as Noble Holding Corporation plc)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands, except per share data)

Year Ended December 31,
2020 2019 2018
Operating revenues
Contract drilling services $ 909,236  $ 1,246,058  $ 1,036,082 
Reimbursables and other 55,036  59,380  46,744 
964,272  1,305,438  1,082,826 
Operating costs and expenses
Contract drilling services 567,487  698,343  629,937 
Reimbursables 48,188  49,061  37,084 
Depreciation and amortization 374,129  440,221  486,530 
General and administrative 121,196  168,792  73,216 
Pre-petition charges 14,409  —  — 
Loss on impairment 3,915,408  615,294  802,133 
5,040,817  1,971,711  2,028,900 
Operating loss (4,076,545) (666,273) (946,074)
Other income (expense)
Interest expense, net of amount capitalized (164,653) (279,435) (297,611)
Gain (loss) on extinguishment of debt, net 17,254  30,616  (1,793)
Interest income and other, net 9,012  6,007  8,302 
Reorganization items, net (23,930) —  — 
Loss from continuing operations before income taxes (4,238,862) (909,085) (1,237,176)
Income tax benefit 260,403  38,540  106,641 
Net loss from continuing operations (3,978,459) (870,545) (1,130,535)
Net loss from discontinued operations, net of tax —  (3,821) — 
Net loss (3,978,459) (874,366) (1,130,535)
Net loss attributable to noncontrolling interests —  173,776  245,485 
Net loss attributable to Noble Corporation $ (3,978,459) $ (700,590) $ (885,050)
Net loss attributable to Noble Corporation
Loss from continuing operations $ (3,978,459) $ (696,769) $ (885,050)
Net loss from discontinued operations, net of tax —  (3,821) — 
Net loss attributable to Noble Corporation $ (3,978,459) $ (700,590) $ (885,050)
Per share data
Basic:
Loss from continuing operations $ (15.86) $ (2.79) $ (3.59)
Loss from discontinued operations —  (0.02) — 
Net loss attributable to Noble Corporation $ (15.86) $ (2.81) $ (3.59)
Diluted:
Loss from continuing operations $ (15.86) $ (2.79) $ (3.59)
Loss from discontinued operations —  (0.02) — 
Net loss attributable to Noble Corporation $ (15.86) $ (2.81) $ (3.59)
Weighted- Average Shares Outstanding
Basic 250,792  248,949  246,614 
Diluted 250,792  248,949  246,614 
See accompanying notes to the consolidated financial statements.
56

NOBLE CORPORATION (formerly known as Noble Holding Corporation plc)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Unless otherwise indicated, dollar amounts in tables are in thousands)

Year Ended December 31,
2020 2019 2018
Net loss $ (3,978,459) $ (874,366) $ (1,130,535)
Other comprehensive income (loss)    
Foreign currency translation adjustments (521) 260  (2,729)
Net pension plan gain (loss) (net of tax provision (benefit) of $(537), $(924) and $(1,828) for the year ended December 31, 2020, 2019 and 2018, respectively)
(1,407) (3,744) (7,099)
Amortization of deferred pension plan amounts (net of tax provision of $583, $584 and $345 for the year ended December 31, 2020, 2019 and 2018, respectively)
2,183  2,197  1,298 
Net pension plan curtailment and settlement gain (loss) (net of tax provision (benefit) of $32, $(8) and $28 for the year ended December 31, 2020, 2019 and 2018, respectively)
122  (30) 107 
Prior service cost arising during the period (net of tax provision (benefit) of zero, zero and $(55) for the year ended December 31, 2020, 2019 and 2018, respectively)
—  —  (221)
Other comprehensive income (loss), net 377  (1,317) (8,644)
Net comprehensive loss attributable to noncontrolling interests —  173,776  245,485 
Comprehensive loss attributable to Noble Corporation $ (3,978,082) $ (701,907) $ (893,694)

See accompanying notes to the consolidated financial statements.
57

NOBLE CORPORATION (formerly known as Noble Holding Corporation plc)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unless otherwise indicated, dollar amounts in tables are in thousands)

Year Ended December 31,
2020 2019 2018
Cash flows from operating activities
Net loss $ (3,978,459) $ (874,366) $ (1,130,535)
Adjustments to reconcile net loss to net cash flow from operating activities:
Depreciation and amortization 374,129  440,221  486,530 
Loss on impairment 3,915,408  615,294  802,133 
(Gain) loss on extinguishment of debt, net (17,254) (30,616) 1,793 
Reorganization items, net (17,366) —  — 
Deferred income taxes (26,325) (17,825) (68,416)
Amortization of share-based compensation 9,169  14,737  23,993 
Other costs, net (61,550) 60,259  6,446 
Changes in components of working capital
Change in taxes receivable 29,880  (11,225) 84,847 
Net changes in other operating assets and liabilities 45,565  (9,708) (34,940)
Net cash provided by operating activities 273,197  186,771  171,851 
Cash flows from investing activities
Capital expenditures (148,886) (268,783) (194,779)
Proceeds from disposal of assets, net 27,366  12,753  5,402 
Net cash used in investing activities (121,520) (256,030) (189,377)
Cash flows from financing activities
Issuance of senior notes —  —  750,000 
Borrowings on credit facilities 210,000  755,000  — 
Repayments of credit facilities —  (420,000) — 
Repayments of debt (101,132) (400,000) (972,708)
Debt issuance costs —  (1,092) (15,639)
Purchase of noncontrolling interests —  (106,744) — 
Dividends paid to noncontrolling interests —  (25,109) (27,579)
Cash paid to settle equity awards (1,010) —  — 
Taxes withheld on employee stock transactions (418) (2,779) (3,470)
Net cash provided by (used in) financing activities 107,440  (200,724) (269,396)
Net increase (decrease) in cash, cash equivalents and restricted cash 259,117  (269,983) (286,922)
Cash, cash equivalents and restricted cash, beginning of period 105,924  375,907  662,829 
Cash, cash equivalents and restricted cash, end of period $ 365,041  $ 105,924  $ 375,907 

See accompanying notes to the consolidated financial statements.
58

NOBLE CORPORATION (formerly known as Noble Holding Corporation plc)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF EQUITY
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Shares Additional Paid-in Capital Retained Earnings (accumulated deficit) Accumulated Other Comprehensive Loss Noncontrolling Interests Total Equity
Balance Par Value
Balance at December 31, 2017 244,971  $ 2,450  $ 678,922  $ 4,637,677  $ (42,888) $ 674,467  $ 5,950,628 
Tax effects of intra-entity asset transfers —  —  —  (148,393) —  —  (148,393)
Stranded tax effect resulting from the Tax Cuts and Jobs Act —  —  —  5,540  (5,540) —  — 
Adjustment for adopting the revenue recognition standard —  —  —  (1,488) —  —  (1,488)
Balance at January 1, 2018 244,971  $ 2,450  $ 678,922  $ 4,493,336  $ (48,428) $ 674,467  $ 5,800,747 
Employee related equity activity
Amortization of share-based compensation —  —  23,993  —  —  —  23,993 
Issuance of share-based compensation shares 1,823  18  (18) —  —  —  — 
Tax benefit of equity transactions —  —  (3,488) —  —  —  (3,488)
Net loss —  —  —  (885,050) —  (245,485) (1,130,535)
Dividends paid to noncontrolling interests —  —  —  —  —  (27,579) (27,579)
Dividend equivalents (1)
—  —  —  80  —  —  80 
Other comprehensive loss, net —  —  —  —  (8,644) —  (8,644)
Balance at December 31, 2018 246,794  $ 2,468  $ 699,409  $ 3,608,366  $ (57,072) $ 401,403  $ 4,654,574 
Employee related equity activity
Amortization of share-based compensation —  —  14,737  —  —  —  14,737 
Issuance of share-based compensation shares 2,406  24  (24) —  —  —  — 
Tax benefit of equity transactions —  —  (2,803) —  —  —  (2,803)
Purchase of noncontrolling interests —  —  95,774  —  —  (202,518) (106,744)
Net loss —  —  —  (700,590) —  (173,776) (874,366)
Dividends paid to noncontrolling interests —  —  —  —  —  (25,109) (25,109)
Other comprehensive loss, net —  —  —  —  (1,317) —  (1,317)
Balance at December 31, 2019 249,200  $ 2,492  $ 807,093  $ 2,907,776  $ (58,389) $ —  $ 3,658,972 
Employee related equity activity
Amortization of share-based compensation —  —  8,159  —  —  —  8,159 
Issuance of share-based compensation shares 1,884  19  (19) —  —  —  — 
Tax benefit of equity transactions —  —  (437) —  —  —  (437)
Net loss —  —  —  (3,978,459) —  (3,978,459)
Other comprehensive loss, net —  —  —  —  377  —  377 
Balance at December 31, 2020 251,084  $ 2,511  $ 814,796  $ (1,070,683) $ (58,012) $ —  $ (311,388)
(1)Activity associated with dividend equivalents, which are related to 2016 performance awards to be paid upon vesting.
See accompanying notes to the consolidated financial statements.

59

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholder of Noble Finance Company:

Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Noble Finance Company (formerly known as Noble Corporation) and its subsidiaries (the “Company”) as of December 31, 2020 and 2019, and the related consolidated statements of operations, of comprehensive income (loss), of equity and of cash flows for each of the three years in the period ended December 31, 2020, including the related notes (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Basis for Opinions
The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Annual Report on Internal Control Over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

60

Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Impairment Assessment – Certain Rigs Within Drilling Equipment and Facilities Assets
As described in Notes 1, 5 and 6 to the consolidated financial statements, the balance of drilling equipment and facilities was $4.5 billion as of December 31, 2020, which included a $2.8 billion impairment related to certain rigs for the year ended December 31, 2020. Management evaluates property and equipment for impairment whenever there are changes in facts that suggest that the carrying value of the asset is not recoverable. As part of this analysis, management makes assumptions and estimates regarding future market conditions. When circumstances indicate that the carrying value of the assets may not be recoverable, management compares the carrying value to the expected undiscounted pre-tax future cash flows (estimated using an undiscounted cash flow model) for the associated rig for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows are lower than the carrying value, the capitalized costs are reduced to fair value. An impairment loss is recognized to the extent that an asset's carrying value exceeds its estimated fair value. Management estimated the fair values of these units using a weighting between an income valuation approach and a market approach, utilizing significant unobservable inputs, representative of a Level 3 fair value measurement. Assumptions used in the assessment included, but were not limited to, future marketability of each unit in light of the current market conditions and its current technical specifications, timing of future contract awards and expected operating dayrates, operating costs, utilization rates, discount rates , capital expenditures, market values, weighting of market values, reactivation costs, estimated economic useful lives and, in certain cases, the belief that a drilling unit is no longer marketable and is unlikely to return to service in the near to medium term.
The principal considerations for our determination that performing procedures relating to the impairment assessment of certain rigs within drilling equipment and facilities assets is a critical audit matter are (i) the significant judgment by management when developing the undiscounted pre-tax future cash flows and estimated fair values of the drilling equipment and facilities assets; (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management’s significant assumptions related to the expected operating dayrates, operating costs, utilization rates, and the discount rate; and (iii) the audit effort involved the use of professionals with specialized skill and knowledge.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the drilling equipment and facilities assets impairment assessment. These procedures also included, among others (i) testing management’s process for developing the undiscounted pre-tax future cash flow and fair value estimates; (ii) evaluating the appropriateness of the undiscounted pre-tax cash flow and discounted cash flow model; (iii) testing the completeness and accuracy of underlying data used in the model; and (iv) evaluating the significant assumptions used by management related to the expected operating dayrates, operating costs, utilization rates, and the discount rate. Evaluating management’s assumptions related to the expected operating day rates, operating costs and utilization rates involved evaluating whether the assumptions used by management were reasonable considering (i) the current and past performance of the assets; (ii) the consistency with external market and industry data; and (iii) whether these assumptions were consistent with evidence obtained in other areas of the audit. Professionals with specialized skill and knowledge were used to assist in the evaluation of the discounted cash flow model and the discount rate.
/s/ PricewaterhouseCoopers LLP
 
Houston, Texas
March 12, 2021

We have served as the Company’s auditor since 1994.

61


NOBLE FINANCE COMPANY (formerly known as Noble Corporation)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED BALANCE SHEETS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands, except per share data)

December 31,
2020 		December 31,
2019
ASSETS
Current assets
Cash and cash equivalents $ 343,332  $ 104,575 
Accounts receivable, net of allowance for credit losses of $1,069 and $1,939, respectively
147,863  198,665 
Accounts receivable from affiliates 31,214  — 
Taxes receivable 30,767  59,771 
Prepaid expenses and other current assets 50,469  57,890 
Total current assets 603,645  420,901 
Property and equipment, at cost 4,777,697  10,306,625 
Accumulated depreciation (1,200,628) (2,572,701)
Property and equipment, net 3,577,069  7,733,924 
Other assets 84,584  128,467 
Total assets $ 4,265,298  $ 8,283,292 
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt $ —  $ 62,505 
Accounts payable 83,649  107,985 
Accrued payroll and related costs 36,516  56,065 
Taxes payable 36,819  30,715 
Interest payable —  88,047 
Other current liabilities 49,820  71,397 
Total current liabilities 206,804  416,714 
Long-term debt —  3,779,499 
Deferred income taxes 9,292  68,201 
Other liabilities 108,039  260,898 
Liabilities subject to compromise 4,154,555  — 
Total liabilities 4,478,690  4,525,312 
Commitments and contingencies (Note 16)
Shareholder equity
Common stock, $0.10 par value, 261,246 ordinary shares; 261,246 shares outstanding as of December 31, 2020 and December 31, 2019
26,125  26,125 
Capital in excess of par value 766,714  757,545 
Retained earnings (accumulated deficit) (948,219) 3,032,699 
Accumulated other comprehensive loss (58,012) (58,389)
Total shareholder equity (213,392) 3,757,980 
Total liabilities and equity $ 4,265,298  $ 8,283,292 
See accompanying notes to the consolidated financial statements.
62

NOBLE FINANCE COMPANY (formerly known as Noble Corporation)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands, except per share data)

Year Ended December 31,
2020 2019 2018
Operating revenues
Contract drilling services $ 909,236  $ 1,246,058  $ 1,036,082 
Reimbursables and other 55,036  59,380  46,744 
964,272  1,305,438  1,082,826 
Operating costs and expenses
Contract drilling services 566,231  696,265  628,128 
Reimbursables 48,188  49,061  37,084 
Depreciation and amortization 372,560  437,690  482,660 
General and administrative 37,798  34,602  38,203 
Loss on impairment 3,915,408  615,294  802,133 
4,940,185  1,832,912  1,988,208 
Operating loss (3,975,913) (527,474) (905,382)
Other income (expense)
Interest expense, net of amount capitalized (164,653) (279,435) (297,611)
Gain (loss) on extinguishment of debt, net 17,254  30,616  (1,793)
Interest income and other, net 9,014  6,670  8,282 
Reorganization items, net (50,778) —  — 
Loss from continuing operations before income taxes (4,165,076) (769,623) (1,196,504)
Income tax benefit 260,403  38,540  106,534 
Net loss from continuing operations (3,904,673) (731,083) (1,089,970)
Net income from discontinued operations, net of tax —  (3,821) — 
Net loss (3,904,673) (734,904) (1,089,970)
Net loss attributable to noncontrolling interests —  173,776  245,485 
Net loss attributable to Noble Finance Company $ (3,904,673) $ (561,128) $ (844,485)
See accompanying notes to the consolidated financial statements.
63

NOBLE FINANCE COMPANY (formerly known as Noble Corporation)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Unless otherwise indicated, dollar amounts in tables are in thousands)

Year Ended December 31,
2020 2019 2018
Net loss $ (3,904,673) $ (734,904) $ (1,089,970)
Other comprehensive income (loss)    
Foreign currency translation adjustments (521) 260  (2,729)
Net pension plan gain (loss) (net of tax provision (benefit) of $(537), $(924) and $(1,828) for the year ended December 31, 2020, 2019 and 2018, respectively)
(1,407) (3,744) (7,099)
Amortization of deferred pension plan amounts (net of tax provision of $583, $584 and $345 for the year ended December 31, 2020, 2019 and 2018, respectively)
2,183  2,197  1,298 
Net pension plan curtailment and settlement gain (loss) (net of tax provision (benefit) of $32, $(8) and $28 for the year ended December 31, 2020, 2019 and 2018, respectively)
122  (30) 107 
Prior service cost arising during the period (net of tax provision (benefit) of zero, zero and $(55) for the year ended December 31, 2020, 2019 and 2018, respectively)
—  —  (221)
Other comprehensive income (loss), net 377  (1,317) (8,644)
Net comprehensive loss attributable to noncontrolling interests —  173,776  245,485 
Comprehensive loss attributable to Noble Finance Company $ (3,904,296) $ (562,445) $ (853,129)
See accompanying notes to the consolidated financial statements.


64

NOBLE FINANCE COMPANY (formerly known as Noble Corporation)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unless otherwise indicated, dollar amounts in tables are in thousands)

Year Ended December 31,
2020 2019 2018
Cash flows from operating activities
Net loss $ (3,904,673) $ (734,904) $ (1,089,970)
Adjustments to reconcile net loss to net cash flow from operating activities:
Depreciation and amortization 372,560  437,690  482,660 
Loss on impairment 3,915,408  615,294  802,133 
(Gain) loss on extinguishment of debt, net (17,254) (30,616) 1,793 
Reorganization items, net 44,134  —  — 
Deferred income taxes (26,325) (17,825) (68,416)
Amortization of share-based compensation 9,169  14,689  23,945 
Other costs, net (115,550) (39,741) 6,446 
Change in components of working capital
Change in taxes receivable 29,880  (11,225) 84,847 
Net changes in other operating assets and liabilities 20,714  (6,456) (30,679)
Net cash provided by operating activities 328,063  226,906  212,759 
Cash flows from investing activities
Capital expenditures (148,886) (268,783) (194,779)
Proceeds from disposal of assets 27,366  12,753  5,402 
Net cash used in investing activities (121,520) (256,030) (189,377)
Cash flows from financing activities
Borrowings on credit facilities 210,000  755,000  — 
Issuance of senior notes —  —  750,000 
Repayment of credit facilities —  (420,000) — 
Repayments of debt (101,132) (400,000) (972,708)
Debt issuance costs —  (1,092) (15,639)
Purchase of noncontrolling interests —  (106,744) — 
Dividends paid to noncontrolling interests —  (25,109) (27,579)
Contributions (distributions) from (to) parent company, net (76,245) (42,103) (44,417)
Net cash provided by (used in) financing activities 32,623  (240,048) (310,343)
Net increase (decrease) in cash, cash equivalents and restricted cash 239,166  (269,172) (286,961)
Cash, cash equivalents and restricted cash, beginning of period 105,878  375,050  662,011 
Cash, cash equivalents and restricted cash, end of period $ 345,044  $ 105,878  $ 375,050 

See accompanying notes to the consolidated financial statements.
65

NOBLE FINANCE COMPANY (formerly known as Noble Corporation)
AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONSOLIDATED STATEMENTS OF EQUITY
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Shares Additional Paid-in Capital Retained Earnings (accumulated deficit) Accumulated Other Comprehensive Loss Noncontrolling Interests Total Equity
Balance Par Value
Balance at December 31, 2017 261,246  $ 26,125  $ 623,137  $ 4,669,173  $ (42,888) $ 674,467  $ 5,950,014 
Tax effects of intra-entity asset transfers —  —  —  (148,393) —  —  (148,393)
Stranded tax effect resulting from the Tax Cuts and Jobs Act —  —  —  5,540  (5,540) —  — 
Adjustment for adopting the revenue recognition standard —  —  —  (1,488) —  —  (1,488)
Balance at January 1, 2018 261,246  $ 26,125  $ 623,137  $ 4,524,832  $ (48,428) $ 674,467  $ 5,800,133 
Contributions from parent company, net —  —  —  (44,417) —  —  (44,417)
Capital contribution by parent - share-based compensation —  —  23,945  —  —  —  23,945 
Net loss —  —  —  (844,485) —  (245,485) (1,089,970)
Dividends paid to noncontrolling interests —  —  —  —  —  (27,579) (27,579)
Other comprehensive income, net —  —  —  —  (8,644) —  (8,644)
Balance at December 31, 2018 261,246  $ 26,125  $ 647,082  $ 3,635,930  $ (57,072) $ 401,403  $ 4,653,468 
Distributions to parent company, net —  —  —  (42,103) —  —  (42,103)
Capital contribution by parent - share-based compensation —  —  14,689  —  —  —  14,689 
Purchase of noncontrolling interests —  —  95,774  —  —  (202,518) (106,744)
Net loss —  —  —  (561,128) —  (173,776) (734,904)
Dividends paid to noncontrolling interests —  —  —  —  —  (25,109) (25,109)
Other comprehensive loss, net —  —  —  —  (1,317) —  (1,317)
Balance at December 31, 2019 261,246  $ 26,125  $ 757,545  $ 3,032,699  $ (58,389) $ —  $ 3,757,980 
Distributions to parent company, net —  —  —  (76,245) —  —  (76,245)
Capital contribution by parent - share-based compensation —  —  9,169  —  —  —  9,169 
Net loss —  —  —  (3,904,673) —  —  (3,904,673)
Other comprehensive loss, net —  —  —  —  377  —  377 
Balance at December 31, 2020 261,246  $ 26,125  $ 766,714  $ (948,219) $ (58,012) $ —  $ (213,392)
See accompanying notes to the consolidated financial statements.

66
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)

Note 1— Organization and Significant Accounting Policies
Noble Corporation, an exempted company incorporated in the Cayman Islands with limited liability (“Noble” or “Successor”), is a leading offshore drilling contractor for the oil and gas industry. We provide contract drilling services to the international oil and gas industry with our global fleet of mobile offshore drilling units. Noble and its predecessors have been engaged in the contract drilling of oil and gas wells since 1921. As of December 31, 2020, our fleet of 19 drilling rigs consisted of 7 floaters and 12 jackups.
We report our contract drilling operations as a single reportable segment, Contract Drilling Services, which reflects how we manage our business. The mobile offshore drilling units comprising our offshore rig fleet operate in a global market for contract drilling services and are often redeployed to different regions due to changing demands of our customers, which consist primarily of large, integrated, independent and government-owned or controlled oil and gas companies throughout the world.
On July 31, 2020 (the “Petition Date”), our former parent company, Noble Holding Corporation plc (formerly known as Noble Corporation plc), a public limited company incorporated under the laws of England and Wales (“Legacy Noble” or the “Predecessor”), and certain of its subsidiaries, including Noble Finance Company (formerly known as Noble Corporation), a Cayman Islands company (“Finco”), filed voluntary petitions in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”) seeking relief under chapter 11 of title 11 of the United States Code (the “Bankruptcy Code”). On September 4, 2020, the Debtors (as defined herein) filed with the Bankruptcy Court the Joint Plan of Reorganization of Noble Corporation plc and its Debtor Affiliates, which was subsequently amended on October 8, 2020 and October 13, 2020 and modified on November 18, 2020 (as amended, modified or supplemented, the “Plan”), and the related disclosure statement (the “Disclosure Statement”). On September 24, 2020, six additional subsidiaries of Legacy Noble (together with Legacy Noble and its subsidiaries that filed on the Petition Date, as the context requires, the “Debtors”) filed voluntary petitions in the Bankruptcy Court. The chapter 11 proceedings were jointly administered under the caption Noble Corporation plc, et al. (Case No. 20-33826) (the “Chapter 11 Cases”). On November 20, 2020, the Bankruptcy Court entered an order confirming the Plan. In connection with the Chapter 11 Cases and the Plan, on and prior to the Effective Date (as defined herein), Legacy Noble and certain of its subsidiaries effectuated certain restructuring transactions pursuant to which Legacy Noble formed Noble as an indirect wholly-owned subsidiary of Legacy Noble and transferred to Noble substantially all of the subsidiaries and other assets of Legacy Noble. On February 5, 2021 (the “Effective Date”), the Plan became effective in accordance with its terms and the Debtors emerged from the Chapter 11 Cases.
Noble is the successor issuer to Legacy Noble for purposes of and pursuant to Rule 15d-5 of the Exchange Act. References to the “Company,” “we,” “us” or “our” in this Annual Report are to Noble, together with its consolidated subsidiaries, when referring to periods following the Effective Date, and to Legacy Noble, together with its consolidated subsidiaries, when referring to periods prior to the Effective Date.
Finco was an indirect, wholly-owned subsidiary of Legacy Noble prior to the Effective Date and has been a direct, wholly-owned subsidiary of Noble, our parent company, since the Effective Date. Noble’s principal asset is all of the shares of Finco. Finco has no public equity outstanding. The consolidated financial statements of Noble include the accounts of Finco, and Noble conducts substantially all of its business through Finco and its subsidiaries.
Going Concern
A prolonged offshore industry downturn which began in 2014 was further exacerbated throughout 2020 by a steep decline in crude oil demand and crude oil price instability. The severity and length of these industry challenges negatively impacted our liquidity position resulting in higher than previously anticipated free cash flow deficits, increased borrowings and reduced availability under our 2017 Credit Facility (as defined herein), and significantly reduced access to sources of new capital. We actively pursued a variety of transactions and cost-cutting measures during the first half of 2020, including, but not limited to, potential refinancing transactions by us or our subsidiaries, potential capital exchange transactions, and a potential waiver from lenders under, or amendment to, our 2017 Credit Facility.
Legacy Noble performed the required assessments in conjunction with the filing of its Form 10-Q for the three months ended March 31, 2020 and determined, at that time, that substantial doubt about its ability to continue as a going concern existed. Subsequent to emergence from the Chapter 11 Cases, Noble performed a reassessment and concluded there was no longer substantial doubt regarding the Noble’s ability to continue as a going concern one year from the date of filing the Noble's Form 10-K for the year ended December 31, 2020. This was primarily due to the cancellation of Legacy Noble’s outstanding debt obligations and increased liquidity with the Exit Credit Agreement (as defined herein). Management’s assessment was based on the relevant conditions that were known and reasonably knowable at the issuance date and included the Noble’s post-emergence financial condition and liquidity sources, forecasted future cash flows, contractual obligations and
67
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
commitments and other conditions that could adversely affect the Noble’s ability to meet its obligations through one year from the issuance date of the Form 10-K.
Principles of Consolidation
The consolidated financial statements include our accounts and those of our wholly-owned subsidiaries and entities in which we hold a controlling financial interest. Until December 3, 2019 our consolidated financial statements included the accounts of two joint ventures, in each of which we owned a 50 percent interest. On December 3, 2019, we acquired the remaining 50 percent interest not owned by us and as a result the two joint ventures became our wholly-owned subsidiaries. Our historical ownership interest in the joint ventures met the definition of variable interest under Financial Accounting Standards Board (“FASB”) codification and we determined that we were the primary beneficiary. Intercompany balances and transactions have been eliminated in consolidation.
Cash and Cash Equivalents
Cash and cash equivalents include cash on hand, demand deposits with banks and all highly liquid investments with original maturities of three months or less. Our cash, cash equivalents and short-term investments are subject to potential credit risk, and certain of our cash accounts carry balances greater than the federally insured limits. Cash and cash equivalents are primarily held by major banks or investment firms. Our cash management and investment policies restrict investments to lower risk, highly liquid securities and we perform periodic evaluations of the relative credit standing of the financial institutions with which we conduct business.
Restricted Cash
We classify restricted cash balances in current assets if the restriction is expected to expire or otherwise be resolved within one year and in other assets if the restriction is expected to expire or otherwise be resolved in more than one year. As of December 31, 2020 and 2019, our Noble restricted cash balance consisted of $21.7 million and $1.3 million, respectively. As of December 31, 2020 and 2019, our Finco restricted cash balance consisted of $1.7 million and $1.3 million, respectively. All restricted cash is recorded in “Prepaid expenses and other current assets.” As of December 31, 2019, our restricted cash balance was associated with our financing of the Noble Johnny Whitstine and Noble Joe Knight. As of December 31, 2020, our restricted cash balance is to comply with restrictions from a Bankruptcy Court order to settle certain professional fees incurred upon or prior to our emergence from bankruptcy.
Accounts Receivable
We record accounts receivable at the amount we invoice our clients, net of allowance for credit losses. We provide an allowance for uncollectible accounts, as necessary. Our allowance for doubtful accounts as of December 31, 2020 and 2019 was $1.1 million and $1.9 million, respectively.
Property and Equipment
Property and equipment is stated at cost, reduced by provisions to recognize economic impairment. Major replacements and improvements are capitalized. When assets are sold, retired or otherwise disposed of, the cost and related accumulated depreciation are eliminated from the accounts and the gain or loss is recognized. Drilling equipment and facilities are depreciated using the straight-line method over their estimated useful lives as of the date placed in service or date of major refurbishment. Estimated useful lives of our drilling equipment range from three to thirty years. Other property and equipment is depreciated using the straight-line method over useful lives ranging from two to forty years. Included in accounts payable were $35.3 million and $36.0 million of capital accruals as of December 31, 2020 and 2019, respectively.
Interest is capitalized on long-term construction project using the weighted average cost of debt outstanding during the period of construction.
Scheduled maintenance of equipment is performed based on the number of hours operated in accordance with our preventative maintenance program. Routine repair and maintenance costs are charged to expense as incurred; however, the costs of the overhauls and asset replacement projects that benefit future periods and which typically occur every three to five years are capitalized when incurred and depreciated over an equivalent period. These overhauls and asset replacement projects are included in “Drilling equipment and facilities” in “Note 5— Property and Equipment.”
We evaluate our property and equipment for impairment whenever there are changes in facts that suggest that the value of the asset is not recoverable. As part of this analysis, we make assumptions and estimates regarding future market conditions. When circumstances indicate that the carrying value of the assets may not be recoverable, management compares the carrying value to the expected undiscounted pre-tax
68
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
future cash flows for the associated rig for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows are lower than the carrying value, the net capitalized costs are reduced to fair value. An impairment loss is recognized to the extent that an asset's carrying value exceeds its estimated fair value. Fair value is generally estimated using a discounted cash flow model. The expected future cash flows used for impairment assessment and related fair value measurements are typically based on judgmental assessments of, but were not limited to, timing of future contract awards and expected operating dayrates, operating costs, utilization rates, discount rates, capital expenditures, reactivation costs, estimated economic useful lives and, in certain cases, our belief that a drilling unit is no longer marketable and is unlikely to return to service in the near to medium term, and considering all available information at the date of assessment. For more detailed information, see “Note 6— Loss on Impairment.”
Fair Value Measurements
We measure certain of our assets and liabilities based on a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The three-level hierarchy, from highest to lowest level of observable inputs, are as follows:
Level 1 - Valuations based on quoted prices in active markets for identical assets;
Level 2 - Valuations based on observable inputs that do not meet the criteria for Level 1, including quoted prices in inactive markets and quoted prices in active markets for similar but not identical instruments; and
Level 3 - Valuations based on unobservable inputs.
Revenue Recognition
The activities that primarily drive the revenue earned in our drilling contracts include (i) providing a drilling rig and the crew and supplies necessary to operate the rig, (ii) mobilizing and demobilizing the rig to and from the drill site, and (iii) performing rig preparation activities and/or modifications required for the contract. Consideration received for performing these activities may consist of dayrate drilling revenue, mobilization and demobilization revenue, contract preparation revenue and reimbursement revenue. We account for these integrated services provided within our drilling contracts as a single performance obligation satisfied over time and comprised of a series of distinct time increments in which we provide drilling services.
Our standard drilling contracts require that we operate the rig at the direction of the customer throughout the contract term (which is the period we estimate to benefit from the corresponding activities and generally ranges from two to 60 months). The activities performed and the level of service provided can vary hour to hour. Our obligation under a standard contract is to provide whatever level of service is required by the operator, or customer, over the term of the contract. We are, therefore, under a stand-ready obligation throughout the entire contract duration. Consideration for our stand-ready obligation corresponds to distinct time increments, though the rate may be variable depending on various factors, and is recognized in the period in which the services are performed. The total transaction price is determined for each individual contract by estimating both fixed and variable consideration expected to be earned over the term of the contract. We have elected to exclude from the transaction price measurement all taxes assessed by a governmental authority. See further discussion regarding the allocation of the transaction price to the remaining performance obligations below.
The amount estimated for variable consideration may be subject to interrupted or restricted rates and is only included in the transaction price to the extent that it is probable that a significant reversal of previously recognized revenue will not occur throughout the term of the contract (“constrained revenue”). When determining if variable consideration should be constrained, management considers whether there are factors outside the Company’s control that could result in a significant reversal of revenue as well as the likelihood and magnitude of a potential reversal of revenue. These estimates are re-assessed each reporting period as required.
Dayrate Drilling Revenue. Our drilling contracts generally provide for payment on a dayrate basis, with higher rates for periods when the drilling unit is operating and lower rates or zero rates for periods when drilling operations are interrupted or restricted. The dayrate invoices billed to the customer are typically determined based on the varying rates applicable to the specific activities performed on an hourly basis. Such dayrate consideration is allocated to the distinct hourly increment it relates to within the contract term, and therefore, recognized in line with the contractual rate billed for the services provided for any given hour.
Mobilization/Demobilization Revenue. We may receive fees (on either a fixed lump-sum or variable dayrate basis) for the mobilization and demobilization of our rigs. These activities are not considered to be distinct within the context of the contract and, therefore, the associated revenue is allocated to the overall performance obligation and the associated pre-operating costs are deferred. We record a contract liability for mobilization fees received and a deferred asset for costs. Both revenue and pre-operating costs are recognized ratably over the initial term of the related drilling contract.
69
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
In most contracts, there is uncertainty as to the amount of expected demobilization revenue due to contractual provisions that stipulate that certain conditions must be present at contract completion for such revenue to be received and as to the amount thereof, if any. For example, contractual provisions may require that a rig demobilize a certain distance before the demobilization revenue is payable or the amount may vary dependent upon whether or not the rig has additional contracted work within a certain distance from the wellsite. Therefore, the estimate for such revenue may be constrained, as described earlier, depending on the facts and circumstances pertaining to the specific contract. We assess the likelihood of receiving such revenue based on past experience and knowledge of the market conditions. In cases where demobilization revenue is expected to be received upon contract completion, it is estimated as part of the overall transaction price at contract inception and recognized in earnings ratably over the initial term of the contract with an offset to an accretive contract asset.
Contract Preparation Revenue. Some of our drilling contracts require downtime before the start of the contract to prepare the rig to meet customer requirements. At times, we may be compensated by the customer for such work (on either a fixed lump-sum or variable dayrate basis). These activities are not considered to be distinct within the context of the contract and, therefore, the related revenue is allocated to the overall performance obligation and recognized ratably over the initial term of the related drilling contract. We record a contract liability for contract preparation fees received, which is amortized ratably to contract drilling revenue over the initial term of the related drilling contract.
Bonuses, Penalties and Other Variable Consideration. We may receive bonus increases to revenue or penalty decreases to revenue. Based on historical data and ongoing communication with the operator/customer, we are able to reasonably estimate this variable consideration. We will record such estimated variable consideration and re-measure our estimates at each reporting date. For revenue estimated, but not received, we will record to “Prepaid expenses and other current assets” on our Consolidated Balance Sheets.
Capital Modification Revenue. From time to time, we may receive fees from our customers for capital improvements to our rigs to meet contractual requirements (on either a fixed lump-sum or variable dayrate basis). Such revenue is allocated to the overall performance obligation and recognized ratably over the initial term of the related drilling contract as these activities are integral to our drilling activities and are not considered to be a stand-alone service provided to the customer within the context of our contracts. We record a contract liability for such fees and recognize them ratably as contract drilling revenue over the initial term of the related drilling contract.
Revenues Related to Reimbursable Expenses. We generally receive reimbursements from our customers for the purchase of supplies, equipment, personnel services and other services provided at their request in accordance with a drilling contract or other agreement. Such reimbursable revenue is variable and subject to uncertainty, as the amounts received and timing thereof is highly dependent on factors outside of our influence. Accordingly, reimbursable revenue is constrained revenue and not included in the total transaction price until the uncertainty is resolved, which typically occurs when the related costs are incurred on behalf of a customer. We are generally considered a principal in such transactions and record the associated revenue at the gross amount billed to the customer as “Reimbursables and other” in our Consolidated Statements of Operations. Such amounts are recognized ratably over the period within the contract term during which the corresponding goods and services are to be consumed.
Deferred revenues from drilling contracts totaled $59.9 million and $65.1 million at December 31, 2020 and 2019, respectively. Such amounts are included in either “Other current liabilities” or “Other liabilities” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition. Related expenses deferred under drilling contracts totaled $13.9 million at December 31, 2020 as compared to $30.8 million at December 31, 2019 and are included in either “Prepaid expenses and other current assets,” “Other assets” or “Property and equipment, net” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition.
We record reimbursements from customers for “out-of-pocket” expenses as revenues and the related direct cost as operating expenses.
Income Taxes
Income taxes are based on the laws and rates in effect in the countries in which operations are conducted or in which we or our subsidiaries are considered resident for income tax purposes. In certain circumstances, we expect that, due to changing demands of the offshore drilling markets and the ability to redeploy our offshore drilling units, certain of such units will not reside in a location long enough to give rise to future tax consequences. As a result, no deferred tax asset or liability has been recognized in these circumstances. Should our expectations change regarding the length of time an offshore drilling unit will be used in a given location, we will adjust deferred taxes accordingly.
Deferred tax assets and liabilities are recognized for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of our assets and liabilities using the applicable jurisdictional tax rates at year-end. A valuation allowance for deferred tax assets is recorded when it is more likely than not that the deferred tax asset will not be realized in a future period.
We operate through various subsidiaries in numerous countries throughout the world, including the United States. Consequently, we are subject to changes in tax laws, treaties or regulations or the interpretation or enforcement thereof in the United States, UK and any other jurisdictions in which we or any of our subsidiaries operate or are resident. Our income tax expense is based upon our interpretation of the tax
70
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
laws in effect in various countries at the time that the expense was incurred. If the IRS or other taxing authorities do not agree with our assessment of the effects of such laws, treaties and regulations, this could have a material adverse effect on us including the imposition of a higher effective tax rate on our worldwide earnings or a reclassification of the tax impact of our significant corporate restructuring transactions. The Company has adopted an accounting policy to look through the outside basis of partnerships and all other flow-through entities and exclude these from the computation of deferred taxes.
Insurance Reserves
We maintain various levels of self-insured retention for certain losses including property damage, loss of hire, employment practices liability, employers’ liability and general liability, among others. We accrue for property damage and loss of hire charges on a per event basis.
Employment practices liability claims are accrued based on actual claims during the year. Maritime employer’s liability claims are generally estimated using actuarial determinations. General liability claims are estimated by our internal claims department by evaluating the facts and circumstances of each claim (including incurred but not reported claims) and making estimates based upon historical experience with similar claims. At December 31, 2020 and 2019, loss reserves for personal injury and protection claims totaled $30.9 million and $27.9 million, respectively, and such amounts are included in “Other current liabilities” or “Liabilities subject to compromise” in the accompanying Consolidated Balance Sheets.
Earnings per Share
Our unvested share-based payment awards, which contain non-forfeitable rights to dividends, are participating securities and are included in the computation of earnings per share pursuant to the two-class method. The two-class method allocates undistributed earnings between common shares and participating securities. The diluted earnings per share calculation under the two-class method also includes the dilutive effect of potential shares issued in connection with stock options. The dilutive effect of stock options is determined using the treasury stock method.
Share-Based Compensation Plans
We record the grant date fair value of share-based compensation arrangements as compensation cost using a straight-line method over the service period. Share-based compensation is expensed or capitalized based on the nature of the employee’s activities.
Liability-Classified Awards
The Company classified certain awards that will be settled in cash as liability awards. The fair value of a liability-classified award is determined on a quarterly basis beginning at the grant date until final vesting. Changes in the fair value of liability-classified awards are expensed or capitalized based on the nature of the employee’s activities over the vesting period of the award.
Litigation Contingencies
We are involved in legal proceedings, claims, and regulatory, tax or government inquiries and investigations that arise in the ordinary course of business. Certain of these matters include speculative claims for substantial or indeterminate amounts of damages. We record a liability when we believe that it is both probable that a loss has been incurred and the amount can be reasonably estimated. If we determine that a loss is reasonably possible and the loss or range of loss can be estimated, we disclose the possible loss in the notes to the consolidated financial statements.
We review the developments in our contingencies that could affect the amount of the provisions that has been previously recorded, and the matters and related possible losses disclosed. We make adjustments to our provisions and changes to our disclosures accordingly to reflect the impact of negotiations, settlements, rulings, advice of legal counsel, and updated information. Significant judgement is required to determine both the probability and the estimated amount.
Foreign Currency Translation
Although we are a Cayman Islands company, our functional currency is the US dollar, and we define any non-US dollar denominated currency as “foreign currencies.” In non-US locations where the US Dollar has been designated as the functional currency (based on an evaluation of factors including the markets in which the subsidiary operates, inflation, generation of cash flow, financing activities and intercompany arrangements), local currency transaction gains and losses are included in net income or loss. In non-US locations where the local currency is the functional currency, assets and liabilities are translated at the rates of exchange on the balance sheet date, while statement of operations items are translated at average rates of exchange during the year. The resulting gains or losses arising from the translation of
71
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
accounts from the functional currency to the US Dollar are included in “Accumulated other comprehensive loss” in the Consolidated Balance Sheets. We did not recognize any material gains or losses on foreign currency transactions or translations during the three years ended December 31, 2020.
Discontinued Operations
On August 1, 2014, Legacy Noble completed the separation and spin-off of a majority of its standard specification offshore drilling business (the “Spin-off”) through a pro rata distribution of all of the ordinary shares of its wholly-owned subsidiary, Paragon Offshore plc (“Paragon Offshore”), to the holders of Noble’s ordinary shares. Paragon Offshore, which had been reflected as continuing operations in our consolidated financial statements prior to the Spin-off, meets the criteria for being reported as discontinued operations and has been reclassified as such in our results of operations.
Prior to the completion of the Spin-off, Legacy Noble and Paragon Offshore entered into a series of agreements to effect the separation and Spin-off and govern the relationship between the parties after the Spin-off (the “Separation Agreements”), including the Master Separation Agreement (the “MSA”) and the Tax Sharing Agreement (the “TSA”). During the year ended December 31, 2019, we recognized charges of $3.8 million recorded in “Net loss from discontinued operations, net of tax” on our Consolidated Statement of Operations relating to settlement of Mexico customs audits from rigs included in the Spin-off. For additional information related to the Spin-off, refer to “Note 16— Commitments and Contingencies.”
Certain Significant Estimates
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our consolidated financial statements.
Accounting Pronouncements
Accounting Standards Adopted
In August 2018, the FASB issued Accounting Standards Update (“ASU”) No. 2018-14, which amends Accounting Standards Codification (“ASC”) Subtopic 715-20, “Compensation — Retirement Benefits — Defined Benefit Plans — General.” This update applies to all employers that sponsor defined benefit pension or other postretirement plans and is part of the disclosure framework project to improve the effectiveness of disclosures in notes to the financial statements. The amendment is effective for fiscal years ending after December 15, 2020. We adopted this standard effective January 1, 2020 and our adoption did not have a material effect on our consolidated financial statements.
In June 2016, the FASB issued ASU No. 2016-13 (Topic 326, “Measurement of Credit Losses on Financial Instruments”), which requires changes to the recognition of credit losses on financial instruments not accounted for at fair value through net income, including loans, debt securities, trade receivables, net investments in leases and available-for-sale debt securities. This guidance is effective for annual and interim periods beginning after December 15, 2019. Entities are required to apply the standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. We adopted this standard effective January 1, 2020 and our adoption did not have a material effect on our consolidated financial statements.
Recently Issued Accounting Standards
In December 2019, the FASB issued ASU No. 2019-12, which amends ASC Topic 740, “Income Taxes” This update simplifies the accounting for income taxes by removing certain exceptions to general principles. The amendment is effective for fiscal years beginning after December 15, 2020 and is required to be adopted on a retrospective basis for all periods presented. We do not expect the adoption of this guidance to materially affect our consolidated financial statements.
With the exception of the updated standards discussed above, there have been no new accounting pronouncements not yet effective that have significance, or potential significance, to our consolidated financial statements.

72
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Note 2— Chapter 11 Proceedings
Bankruptcy Petition and Emergence
On the Petition Date, Legacy Noble and certain of its subsidiaries, including Finco, filed voluntary petitions in the Bankruptcy Court seeking relief under chapter 11 of the Bankruptcy Code. In September 2020, the Debtors filed the Plan and the Disclosure Statement with the Bankruptcy Court and six additional subsidiaries of Legacy Noble filed voluntary petitions in the Bankruptcy Court. During the proceedings, the Debtors operated their business as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court pursuant to sections 1107 and 1108 of the Bankruptcy Code and orders of the Bankruptcy Court. To ensure the Debtors’ ability to continue operating in the ordinary course of business, on August 3, 2020, the Bankruptcy Court entered a variety of orders providing “first day” relief to the Debtors, including the authority for the Debtors to continue using their cash management system, pay employee wages and benefits and pay vendors and suppliers in the ordinary course of business. As of the Petition Date, the Company began applying ASC Topic 852, Reorganizations (“ASC 852”).
The filing of the Chapter 11 Cases constituted events of default that accelerated the Company’s obligations under the indentures governing its outstanding senior notes and under our 2017 Credit Facility. In addition, the unpaid principal and interest due under our then-outstanding senior notes and 2017 Credit Facility became immediately due and payable. As of December 31, 2020, the estimated claim amounts of our senior notes and the 2017 Credit Facility have been presented as “Liabilities subject to compromise” in our Consolidated Balance Sheet. However, any efforts to enforce such payment obligations with respect to such senior notes and 2017 Credit Facility were automatically stayed as a result of the filing of the Chapter 11 Cases, and the creditors’ rights of enforcement were subject to the applicable provisions of the Bankruptcy Code. As of December 31, 2020, we had an aggregate outstanding principal amount of approximately $3.4 billion in senior notes with stated maturities at various times from 2020 through 2045 and $545.0 million of borrowings outstanding under our 2017 Credit Facility. We elected not to make the semiannual interest payment due in respect of our Senior Notes due 2024 (the “2024 Notes”), which was due on July 15, 2020, and did not make any additional interest payments due on any senior notes through the Effective Date.
As a result of the filing of the Chapter 11 Cases, Legacy Noble’s Board of Directors determined to cancel Legacy Noble’s share ownership policy applicable to the officers and directors, and the Company will consider an appropriate policy in due course.
On the Petition Date, the Debtors entered into a Restructuring Support Agreement (together with all exhibits and schedules thereto, and as amended by the First Amendment thereto dated as of August 20, 2020, the “Restructuring Support Agreement”) with an ad hoc group of certain holders of approximately 70% of the aggregate outstanding principal amount of the outstanding Senior Notes due 2026 (the “Guaranteed Notes”) and an ad hoc group of certain holders of approximately 45% of the aggregate principal amount of our other then-outstanding senior notes, taken as a whole (the “Legacy Notes”). Legacy Noble entered into a Backstop Commitment Agreement (the “Backstop Commitment Agreement”) with the backstop parties thereto (the “Backstop Parties”) on October 12, 2020, pursuant to which the issuance of the senior secured second lien notes (the “Second Lien Notes”) as part of the rights offering contemplated by the Restructuring Support Agreement and the Plan (the “Rights Offering”) were fully backstopped by the Ad Hoc Guaranteed Group and the Ad Hoc Legacy Group (each as defined in the Restructuring Support Agreement). Participation in the Rights Offering was offered to the holders of the Guaranteed Notes and the Legacy Notes.
The Restructuring Support Agreement, among other things, provides that the Consenting Creditors (as defined in the Restructuring Support Agreement) will support the Debtors' restructuring efforts as set forth in, and subject to the terms and conditions of, the Restructuring Support Agreement. The Restructuring Support Agreement contains customary conditions, representations, and warranties of the parties and is subject to a number of conditions, including, among others, the accuracy of the representations and warranties of the parties and compliance with the obligations set forth in the Restructuring Support Agreement. The Restructuring Support Agreement also provides for termination by the parties upon the occurrence of certain events.
On the Effective Date, and pursuant to the terms of the Plan, the Company:
•Appointed five new members to the Successor’s board of directors to replace all of the directors of the Predecessor, other than the director also serving as President and Chief Executive Officer, who was re-appointed pursuant to the Plan;
•Terminated and cancelled all common stock and equity-based awards of Legacy Noble that were outstanding immediately prior to the Effective Date;
•Transferred approximately 31.7 million ordinary shares of Noble with a nominal value of $0.00001 per share (“New Shares”) to holders of the Guaranteed Notes in the cancellation of the Guaranteed Notes;
•Transferred approximately 2.1 million New Shares, approximately 8.3 million seven-year warrants with Black-Scholes protection (the “Tranche 1 Warrants”) with an exercise price of $19.27 and approximately 8.3 million seven-year warrants with Black-Scholes protection (the “Tranche 2 Warrants”) with an exercise price of $23.13 to holders of the Legacy Notes in cancellation of the Legacy Notes;
73
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
•Issued approximately 7.7 million New Shares and Second Lien Notes to participants in the Rights Offering at an aggregate subscription price of $200 million;
•Issued approximately 5.6 million New Shares to the Backstop Parties as Holdback Securities (as defined in the Backstop Commitment Agreement);
•Issued approximately 1.7 million New Shares to the Backstop Parties in respect of their backstop commitment to subscribe for Unsubscribed Securities (as defined in the Backstop Commitment Agreement);
•Issued approximately 1.2 million New Shares to the Backstop Parties in connection with the payment of the Backstop Premiums (as defined in the Backstop Commitment Agreement);
•Issued 2.8 million five-year warrants with no Black-Scholes protection (the “Tranche 3 Warrants”) with an exercise price of $124.40 to the holders of Legacy Noble’s ordinary shares outstanding prior to the Effective Date;
•Entered into a senior secured revolving credit agreement (the “Exit Credit Agreement”) that provides for a $675.0 million senior secured revolving credit facility (with a $67.5 million sublimit for the issuance of letters of credit thereunder) (the “Exit Credit Facility”);
•Entered into an exchange agreement with certain Backstop Parties which provided that, as soon as reasonably practicable after the Effective Date, the other parties to such agreement would deliver to the Company an aggregate of approximately 6.5 million New Shares issued pursuant to the Plan in exchange for the issuance of penny warrants to purchase up to approximately 6.5 million New Shares, with an exercise price of $0.01 per share (“Penny Warrants”) which were exchanged on a one-for-one basis for New Shares issued to certain initial holders of New Shares;
•Entered into an indenture governing the Second Lien Notes;
•Entered into a registration rights agreement with certain parties who received New Shares under the Plan; and
•Entered into a registration rights agreement with certain parties who received Second Lien Notes under the Plan.
Management Incentive Plan. The Plan contemplated that on or after the Effective Date, (i) the Company would adopt a long-term incentive plan and authorize and reserve 7.7 million New Shares for issuance pursuant to equity incentive awards to be granted under such plan, and (ii) the initial awards under such plan would consist of at least 40% of such shares and be made as soon as practicable after the Effective Date on the terms and conditions as determined by Noble’s Board of Directors; provided that at least 40% of such initial awards would be in the form of time-based vesting awards vesting over a period of no shorter than three years and no longer than four years. As contemplated by the Plan, on February 18, 2021, the Company adopted a long-term incentive plan and authorized and reserved 7.7 million New Shares for issuance pursuant to equity incentive awards to be granted under such plan.
Sources of Cash for Plan Distribution. All cash required for payments made by the Company under the Plan on the Effective Date was obtained from cash on hand, proceeds of the Rights Offering, and proceeds of the Exit Credit Facility.
Under ASC Topic 852, fresh start accounting is required upon emergence from Chapter 11 if (i) the value of the assets of the emerging entity immediately before the date of confirmation is less than the total of all post-petition liabilities and allowed claims; and (ii) holders of existing voting shares immediately before confirmation receive less than 50% of the voting shares of the emerging entity. The value of the assets of Legacy Noble immediately before the date of confirmation is expected to be less than the total of all postpetition liabilities and allowed claims. Additionally, the holders of the existing voting shares of Legacy Noble immediately before the date of confirmation held less than 50% of the voting shares of Noble. The same test was performed for Finco and yielded the same result. As such, Noble and Finco will adopt fresh start accounting as of the Effective Date. Adopting fresh start accounting results in a new reporting entity with no beginning retained earnings or accumulated deficit. In accordance with ASC Topic 852, with the application of fresh start accounting, the Company will be required to allocate its reorganization value to its individual assets based on their estimated fair values in conformity with ASC Topic 805, “Business Combinations.” The reorganization value represents the fair value of the Successor Company's assets before considering liabilities. The Company is in the process of evaluating the potential impact of the fresh start accounting on its consolidated financial statements. We cannot currently estimate the financial effect of emergence from bankruptcy on our financial statements, although we expect to record material adjustments related to our Plan and the application of fresh start accounting as of the Effective Date.
The Company’s financial advisor performed a valuation of the reorganized Company dated as of August 24, 2020. According to the valuation, which was included in the Disclosure Statement related to the Plan, the post-confirmation estimated enterprise value of the Company to be in a range between $1.1 billion and $1.6 billion. The following assumptions were made in the valuation of the projected amounts upon emergence; $430.0 million of debt under the Exit Financing Facility and the Second Lien Notes and cash on hand of $100.0 million.
74
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Executory Contracts
Subject to certain exceptions, under the Bankruptcy Code, the Debtors may assume, assign, or reject certain executory contracts and unexpired leases subject to the approval of the Bankruptcy Court and certain other conditions. Generally, the rejection of an executory contract or unexpired lease is treated as a pre-petition breach of such executory contract or unexpired lease and, subject to certain exceptions, relieves the Debtors from performing their future obligations under such executory contract or unexpired lease but entitles the contract counterparty or lessor to a pre-petition general unsecured claim for damages caused by such deemed breach. Typically, the assumption of an executory contract or unexpired lease requires the Debtors to cure existing monetary defaults under such executory contract or unexpired lease and provide adequate assurance of future performance. Accordingly, any description of an executory contract or unexpired lease with the Debtors in this Annual Report on Form 10-K, including where applicable a quantification of the Company’s obligations under any such executory contract or unexpired lease of the Debtors, is qualified by any overriding rejection rights the Company has under the Bankruptcy Code. As of December 31, 2020, the Debtors have rejected three immaterial executory contracts and have not rejected any unexpired leases.
Claims Reconciliation
The Debtors have filed with the Bankruptcy Court schedules and statements setting forth, among other things, the assets and liabilities of each Debtor, subject to the assumptions filed in connection therewith. These schedules and statements may be subject to further amendment or modification after filing. Certain holders of pre-petition claims that are not governmental units were required to file proofs of claim by the deadline for general claims, which was set by the Bankruptcy Court as October 6, 2020 and November 13, 2020 for the initial Debtors that filed on July 31, 2020 (the “Initial Debtors”) and the additional Debtors that filed on September 24, 2020 (the “Additional Debtors”), respectively. The governmental bar date has been set as January 27, 2021 and March 23, 2021, for the Initial Debtors and the Additional Debtors, respectively.
The Debtors received approximately 1,200 proofs of claim as of March 5, 2021 for an amount of approximately $23.0 billion. Such amount includes duplicate claims across multiple Debtor legal entities. These claims are being reconciled to amounts recorded in the Debtors’ accounting records. Differences between amounts recorded by the Debtors and claims filed by creditors will be investigated and resolved, at the direction of the Debtors, including through proceedings before the Bankruptcy Court. In addition, the Debtors have been identifying claims that have been amended or superseded, are without merit, are overstated or should be adjusted or expunged for other reasons. As a result of this process, the Debtors may identify additional liabilities that will need to be recorded or reclassified to Liabilities subject to compromise. In light of the number of claims filed, the claims resolution process will continue after the Debtors emerge from bankruptcy.
Pre-petition Charges
Pre-petition charges consist primarily of legal and other professional advisory fees incurred in relation to the Chapter 11 Cases, but prior to the Petition Date, and are presented as “Pre-petition charges” in our Consolidated Statements of Operations for the year ended December 31, 2020.
Reorganization Items, Net
In accordance with ASC Topic 852, any incremental expenses, gains and losses that are realized or incurred as of or subsequent to the Petition Date and as a direct result of the Chapter 11 Cases are recorded under “Reorganization items, net”. The following table summarizes the components of reorganization items included in our Consolidated Statements of Operations for the year ended December 31, 2020:
Noble Finco
December 31, 2020 December 31, 2020
Adjustments for estimated litigation claims (1)
(57,000) 4,500 
Write-off of debt financing costs and discount 45,469  45,469 
Professional fees (1)
37,296  2,644 
Revision of estimated claims (1,835) (1,835)
Total Reorganization items, net $ 23,930  $ 50,778 
(1)Payments of $25.6 million and $5.0 million related to professional fees and the first installment payment for the previously disclosed patent infringement settlement with Transocean Ltd. (“Transocean”) have been presented as cash outflows from operating activities in our Consolidated Statements of Cash Flows for the year ended December 31, 2020 for Noble and Finco, respectively.
75
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Liabilities Subject to Compromise
Since the Petition Date, the Company operated as a debtor-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with provisions of the Bankruptcy Code. In accordance with ASC 852, on our Balance Sheets, the caption “Liabilities subject to compromise” reflects the expected allowed amount of the pre-petition claims that are not fully secured and that have at least a possibility of not being repaid at the full claim amount. The Company has considered the chapter 11 motions approved by the Bankruptcy Court with respect to the amount and classification of its pre-petition liabilities. However, the determination of the value at which liabilities will ultimately be settled was made on the Effective Date. The Company will evaluate and adjust the amount and classification of its pre-petition liabilities through the Effective Date.
The following table summarizes the components of liabilities subject to compromise included on our Consolidated Balance Sheet as of December 31, 2020:
Noble Finco
December 31, 2020 December 31, 2020
4.900% Senior Notes due August 2020
$ 62,535  $ 62,535 
4.625% Senior Notes due March 2021
79,936  79,936 
3.950% Senior Notes due March 2022
21,213  21,213 
7.750% Senior Notes due January 2024
397,025  397,025 
7.950% Senior Notes due April 2025
450,000  450,000 
7.875% Senior Notes due February 2026
750,000  750,000 
6.200% Senior Notes due August 2040
393,596  393,596 
6.050% Senior Notes due March 2041
395,002  395,002 
5.250% Senior Notes due March 2042
483,619  483,619 
8.950% Senior Notes due April 2045
400,000  400,000 
2017 Credit Facility 545,000  545,000 
Litigation 93,000  8,000 
Accrued and unpaid interest 110,301  110,301 
Accounts payable and other liabilities 37,447  37,359 
Lease liabilities 20,969  20,969 
Total consolidated liabilities subject to compromise $ 4,239,643  $ 4,154,555 
Since the filing of the Chapter 11 Cases on the Petition Date, the Company ceased accruing interest on all debt. As a result, the Company did not record $112.9 million of contractual interest expense related to the Guaranteed Notes, Legacy Notes, and 2017 Credit Facility.
Note 3— Consolidated Joint Ventures
On December 3, 2019, we completed a transaction with a subsidiary of Royal Dutch Shell plc (“Shell”), in which Shell bought out the remaining term of its drilling contract for the drillship Noble Bully II for $166.9 million, and we acquired Shell’s 50 percent interests in the Bully I and Bully II joint ventures for $106.7 million. As a result of this transaction, the former joint venture entities became our wholly-owned subsidiaries.
Prior to this transaction, we maintained a 50 percent interest in the two joint ventures, each with Shell, that owned and operated the two Bully-class drillships. We had determined that we were the primary beneficiary of the joint ventures. Accordingly, we consolidated the entities in our consolidated financial statements after eliminating intercompany transactions. Shell’s equity interests were presented as noncontrolling interests on our Consolidated Balance Sheets.
During the years ended December 31, 2019 and 2018, the Bully joint ventures approved and paid dividends totaling $50.2 million and $55.2 million, respectively. Of these amounts, 50 percent was paid to our former joint venture partner, Shell.
During the year ended December 31, 2019, we recognized a $595.5 million impairment charge on the Noble Bully II, of which $265.0 million is attributable to Shell, our former joint venture partner. During the year ended December 31, 2018, we recognized a $550.3 million
76
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
impairment on the Noble Bully I, of which $250.3 million is attributable to our former joint venture partner. See “Note 6— Loss on Impairment” for additional information.
Note 4— Loss Per Share
The following table presents the computation of basic and diluted loss per share for Legacy Noble:
Year Ended December 31,
  2020 2019 2018
Numerator:      
Basic
Net loss from continuing operations $ (3,978,459) $ (696,769) $ (885,050)
Net loss from discontinued operations, net of tax —  (3,821) — 
Net loss attributable to Noble Corporation $ (3,978,459) $ (700,590) $ (885,050)
Diluted      
Net loss from continuing operations $ (3,978,459) $ (696,769) $ (885,050)
Net loss from discontinued operations, net of tax —  (3,821) — 
Net loss attributable to Noble Corporation $ (3,978,459) $ (700,590) $ (885,050)
Denominator:      
Weighted average shares outstanding — basic 250,792  248,949  246,614 
Weighted average shares outstanding — diluted 250,792  248,949  246,614 
Loss per share      
Basic:
Loss from continuing operations $ (15.86) $ (2.79) $ (3.59)
Loss from discontinued operations —  (0.02) — 
Net loss attributable to Noble Corporation $ (15.86) $ (2.81) $ (3.59)
Diluted:
Loss from continuing operations $ (15.86) $ (2.79) $ (3.59)
Loss from discontinued operations —  (0.02) — 
Net loss attributable to Noble Corporation $ (15.86) $ (2.81) $ (3.59)
Dividends per share $ —  $ —  $ — 
Only those items having a dilutive impact on our basic loss per share are included in diluted loss per share. For the years ended December 31, 2020, 2019 and 2018, 6.1 million, 11.9 million and 12.5 million share-based awards, respectively, were excluded from the diluted loss per share since the effect would have been anti-dilutive. On the Effective Date, all issued and outstanding shares of common stock, including all share-based awards, were cancelled and extinguished. See “Note 2— Chapter 11 Proceedings” for additional information.
Note 5— Property and Equipment
Property and equipment, at cost, for Noble consisted of the following:
Year Ended December 31,
2020 2019
Drilling equipment and facilities $ 4,476,960  $ 10,014,314 
Construction in progress 99,812  88,904 
Other 200,925  203,407 
Property and equipment, at cost $ 4,777,697  $ 10,306,625 

77
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Capital expenditures, including capitalized interest, totaled $148.2 million, $306.4 million and $281.3 million for the years ended December 31, 2020, 2019 and 2018, respectively. During the years ended December 31, 2020, 2019 and 2018, capitalized interest was zero, $9.6 million and $2.9 million, respectively.
On February 28, 2019, we purchased a new GustoMSC CJ46 rig, the Noble Joe Knight, from the PaxOcean Group in connection with a concurrently awarded drilling contract in the Middle East region. We paid $83.8 million for the rig, with $30.2 million paid in cash and the remaining $53.6 million of the purchase price financed with a loan by the seller. See “Note 7— Debt” for additional information.
During the years ended December 31, 2020, 2019 and 2018, we recognized a non-cash loss on impairment of $3.9 billion, $615.3 million and $802.1 million, respectively, related to our long-lived assets. See “Note 6— Loss on Impairment” for additional information.
For the year ended December 31, 2020, we sold six rigs, which had a net book value of $17.1 million for total proceeds of $26.7 million, resulting in a gain of $8.9 million.
Note 6— Loss on Impairment
Asset Impairments
As discussed in “Note 1— Organization and Significant Accounting Policies,” during the first quarter of 2020, the pandemic and OPEC+ production level disagreements resulted in an unprecedented steep decline in the demand for oil and a substantial surplus of oil. We considered these events to be an impairment indicator and based on our assumptions and analysis, we impaired the carrying value of four floaters. For our impaired units, the carrying values were written down to scrap value and subsequently sold in late 2020.
During the fourth quarter of 2020, the combination of the growing commitments by many of our customers to a transition to cleaner energy options, and the prolonged impacts of the pandemic, the continued oversupply of offshore drilling units placed further downward pressure on global oil demand and on our industry, potentially lengthening what was already expected to be a slow recovery. We considered these events to be an impairment indicator and based on our assumptions and analysis, we impaired the carrying value of three floaters and nine jackups. We estimated the fair values of these units using a weighting between an income valuation approach and a market approach, utilizing significant unobservable inputs, representative of a Level 3 fair value measurement. Assumptions used in our assessment included, but were not limited to, future marketability of each unit in light of the current market conditions and its current technical specifications, timing of future contract awards and expected operating dayrates, operating costs, utilization rates, discount rates, capital expenditures, market values, weighting of market values, reactivation costs, estimated economic useful lives and, in certain cases, our belief that a drilling unit is no longer marketable and is unlikely to return to service in the near to medium term.
During the quarters ended March 31, 2020 and December 31, 2020, we recognized non-cash losses on impairment of $1.1 billion and $2.8 billion, respectively, related to certain rigs and related capital spares. If we experience prolonged unfavorable changes to current market conditions, reactivation costs or dayrates or if we are unable to secure new or extended contracts for our rigs, it is reasonably possible that the estimate of undiscounted cash flows may change in the near term, resulting in the need to write down the affected assets to their corresponding estimated fair values. The impact of the current global economic turmoil on our customers’ and our business continues to be uncertain. During the year ended December 31, 2020, we recognized approximately $3.9 billion in impairment charges for seven floaters and nine jackups, and $24.0 million of impairment charges related to certain capital spare equipment.
Based upon our impairment analysis, we impaired the carrying values to their corresponding estimated fair values for two floaters, and certain capital spare equipment, which resulted in an impairment charge of approximately $615.3 million for the year ended December 31, 2019. During the year ended December 31, 2019, we recognized a $595.5 million impairment on the Noble Bully II, of which $265.0 million was attributable to our joint venture partner at the time of impairment. See “Note 3— Consolidated Joint Ventures” for additional information. For our impaired units, we estimated the fair value of these units by applying the income valuation approach utilizing significant unobservable inputs, representative of a Level 3 fair value measurement. If we experience unfavorable changes to current market conditions, reactivation costs or dayrates, or we are unable to return cold stacked rigs to service in the anticipated time frame or if we are unable to secure new or extended contracts for our active rigs, it is reasonably possible that the estimate of undiscounted cash flows may change in the near term, resulting in the need to write down the affected assets to their corresponding estimated fair values.
Based upon our impairment analysis, we impaired the carrying values to their corresponding estimated fair values for three floaters and two jackups, and certain capital spare equipment. During the year ended December 31, 2018, impairment charges related to these units and certain capital spare equipment were approximately $802.1 million. For our impaired units, we estimated the fair values of these units by applying the income valuation approach utilizing significant unobservable inputs, representative of a Level 3 fair value measurement. During the year ended December 31, 2018, we recognized a $550.3 million impairment on the Noble Bully I, of which $250.3 million was attributable to our joint venture partner at the time of impairment. See “Note 3— Consolidated Joint Ventures” for additional information.
78
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Note 7— Debt
Pre-emergence Debt
2017 Credit Facility
In December 2017, Noble Cayman Limited, a Cayman Islands company and a wholly-owned indirect subsidiary of Finco; Noble International Finance Company, a Cayman Islands company and a wholly-owned indirect subsidiary of Finco; and Noble Holding UK Limited, a company incorporated under the laws of England and Wales and a wholly-owned direct subsidiary of Legacy Noble (“NHUK”), as parent guarantor, entered into a senior unsecured credit agreement (as amended, the “2017 Credit Facility”). In July 2019, we executed a first amendment to our 2017 Credit Facility, which, among other things, reduced the maximum aggregate amount of commitments thereunder from $1.5 billion to $1.3 billion. As a result of such reduction in the maximum aggregate amount of commitments, we recognized a net loss of approximately $0.7 million in the year ended December 31, 2019.
Prior to the filing of the Chapter 11 Cases, the 2017 Credit Facility was scheduled to mature in January 2023. Borrowings were available for working capital and other general corporate purposes. The 2017 Credit Facility provided for a letter of credit sub-facility in the amount of $15.0 million, with the ability to increase such amount up to $500.0 million with the approval of the lenders. The 2017 Credit Facility had provisions that varied the applicable interest rates for borrowings based upon our debt ratings. Borrowings under the 2017 Credit Facility bore interest at LIBOR plus an applicable margin. NHUK guaranteed the obligations of the borrowers under the 2017 Credit Facility. In addition, certain indirect subsidiaries of Legacy Noble that owned rigs were guarantors under the 2017 Credit Facility.
In April 2020, we borrowed $100.0 million under the 2017 Credit Facility to pay down our indebtedness under the Seller Loans (as defined herein) as further described below. At December 31, 2020, we had $545.0 million of borrowings outstanding under the 2017 Credit Facility. At December 31, 2020, we had $8.8 million of letters of credit issued under the 2017 Credit Facility and an additional $6.0 million in letters of credit and surety bonds issued under unsecured or cash collateralized bilateral arrangements.
The filing of the Chapter 11 Cases constituted events of default that accelerated the Company’s obligations under the indentures governing our outstanding senior notes and under our 2017 Credit Facility. In addition, the unpaid principal and interest due under our indentures and the 2017 Credit Facility became immediately due and payable. However, any efforts to enforce such payment obligations with respect to our senior notes and 2017 Credit Facility were automatically stayed as a result of the filing of the Chapter 11 Cases, and the creditors’ rights of enforcement were subject to the applicable provisions of the Bankruptcy Code. See “Note 1— Organization and Basis of Presentation” for additional information.
On the Effective Date, all outstanding obligations under the 2017 Credit Facility were terminated and the holders of claims under the 2017 Credit Facility had such obligations refinanced through the Exit Credit Facility. On the Effective Date, all liens and security interests granted to secure such obligations were terminated and are of no further force and effect.
2015 Credit Facility
Effective January 2018, in connection with entering into the 2017 Credit Facility, we amended our $300.0 million senior unsecured credit facility that would have matured in January 2020 and was guaranteed by our indirect, wholly-owned subsidiaries, Noble Holding (U.S.) LLC and Noble Holding International Limited (“NHIL”), a finance subsidiary of Finco, (as amended, the “2015 Credit Facility”). As a result of the 2015 Credit Facility's reduction in the aggregate principal amount of commitments, we recognized a net loss of approximately $2.3 million in the year ended December 31, 2018. On December 20, 2019, we repaid $300.0 million of outstanding borrowings and terminated the 2015 Credit Facility.
Seller Loans
In February 2019, we purchased the Noble Joe Knight for $83.8 million with a $53.6 million seller-financed secured loan (the “2019 Seller Loan”). The 2019 Seller Loan had a term of four years and required a 5% principal payment at the end of the third year with the remaining 95% of the principal due at the end of the term. The 2019 Seller Loan bore a cash interest rate of 4.25% and the equivalent of a 1.25% interest rate paid-in-kind over the four-year term of the 2019 Seller Loan. Based on the terms of the 2019 Seller Loan, the 1.25% paid-in-kind interest rate was accelerated into the first year, resulting in an overall first year interest rate of 8.91%, of which only 4.25% was payable in cash. Thereafter, the paid-in-kind interest ended and the cash interest rate of 4.25% was payable for the remainder of the term.
In September 2018, we purchased the Noble Johnny Whitstine for $93.8 million with a $60.0 million seller-financed secured loan (the “2018 Seller Loan” and, together with the 2019 Seller Loan, the “Seller Loans”). The 2018 Seller Loan had a term of four years and required a 5% principal payment at the end of the third year with the remaining 95% of the principal due at the end of the term. The 2018 Seller Loan bore
79
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
a cash interest rate of 4.25% and the equivalent of a 1.25% interest rate paid-in-kind over the four-year term of the 2018 Seller Loan. Based on the terms of the 2018 Seller Loan, the 1.25% paid-in-kind interest rate was accelerated into the first year, resulting in an overall first year interest rate of 8.91%, of which only 4.25% was payable in cash. Thereafter, the paid-in-kind interest ended and the cash interest rate of 4.25% was payable for the remainder of the term.
Both of the Seller Loans were guaranteed by Finco and each was secured by a mortgage on the applicable rig and by the pledge of the shares of the applicable single-purpose entity that owned the relevant rig. Each Seller Loan contained a debt to total capitalization ratio requirement that such ratio not exceed 0.55 at the end of each fiscal quarter, a $300.0 million minimum liquidity financial covenant and an asset and revenue covenant substantially similar to the Guaranteed Notes, as well as other covenants and provisions customarily found in secured transactions, including a cross-default provision. Each Seller Loan required immediate repayment on the occurrence of certain events, including the termination of the drilling contract associated with the relevant rig or circumstances in connection with a material adverse effect.
In April 2020, the Company agreed with the lender under the Seller Loans to pay off 85% of the outstanding principal amount of the Seller Loans in exchange for a discount to the outstanding loan balance. On April 20, 2020, the Company made a payment of $48.1 million under the 2019 Seller Loan and $53.6 million under the 2018 Seller Loan, and, upon the lender’s receipt of such payment, interest ceased accruing, and the financial covenants set forth in the agreements relating to the Seller Loans ceased to apply. On July 20, 2020, at the conclusion of the 90-day period following the payment date, all outstanding amounts were reduced to zero, all security was released, and the Seller Loans were terminated.
As a result of the early repayment of the Seller Loans and the conclusion of the 90-day period following the payment date, we recognized gains of approximately and $17.3 million in the year ended December 31, 2020.
Senior Notes
In March 2019, we completed cash tender offers for our Senior Notes due 2020, Senior Notes due 2021, Senior Notes due 2022 and Senior Notes due 2024. Pursuant to such tender offers, we purchased $440.9 million aggregate principal amount of these senior notes for $400.0 million, plus accrued interest, using cash on hand and borrowings under the 2015 Credit Facility. As a result of these transactions, we recognized a net gain of approximately $31.3 million.
On the Effective Date, in accordance with the Plan, all outstanding obligations under our senior notes were cancelled and the indentures governing such obligations were cancelled, except to the limited extent expressly set forth in the Plan.
80
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Fair Value of Debt
Fair value represents the amount at which an instrument could be exchanged in a current transaction between willing parties. The estimated fair value of our debt instruments was based on the quoted market prices for similar issues or on the current rates offered to us for debt of similar remaining maturities (Level 2 measurement). All remaining fair value disclosures are presented in “Note 15— Fair Value of Financial Instruments.”
The following table presents the carrying value, net of unamortized debt issuance costs and discounts, and the estimated fair value of our total debt, not including the effect of unamortized debt issuance costs, respectively:
December 31, 2020 (1)
December 31, 2019
Carrying Value Estimated Fair Value Carrying Value Estimated Fair Value
Senior unsecured notes
4.900% Senior Notes due August 2020
$ 62,535  $ 1,366  $ 62,505  $ 60,660 
4.625% Senior Notes due March 2021
79,936  1,596  79,854  64,262 
3.950% Senior Notes due March 2022
21,213  354  21,181  12,170 
7.750% Senior Notes due January 2024
397,025  7,925  389,800  211,035 
7.950% Senior Notes due April 2025
450,000  8,348  446,962  228,515 
7.875% Senior Notes due February 2026
750,000  301,935  739,371  546,353 
6.200% Senior Notes due August 2040
393,596  7,966  390,526  149,134 
6.050% Senior Notes due March 2041
395,002  7,327  389,809  142,646 
5.250% Senior Notes due March 2042
483,619  9,701  478,122  176,265 
8.950% Senior Notes due April 2045
400,000  7,420  390,763  164,664 
Seller loans:
Seller-financed secured loan due September 2022 —  —  62,453  36,968 
Seller-financed secured loan due February 2023 —  —  55,658  31,175 
Credit facility:
2017 Credit Facility due to mature January 2023 545,000  545,000  335,000  335,000 
Total debt 3,977,926  898,938  3,842,004  2,158,847 
Less: Current maturities of long-term debt —  —  62,505  60,660 
Long-term debt (2)
$ —  $ —  $ 3,779,499  $ 2,098,187 
(1) Includes write-off of applicable deferred financing cost and discounts of $45.5 million. See “Note 2— Chapter 11 Proceedings” for additional information.
(2) All of our long-term debt as of December 31, 2020 has been presented as “Liabilities subject to compromise”. See “Note 2— Chapter 11 Proceedings” for additional information.
As discussed in “Note 1— Organization and Basis of Presentation,” since the Petition Date, the Company operated as a debtor-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with provisions of the Bankruptcy Code. Accordingly, all of our long-term debt obligations have been presented as “Liabilities subject to compromise” on our Consolidated Balance Sheet at December 31, 2020.
On the Effective Date, in accordance with the Plan, all outstanding obligations under our senior notes were cancelled and the indentures governing such obligations were cancelled, except to the limited extent expressly set forth in the Plan. See “Note 2— Chapter 11 Proceedings” for additional information.
81
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Post-emergence Debt
Senior Secured Exit Revolving Credit Facility
On the Effective Date, Finco and Noble International Finance Company (“NIFCO”) entered into the Exit Credit Agreement providing for the $675.0 million Exit Credit Facility and canceled all debt that existed immediately prior to the Effective Date. The Exit Credit Facility matures on July 31, 2025. Subject to the satisfaction of certain conditions, Finco may from time to time designate one or more of Finco’s other wholly-owned subsidiaries as additional borrowers under the Exit Credit Agreement (collectively with Finco and NIFCO, the “Borrowers”). As of the Effective Date, $177.5 million of loans were outstanding, and $8.8 million of letters of credit were issued, under the Exit Credit Facility.
All obligations of the Borrowers under the Exit Credit Agreement, certain cash management obligations and certain swap obligations are unconditionally guaranteed, on a joint and several basis, by Finco and certain of its direct and indirect subsidiaries (collectively with the Borrowers, the “Credit Parties”), including a guarantee by each Borrower of the obligations of each other Borrower under the Exit Credit Agreement. All such obligations, including the guarantees of the Exit Credit Facility, are secured by senior priority liens on substantially all assets of, and the equity interests in, each Credit Party, including all of the rigs owned by the Company as of the Effective Date or acquired thereafter and certain assets related thereto, in each case, subject to certain exceptions and limitations described in the Exit Credit Agreement.
The loans outstanding under the Exit Credit Facility bear interest at a rate per annum equal to the applicable margin plus, at Finco’s option, either: (i) the reserve-adjusted LIBOR or (ii) a base rate, determined as the greatest of (x) the prime loan rate as published in the Wall Street Journal, (y) the federal funds effective rate plus 1⁄2 of 1%, and (z) the reserve-adjusted one-month LIBOR plus 1%. The applicable margin is initially 4.75% per annum for LIBOR loans and 3.75% per annum for base rate loans and will be increased by 50 basis points after July 31, 2024, and may be increased by an additional 50 basis points under certain conditions described in the Exit Credit Agreement.
The Borrowers are required to pay a quarterly commitment fee to each lender under the Exit Credit Agreement, which accrues at a rate per annum equal to 0.50% on the average daily unused portion of such lender’s commitments under the Exit Credit Facility. The Borrowers are also required to pay customary letter of credit and fronting fees.
Borrowings under the Exit Credit Agreement may be used for working capital and other general corporate purposes. Availability of borrowings under the Exit Credit Agreement is subject to the satisfaction of certain conditions, including restrictions on borrowings if, after giving effect to any such borrowings and the application of the proceeds thereof, (i) the aggregate amount of Available Cash (as defined in the Exit Credit Agreement) would exceed $100 million, (ii) the Consolidated First Lien Net Leverage Ratio (as defined in the Exit Credit Agreement) would be greater than 5.50 to 1.00 and the aggregate principal amount outstanding under the Exit Credit Facility would exceed $610 million, or (iii) the Asset Coverage Ratio (as described below) would be less than 2.00 to 1.00.
Mandatory prepayments and, under certain circumstances, commitment reductions are required under the Exit Credit Facility in connection with (i) certain asset sales, asset swaps and events of loss (subject to reinvestment rights if no event of default exists) and (ii) certain debt issuances. Available Cash in excess of $150 million is also required to be applied periodically to prepay loans (without a commitment reduction). The loans under the Exit Credit Facility may be voluntarily prepaid, and the commitments thereunder voluntarily terminated or reduced, by the Borrowers at any time without premium or penalty, other than customary breakage costs.
The Exit Credit Agreement obligates Finco and its restricted subsidiaries to comply with the following financial maintenance covenants:
•as of the last day of each fiscal quarter in 2021, Adjusted EBITDA (as defined in the Exit Credit Agreement) is not permitted to be lower than (i) $70 million for the four fiscal quarter period ending March 31, 2021, (ii) $40 million for the four fiscal quarter period ending June 30, 2021 and (iii) $25 million for the four fiscal quarter periods ending on each of September 30, 2021 and December 31, 2021;
•as of the last day of each fiscal quarter ending on or after March 31, 2022, the ratio of Adjusted EBITDA to Cash Interest Expense (as defined in the Exit Credit Agreement) is not permitted to be less than (i) 2.00 to 1.00 for each four fiscal quarter period ending on or after March 31, 2022 until June 30, 2024, and (ii) 2.25 to 1.00 for each four fiscal quarter period ending thereafter; and
•for each fiscal quarter ending on or after June 30, 2021, the ratio of (x) Asset Coverage Aggregate Rig Value (as defined in the Exit Credit Agreement) to (y) the aggregate principal amount of loans and letters of credit outstanding under the Exit Credit Facility (the “Asset Coverage Ratio”) as of the last day of any such fiscal quarter is not permitted to be less than 2.00 to 1.00.
The Exit Credit Facility contains affirmative and negative covenants, representations and warranties and events of default that the Company considers customary for facilities of this type.
82
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Second Lien Notes Indenture
On the Effective Date, pursuant to the Backstop Commitment Agreement and in accordance with the Plan, Noble and Finco consummated the Rights Offering of Second Lien Notes and associated New Shares at an aggregate subscription price of $200.0 million.
On the Effective Date, Finco issued an aggregate principal amount of $216 million of Second Lien Notes, which includes the aggregate subscription price of $200.0 million plus a backstop fee of $16.0 million which was paid in kind. The Second Lien Notes mature on February 15, 2028. The Second Lien Notes are fully and unconditionally guaranteed, jointly and severally, on a senior secured second-priority basis, by the direct and indirect subsidiaries of Finco that are Credit Parties under the Exit Credit Facility. The Second Lien Notes and such guarantees are secured by senior priority liens on the assets subject to liens securing the Exit Credit Facility, including the equity interests in Finco and each guarantor of the Second Lien Notes, all of the rigs owned by the Company as of the Effective Date or acquired thereafter, certain assets related thereto, and substantially all other assets of Finco and such guarantors, in each case, subject to certain exceptions and limitations.
Interest on the Second Lien Notes accrues, at Finco’s option, at a rate of: (i) 11% per annum, payable in cash; (ii) 13% per annum, with 50% of such interest to be payable in cash and 50% of such interest to be payable by issuing additional Second Lien Notes (“PIK Notes”); or (iii) 15% per annum, with the entirety of such interest to be payable by issuing PIK Notes. Finco shall pay interest semi-annually in arrears on February 15 and August 15 of each year, commencing August 15, 2021.
On or after February 15, 2024, Finco may redeem all or part of the Second Lien Notes at fixed redemption prices (expressed as percentages of the principal amount), plus accrued and unpaid interest, if any, to, but excluding, the redemption date. Finco may also redeem the Second Lien Notes, in whole or in part, at any time and from time to time on or before February 14, 2025 at a redemption price equal to 106% of the principal amount plus accrued and unpaid interest, if any, to, but excluding, the applicable redemption date, plus a “make-whole” premium. Notwithstanding the foregoing, if a Change of Control (as defined in the Second Lien Notes Indenture) occurs prior to (but not including) February 15, 2024, then, within 120 days of such Change of Control, Finco may elect to purchase all remaining outstanding Second Lien Notes at a redemption price equal to 106% of the principal amount, plus accrued and unpaid interest, if any, to, but excluding, the applicable redemption date.
The Second Lien Notes contain covenants and events of default that the Company considers customary for notes of this type.
Note 8— Equity
Share Capital
As of December 31, 2020, Noble had approximately 251.1 million shares outstanding and trading as compared to approximately 249.2 million shares outstanding and trading at December 31, 2019. At Legacy Noble’s 2020 Annual General Meeting, Legacy Noble’s shareholders authorized its Board of Directors to increase share capital through the issuance of up to approximately 8.7 million ordinary shares (at then current nominal value of $0.01 per share). That authority to allot shares has expired on the Effective Date. Other than shares issued to Legacy Noble’s directors under the Noble Corporation 2017 Director Omnibus Plan, the authority was not used to allot shares during the year ended December 31, 2020. Pursuant to the Memorandum of Association of Noble Corporation, the share capital of Noble is $6,000 divided into 500,000,000 ordinary shares of a par value of $0.00001 each and 100,000,000 shares of a par value of $0.00001, each of such class or classes having the rights as the Board may determine from time to time.
The declaration and payment of dividends required the authorization of the Board of Directors of Legacy Noble, provided that such dividends on issued share capital may be paid only out of Legacy Noble’s “distributable reserves” on its statutory balance sheet in accordance with UK law. Therefore, Legacy Noble was not permitted to pay dividends out of share capital, which includes share premium. Noble has not paid dividends since the third quarter of 2016. The payment of future dividends will depend on our results of operations, financial condition, cash requirements, future business prospects, contractual and indenture restrictions and other factors deemed relevant by our current Board of Directors; however, at this time, we do not expect to pay any dividends in the foreseeable future.
In accordance with the Plan, all agreements, instruments and other documents evidencing, relating to or otherwise connected with any of Legacy Noble’s equity interests outstanding prior to the Effective Date, including all equity-based awards, were cancelled and all such equity interests have no further force or effect after the Effective Date. Pursuant to the Plan, the holders of Legacy Noble’s ordinary shares, par value $0.01 per share, outstanding prior to the Effective Date received their pro rata share of the Tranche 3 Warrants to acquire New Shares.
Share Repurchases
Under UK law, Legacy Noble was only permitted to purchase its own shares by way of an “off-market purchase” in a plan approved by shareholders. We currently do not have shareholder authority to repurchase shares of Legacy Noble and there is currently no share repurchase plan in place for the Successor. During the years ended December 31, 2020, 2019 and 2018, we did not repurchase any of our shares.
83
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Share-Based Compensation Plans
Stock Plans
During 2015, Noble Corporation shareholders approved a new equity plan, the Noble Corporation plc 2015 Omnibus Incentive Plan (the “Noble Incentive Plan”), which permits grants of options, stock appreciation rights (“SARs”), stock or stock unit awards or cash awards, any of which may be structured as a performance award, from time to time to employees who are to be granted awards under the Noble Incentive Plan. Neither consultants nor non-employee directors are eligible for awards under the Noble Incentive Plan. The Noble Incentive Plan replaced the Noble Corporation 1991 Stock Options and Restricted Stock Plan, as amended (the “1991 Plan”). The 1991 Plan was terminated, and equity awards have thereafter only been made under the Noble Incentive Plan. Stock option awards previously granted under the 1991 Plan remain outstanding in accordance with their terms.
During 2020, 2019 and 2018, the Noble Incentive Plan was restated and shareholders approved amendments, primarily to increase the number of ordinary shares available for issuance as long-term incentive compensation under the Noble Incentive Plan by 8.7 million, 5.8 million and 5.0 million shares, respectively. The maximum aggregate number of ordinary shares that may be granted for any and all awards under the Noble Incentive Plan will not exceed 40.0 million shares and at December 31, 2020, we had 25.0 million shares remaining available for grants to employees.
During 2017, upon shareholder approval, the Noble Corporation 2017 Director Omnibus Plan (the “Director Plan”) replaced the previous plans that were terminated. Equity awards to our non-employee directors have thereafter only been made under the Director Plan. No awards made under previous plans remain outstanding.
During 2019, shareholders approved amendments to increase the number of ordinary shares available for issuance under the Director Plan by 0.9 million shares, bringing the maximum aggregate number of ordinary shares that may be granted for any and all awards under the Director Plan to 1.8 million shares. At December 31, 2020, we had 1.0 million shares remaining for grants to non-employee directors.
Stock Options
Options have a term of 10 years, an exercise price equal to the fair market value of a share on the date of grant and generally vest over a three-year period. A summary of the status of stock options granted under the 1991 Plan as of December 31, 2020, 2019 and 2018 and the changes during the year ended on those dates is presented below:
  2020 2019 2018
Number of
Shares
Underlying
Options 		Weighted
Average
Exercise
Price 		Number of
Shares
Underlying
Options 		Weighted
Average
Exercise
Price 		Number of
Shares
Underlying
Options 		Weighted
Average
Exercise
Price
Outstanding at beginning of year 708,400  $ 30.90  1,103,242  $ 28.74  1,313,155  $ 29.51 
Expired (152,245) 32.78  (394,842) 24.85  (209,913) 33.56 
Outstanding at end of year (1)
556,155  30.39  708,400  30.90  1,103,242  28.74 
Exercisable at end of year (1)
556,155  $ 30.39  708,400  $ 30.90  1,103,242  $ 28.74 
(1)Options outstanding and exercisable at December 31, 2020 had no intrinsic value.
The following table summarizes additional information about stock options outstanding at December 31, 2020:
  Options Outstanding and Exercisable
Number of
Shares
Underlying
Options 		Weighted
Average
Remaining
Life (Years) 		Weighted
Average
Exercise
Price
$20.49 to $25.41
53,934  1.02 $ 25.41 
$25.42 to $30.59
277,177  1.09 30.59 
$30.60 to $32.78
225,044  0.10 31.33 
Total 556,155  0.68 $ 30.39 
84
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
The fair value of each option is estimated on the date of grant using a Black-Scholes pricing model. The expected term of options granted represents the period of time that the options are expected to be outstanding and is derived from historical exercise behavior, current trends and values derived from lattice-based models. Expected volatilities are based on implied volatilities of traded options on our shares, historical volatility of our shares, and other factors. The expected dividend yield is based on historical yields on the date of grant. The risk-free rate is based on the US Treasury yield curve in effect at the time of grant.
There were no non-vested stock option balances at December 31, 2020 or any changes during the year ended December 31, 2020. No new stock options were granted during the years ended December 31, 2020, 2019 and 2018. There was no compensation cost recognized during the years ended December 31, 2020, 2019 and 2018 related to stock options.
All outstanding options were cancelled as a result of the Chapter 11 Cases.
Restricted Stock Units (“RSUs”)
We have awarded both Time Vested (“TVRSUs”) and Performance Vested (“PVRSUs”) RSUs under the Noble Incentive Plan. The TVRSUs generally vest over a three-year period. The number of PVRSUs which vest will depend on the degree of achievement of specified corporate performance criteria over a three-year performance period. Depending on the date the PVRSU was awarded, these criteria consist of market based criteria or market and performance based criteria.
The TVRSUs are valued on the date of award at our underlying share price. The total compensation for units that ultimately vest is recognized over the service period. The shares and related nominal value are recorded when the restricted stock unit vests and additional paid-in capital is adjusted as the share-based compensation cost is recognized for financial reporting purposes.
The market-based PVRSUs are valued on the date of grant based on the estimated fair value. Estimated fair value is determined based on numerous assumptions, including an estimate of the likelihood that our stock price performance will achieve the targeted thresholds and the expected forfeiture rate. The fair value is calculated using a Monte Carlo Simulation Model. The assumptions used to value the PVRSUs include historical volatility and risk-free interest rates over a time period commensurate with the remaining term prior to vesting, as follows:
  2020 2019 2018
Valuation assumptions:      
Expected volatility 69.8  % 59.6  % 61.8  %
Risk-free interest rate 1.40  % 2.50  % 2.31  %
 
Additionally, similar assumptions were made for each of the companies included in the defined index and the peer group of companies in order to simulate the future outcome using the Monte Carlo Simulation Model.
A summary of the RSUs awarded for each of the years ended December 31, 2020, 2019 and 2018 is as follows:
2020 2019 2018
TVRSU      
Units awarded 5,559,678  4,639,119  3,578,212 
Weighted-average share price at award date $ 0.82  $ 3.02  $ 4.71 
Weighted-average vesting period (years) 3.0 3.0 3.0
PVRSU      
Units awarded 2,696,774  1,623,399  2,733,906 
Weighted-average share price at award date $ 0.91  $ 3.13  $ 4.55 
Three-year performance period ended December 31 2022 2021 2020
Weighted-average award date fair value $ 1.14  $ 3.61  $ 2.96 
During the years ended December 31, 2020, 2019 and 2018, we awarded zero, 280,635 and 267,204 shares, respectively, to our non-employee directors.
85
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
A summary of the status of non-vested RSUs at December 31, 2020 and changes during the year ended December 31, 2020 is presented below:
TVRSUs
Outstanding 		Weighted
Average
Award-Date
Fair Value
PVRSUs
Outstanding (1)
Weighted
Average
Award-Date
Fair Value
Non-vested RSUs at January 1, 2020 6,329,029  $ 3.89  4,854,352  $ 3.56 
Awarded 5,559,678  0.82  2,696,774  1.14 
Vested (2,924,900) 4.24  (1,063,242) 4.37 
Forfeited (6,601,307) 1.19  (3,324,771) 1.67 
Non-vested RSUs at December 31, 2020 2,362,500  $ 3.43  3,163,113  $ 3.22 
(1)For awards granted prior to 2019, the number of PVRSUs shown equals the units that would vest if the “maximum” level of performance is achieved. The minimum number of units is zero and the “target” level of performance is 50 percent of the amounts shown. For awards granted during 2020 and 2019, the number of PVRSUs shown equals the units that would vest if the “target” level of performance is achieved. The minimum number of units is zero and the “maximum” level of performance is 200 percent of the amounts shown.
At December 31, 2020, there was $3.5 million of total unrecognized compensation cost related to the TVRSUs, to be recognized over a remaining weighted-average period of 0.9 years. The total award-date fair value of TVRSUs vested during the year ended December 31, 2020 was $12.4 million.
At December 31, 2020, there was $1.7 million of total unrecognized compensation cost related to the PVRSUs, to be recognized over a remaining weighted-average period of 0.5 years. The total potential compensation for PVRSUs is recognized over the service period regardless of whether the performance thresholds are ultimately achieved.
Share-based amortization recognized during the years ended December 31, 2020, 2019 and 2018 related to all restricted stock totaled $9.2 million ($8.6 million net of income tax), $14.7 million ($14.1 million net of income tax) and $24.0 million ($21.9 million net of income tax), respectively. During the years ended December 31, 2020, 2019 and 2018, capitalized share-based amortization was zero.
All outstanding shares and equity awards were cancelled as a result of the Chapter 11 Cases.
Liability-Classified Cash Incentive Awards
In 2020, the Company granted cash incentive awards that vest over a three-year period and the final cash payment depends on the degree of achievement of specified corporate performance criteria over a three-year performance period. These criteria consist of market based criteria or market and performance based criteria. These awards were valued on the date of grant based on the estimated fair value. Estimated fair value is determined based on numerous assumptions, including an estimate of the likelihood that our stock price performance will achieve the targeted thresholds and the expected forfeiture rate. The fair value is calculated using a Monte Carlo Simulation Model. The assumptions used to value the awards include historical volatility of 69.8% and a risk-free interest rate of 1.4% over a time period commensurate with the remaining term prior to vesting. Additionally, similar assumptions were made for each of the companies included in the defined index and the peer group of companies in order to simulate the future outcome using the Monte Carlo Simulation Model.
86
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
A summary of the status of non-vested RSUs at December 31, 2020 and changes during the year ended December 31, 2020 is presented below:
Number of Awards Weighted
Average
Award-Date
Fair Value
Non-vested Liability-Classified Award at January 1, 2020 —  $ — 
Awarded 3,619,000  0.77 
Vested (1)
(2,401,362) 0.77 
Forfeited (1,217,638) 0.77 
Non-vested Liability-Classified Awards at December 31, 2020 —  $ — 
(1) As of December 31, 2020, approximately 91,362 awards are still outstanding and fully vested. The remaining balance of the vested awards were cancelled and replaced as part of the 2020 Other Cash Award Plan.
All outstanding shares and equity awards were cancelled as a result of the Chapter 11 Cases.
Note 9— Accumulated Other Comprehensive Income (Loss)
The following table presents the changes in the accumulated balances for each component of “Accumulated other comprehensive income (loss)” for the years ended December 31, 2020 and 2019. All amounts within the tables are shown net of tax.
Defined Benefit Pension Items (1)
Foreign Currency Items Total
Balance at December 31, 2018 $ (39,058) $ (18,014) $ (57,072)
Activity during period:
Other comprehensive loss before reclassifications
—  260  260 
Amounts reclassified from AOCI (1,577) —  (1,577)
Net other comprehensive loss (1,577) 260  (1,317)
Balance at December 31, 2019 $ (40,635) $ (17,754) $ (58,389)
Activity during period:
Other comprehensive income before reclassifications
—  (521) (521)
Amounts reclassified from AOCI 898  —  898 
Net other comprehensive income (loss) 898  (521) 377 
Balance at December 31, 2020 $ (39,737) $ (18,275) $ (58,012)
(1)Defined benefit pension items relate to actuarial changes and the amortization of prior service costs. Reclassifications from AOCI are recognized as expense on our Consolidated Statements of Operations through “Other income (expense).” See “Note 13— Employee Benefit Plans” for additional information.
Note 10— Revenue and Customers
Contract Balances
Accounts receivable are recognized when the right to consideration becomes unconditional based upon contractual billing schedules. Payment terms on invoiced amounts are typically 30 days. Current contract asset and liability balances are included in “Prepaid expenses and other current assets” and “Other current liabilities,” respectively, and noncurrent contract assets and liabilities are included in “Other assets” and “Other liabilities,” respectively, on our Consolidated Balance Sheets.
87
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
The following table provides information about contract assets and contract liabilities from contracts with customers:
December 31, 2020 December 31, 2019
Current contract assets $ 10,687  $ 21,292 
Noncurrent contract assets 3,174  9,508 
Total contract assets 13,861  30,800 
Current contract liabilities (deferred revenue) (34,990) (34,196)
Noncurrent contract liabilities (deferred revenue) (24,896) (30,859)
Total contract liabilities $ (59,886) $ (65,055)
Significant changes in the remaining performance obligation contract assets and the contract liabilities balances for the years ended December 31, 2020 and 2019 are as follows:
Contract Assets Contract Liabilities
Net balance at December 31, 2018 $ 47,664  $ (80,753)
Amortization of deferred costs (39,936) — 
Additions to deferred costs 23,072  — 
Amortization of deferred revenue —  65,312 
Additions to deferred revenue —  (49,614)
Total (16,864) 15,698 
Net balance at December 31, 2019 $ 30,800  $ (65,055)
Amortization of deferred costs (27,043) — 
Additions to deferred costs 10,104  — 
Amortization of deferred revenue —  57,915 
Additions to deferred revenue —  (52,746)
Total (16,939) 5,169 
Net balance at December 31, 2020 $ 13,861  $ (59,886)
Contract Costs
Certain direct and incremental costs incurred for upfront preparation, initial rig mobilization and modifications are costs of fulfilling a contract and are recoverable. These recoverable costs are deferred and amortized ratably to contract drilling expense as services are rendered over the initial term of the related drilling contract. Certain of our contracts include capital rig enhancements used to satisfy our performance obligations. These capital items are capitalized and depreciated in accordance with our existing property and equipment accounting policy.
Costs incurred for the demobilization of rigs at contract completion are recognized as incurred during the demobilization process. Costs incurred for rig modifications or upgrades required for a contract, which are considered to be capital improvements, are capitalized as drilling and other property and equipment and depreciated over the estimated useful life of the improvement.
88
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Transaction Price Allocated to the Remaining Performance Obligations
The following table reflects revenue expected to be recognized in the future related to unsatisfied performance obligations, by rig type, at the end of the reporting period:
Year Ending December 31,
2021 2022 2023 2024 2025 and beyond Total
Floaters $ 27,005  $ 13,487  $ 9,199  $ 915  $ —  $ 50,606 
Jackups 7,539  1,741  —  —  —  9,280 
Total $ 34,544  $ 15,228  $ 9,199  $ 915  $ —  $ 59,886 
The revenue included above consists of expected mobilization, demobilization, and upgrade revenue for unsatisfied performance obligations. The amounts are derived from the specific terms within drilling contracts that contain such provisions, and the expected timing for recognition of such revenue is based on the estimated start date and duration of each respective contract based on information known at December 31, 2020. The actual timing of recognition of such amounts may vary due to factors outside of our control. We have taken the optional exemption, permitted by accounting standards, to exclude disclosure of the estimated transaction price related to the variable portion of unsatisfied performance obligations at the end of the reporting period, as our transaction price is based on a single performance obligation consisting of a series of distinct hourly, or more frequent, periods, the variability of which will be resolved at the time of the future services.
Disaggregation of Revenue
The following table provides information about contract drilling revenue by rig types:
Year Ended December 31, 2020 Year Ended December 31, 2019
Floaters (1)
491,407  727,177 
Jackups 417,829  518,881 
Total (1)
909,236  1,246,058 
(1) Includes the impact of the Noble Bully II contract buyout during the year ended December 31, 2019. Exclusive of this item, revenue for the year ended December 31, 2019 would have been $560,319 for floaters and $1,079,200 for total rigs.
Note 11— Leases
Leases
We determine if an arrangement is a lease at inception. Our operating lease agreements are primarily for real estate, equipment, storage, dock space and automobiles and are included within “Other current liabilities,” “Other assets” and “Other liabilities,” on our Consolidated Balance Sheets. As discussed in “Note 1— Organization and Basis of Presentation,” since the Petition Date, the Company operated as a debtor-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with provisions of the Bankruptcy Code. Accordingly, all of the leases liabilities on the Debtor companies have been presented as “Liabilities subject to compromise” on our Consolidated Balance Sheet at December 31, 2020.
As most of our leases do not provide an implicit rate, we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. Certain of our lease agreements include options to extend or terminate the lease, which we do not include in our minimum lease terms unless management is reasonably certain to exercise and reasonably certain not to exercise, respectively.
In early January 2021, the Company entered into agreements to surrender a portion of the Sugar Land office lease and to terminate the Brook Street London office leases with the respective lessors. This will reduce the Right of Use Asset and Lease Liability by approximately $11.3 million and $11.9 million, respectively.
89
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Supplemental balance sheet information related to leases was as follows:
December 31, 2020 December 31, 2019
Operating Leases
Operating lease right-of-use assets $ 26,648  $ 33,480 
Current operating lease liabilities
1,942  6,591 
Long-term operating lease liabilities 4,969  26,778 
Weighted average remaining lease term for operating leases (years) 7.8 7.7
Weighted average discounted rate for operating leases 11.1  % 9.7  %
The components of lease cost were as follows:
Year Ended December 31, 2020 Year Ended December 31, 2019
Operating lease cost $ 9,065  $ 8,878 
Short-term lease cost 2,893  7,012 
Variable lease cost 1,265  1,620 
    Total lease cost $ 13,223  $ 17,510 
Supplemental cash flow information related to leases was as follows:
Year Ended December 31, 2020 Year Ended December 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases $ 9,614  $ 8,812 
Maturities of lease liabilities as of December 31, 2020 were as follows:
Operating Leases
2021 $ 8,594 
2022 5,545 
2023 3,567 
2024 3,629 
2025 3,687 
Thereafter 17,018 
    Total lease payments 42,040 
Less: Interest (14,343)
    Present value of lease liability (1)
$ 27,697 
(1) Includes $21.0 million of lease liabilities which are currently classified as “Liabilities subject to compromise” on our Consolidated Balance Sheet.
90
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Note 12— Income Taxes
Legacy Noble is a tax resident in the UK and, as such, is subject to UK corporation tax on its taxable profits and gains. A UK tax exemption is available in respect of qualifying dividends income and capital gains related to the sale of qualifying participations. We operate in various countries throughout the world, including the United States. The income or loss of the non-UK subsidiaries is not expected to be subject to UK corporation tax.
Consequently, we have taken account of the above exemption and provided for income taxes based on the laws and rates in effect in the countries in which operations are conducted, or in which we or our subsidiaries have a taxable presence for income tax purposes.
The components of the net deferred taxes are as follows:
  2020 2019
Deferred tax assets    
United States    
Net operating loss carry forwards $ 79,047  $ 129,695 
Disallowed interest deduction carryforwards 62,337  92,030 
Deferred pension plan amounts 10,568  10,447 
Accrued expenses not currently deductible 5,625  8,434 
Other 3,178  2,356 
Non-United States  
Net operating loss carry forwards 47,187  22,426 
Disallowed interest deduction carryforwards 13,625  13,942 
Deferred pension plan amounts 558  787 
Deferred tax assets 222,125  280,117 
Less: valuation allowance (191,835) (8,084)
Net deferred tax assets $ 30,290  $ 272,033 
Deferred tax liabilities    
United States    
Excess of net book basis over remaining tax basis $ (30,349) $ (299,136)
Other (1,796) (2,420)
Non-United States  
Excess of net book basis over remaining tax basis (5,474) (4,780)
Other (1,272) (1,342)
Deferred tax liabilities (38,891) (307,678)
Net deferred tax liabilities $ (8,601) $ (35,645)
Loss from continuing operations before income taxes consists of the following:
  Year Ended December 31,
  2020 2019 2018
United States $ (2,150,591) $ (65,062) $ (136,083)
Non-United States (2,088,271) (844,022) (1,101,093)
Total $ (4,238,862) $ (909,084) $ (1,237,176)
91
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
The income tax provision (benefit) for continuing operations consists of the following: 
  Year Ended December 31,
  2020 2019 2018
Current- United States $ (257,552) $ (34,726) $ (56,574)
Current- Non-United States 23,474  14,011  18,348 
Deferred- United States (57,514) (5,307) (67,371)
Deferred- Non-United States 31,189  (12,518) (1,044)
Total $ (260,403) $ (38,540) $ (106,641)
The following is a reconciliation of our reserve for uncertain tax positions, excluding interest and penalties.
  2020 2019 2018
Gross balance at January 1, $ 130,837  $ 161,256  $ 174,437 
Additions based on tax positions related to current year 20,266  934  97 
Additions for tax positions of prior years 206  224  25 
Reductions for tax positions of prior years (109,330) (28,542) (12,806)
Expiration of statutes (4,258) (1,629) (497)
Tax settlements —  (1,406) — 
Gross balance at December 31, 37,721  130,837  161,256 
Related tax benefits (384) (400) (1,008)
Net reserve at December 31, $ 37,337  $ 130,437  $ 160,248 
The liabilities related to our reserve for uncertain tax positions are comprised of the following:
  2020 2019
Reserve for uncertain tax positions, excluding interest and penalties
$ 37,337  $ 130,437 
Interest and penalties included in “Other liabilities” 5,164  29,232 
Reserve for uncertain tax positions, including interest and penalties
$ 42,501  $ 159,669 
At December 31, 2020, the reserves for uncertain tax positions totaled $42.5 million (net of related tax benefits of $0.4 million). If a portion or all of the December 31, 2020 reserves are not realized, the provision for income taxes could be reduced by up to $42.5 million. At December 31, 2019, the reserves for uncertain tax positions totaled $159.7 million (net of related tax benefits of $0.4 million).
It is reasonably possible that our existing liabilities related to our reserve for uncertain tax positions may fluctuate in the next 12 months primarily due to the completion of open audits or the expiration of statutes of limitation. We estimate the potential changes could range up to $14.0 million.
On March 27, 2020, the 45th President of the United States signed the CARES Act into law. The CARES Act makes significant changes to various areas of US federal income tax law by, among other things, allowing a five-year carryback period for 2018, 2019 and 2020 NOLs, accelerating the realization of remaining alternative minimum tax credits, and increasing the interest expense limitation under Section 163(j) for years 2019 and 2020. The Company recognized an income tax benefit of $39.0 million as a result of the application of the CARES Act in its 2020 financial statements. Such $39.0 million tax benefit was comprised primarily of a current income tax receivable of $151.4 million, partially offset by non-cash deferred tax expense of $112.4 million related to NOL utilization. As of December 31, 2020, we had received $134.0 million of the income tax receivable related to the CARES Act, along with an additional receipt of $4.4 million of related interest.
We include, as a component of our “Income tax benefit (provision),” potential interest and penalties related to recognized tax contingencies within our global operations. Interest and penalties resulted in an income tax benefit of $24.1 million in 2020, an income tax benefit of $3.0 million in 2019 and an income tax expense of $5.1 million in 2018.
92
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
During the year ended December 31, 2020, our income tax provision included the following non-recurring significant items:
Tax benefit related to the following:
•gross benefit of $192.4 million related to the impairment of rigs and certain capital spares partially offset by a corresponding increase in valuation allowance of $92.7 million;
•the application of the CARES Act of $39.0 million;
• release of reserves related to the closure of the 2012-2017 US tax audit of $111.9 million; and
• tax impact of an internal restructuring net of resulting adjustment of the valuation allowance of $17.9 million.
Tax expenses related to the following:
•a 2019 US return-to-provision adjustment and resulting adjustment to the valuation allowance of $21.2 million;
•an increase in UK valuation allowance of $31.1 million; and
•an increase in non-US reserve of $7.8 million.
Our gross deferred tax asset balance at year-end reflects the application of our income tax accounting policies and is based on management’s estimates, judgments and assumptions regarding realizability. If it is more likely than not that a portion of the deferred tax assets will not be realized in a future period, the deferred tax assets will be reduced by a valuation allowance based on management’s estimates. During the year ended December 31, 2020, we recorded additional valuation allowance of $183.8 million for deferred tax assets in the US, Guyana and the UK.
We conduct business globally and, as a result, we file numerous income tax returns in the US and in non-US jurisdictions. In the normal course of business, we are subject to examination by taxing authorities throughout the world, including in jurisdictions such as Brazil, Brunei, Bulgaria, Canada, Cyprus, Egypt, Ghana, Guyana, Hungary, Malta, Mexico, Nigeria, Norway, Saudi Arabia, Argentina, Australia, Denmark, Gabon, Luxembourg, Malaysia, Morocco, Myanmar, the Netherlands, Oman, Qatar, Tanzania, Timor-Leste, Singapore, Suriname, Switzerland, the United Kingdom and the United States. We are no longer subject to US Federal income tax examinations for years before 2009 and non-US income tax examinations for years before 2007.
Legacy Noble conducted substantially all of its business through Finco and its subsidiaries. The income or loss of our non-UK subsidiaries is not subject to UK income tax. Earnings are taxable in the United Kingdom at the UK statutory rate of 19 percent. The ongoing consultative process in the United Kingdom and a possible change in law could materially impact our tax rate on operations in the United Kingdom continental shelf. A reconciliation of tax rates outside of the United Kingdom and the Cayman Islands to our Legacy Noble effective rate for continuing operations is shown below:
Year Ended December 31,
2020 2019 2018
Effect of:      
Tax rates which are different than the UK and Cayman Island rates
0.4  % 4.3  % 5.0  %
Tax impact of asset impairment and disposition
4.5  % 0.3  % 2.9  %
Tax impact of restructuring
2.1  % (4.1) % —  %
Tax impact of the tax regulation change 0.9  % —  % 2.1  %
Tax impact of valuation allowance
(4.3) % 0.5  % (1.0) %
Resolution of (reserve for) tax authority audits
2.5  % 3.2  % (0.4) %
Total 6.1  % 4.2  % 8.6  %
Due to US foreign tax credit limitation constraints, for the years ended December 31, 2020, 2019 and 2018, the Company has made the determination to take foreign tax expense as a deduction against US taxable income.
At December 31, 2020, the Company asserts that its unremitted earnings and/or book/tax outside basis differences in certain of its subsidiaries are either permanently reinvested or are not expected to result in a taxable event in the foreseeable future. Therefore, no deferred taxes have been recorded related to such earnings and/or investments.
Certain of the restructuring transactions effected by the Company in connection with the Plan have a material impact on the Company, the full extent of which is still being finalized. For example, cancellation of indebtedness income resulting from such restructuring transactions
93
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
has significantly reduced the Company’s US tax attributes, including but not limited to NOL carryforwards. Further, the Plan was approved by the Bankruptcy Court on November 20, 2020. As a result, on the Effective Date, the Company experienced an ownership change under Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”), which is anticipated to subject certain remaining tax attributes to an annual limitation under Section 382 of the Code.
Note 13— Employee Benefit Plans
Defined Benefit Plans
Noble Drilling (Land Support) Limited, an indirect, wholly-owned subsidiary of Noble (“NDLS”), maintains a pension plan that covers all of its salaried, non-union employees, whose most recent date of employment is prior to April 1, 2014 (referred to as our “non-US plan”).
In addition to the non-US plan discussed above, we have a US noncontributory defined benefit pension plan that covers certain salaried employees and a US noncontributory defined benefit pension plan that covers certain hourly employees, whose initial date of employment is prior to August 1, 2004 (collectively referred to as our “qualified US plans”). These plans are governed by the Noble Drilling Employees’ Retirement Trust (the “Trust”). The benefits from these plans are based primarily on years of service and, for the salaried plan, employees' compensation near retirement. These plans are designed to qualify under the Employee Retirement Income Security Act of 1974 (“ERISA”), and our funding policy is consistent with funding requirements of ERISA and other applicable laws and regulations. We make cash contributions, or utilize credits available to us, for the qualified US plans when required. The benefit amount that can be covered by the qualified US plans is limited under ERISA and the Internal Revenue Code of 1986. Therefore, we maintain an unfunded, nonqualified excess benefit plan designed to maintain benefits for specified employees at the formula level in the qualified salaried US plan. We refer to the qualified US plans and the excess benefit plan collectively as the “US plans.”
During the fourth quarter of 2016, we approved amendments, effective as of December 31, 2016, to our non-US and US defined benefit plans. With these amendments, employees and alternate payees will accrue no future benefits under the plans after December 31, 2016. However, these amendments will not affect any benefits earned through that date.
A reconciliation of the changes in projected benefit obligations (“PBO”) for our non-US and US plans is as follows:
Years Ended December 31,
2020 2019
Non-US US Non-US US
Benefit obligation at beginning of year $ 62,485  $ 240,249  $ 54,898  $ 210,944 
Service cost —  —  —  — 
Interest cost 1,877  7,567  1,814  8,711 
Actuarial loss (gain) 7,190  28,266  6,649  29,078 
Plan amendments 104  —  —  — 
Benefits paid (2,261) (8,024) (2,821) (7,201)
Settlements and curtailments (3,751) (1,968) —  (1,283)
Foreign exchange rate changes 2,299  —  1,945  — 
Benefit obligation at end of year $ 67,943  $ 266,090  $ 62,485  $ 240,249 
94
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
A reconciliation of the changes in fair value of plan assets is as follows:
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Fair value of plan assets at beginning of year $ 76,429  $ 194,160  $ 68,597  $ 165,730 
Actual return on plan assets 8,741  36,247  8,282  35,597 
Employer contributions —  2,002  —  1,317 
Benefits paid (2,261) (8,024) (2,821) (7,201)
Settlement and curtailment (3,751) (1,968) —  (1,283)
Foreign exchange rate changes 4,650  —  2,371  — 
Fair value of plan assets at end of year $ 83,808  $ 222,417  $ 76,429  $ 194,160 
The funded status of the plans is as follows:
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Funded status $ 15,865  $ (43,673) $ 13,944  $ (46,089)

Amounts recognized in the Consolidated Balance Sheets consist of:
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Other assets (noncurrent) $ 15,865  $ —  $ 13,944  $ — 
Other liabilities (current) —  (8,169) —  (2,535)
Other liabilities (noncurrent) —  (35,504) —  (43,554)
Net amount recognized $ 15,865  $ (43,673) $ 13,944  $ (46,089)
95
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Amounts recognized in AOCI consist of:
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Net actuarial loss $ 3,108  $ 47,094  $ 4,758  $ 46,420 
Prior service cost —  —  —  — 
Deferred income tax asset (558) (9,890) (787) (9,748)
Accumulated other comprehensive loss $ 2,550  $ 37,204  $ 3,971  $ 36,672 
Pension costs include the following components:
Years Ended December 31,
2020 2019 2018
Non-US US Non-US US Non-US US
Service cost $ —  $ —  $ —  $ —  $ —  $ — 
Interest cost 1,877  7,567  1,814  8,711  1,747  8,179 
Return on plan assets (1,649) (11,676) (2,471) (10,313) (2,762) (11,914)
Amortization of prior service cost 10  —  10  —  —  — 
Recognized net actuarial loss —  2,866  —  2,771  —  1,642 
Settlement and curtailment gains 9  154  —  (37) —  135 
Net pension benefit cost (gain) $ 247  $ (1,089) $ (647) $ 1,132  $ (1,015) $ (1,958)
There is less than $0.1 million and $2.9 million estimated net actuarial losses and prior service costs for the non-US plan and the US plans, respectively, that will be amortized from AOCI into net periodic pension cost in 2021.
During the years ended December 31, 2020, 2019 and 2018, we adopted the Retirement Plan (“RP”) mortality tables with the Mortality Projection (“MP”) scale as issued by the Society of Actuaries for each of the respective years. The RP 2020, 2019 and 2018 mortality tables represent the new standard for defined benefit mortality assumptions due to adjusted life expectancies. The adoption of the updated mortality tables and the mortality improvement scales decreased our pension liability on our US plans by approximately $1.7 million, $2.1 million and $0.6 million as of December 31, 2020, 2019 and 2018.
During the fourth quarter of 2018, the UK High Court made a judgement confirming that UK pension schemes are required to equalize male and female members’ benefits for the effect of guaranteed minimum pensions (GMP). We have accounted for the impact of the GMP equalization as a plan amendment to our non-US plan, and the impact is included as a prior service cost as of December 31, 2020, which will be amortized over the average life expectancy of the members at that date.
Defined Benefit Plans—Disaggregated Plan Information
Disaggregated information regarding our non-US and US plans is summarized below:
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Projected benefit obligation $ 67,943  $ 266,090  $ 62,485  $ 240,249 
Accumulated benefit obligation 67,943  266,090  62,485  240,249 
Fair value of plan assets 83,808  222,417  76,429  194,160 
96
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
The following table provides information related to those plans in which the PBO exceeded the fair value of the plan assets at December 31, 2020 and 2019. The PBO is the actuarially computed present value of earned benefits based on service to date and includes the estimated effect of any future salary increases. Employees and alternate payees have no longer accrued future benefits under the plans since December 31, 2017.
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Projected benefit obligation $ —  $ 266,090  $ —  $ 240,249 
Fair value of plan assets —  222,417  —  194,160 
The PBO for the unfunded excess benefit plan was $9.7 million at December 31, 2020 as compared to $10.8 million in 2019, and is included under “US” in the above tables.
The following table provides information related to those plans in which the accumulated benefit obligation (“ABO”) exceeded the fair value of plan assets at December 31, 2020 and 2019. The ABO is the actuarially computed present value of earned benefits based on service to date, but differs from the PBO in that it is based on current salary levels. Employees and alternate payees have no longer accrued future benefits under the plans since December 31, 2016.
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Accumulated benefit obligation $ —  $ 266,090  $ —  $ 240,249 
Fair value of plan assets —  222,417  —  194,160 
The ABO for the unfunded excess benefit plan was $9.7 million at December 31, 2020 as compared to $10.8 million in 2019, and is included under “US” in the above tables.
Defined Benefit Plans—Key Assumptions
The key assumptions for the plans are summarized below:
  Years Ended December 31,
  2020 2019
  Non-US US Non-US US
Weighted-average assumptions used to determine benefit obligations:
Discount Rate 1.40%
1.82% -2.60%
2.10%
2.56% - 3.32%
Rate of compensation increase N/A N/A N/A N/A
  Years Ended December 31,
  2020 2019 2018
  Non-US US Non-US US Non-US US
Weighted-average assumptions used to determine periodic benefit cost:
Discount Rate 2.10%
2.56% - 3.32%
2.90%
3.65% - 4.29%
2.60%
2.84% - 3.66%
Expected long-term return on assets 2.90%
5.40% - 6.30%
3.70%
5.40% -6.50%
3.70%
5.75% -6.50%
Rate of compensation increase N/A N/A N/A N/A N/A N/A
The discount rates used to calculate the net present value of future benefit obligations for our US plans is based on the average of current rates earned on long-term bonds that receive a Moody’s rating of “Aa” or better. We have determined that the timing and amount of expected
97
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
cash outflows on our plans reasonably match this index. For our non-US plan, the discount rate used to calculate the net present value of future benefit obligations is determined by using a yield curve of high quality bond portfolios with an average maturity approximating that of the liabilities.
In developing the expected long-term rate of return on assets, we considered the current level of expected returns on risk free investments (primarily government bonds), the historical level of risk premium associated with the other asset classes in which the portfolio is invested and the expectations for future returns of each asset class. The expected return for each asset class was then weighted based on the target asset allocation to develop the expected long-term rate of return on assets for the portfolio. To assist us with this analysis, we employ third-party consultants for our US and non-US plans that use a portfolio return model.
Defined Benefit Plans—Plan Assets
Non-US Plan
As of December 31, 2020, the NDLS pension Scheme targets an asset allocation of 10.0% return-seeking securities (Growth) and 90.0% debt securities (Matching) in order to protect the strong funding position the Scheme had achieved and reduce the level of funding level volatility arising as a result of the Scheme’s investment portfolio while the Trustees and Company considered entering into a buy-out contract with an insurance provider. However, following the year end and the conclusion of the assessment of a buy-out contract, the Trustees increased the Scheme's target an asset allocation of 20.0% return-seeking securities (Growth) and 80.0% in debt securities (Matching) and recommended the de-risking strategy whereby the level of investment risk reduces as the Scheme’s funding level improves. The overall investment objective of the Scheme, as adopted by the Scheme’s Trustees, is to reach a fully funded position on the agreed de-risking basis of Gilts - 0.20% per annum. The objectives within the Scheme’s overall investment strategy is to outperform the cash + 4% per annum long term objective for Growth assets and to sufficiently hedge interest rate and inflation risk within the Matching portfolio in relation to the Scheme’s liabilities. By achieving these objectives, the Trustees believe the Scheme will be able to avoid significant volatility in the contribution rate and provide sufficient assets to cover the Scheme’s benefit obligations. To achieve this the Trustees have given Mercer, the appointed investment manager, full discretion in the day-to-day management of the Scheme’s assets and implementation of the de-risking strategy, who in turn invests in multiple underlying investment managers where appropriate. The Trustees meet with Mercer periodically to review and discuss their investment performance.
The actual fair values of the non-US plan are as follows:
  Year Ended December 31, 2020
Estimated Fair Value Measurements
Carrying Amount Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3)
Cash and cash equivalents $ 5,405  $ 5,405  $ —  $ — 
Equity securities:
International companies 4,179  4,179  —  — 
Fixed income securities:
Corporate bonds 72,407  72,407  —  — 
Other 1,817  1,817  —  — 
Total $ 83,808  $ 83,808  $ —  $ — 
98
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Year Ended December 31, 2019
Estimated Fair Value
Measurements
Carrying Amount Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3)
Cash and cash equivalents $ 903  $ 903  $ —  $ — 
Equity securities:
International companies 26,131  26,131  —  — 
Fixed income securities:
Corporate bonds 49,395  49,395  —  — 
Other —  —  —  — 
Total $ 76,429  $ 76,429  $ —  $ — 
US Plans
The fundamental objective of the US plan is to provide the capital assets necessary to meet the financial obligations made to plan participants. In order to meet this objective, the Investment Policy Statement depicts how the investment assets of the plan are to be managed in accordance with the overall target asset allocation of approximately 41.0% equity securities, 57.7% fixed income securities, and 1.3% in cash and equivalents. The target asset allocation is intended to generate sufficient capital to meet plan obligations and provide a portfolio rate of return equal to or greater than the return realized using appropriate blended, market benchmark over a full market cycle (usually a five to seven year time period). Actual allocations may deviate from the target range, however any deviation from the target range of asset allocations must be approved by the Trust’s governing committee.
For investments in mutual funds, the assets of the Trust are subject to the guidelines and limits imposed by such mutual fund’s prospectus and the other governing documentation at the fund level.
No shares of Noble were included in equity securities at either December 31, 2020 or 2019.
The actual fair values of US plan assets are as follows:
Year Ended December 31, 2020
Estimated Fair Value
Measurements
Carrying
Amount 		Quoted
Prices in
Active
Markets
(Level 1) 		Significant
Other
Observable
Inputs
(Level 2) 		Significant
Unobservable
Inputs
(Level 3)
Cash and cash equivalents $ 1,727  $ 1,727  $ —  $ — 
Equity securities:
United States 78,019  32,387  45,632  — 
International 32,310  32,310  —  — 
Fixed income securities:
Corporate bonds 83,645  82,669  976  — 
Municipal bonds —  —  — 
Treasury bonds 26,716  26,716  —  — 
Total $ 222,417  $ 175,809  $ 46,608  $ — 
99
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Year Ended December 31, 2019
Estimated Fair Value
Measurements
Carrying
Amount 		Quoted
Prices in
Active
Markets
(Level 1) 		Significant
Other
Observable
Inputs
(Level 2) 		Significant
Unobservable
Inputs
(Level 3)
Cash and cash equivalents $ 2,254  $ 2,254  $ —  $ — 
Equity securities:
United States 60,422  21,502  38,920  — 
International 23,470  23,470  —  — 
Fixed income securities:
Corporate bonds 75,131  74,253  878  — 
Municipal bonds 1,064  $ —  $ 1,064 
Treasury bonds 31,819  31,819  —  — 
Total $ 194,160  $ 153,298  $ 40,862  $ — 
Defined Benefit Plans—Cash Flows
In 2020, we made no contributions to our non-US plan and we made contributions of $2.0 million to our US plans. In 2019, we made no contributions to our non-US plan and contributions of $1.3 million to our US plans. In 2018, we made no contributions to our non-US plan and contributions of $4.6 million to our US plans. We expect our aggregate minimum contributions to our non-US and US plans in 2021, subject to applicable law, to be zero and $8.2 million, respectively. We continue to monitor and evaluate funding options based upon market conditions and may increase contributions at our discretion.
The following table summarizes our estimated benefit payments at December 31, 2020:
Payments by Period
Total 2021 2022 2023 2024 2025 Thereafter
Estimated benefit payments
Non-US plans $ 24,311  $ 2,071  $ 2,143  $ 2,218  $ 2,296  $ 2,376  $ 13,207 
US plans 115,735  17,319  9,648  10,157  10,367  10,824  57,420 
Total estimated benefit payments $ 140,046  $ 19,390  $ 11,791  $ 12,375  $ 12,663  $ 13,200  $ 70,627 
Other Benefit Plans
We sponsor a 401(k) Restoration Plan, which is a nonqualified, unfunded employee benefit plan under which specified employees may elect to defer compensation in excess of amounts deferrable under our 401(k) savings plan. The 401(k) Restoration Plan has no assets, and amounts withheld for the 401(k) Restoration Plan are kept by us for general corporate purposes. The investments selected by employees and associated returns are tracked on a phantom basis. Accordingly, we have a liability to the employee for amounts originally withheld plus phantom investment income or less phantom investment losses. We are at risk for phantom investment income and, conversely, benefit should phantom investment losses occur. At December 31, 2020 and 2019, our liability for the 401(k) Restoration Plan was $7.8 million and $8.4 million, respectively, and is included in “Accrued payroll and related costs.”
In 2005, we enacted a profit sharing plan, the Noble Drilling Services Inc. Profit Sharing Plan, which covers eligible employees, as defined in the plan. Participants in the plan become fully vested in the plan after three years of service. We sponsor other retirement, health and welfare plans and a 401(k) savings plan for the benefit of our employees. On January 1, 2019, the 401(k) savings plan and the profit sharing plan were merged into the Noble Drilling Services Inc. 401(k) and Profit Sharing Plan.
Profit sharing contributions are discretionary, require Board of Directors approval and are made in the form of cash. Contributions recorded related to this plan totaled $2.4 million, $2.4 million and $2.3 million, respectively, for three years ended December 31, 2020, 2019
100
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
and 2018. The cost of maintaining these plans for continuing operations aggregated approximately $24.9 million, $28.1 million and $25.0 million in 2020, 2019 and 2018, respectively. We do not provide post-retirement benefits (other than pensions) or any post-employment benefits to our employees.
Note 14— Derivative Instruments and Hedging Activities
We are exposed to certain concentrations of interest rate and foreign currency exchange rate risk: periodically, we enter into derivative instruments to manage our exposure to fluctuations in these rates. We have documented policies and procedures to monitor and control the use of derivative instruments. We do not engage in derivative transactions for speculative or trading purposes, nor are we a party to leveraged derivatives.
For foreign currency forward contracts, hedge effectiveness is evaluated at inception based on the matching of critical terms between derivative contracts and the hedged item. Any change in fair value resulting from ineffectiveness is recognized immediately in earnings.
Cash Flow Hedges
Several of our regional shorebases have a significant amount of their cash operating expenses payable in local currencies. To limit the potential risk of currency fluctuations, we periodically enter into forward contracts, which have historically settled monthly in the operations’ respective local currencies. All of these contracts had a maturity of less than 12 months. During 2020, we did not enter into any forward contracts. During 2019, we entered into forward contracts of approximately $15.8 million, all of which settled during 2019. At both December 31, 2020 and 2019, we had no outstanding derivative contracts.
Financial Statement Presentation
The following table, together with “Note 15— Fair Value of Financial Instruments,” summarizes the recognized gains and losses of cash flow hedges and non-designated derivatives through AOCI or as “Contract drilling services” revenue or costs for the years ended December 31, 2020 and 2019:
Year Ended December 31,
2020 2019
Gain/(loss) reclassified from AOCI to “Contract drilling services” costs
Cash flow hedges
Foreign currency forward contracts $ —  $ 320 
There were no foreign currency forward contracts outstanding as of December 31, 2020.

Note 15— Fair Value of Financial Instruments
The following tables present the carrying amount and estimated fair value of our financial instruments recognized at fair value on a recurring basis:
December 31, 2020
Estimated Fair Value Measurements
Carrying Amount Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs
(Level 2) 		Significant Unobservable Inputs
(Level 3)
Assets -
Marketable securities $ 12,326  $ 12,326  $ —  $ — 
101
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
December 31, 2019
Estimated Fair Value Measurements
Carrying Amount Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs
(Level 2) 		Significant Unobservable Inputs
(Level 3)
Assets -
Marketable securities $ 10,433  $ 10,433  $ —  $ — 
Our cash and cash equivalents, and restricted cash, accounts receivable, marketable securities and accounts payable are by their nature short-term. As a result, the carrying values included in our Consolidated Balance Sheets approximate fair value.
Note 16— Commitments and Contingencies
Transocean Ltd.
In January 2017, a subsidiary of Transocean Ltd. filed suit against us and certain of our subsidiaries seeking damages for patent infringement in a Texas federal court. The suit claimed that five of our newbuild rigs that operated in the US Gulf of Mexico violated Transocean patents relating to what is generally referred to as dual-activity drilling, and Transocean sought royalties of a $10.0 million fee and a five percent license fee for the pertinent period of operation for each vessel and damages for the breach of contract alleged in February 2019, regarding a 2007 settlement agreement that we entered into with Transocean relating to patent claims in respect of another Noble rig. On September 15, 2020, the Company entered into a settlement agreement with Transocean to settle this matter in exchange for payment by the Company of an immaterial amount to be paid in three installment payments due 2020, 2021 and 2022, which was approved by the Bankruptcy Court on October 9, 2020 and is included in “Liabilities subject to compromise” on our Consolidated Balance Sheet as of December 31, 2020.
Paragon Offshore
On August 1, 2014, Legacy Noble completed the separation and spin-off of a majority of its standard specification offshore drilling business (the “Spin-off”) through a pro rata distribution of all of the ordinary shares of its wholly-owned subsidiary, Paragon Offshore plc (“Paragon Offshore”), to the holders of Legacy Noble’s ordinary shares. Paragon Offshore filed for protection under chapter 11 of the Bankruptcy Code in February 2016, and in connection with Paragon Offshore’s emergence from bankruptcy in July 2017, all claims it may have had against Legacy Noble were transferred to a litigation trust.
On December 15, 2017, the litigation trust filed fraudulent conveyance and related claims relating to the Spin-off in an action (the “Action”) against Legacy Noble and certain of its subsidiaries (the “Noble Defendants”) and certain of Legacy Noble’s then current and former officers and directors (the “Individual Defendants”) in the Delaware bankruptcy court that heard Paragon Offshore’s bankruptcy (the “Delaware Court”). The litigation trust sought total damages of approximately $2.6 billion and unspecified amounts in respect of the claims against the officer and director defendants, all of whom had indemnification agreements with Legacy Noble.
On September 23, 2020, the Noble Defendants entered into a settlement agreement (the “Settlement Agreement”) with the litigation trust to fully and finally settle the disputes among them in the Action on the terms set forth in the Settlement Agreement and, subject to certain terms and conditions, to allow the litigation trust’s claims to proceed against the Individual Defendants in the Delaware Court. Among other things, the Settlement Agreement provided that the claims asserted by the litigation trust against each of the Noble Defendants in the Action would be allowed as a prepetition unsecured claim in the Chapter 11 Cases in the aggregate amount of $85 million, and, on account of that claim, required the Debtors to either (a) make a $10 million payment to the litigation trust, if a full settlement and release of (i) all claims brought against all defendants in the Action, including the Noble Defendants and the Individual Defendants, (ii) the Noble Defense Cost Claim (as defined in the Settlement Agreement), and (iii) the Noble Indemnity Claim (as defined in the Settlement Agreement) (a “Global Resolution”) is reached on or before October 1, 2020, or (b) if a Global Resolution was not reached on or before October 1, 2020, make an up-front payment of $7.5 million for a release of only the claims against the Noble Defendants, and bring litigation against the insurers with respect to the Individual Defendants’ director and officer’s liability insurance policies the proceeds of which would be shared with the litigation trust on the terms and conditions set forth in the Settlement Agreement and with respect to a determination of the insurance coverage for the Noble Defendants. On October 9, 2020, the Bankruptcy Court entered an order approving the Debtors' entry into the Settlement Agreement.
On February 3, 2021, the Noble Defendants, the Individual Defendants and the litigation trust entered into an agreement (the “Global Resolution Agreement”) to effectuate the global resolution contemplated by the Settlement Agreement. Pursuant to the Global Resolution Agreement, among other things, the Debtors made a $7.7 million payment into escrow which, together with $82.7 million contributed by
102
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
certain insurers, will be paid to the litigation trust upon the satisfaction of certain conditions precedent, and all claims brought against all defendants, including the Noble Defendants and Individual Defendants will be settled and released. The Global Resolution Agreement was subject to approval by the Delaware Court, which approval was granted on February 24, 2021. All claims related to the Action have now been fully settled.
Tax matters
The Internal Revenue Service (“IRS”) has completed its examination procedures, including all appeals and administrative reviews, for the taxable years ended December 31, 2012 through December 31, 2017. In May 2020, the IRS examination team notified us that it was no longer proposing any adjustments with respect to our tax reporting for the taxable years ended December 31, 2012 through December 31, 2017. Subsequent to our filing of an Application for Tentative Refund with the IRS under the CARES Act in the months of April and August 2020, the IRS informed us that it would be conducting a limited scope examination of the taxable years ended December 31, 2012, 2013, 2014, 2018 and 2019. In the first quarter of 2020, we filed a foreign tax credit refund claim for taxable year 2009. The IRS is currently auditing taxable year 2009 in relation to our refund claim. We believe that we have accurately reported all amounts in our returns.
Audit claims of approximately $96.1 million attributable to income and other business taxes were assessed against Noble entities in Mexico related to tax years 2007, 2009 and 2010, in Australia related to tax years 2013 to 2016, in Guyana related to tax years 2019 and 2020 and in Saudi Arabia related to tax years 2015 to 2018. We intend to vigorously defend our reported positions and believe the ultimate resolution of the audit claims will not have a material adverse effect on our consolidated financial statements.
We operate in a number of countries throughout the world and our tax returns filed in those jurisdictions are subject to review and examination by tax authorities within those jurisdictions. We recognize uncertain tax positions that we believe have a greater than 50 percent likelihood of being sustained upon challenge by a tax authority. We cannot predict or provide assurance as to the ultimate outcome of any existing or future assessments.
Other contingencies
    Legacy Noble had entered into agreements with certain of our executive officers, as well as certain other employees. These agreements were effective upon a change of control of Noble (within the meaning set forth in the agreements) or a termination of employment in connection with or in anticipation of a change of control, and remained effective for three years thereafter. These agreements provided for compensation and certain other benefits under such circumstances. On the Effective Date of our emergence from the Chapter 11 Cases, the Legacy Noble agreements were superseded by new employment agreements.
We are a defendant in certain claims and litigation arising out of operations in the ordinary course of business, including personal injury claims, the resolution of which, in the opinion of management, will not be material to our financial position, results of operations or cash flows. There is inherent risk in any litigation or dispute and no assurance can be given as to the outcome of these claims.
103
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Note 17— Segment and Related Information
We report our contract drilling operations as a single reportable segment, Contract Drilling Services, which reflects how we manage our business. The mobile offshore drilling units comprising our offshore rig fleet operate in a global market for contract drilling services and are often redeployed to different regions due to changing demands of our customers, which consist primarily of large, integrated, independent and government-owned or controlled oil and gas companies throughout the world. As of December 31, 2020, our contract drilling services segment conducts contract drilling operations in Canada, Far East Asia, the Middle East, the North Sea, Oceania, South America and the US Gulf of Mexico.
The following table presents revenues and identifiable assets by country based on the location of the service provided:
Revenues for Year Ended December 31, Identifiable Assets as of December 31,
2020 2019 2018 2020 2019
Australia $ 50,434  $ 33,623  $ —  $ 30,498  $ 244,244 
Brazil —  —  —  14,184  8,910 
Brunei —  —  3,080  —  — 
Bulgaria —  61,525  84,757  —  — 
Canada 28,915  46,147  47,085  4,579  199,696 
Curacao —  —  —  —  75,776 
Denmark 7,662  31,076  35,855  —  238,413 
East Timor —  —  33,733  —  — 
Egypt —  49,209  112,473  —  — 
Gabon 147  —  —  4,509  4,160 
Guyana 222,088  132,414  50,839  1,824,921  1,807,296 
Malaysia —  251,497  91,052  9,199  30,012 
Mexico —  —  —  1,297  28,032 
Myanmar 21,084  56,207  16,572  —  151,116 
Qatar 31,024  36,948  35,180  24,024  219,569 
Saudi Arabia 133,246  154,807  156,989  398,093  673,884 
Singapore —  —  1,769  —  — 
Suriname 61,474  17,374  (3) 585,994  599,659 
Tanzania —  —  381  —  — 
Trinidad and Tobago 9,468  —  —  19,031  — 
United Arab Emirates —  —  (17) 52,266  31,150 
United Kingdom 180,610  243,063  194,602  749,416  1,373,524 
United States 209,401  191,548  218,479  545,926  2,599,057 
Vietnam 8,719  —  —  —  — 
Total $ 964,272  $ 1,305,438  $ 1,082,826  $ 4,263,937  $ 8,284,498 
Note 18— Supplemental Financial Information
Consolidated Balance Sheets Information
Deferred revenues from drilling contracts totaled $59.9 million and $65.1 million at December 31, 2020 and 2019, respectively. Such amounts are included in either “Other current liabilities” or “Other liabilities” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition. Related expenses deferred under drilling contracts totaled $13.9 million at December 31, 2020 as compared to $30.8 million at December 31, 2019, and are included in either “Prepaid expenses and other current assets,” “Other assets” or “Property and equipment, net” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition.
104
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
Consolidated Statements of Cash Flows Information
Operating cash activities
The net effect of changes in other assets and liabilities on cash flows from operating activities is as follows:
Noble Finco
December 31, December 31,
2020 2019 2018 2020 2019 2018
Accounts receivable $ 50,802  $ 2,057  $ 3,974  $ 19,588  $ 2,057  $ 3,974 
Other current assets (866) 3,573  (2,722) 7,830  4,046  (2,700)
Other assets (2,369) 16,218  (10,378) (800) 18,749  (6,424)
Accounts payable 357  (2,279) 14,955  (11,018) (2,182) 14,795 
Other current liabilities 8,582  (4,700) (13,940) 16,055  (4,549) (13,495)
Other liabilities (10,941) (24,577) (26,829) (10,941) (24,577) (26,829)
Total net change in assets and liabilities $ 45,565  $ (9,708) $ (34,940) $ 20,714  $ (6,456) $ (30,679)
Non-cash investing and financing activities
Additions to property and equipment, at cost for which we had accrued a corresponding liability in accounts payable as of December 31, 2020, 2019 and 2018 were $35.3 million, $36.0 million and $52.1 million, respectively.
We entered into the $60.0 million 2018 Seller Loan to finance a portion of the purchase price for the Noble Johnny Whitstine in September 2018. We entered into the $53.6 million 2019 Seller Loan to finance a portion of the purchase price for the Noble Joe Knight in February 2019. See “Note 7— Debt” for additional information.
Additional cash flow information is as follows:
Noble Finco
December 31, December 31,
2020 2019 2018 2020 2019 2018
Cash paid during the period for:
Interest, net of amounts capitalized $ 138,040  $ 289,457  $ 286,506  $ 138,040  $ 289,457  $ 286,506 
Income taxes paid (refunded), net (133,708) 8,181  (107,554) (133,708) 8,181  (107,554)
Note 19— Combined Debtor-In-Possession Financial Information
The financial statements included below represent the combined financial statements of the Debtors only. These statements reflect the results of operations, financial position and cash flows of the combined Debtor subsidiaries, including certain amounts and activities between Debtor and non-Debtor subsidiaries of the Company, which are eliminated in the consolidated financial statements.

105
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)

COMBINED DEBTORS’ BALANCE SHEET
(In thousands)
December 31, 2020
ASSETS
Current assets
Cash and cash equivalents $ 201,239 
Accounts receivable 117,179 
Receivables from non-debtor affiliates 2,921,225 
Taxes receivable 24,475 
Prepaid expenses and other current assets 58,973 
Short-term notes receivable from non-debtor affiliates 365,112 
Total current assets 3,688,203 
Property and equipment, at cost 4,728,956 
Accumulated depreciation (1,184,698)
Property and equipment, net 3,544,258 
Investment in non-debtor affiliates 19,622,028 
Receivables from non-debtor affiliates 551,368 
Other assets 60,173 
Total assets $ 27,466,030 
LIABILITIES AND EQUITY
Current liabilities
Accounts payable $ 76,190 
Accounts payable to non-debtor affiliates 36,140 
Accrued payroll and related costs 31,327 
Taxes payable 24,865 
Other current liabilities 40,652 
Total current liabilities 209,174 
Deferred income taxes 8,678 
Other liabilities 99,441 
Liabilities subject to compromise, inclusive of payables to non-debtor affiliates of $6,217,729
10,457,372 
Total liabilities 10,774,665 
Total debtors’ equity
16,691,365 
Total liabilities and debtors’ equity $ 27,466,030 
106
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
COMBINED DEBTORS’ STATEMENTS OF OPERATIONS
(In thousands)
Year Ended December 31, 2020
Operating revenues
Contract drilling services $ 717,655 
Reimbursables and other 53,284 
Non-debtor affiliates 103,551 
874,490 
Operating costs and expenses
Contract drilling services 477,144 
Reimbursables 47,794 
Depreciation and amortization 372,663 
General and administrative 120,497 
Pre-petition charges 14,409 
Loss on impairment 3,914,608 
4,947,115 
Operating loss (4,072,625)
Other income (expense)
Interest expense, net of amounts capitalized (164,421)
Interest expense from non-debtor affiliates (33,421)
Gain on extinguishment of debt, net 17,254 
Interest income and other, net 9,548 
Interest income from non-debtor affiliates 31,751 
Reorganization items, net (23,930)
Loss from continuing operations before income taxes (4,235,844)
Income tax benefit (provision) 247,021 
Net loss $ (3,988,823)
107
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)
COMBINED DEBTORS’ STATEMENTS OF CASH FLOWS
(In thousands)
Year Ended December 31, 2020
Cash flows from operating activities
Net loss $ (3,988,823)
Adjustments to reconcile net loss to net cash flow from operating activities:
Depreciation and amortization 372,663 
Loss on impairment 3,914,608 
Reorganization items, net (17,366)
Gain on extinguishment of debt, net (17,254)
Deferred income taxes (26,435)
Amortization of share-based compensation 9,169 
Other costs, net (42,020)
Changes in components of working capital:
Change in taxes receivable 28,117 
Net changes in other operating assets and liabilities (274,902)
Net changes in other operating assets and liabilities with non-debtor affiliates (143,759)
Net cash used in operating activities (186,002)
Cash flows from investing activities
Capital expenditures (148,028)
Proceeds from disposal of assets, net 26,999 
Net cash used in investing activities (121,029)
Cash flows from financing activities
Borrowings on credit facilities 210,000 
Repayments of senior notes (101,132)
Cash paid to settle equity awards (1,010)
Other financing activities with non-debtor affiliates 348,107 
Taxes withheld on employee stock transactions (418)
Net cash provided by financing activities 455,547 
Net increase in cash, cash equivalents and restricted cash 148,516 
Cash, cash equivalents and restricted cash, beginning of period 73,682 
Cash, cash equivalents and restricted cash, end of period $ 222,198 
108
NOBLE CORPORATION (formerly known as Noble Holding Corporation plc) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOBLE FINANCE COMPANY (formerly known as Noble Corporation) AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar and share amounts in tables are in thousands)

Note 20— Unaudited Interim Financial Data
Unaudited interim consolidated financial information from continuing operations for Noble is as follows:
Quarter Ended
March 31 June 30 September 30 December 31
2020
Operating revenues
$ 281,311  $ 237,918  $ 241,836  $ 203,207 
Operating income (loss)
(1,132,555) (95,453) (18,875) (2,829,662)
Net loss from continuing operations
(1,062,677) (42,194) (50,868) (2,822,720)
Net loss per share from continuing operations attributable to Noble (1)
Basic
Loss from continuing operations (4.25) (0.17) (0.20) (11.24)
Diluted
Loss from continuing operations (4.25) (0.17) (0.20) (11.24)
  Quarter Ended
  March 31 June 30 September 30 December 31
2019        
Operating revenues
$ 282,888  $ 292,936  $ 275,526  $ 454,088 
Operating loss
(23,812) (118,710) (640,012) 116,261 
Net loss from continuing operations
(67,068) (151,960) (444,871) (32,870)
Net loss from discontinued operations, net of tax
(3,821) —  —  — 
Net loss per share from continuing operations attributable to Noble (1)
Basic
Loss from continuing operations (0.27) (0.61) (1.79) (0.13)
Loss from discontinued operations (0.02) —  —  — 
Diluted
Loss from continuing operations (0.27) (0.61) (1.79) (0.13)
Loss from discontinued operations (0.02) —  —  — 
(1)Net loss per share is computed independently for each of the quarters presented. Therefore, the sum of the quarters’ net loss per share may not equal the total computed for the year.
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
Item 9A. Evaluation of Disclosure Controls and Procedures
Noble Corporation
Conclusions Regarding Disclosure Controls and Procedures
Robert W. Eifler, President and Chief Executive Officer (Principal Executive Officer) of Noble, and Richard B. Barker, Senior Vice President and Chief Financial Officer (Principal Financial Officer) of Noble, have evaluated the disclosure controls and procedures of Noble as of the end of the period covered by this report. On the basis of this evaluation, Mr. Eifler and Mr. Barker have concluded that Noble’s disclosure controls and procedures were effective as of December 31, 2020. Noble’s disclosure controls and procedures are designed to ensure that information required to be disclosed by Noble in the reports that it files with or submits to the SEC are recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management as appropriate to allow timely decisions regarding required disclosure.
109

Changes in Internal Control Over Financial Reporting
There were no changes in Noble’s internal control over financial reporting that occurred during the quarter ended December 31, 2020 that have materially affected, or are reasonably likely to materially affect, the internal control over financial reporting of Noble.
Management’s Annual Report on Internal Control Over Financial Reporting
The management of Noble is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rule 13a-15(f) promulgated under the US Securities Exchange Act of 1934, as amended.
Internal control over financial reporting includes the controls themselves, monitoring (including internal auditing practices), and actions taken to correct deficiencies as identified. There are inherent limitations to the effectiveness of internal control over financial reporting, however well designed, including the possibility of human error and the possible circumvention or overriding of controls. The design of an internal control system is also based in part upon assumptions and judgments made by management about the likelihood of future events, and there can be no assurance that an internal control will be effective under all potential future conditions. As a result, even an effective system of internal controls can provide no more than reasonable assurance with respect to the fair presentation of financial statements and the processes under which they were prepared.
Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013. Based on the assessment by management of Noble, Noble maintained effective internal control over financial reporting as of December 31, 2020.
PricewaterhouseCoopers LLP, the independent registered public accounting firm that audited our financial statements included in this Annual Report on Form 10-K, has audited the effectiveness of internal control over financial reporting as of December 31, 2020 as stated in their report, which is provided in Part II, Item 8, “Financial Statements and Supplementary Data” in this Annual Report on Form 10-K.
Noble Finance Company
Conclusions Regarding Disclosure Controls and Procedures
Robert W. Eifler, President and Chief Executive Officer (Principal Executive Officer) of Finco, and Richard B. Barker, Director, Senior Vice President and Chief Financial Officer (Principal Financial Officer) of Finco, have evaluated the disclosure controls and procedures of Finco as of the end of the period covered by this report. On the basis of this evaluation, Mr. Eifler and Mr. Barker have concluded that Finco’s disclosure controls and procedures were effective as of December 31, 2020. Finco’s disclosure controls and procedures are designed to ensure that information required to be disclosed by Finco in the reports that it files with or submits to the SEC are recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management as appropriate to allow timely decisions regarding required disclosure.
Changes in Internal Control Over Financial Reporting
There were no changes in Finco’s internal control over financial reporting that occurred during the quarter ended December 31, 2020 that have materially affected, or are reasonably likely to materially affect, the internal control over financial reporting of Finco.
Management’s Annual Report on Internal Control Over Financial Reporting
The management of Finco is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rule 13a-15(f) promulgated under the US Securities Exchange Act of 1934, as amended.
Internal control over financial reporting includes the controls themselves, monitoring (including internal auditing practices), and actions taken to correct deficiencies as identified. There are inherent limitations to the effectiveness of internal control over financial reporting, however well designed, including the possibility of human error and the possible circumvention or overriding of controls. The design of an internal control system is also based in part upon assumptions and judgments made by management about the likelihood of future events, and there can be no assurance that an internal control will be effective under all potential future conditions. As a result, even an effective system of internal controls can provide no more than reasonable assurance with respect to the fair presentation of financial statements and the processes under which they were prepared.
Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control—
110

Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013. Based on the assessment by management of Finco, Finco maintained effective internal control over financial reporting as of December 31, 2020.
PricewaterhouseCoopers LLP, the independent registered public accounting firm that audited our financial statements included in this Annual Report on Form 10-K, has audited the effectiveness of internal control over financial reporting as of December 31, 2020 as stated in their report, which is provided in Part II, Item 8, “Financial Statements and Supplementary Data” in this Annual Report on Form 10-K.
Item 9B. Other Information.
None.

111

PART III
Item 10. Directors, Executive Officers and Corporate Governance.
The information required by this item will be provided in an amendment to this Annual Report on Form 10-K/A.
Item 11. Executive Compensation.
The information required by this item will be provided in an amendment to this Annual Report on Form 10-K/A.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
The information required by this item will be provided in an amendment to this Annual Report on Form 10-K/A.
Item 13. Certain Relationships and Related Transactions and Director Independence.
The information required by this item will be provided in an amendment to this Annual Report on Form 10-K/A.
Item 14. Principal Accounting Fees and Services.
The information required by this item will be provided in an amendment to this Annual Report on Form 10-K/A.

112


PART IV
Item 15. Exhibits, Financial Statement Schedules.
(a)The following documents are filed as part of this report:
(1)A list of the financial statements filed as a part of this report is set forth in Item 8 on page 52 and is incorporated herein by reference.
(2)Financial Statement Schedules:
All schedules are omitted because they are either not applicable or required information is shown in the financial statements or notes thereto.
(3)Exhibits:
     The information required by this Item 15(a)(3) is set forth in the Index to Exhibits accompanying this Annual Report on Form 10-K and is incorporated herein by reference.
Item 16. Form 10-K Summary.
None.
113

Index to Exhibits
Exhibit
Number 		Exhibit
2.1
2.2
2.3
2.4
3.1
3.2
3.3
3.4
4.1
10.1*
10.2*
10.3*
114

Exhibit
Number 		Exhibit
10.4*
10.5*
10.6*
10.7*
10.8*
10.9*
10.10*
10.11*
10.12*
10.13*
10.14*
10.15*
10.16*
115

Exhibit
Number 		Exhibit
10.17*
10.18*
10.19*
10.20*
10.21*†
10.22*†
10.23*
10.24*
10.25*†
10.26†
10.27†
10.28†
116

Exhibit
Number 		Exhibit
10.29†
10.30†
10.31
10.32†
10.33
10.34
10.35
10.36
10.37
10.38
117

Exhibit
Number 		Exhibit
10.39*
10.40*
10.41*
10.42*
10.43*
10.44
10.45*
10.46*
21.1
22
31.1
31.2
31.3
31.4
118

Exhibit
Number 		Exhibit
32.1+
32.2+
32.3+
32.4+
101.INS Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH Inline XBRL Taxonomy Extension Schema Document.
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB Inline XBRL Taxonomy Extension Label Linkbase Document.
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104 Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
______________________________________________________
*    Management contract or compensatory plan or arrangement.
†    Certain portions of the exhibit have been omitted. The Company agrees to furnish a supplemental copy with any omitted information to the SEC upon request.
+    Furnished in accordance with Item 601(b)(32)(ii) of Regulation S-K.

119

SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Noble Corporation, a Cayman Islands company
 
March 12, 2021 By: /s/ Robert W. Eifler
    Robert W. Eifler
President and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
/s/ Robert W. Eifler   March 12, 2021
Robert W. Eifler
President and Chief Executive Officer
(Principal Executive Officer)
  Date
/s/ Richard B. Barker March 12, 2021
Richard B. Barker
Senior Vice President and Chief Financial Officer
(Principal Financial Officer) 		Date
/s/ Laura D. Campbell   March 12, 2021
Laura D. Campbell
Vice President, Chief Accounting Officer and Controller
(Principal Accounting Officer) 		  Date
/s/ Patrick J. Bartels, Jr. March 12, 2021
Patrick J. Bartels, Jr.
Director 		Date
/s/ Alan J. Hirshberg March 12, 2021
Alan J. Hirshberg
Director 		Date
/s/ Ann Pickard March 12, 2021
Ann Pickard
Director 		Date
/s/ Charles Sledge March 12, 2021
Charles Sledge
Director 		Date
/s/ Melanie M. Trent March 12, 2021
Melanie M. Trent
Director 		Date
120

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Noble Finance Company, a Cayman Islands company
March 12, 2021 By: /s/ Robert W. Eifler
    Robert W. Eifler
President and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
/s/ Robert W. Eifler   March 12, 2021
Robert W. Eifler
President and Chief Executive Officer
(Principal Executive Officer)
  Date
/s/ Richard B. Barker   March 12, 2021
Richard B. Barker
Director, Senior Vice President and Chief Financial Officer
(Principal Financial Officer) 		  Date
     
/s/ Laura D. Campbell   March 12, 2021
Laura D. Campbell
Vice President and Controller
(Principal Accounting Officer) 		  Date
/s/ David M.J. Dujacquier March 12, 2021
David M.J. Dujacquier
Director 		Date
/s/ Brad A. Baldwin March 12, 2021
Brad A. Baldwin
Director 		Date

121
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