Noble Corporation plc
10 Brook Street
London W1S 1BG
www.noblecorp.com
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Noble Corporation plc
2018 Annual Report
Noble Corporation plc Financial Highlights
Operating Revenues
From Continuing Operations
Net Income / (Loss)
From Continuing Operations
Diluted Income / (Loss)
From Continuing Operations Per Share
2018 (1)
1,082,826
2017 (1)
1,236,915
2016 (1)
$2,302,065
2015 (1)
$3,352,252
2014 (1)
$3,232,504
Year Ended December 31,
(885,050)
(515,025)
(929,580)
511,000
(152,011)
(3.59)
(2.10)
(3.82)
2.06
(0.60)
Cash Flow from Operations (2)
171,851
416,675
1,142,740
1,764,907
1,778,627
Total Assets (3)
Total Debt (3) (4)
Total Equity
9,264,923
10,794,659
11,440,117
12,865,645
13,266,480
3,877,402
4,045,710
4,340,111
4,462,562
4,848,678
4,654,574
5,950,628
6,467,445
7,422,230
7,287,034
All numbers in thousands, except per share data
(1) Results for 2018, 2017, 2016, 2015, and 2014 include impairment charges of $802 million, $122 million, $1.5 billion, $418 million
and $745 million, respectively.
(2) Certain amounts in prior periods have been reclassified to conform to the current year presentation. In accordance with our adoption of
Accounting Standard Update No. 2016-9, excess tax benefits are now classified as an operating activity and employee taxes paid for share-based
payment arrangements are now classified as a financing activity on the Consolidated Statement of Cash Flows.
(3) Certain amounts in prior periods have been reclassified to conform to the current year presentation. In accordance with our adoption of
Accounting Standard Update No. 2015-3, unamortized debt issuance costs related to our senior notes are now shown as a direct reduction
of the carrying amount of the related debt.
(4) Consists of Long-term debt and Current maturities of long-term debt.
On the cover: Sunrise off the bow of the Noble Clyde Boudreaux, a recently reactivated
semisubmersible operating offshore Myanmar for PTTEP.
The ultra-deepwater drillship Noble Tom Madden
operating offshore Guyana for ExxonMobil.
Investor Information
Shareholders, brokers, securities analysts or portfolio managers
seeking information about Noble Corporation plc should
contact Jeff Chastain, Vice President – Investor Relations, Noble
Drilling Services Inc., by phone at 281-276-6100 or by e-mail at
jlchastain@noblecorp.com.
Forward Looking Statements
Any statements included in this 2018 Annual Report that are not
historical facts, including without limitation regarding future
market trends and results of operations are forward-looking
statements within the meaning of the applicable securities law.
Please see “Forward-Looking Statements” in this 2018 Annual
Report for more information.
Corporate Information
Transfer Agent and Registrar
Computershare Trust Company, N.A.
Canton, Massachusetts
Independent Registered Public Accounting Firm
PricewaterhouseCoopers LLP
Houston, Texas
Independent Auditors
PricewaterhouseCoopers LLP
London, UK
Shares Listed on
New York Stock Exchange
Trading Symbol “NE”
Form 10-K
A copy of Noble Corporation plc’s 2018 Annual Report on Form
10-K, as filed with the U.S. Securities and Exchange Commission,
will be furnished without charge to any shareholder upon written
request to:
William E. Turcotte
General Counsel & Corporate Secretary
Noble Corporation plc
10 Brook Street
London W1S 1BG
Annual Meeting
The Annual Meeting of Shareholders of Noble Corporation plc
will be held on April 26, 2019, at 3:00 p.m. local time at The Ritz
Hotel in London, England.
Contact the Board
If you would like to contact the Noble Corporation plc Board of
Directors, send an e-mail to nobleboard@noblecorp.com
or write to:
Noble Corporation plc
Board of Directors
10 Brook Street
London W1S 1BG
For additional information about Noble Corporation plc, please
refer to our proxy statement which is being mailed or made
available with this Annual Report.
Board of Directors
Julie H. Edwards 2, 3, 4
Former Senior Vice President & Chief Financial Officer
Southern Union Company
Director since 2006.
Gordon T. Hall 2, 3, 4, 6
Chairman of the Board
Archrock, Inc.
Director since 2009.
Roger W. Jenkins 1, 5
President and Chief Executive Officer
Murphy Oil Corporation
Director since 2018.
Scott D. Josey 1, 5
Chairman & Chief Executive Officer
Sequitur Energy Resources, LLC
Director since 2014.
Jon A. Marshall 2, 3, 5
Former President & Chief Operating Officer
Transocean Inc.
Director since 2009.
Mary P. Ricciardello 1, 4
Former Senior Vice President & Chief Accounting Officer
Reliant Energy, Inc.
Director since 2003.
Julie J. Robertson
Chairman, President & Chief Executive Officer
Noble Corporation plc
Director since 2017.
1 Audit Committee
3 Finance Committee
5 Health, Safety, Environment and Engineering Committee
6 Lead Director
2 Compensation Committee
4 Nominating and Corporate Governance Committee
Corporate Officers
Julie J. Robertson
Chairman, President & Chief Executive Officer
Adam C. Peakes
Senior Vice President & Chief Financial Officer
William E. Turcotte
Senior Vice President, General Counsel & Corporate Secretary
Scott W. Marks
Senior Vice President – Engineering
Robert W. Eifler
Senior Vice President – Marketing & Contracts
Laura D. Campbell
Vice President and Controller
To Our Shareholders
The offshore drilling industry continues to await
robust recovery. However, despite the various
hurdles that the industry may face, at Noble, we
still saw encouraging signs of improvement.
There is little doubt that weakness in crude oil and natural gas prices and the
recent interruption in sustainable trading patterns of these commodities have led
to our customers demonstrating a disciplined approach to the business, including a
commitment to spend within the limits of a restricted amount of annual cash flow and
allocation of capital that has frequently subordinated offshore programs.
However, recent activities by our customers imply that interest in offshore
prospects is once again emerging. The resource potential found in many of the world’s
offshore basins has continued to expand, while our customers’ cost per barrel of crude
oil equivalent to access this growing potential has seldom been lower. At the same
time, our industry is experiencing important and much needed fundamental change,
and we believe the lack of recent meaningful investment in offshore production will
be a catalyst in an improving market for our services. Together, these important
developments should set the stage for a robust business environment, and we certainly
experienced encouraging signs of an improving market in 2018.
Indications of Growing Offshore Interest
Customer interest in emerging offshore basins is rapidly building due, in part, to
improving access and successful exploration results. Guyana, Brazil, Suriname and
Mexico offer excellent recent examples of basins where exploration and production
companies have gained access to expansive offshore acreage while the resource potential
of these areas is increasingly supported by encouraging exploration results. In 2018,
five of the 18 announced deepwater discoveries worldwide were located in these four
basins. Offshore Guyana, where exceptional resource potential is particularly evident,
12 out of 13 exploration probes to date have located hydrocarbons. It is worth noting
that Noble is a leading provider of drilling services in this region with two of our ultra-
deepwater drillships located there. We expect exploration in these areas, and in others
around the world, to experience gradual improvement as operators identify offshore
prospects with excellent resource potential that can support future production growth
and reserve replacement.
Growing interest from operators is not limited to the emerging frontier regions.
Activity in mature offshore basins is also expected to expand due to a combination of
changes in ownership of producing and undeveloped acreage, exploration success, and
the presence of established offshore infrastructure that provides a quick and efficient
path to commercialization. The North Sea has been a prime example of activity
supported by new owners in mature basins.
Finally, exploration and production companies are experiencing increased success
in utilizing technological advances that lower the cost of doing business offshore
while delivering improved results in exploration and field recovery. Enhanced seismic
acquisition and expedited imaging technologies are also creating value for our
customers and should lead to increased offshore activity.
Improvement in Industry Fundamentals
In addition to the mounting evidence of growing offshore interest from operators,
2018 saw a healthy increase in bidding and award activity, including a welcomed
improvement in the floating rig category. Jackup demand has continued to improve,
particularly for high specification units which has led to improving margins for those
assets.
Also, the industry’s total rig supply declined further in 2018 as more rigs were
retired from service. Among the industry’s floating rig fleet, 18 units were retired in
2018, bringing the total number of floating rig retirements since 2014 to 126 units,
with additional retirements likely in the future. Noble has been an active participant
in fleet rationalization, having retired approximately one-third of our fleet since late
2014. These rig retirements, combined with the addition of new, high specification
assets, have resulted in one of the industry’s youngest, most modern fleets. Noble’s
average fleet age is only six years as we begin 2019.
Positioning Noble for Industry Recovery
We believe the early stages of recovery in the offshore drilling industry have begun.
As a result of this outlook, we have taken several actions in 2018 and into 2019 to
strengthen our customer base and further improve our ability to compete in what will
remain a competitive industry environment. These actions were led by our acquisition
of two newbuild jackups. The attractively priced rigs, the Noble Johnny Whitstine and
Noble Joe Knight, have both received multi-year contracts for operations in the Middle
East. These modern, fit-for-purpose drilling solutions are expected to remain active in
the region well into the future.
We believe
a prolonged
period of under-
investment by
exploration
and production
companies over
recent years
will provide the
eventual
catalyst for
increased offshore
rig demand.
Also, in keeping with our improved industry outlook,
we completed reactivation programs for five premium
rigs, including four ultra-deepwater floating units and
a high-specification jackup. Recognizing our customers’
preference for premium rigs with proven performance
records, we moved decisively to position each unit to
compete for an expanding list of contract opportunities in
2018 and beyond. Our intended objective was achieved, as
all of the reactivation projects were executed successfully,
with each of the five units securing contracts. Even better,
new contract opportunities are now visible, increasing the
likelihood that each of these rigs will remain contractually
engaged well into or beyond 2019, as demonstrated by the
recent contract award for the drillship Noble Tom Madden
in Guyana.
I also believe efforts to focus our fleet in key geographies
have advantageously positioned our premium jackup and
floating rigs for a growing number of contract opportunities
as customer demand strengthens. In our jackup fleet, 11 of
our 13 units are, or will soon be, located in the North Sea
and Middle East regions where numerous customer needs
are outstanding, including an estimated 50 rig-years of
customer demand in the Middle East.
Our marketed premium floating fleet is concentrated in the Western Hemisphere
where enormous resource potential is driving heightened ultra-deepwater exploration
interest and multi-year development opportunities. We have already established
ourselves as a leading service provider in some regions, such as Guyana, and we
have an established and successful history in others, such as the U.S. Gulf of Mexico,
Suriname, Mexico and Brazil, attractive locations to which we maintain prompt access.
In 2018, for the second consecutive year, we established record results in fleet
uptime and safety performance as measured by our total recordable incident rate.
More impressively, these important measures of operational execution were achieved
during a year in which we increased our active fleet by four rigs and expanded our
headcount by 10 percent. Safety performance and operational excellence have long
been hallmarks at Noble and will continue to contribute to our success going forward.
Conclusion
We believe a prolonged period of under-investment by exploration and production
companies over recent years will provide the eventual catalyst for increased offshore
rig demand. Recent actions by our customers are encouraging and should eventually
support heightened offshore activities. As we enter 2019, Noble is better positioned
to capture this expected growth in customer activity, and we remain committed to
maintaining our foundation and culture of safe, environmentally respectful and
efficient service delivery through the cycle.
Thank you for your continued interest in Noble. I extend my gratitude on behalf
of our Board of Directors to the entire Noble team for their exemplary hard work and
dedication to pursuing excellence at all times. I look forward to success in the New Year
as we extend the achievements of 2018.
Julie J. Robertson
Chairman, President &
Chief Executive Officer
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, 2018
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 plc
(Exact name of registrant as specified in its charter)
England and Wales (Registered Number 08354954)
(State or other jurisdiction of
incorporation or organization)
98-0619597
(I.R.S. employer
identification number)
10 Brook Street, London, England, W1S1BG
(Address of principal executive offices) (Zip Code)
Registrant’s Telephone Number, Including Area Code: +44 20 3300 2300
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Name of each exchange on which registered
Shares, Nominal Value $0.01 per Share
New York Stock Exchange
Commission file number: 001-31306
_____________________________________________________________________________________________________
Noble Corporation
(Exact name of registrant as specified in its charter)
Cayman Islands
(State or other jurisdiction of
incorporation or organization)
98-0366361
(I.R.S. employer
identification number)
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
Securities registered pursuant to Sections 12(b) and 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
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
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
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
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or
information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.
Indicate by check mark whether 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
(Check one):
“large
in Rule 12b-2 of
the Exchange Act.
“emerging growth
“accelerated
accelerated
company,”
company”
reporting
“smaller
No
No
No
filer,”
filer,”
No
and
Noble Corporation plc:
Large accelerated filer
Accelerated filer
Non-accelerated filer
Smaller reporting company
Emerging growth company
Noble Corporation:
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 each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes
As of June 30, 2018, the aggregate market value of the registered shares of Noble Corporation plc held by non-affiliates of the registrant was $1.5 billion based on the closing sale price on June 29, 2018 as
reported on the New York Stock Exchange.
Number of shares outstanding and trading at February 19, 2019: Noble Corporation plc — 248,704,351
Number of shares outstanding: Noble Corporation — 261,245,693
No
DOCUMENTS INCORPORATED BY REFERENCE
The proxy statement for the 2019 annual general meeting of the shareholders of Noble Corporation plc will be incorporated by reference into Part III of this Form 10-K.
This Form 10-K is a combined annual report being filed separately by two registrants: Noble Corporation plc, a public limited company incorporated under the laws of England and Wales (“Noble-
UK”), and its wholly-owned subsidiary, Noble Corporation, a Cayman Islands company (“Noble-Cayman”). Noble-Cayman meets the conditions set forth in General Instructions I(1)(a), (b) and
(d) of Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format contemplated by General Instructions I(2)(a) and (c) of Form 10-K.
1
TABLE OF CONTENTS
Business
Risk Factors
Unresolved Staff Comments
Properties
Legal Proceedings
Mine Safety Disclosures
Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Selected Financial Data
Management's Discussion and Analysis of Financial Condition and Results of Operations
PART I
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
PART II
Item 5.
Item 6.
Item 7.
Item 7A.
Quantitative and Qualitative Disclosures About Market Risk
Item 8.
Item 9.
Item 9A.
Item 9B.
PART III
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
PART IV
Item 15.
Item 16.
Financial Statements and Supplementary Data
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
Controls and Procedures
Other Information
Directors, Executive Officers and Corporate Governance
Executive Compensation
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Certain Relationships, Related Transactions and Directors Independence
Principal Accounting Fees and Services
Exhibits, Financial Statement Schedules
Form 10-K Summary
SIGNATURES
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This combined Annual Report on Form 10-K is separately filed by Noble Corporation plc, a public limited company incorporated under
the laws of England and Wales (“Noble-UK”), and Noble Corporation, a Cayman Islands company (“Noble-Cayman”). Information in this filing
relating to Noble-Cayman is filed by Noble-UK and separately by Noble-Cayman on its own behalf. Noble-Cayman makes no representation as
to information relating to Noble-UK (except as it may relate to Noble-Cayman) or any other affiliate or subsidiary of Noble-UK.
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-UK and its consolidated subsidiaries, including Noble-Cayman.
2
Forward-Looking Statements
This Annual Report on Form 10-K includes “forward-looking statements” within the meaning of Section 27A of the U.S. Securities Act of
1933, as amended (the “Securities Act”), and Section 21E of the U.S. 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
rig demand, the offshore drilling market, oil prices, contract backlog, fleet status, our future financial position, business strategy, impairments,
repayment of debt, credit ratings, liquidity, borrowings under our Credit Facilities (as defined herein) 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, shipyard risks and timing, delays in
mobilization of rigs, industry conditions, access to financing, impact of competition, governmental regulations and permitting, availability of labor
and spare parts, 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,” “estimate,” “expect,” “intend,” “may,” “plan,”
“project,” “should” 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. 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 SEC filings, among others. Such risks and uncertainties are beyond our ability to
control, and in many cases, we cannot predict the risks and uncertainties that could cause our actual results to differ materially from those indicated
by the forward-looking statements. You should consider these risks when you are evaluating us.
3
PART I
Item 1. Business.
Overview
Noble Corporation plc, a public limited company incorporated under the laws of England and Wales (“Noble-UK”), 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.
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 February 19, 2019, our fleet of 24 drilling rigs consisted of eight drillships,
four semisubmersibles and 12 jackups. On February 14, 2019, we exercised an option to purchase an additional jackup and expect to complete
the purchase in late February 2019.
Noble Corporation, a Cayman Islands company (“Noble-Cayman”), is an indirect, wholly-owned subsidiary of Noble-UK, our publicly-
traded parent company. Noble-UK’s principal asset is all of the shares of Noble-Cayman. Noble-Cayman has no public equity outstanding. The
consolidated financial statements of Noble-UK include the accounts of Noble-Cayman, and Noble-UK conducts substantially all its business
through Noble-Cayman and its subsidiaries.
On August 1, 2014, Noble-UK 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 the ordinary shares of its wholly-owned subsidiary, Paragon Offshore plc (“Paragon Offshore”),
to the holders of Noble’s ordinary shares. The results of operations for Paragon Offshore prior to the Spin-off date and incremental Spin-off related
costs have been classified as discontinued operations for all periods presented in this Annual Report on Form 10-K. For additional information
regarding the Spin-off and certain matters relating to Paragon Offshore, see Part I, Item 1A, “Risk Factors” and Part II, Item 7, “Management’s
Discussion and Analysis of Financial Condition and Results of Operations— Executive Overview— Spin-off of Paragon Offshore plc” and Part
II, Item 8, “Financial Statements and Supplementary Data, Note 15— Commitments and Contingencies.”
Drilling Services
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 wells;
payment of compensation to us (generally in U.S. 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 or (ii) if operations are
suspended for a specified period of time due to breakdown of equipment or breach of contract;
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.
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.
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.
4
During periods of depressed market conditions, such as the one we are currently experiencing, 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 24 offshore drilling units, consisting of eight drillships, four semisubmersibles and 12 jackups, 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, 2018, our fleet was located in Canada, Far East Asia, the Middle East, the North Sea, Oceania, the Black
Sea, South America and the U.S. Gulf of Mexico.
Drillships
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. There are currently eight drillships in Noble's fleet, capable of water
depths from 8,200 feet to 12,000 feet.
Semisubmersibles
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 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 four semisubmersible drilling units, two of which are equipped with mooring systems and two of which
utilize DPS, with fleet diversity to operate in mid-water, deepwater and ultra-deepwater depth ranges with high levels of efficiency.
Jackups
Noble's fleet of modern, high-specification jackup drilling units give 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. 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 standard 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 with drilling hookloads greater than 2,500,000 pounds.
5
Offshore Fleet
The following table presents certain information concerning our offshore fleet at February 19, 2019. We own and operate all of the units included
in the table.
Make
Year Built
or Rebuilt (1)
Water Depth
Rating (feet)(2)
Name
Drillships—8
Noble Bob Douglas
Noble Bully I (4)
Noble Bully II (4)
Noble Don Taylor
Noble Globetrotter I
Noble Globetrotter II
Noble Sam Croft
Noble Tom Madden
Semisubmersibles—4
Noble Clyde Boudreaux
Noble Danny Adkins
Noble Jim Day
Noble Paul Romano
GustoMSC P10000
GustoMSC Bully PRD 12000
GustoMSC Bully PRD 12000
GustoMSC P10000
Globetrotter Class
Globetrotter Class
GustoMSC P10000
GustoMSC P10000
2013 N
2011 N
2011 N
2013 N
2011 N
2013 N
2014 N
2014 N
F&G 9500 Enhanced Pacesetter
Bingo 9000-DP
Bingo 9000-DP
Noble EVA-4000™
2007 R/M
2009 R
2010 R
1998 R/ 2007
M/ 2013 R
Independent Leg Cantilevered Jackups—12 (6)
Noble Hans Deul (5)
Noble Houston Colbert (5)
Noble Joe Beall
Noble Johnny Whitstine
Noble Lloyd Noble (5)
Noble Mick O’Brien (5)
Noble Regina Allen (5)
Noble Roger Lewis (5)
Noble Sam Hartley (5)
Noble Sam Turner (5)
Noble Scott Marks (5)
Noble Tom Prosser (5)
F&G JU-2000E
F&G JU-3000N
Modec 300C-38
GustoMSC CJ46-x100-D
GustoMSC CJ70-x150-ST
F&G JU-3000N
F&G JU-3000N
F&G JU-2000E
F&G JU-3000N
F&G JU-3000N
F&G JU-2000E
F&G JU-3000N
2009 N
2014 N
2004 R
2018 N
2016 N
2013 N
2013 N
2007 N
2014 N
2014 N
2009 N
2014 N
12,000
8,200
10,000
12,000
10,000
10,000
12,000
12,000
10,000
12,000
12,000
6,000
400
400
300
375
500
400
400
400
400
400
400
400
Drilling
Depth
Capacity
(feet)
40,000
40,000
40,000
40,000
30,000
30,000
40,000
40,000
35,000
35,000
35,000
25,000
30,000
30,000
25,000
30,000
32,000
30,000
30,000
30,000
30,000
30,000
30,000
30,000
Location
Status (3)
Guyana
Curaçao
Malaysia
U.S. Gulf of Mexico
Egypt
Bulgaria
U.S. Gulf of Mexico
Guyana
Myanmar
U.S. Gulf of Mexico
U.S. Gulf of Mexico
U.S. Gulf of Mexico
U.K.
Qatar
Saudi Arabia
Singapore
U.K.
Qatar
Canada
Saudi Arabia
U.K.
Denmark
Saudi Arabia
Australia
Active
Stacked
Active
Active
Active
Active
Available
Active
Active
Stacked
Stacked
Available
Active
Active
Active
Shipyard
Active
Active
Active
Active
Active
Active
Active
Available
(1)
(2)
(3)
(4)
(5)
(6)
Rigs designated with an “R” were modified, refurbished or otherwise upgraded in the year indicated by capital expenditures in an amount
deemed material by management. Rigs designated with an “N” are newbuilds. Rigs designated with an “M” have been upgraded to the
Noble NC-5SM mooring standard.
Rated water depth for drillships and semisubmersibles reflects the maximum water depth in which a floating rig has been designed for
drilling operations.
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.
We own and operate the Noble Bully I and Noble Bully II through joint ventures with a subsidiary of Shell. Under the terms of the joint
venture agreements, each party has an equal 50 percent ownership stake in both vessels.
Harsh environment capability.
On February 14, 2019, we exercised our option to purchase another GustoMSC CJ46 rig, to be known as the Noble Joe Knight, and we
expect to complete the purchase in late February 2019. The Jackups Rig list and rig counts shown do not include the Noble Joe Knight.
6
Market
The offshore contract drilling industry is a highly competitive and cyclical business characterized by large capital expenditures and large
swings in pricing. Demand for offshore drilling equipment is driven by the exploration and development programs of oil and gas companies, which
in turn are influenced by many factors, including the price of oil and gas, the availability and relative cost of onshore oil and gas resources, general
global economic conditions, energy demand, 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 equipment well-maintained and technologically competitive.
We maintain a global operational presence and compete in most of the major offshore oil and gas basins worldwide. All of 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.
Demand for our services is, in significant part, a function of the worldwide demand for oil and gas and the global supply of mobile offshore
drilling units. Our industry experienced a significant increase in the number of drilling units prior to and during the period in which crude oil
prices declined precipitously and were highly volatile and in which the supply of onshore oil and gas resources expanded greatly. This combination
of increased supply of drilling rigs and reduced demand for such rigs has resulted in falling dayrates and heightened competition for opportunities
to re-contract our rigs upon expiry of existing contracts.
We believe that improvements in market conditions will ultimately result from, among other things, improved oil prices, additional investment
by our customers in offshore exploration and development, and attrition of rigs in the global offshore fleet. Our young and technologically advanced
fleet is well positioned to compete now and in the future as market dynamics improve.
Significant Customers
Offshore contract drilling operations accounted for approximately 96 percent, 98 percent and 97 percent of our operating revenues for the
years ended December 31, 2018, 2017 and 2016, respectively. During the three years ended December 31, 2018, 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 U.S.
Gulf of Mexico. Revenues from Royal Dutch Shell plc (“Shell”), Equinor ASA (“Equinor” formerly known as “Statoil ASA”) and Saudi Arabian
Oil Company (“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. Revenues from Shell, Equinor and Saudi Aramco accounted for approximately 45.0
percent, 13.2 percent and 11.4 percent, respectively, of our consolidated operating revenues for the year ended December 31, 2017. Revenues
from Shell and Freeport-McMoRan Inc. (“Freeport”) accounted for approximately 37.5 percent and 24.5 percent, respectively, of our consolidated
operating revenues for the year ended December 31, 2016. No other customer accounted for more than 10 percent of our consolidated operating
revenues in 2018, 2017 or 2016.
On May 10, 2016, Freeport, Freeport-McMoRan Oil & Gas LLC and one of our subsidiaries entered into an agreement terminating the
contracts on the Noble Sam Croft and the Noble Tom Madden (“FCX Settlement”), which were scheduled to end in July 2017 and November 2017,
respectively. During 2016, we recognized approximately $393.0 million in “Contract drilling services revenue” associated with the FCX Settlement.
Excluding the $393.0 million of revenue attributable to the FCX Settlement our primary customers during 2016 would have been Shell, Anadarko
Petroleum Corporation and Freeport, accounting for approximately 45.0 percent, 11.0 percent and 9.0 percent of our consolidated operation
revenues, respectively.
Employees
At December 31, 2018, we had approximately 2,000 employees, excluding approximately 1,000 persons we engaged through labor
contractors or agencies. Approximately 84 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 place considerable value on the involvement 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 Noble Advances, our state of the art training facility in Sugar Land, Texas.
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We are committed to a policy of recruitment and promotion based upon merit without discrimination. Management actively pursues both
the employment of disabled persons whenever a suitable vacancy arises and the continued employment and retraining of employees who become
disabled while employed by the Company. Training and development is undertaken for all employees, including disabled persons.
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 and operation of drilling units, environmental discharges and related recordkeeping, safety
management systems, the reduction of greenhouse gas emissions to address climate change, currency conversions and repatriation, oil and gas
exploration and development, taxation of offshore earnings and earnings of expatriate personnel 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 the Organization of Petroleum Exporting Countries (“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 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, results in reduced demand for our services or imposes 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 environmental 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 U.S. Department of Interior, through
the Bureau of Ocean Energy Management (“BOEM”) and the Bureau of Safety and Environmental Enforcement (“BSEE”), has undertaken an
aggressive overhaul of the offshore oil and natural gas regulatory process that has significantly impacted oil and gas development in the U.S. Gulf
of Mexico. From time to time, new rules, regulations and requirements have been proposed and implemented by BOEM, BSEE or the United
States Congress that materially limit or prohibit, and increase the cost of, offshore drilling. We are also subject to the Ports and Waterways Safety
Act (“PWSA”) and similar regulations, which impose certain operational requirements on offshore rigs operating in the U.S. and governs liability
for vessel or cargo loss, or damage to life, property, or the marine environment. See Part I, Item 1A, “Risk Factors —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” for additional information.
Spills and Releases. The U.S. Oil Pollution Act of 1990 (“OPA”), the Comprehensive Environmental Response, Compensation, and Liability
Act in the U.S. (“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 U.S.
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 regulation, 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.
8
Waste Handling. The U.S. 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 U.S. operations.
Water Discharges. The U.S. 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 U.S. Coast Guard 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. We do not anticipate that compliance with these laws will cause a material
impact on our operations or financial condition.
Air Emissions. The U.S. 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. There is increasing attention concerning the issue of climate change and the effect of greenhouse gas (“GHG”) emissions.
The United States Environmental Protection Agency (“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 drillships. 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. 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. Incentives to conserve energy
or use alternative energy sources could have a negative impact on our business if such incentives reduce the worldwide demand for oil and gas.
See Part I, Item1A, “Risk Factors— 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 a 21 percent GHG reduction from these sectors
between 2005 and 2020. The ETS program will continue to require GHG reductions in the future. Phase 4 of the ETS program (covering 2021
to 2030) was revised in 2018 to achieve emission reduction targets as part of the EU’s contribution to the Paris Agreement. Phase 4 targets a 43
percent GHG reduction between 2005 and 2030.
In addition, the United Kingdom (“UK”) government, which implements ETS in the UK North Sea, has introduced a carbon price floor
mechanism to place an incrementally increasing minimum price on carbon. Thus, the cost of compliance with 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 diesel fuel (Scope 1) aboard all of our vessels worldwide is the Company’s primary source of GHG
emissions, including carbon dioxide, methane and nitrous oxide. The data necessary to report indirect emissions from generation of purchased
power (Scope 2) has not been previously collected; however, procedures are being established to collect and report Scope 2 data.
For the year ended December 31, 2018, our estimated carbon dioxide equivalent (“CO2e”) gas emissions were 954,944 tonnes as compared
to 918,439 tonnes for the year ended December 31, 2017. When expressed as an intensity measure of tonnes of CO2e gas emissions per dollar of
contract drilling revenues from continuing operations, the intensity measure for December 31, 2018 and 2017 was .0009 and .0008, respectively.
9
The increase in emissions is due to increases in operational activity from the Noble Tom Madden, Noble Sam Croft, Noble Lloyd Noble, Noble
Tom Prosser and activation of the Noble Clyde Boudreaux.
Our Scope 1 CO2e 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).”
It is our intent to have the procedures related to GHG emissions independently assessed in the future.
Worker Safety. The U.S. 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 MARPOL, including Annex VI to MARPOL which sets limits on sulfur dioxide and nitrogen oxide emissions
from ship exhausts and prohibits deliberate emissions of ozone depleting substances. 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 (beginning in 2009), to be replaced in time with a requirement for 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.
10
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 million per occurrence, with maximum liability coverage of $750 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 $10.0 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 U.S. Securities Exchange Act of 1934 are available free of charge at our website at http://
www.noblecorp.com. The U.S. 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:
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•
•
•
•
•
•
•
Articles of Association;
Code of Business Conduct and Ethics;
Corporate Governance Guidelines;
Audit Committee Charter;
Compensation Committee Charter;
Health, Safety, Environment and Engineering Committee Charter;
Nominating and Corporate Governance Committee Charter; and
Finance Committee Charter.
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.
Our business and results of operations have been materially and negatively impacted and our market value has substantially declined
due to current depressed market conditions which are the result of the dramatic drop in the oil price, the development of additional onshore
oil and gas resources and the oversupply of offshore drilling rigs.
After a period of sustained high crude oil prices, oil prices began a steep decline beginning in late 2014 and dropped to as low as approximately
$30 per barrel in January 2016. Oil prices have recovered to a price of approximately $66 per barrel on February 19, 2019, but have been volatile
and have never recovered to 2014 levels. As a result of the oil price environment prior to the 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 at
the same time that our customers have greatly reduced their planned offshore exploration and development spending in response to the depressed
price of oil.
During the same period, crude oil production in the U.S. rose sharply. Production in the U.S. Permian Basin has increased from less than
1.5 million barrels of oil per day to nearly 4 million barrels per day. While, the cost of production in the Permian Basin (and many other onshore
fields) varies, in some cases it may be significantly less than the cost of production in offshore fields where our rigs are designed to operate,
especially deepwater fields. This increase in U.S. 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
11
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.
These factors have affected market conditions and led to a material decline in the demand for our services, the dayrates we are paid by our
customers and the level of utilization of our drilling rigs. These poor market conditions, in turn, have led to a material deterioration in our results
of operations. We have already experienced a substantial decline in the price of our shares, which has declined from $27 on August 4, 2014 post
Spin-off to $3.15 at February 19, 2019. While the offshore contract drilling industry is highly cyclical and has experienced periods of low demand
and higher demand, there can be no assurance as to 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 which 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:
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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, 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;
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;
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, winter storms and rough seas;
tax laws, regulations and policies;
laws and regulations related to environmental matters, including those addressing alternative energy sources 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,
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
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a material adverse effect on demand for our services since 2015 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 recourses than we do. 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. 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.
The over-supply of offshore rigs is contributing to a reduction in dayrates and demand for our rigs, which reduction may continue 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. As a result, our business, financial condition and results of
operations would be materially adversely affected.
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 analysis for the years ended December 31, 2018 and 2017, we
decided that we would no longer market certain rigs. In connection with these decisions, we recorded impairment charges of $802.1 million and
$121.6 million, respectively, on these 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.
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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 which prevents 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 replacement
contracts at all. 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 term 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. 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). While we believe these assumptions are appropriate, 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 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 Shell, Equinor and Saudi Aramco, 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. Shell, Equinor and Saudi Aramco accounted for approximately
38.8 percent, 15.5 percent and 14.5 percent, respectively, of our consolidated operating revenues and approximately 52.2 percent, 11.0 percent
and 19.8 percent, respectively, of our backlog for the year ended December 31, 2018. 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.
A litigation trust was formed and funded as part of the Paragon Offshore bankruptcy proceedings and the litigation trust has filed claims
against us and certain of our officers and directors. In addition, Paragon Offshore rejected in the bankruptcy proceedings certain separation
agreements entered into with us, and as a result, we are responsible for those liabilities for which we would have otherwise sought indemnification
under the separation agreements.
In August 2014, we completed the Spin-off of a majority of our standard specification offshore drilling business through a pro rata
distribution of all of the ordinary shares of our wholly-owned subsidiary, Paragon Offshore, to the holders of our ordinary shares.
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In April 2017, Paragon Offshore filed a plan of reorganization (the “Plan”) in its bankruptcy proceeding. The Plan, which was modified
in May 2017, provided for the creation of a litigation trust to which Paragon Offshore transferred its claims against us, including claims of alleged
fraudulent conveyance in connection with the Spin-off and the funding of the trust by Paragon Offshore with $10.0 million. The litigation trust is
entitled to pursue those claims against us. In June 2017, the Plan was approved by the bankruptcy court and Paragon Offshore emerged from
bankruptcy on July 18, 2017.
On December 15, 2017, the litigation trust filed claims relating to the Spin-off against us and certain of our current and former officers and
directors in the Delaware bankruptcy court that heard Paragon Offshore’s bankruptcy. The complaint alleges claims of alleged actual and constructive
fraudulent conveyance, unjust enrichment and recharacterization of intercompany notes as equity claims against Noble and claims of breach of
fiduciary duty and aiding and abetting breach of fiduciary duty against the officer and director defendants. The complaint states that the litigation
trust is seeking damages of approximately $1.7 billion from the Company, an amount equal to the amount borrowed by Paragon Offshore immediately
prior to the Spin-off, as well as unspecified amounts in respect of the claims against the officer and director defendants, all of whom have
indemnification agreements with us. We requested that the court dismiss the claims of breach of fiduciary duty, aiding and abetting breach of
fiduciary duty and unjust enrichment, and require such claims to be arbitrated under the master separation agreement (the “MSA”) entered into
between Noble and Paragon Offshore at the time of the Spin-off, as well as stay the other proceedings during the pendency of the arbitration. The
court ruled that the unjust enrichment claim be arbitrated and that the other claims proceed in bankruptcy court. We and the litigation trust have
mutually agreed to drop our respective appeals of the arbitration ruling and now all matters will be heard in court, which will streamline the case.
Discovery continues and the court has approved a litigation schedule, which could result in all pre-trial activity being completed by the end of
2019. A trial date has not yet been set.
We believe that Paragon Offshore, at the time of the Spin-off, was properly funded, solvent and had appropriate liquidity and that the claims
brought by the litigation trust are without merit. We intend to defend ourselves vigorously. However, there is inherent risk and substantial expense
in litigation, and the amount of damages the plaintiff is seeking is substantial. If any of the litigation trust’s claims are successful, or if we elect
to settle any claims (in part to reduce or eliminate the ongoing cost of defending the litigation and eliminate any risk of a larger judgment against
us), any damages or other amounts we would be required to or agree to pay could have a material adverse effect on our business, financial condition
and results of operations. Because of our view of the merits of the claims and the significant discovery still to be conducted in the litigation, we
are not currently able to make a reasonable estimation of the amount of possible loss we may incur, if any. Subsequent developments in the litigation
may make such an estimation possible, in which case we may record a charge against our income when a loss is reasonably estimable. This may
occur even though the litigation may still be ongoing. Any charge could be material and could have a material adverse effect on our financial
condition and results of operations. It may also be materially different than any amount we are required to pay once the litigation is concluded.
We have directors’ and officers’ indemnification coverage for the officers and directors who have been sued by the litigation trust. The
insurers have accepted coverage for the director and officer claims and we are continuing to discuss with them the scope of their reimbursement
of litigation expenses. In addition, at the time of the Spin-off we had entity coverage, or “Side C” coverage, which was meant to cover certain
litigation claims up to the coverage limit of $150.0 million, including litigation expenses. We have made a claim for coverage of the litigation
trust’s claims against Noble under such entity insurance. The insurers have rejected coverage for these claims. We cannot predict the amount of
claims and expenses we may incur, pay or settle in the Paragon Offshore litigation that such insurance will cover, if any.
We entered into certain separation agreements with Paragon Offshore at the time of the Spin-off (including the MSA, tax sharing agreement,
transition services agreement and transition services agreement relating to our operations offshore Brazil) under which we agreed to indemnify
Paragon Offshore for certain liabilities, and Paragon Offshore agreed to indemnify us for certain liabilities. As part of the Plan, Paragon Offshore
rejected all of these contracts. Accordingly, we are no longer entitled to seek indemnity from Paragon Offshore under such agreements, and we
would be responsible for those liabilities for which we would have otherwise sought indemnification. Such liabilities could have a material adverse
effect on our business, financial condition and results of operations.
Our business involves numerous operating hazards.
Our operations are subject to many hazards inherent in the drilling business, including:
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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;
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toxic gas emanating from the well;
spillage handling and disposing of materials; and
adverse weather conditions, including hurricanes, typhoons, tsunamis, winter storms and rough seas.
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 have substantial debt obligations that have significant covenant restrictions and could restrict our operations and prevent us from
fulfilling our obligations with respect to our outstanding debt.
As of February 19, 2019, Noble-Cayman and its subsidiaries, including NHIL and its subsidiaries, had approximately $3.9 billion aggregate
principal amount of unsecured long-term senior notes and seller loans (including current maturities) outstanding. At February 19, 2019, no amounts
were currently outstanding under our 2015 Credit Facility or our 2017 Credit Facility (each as defined herein). We may also incur additional
indebtedness in the future. If we do so, the risks related to our level of debt could intensify. Our substantial indebtedness could have adverse
consequences, including:
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making it more difficult for us to satisfy our financial obligations, including our obligations with respect to our outstanding
debt;
increasing our vulnerability to adverse economic, regulatory and industry conditions, and placing us at a disadvantage
compared to our competitors that are less leveraged;
limiting our ability to compete and our flexibility in planning for, or reacting to, changes in our business and the industry in
which we operate; and
limiting our ability to borrow additional funds for working capital, capital expenditures, acquisitions and general corporate or
other purposes.
Our debt service obligations will require us to use a significant portion of our operating cash flow to pay interest and principal on indebtedness
instead of for other corporate purposes, including funding future expansion of our business and ongoing capital expenditures, which could impede
our growth. If our operating cash flow and capital resources are insufficient to comply with the financial covenants in our Credit Facilities or to
service our debt obligations, we may be forced to sell assets, seek additional equity or debt financing or restructure our debt, which could harm
our long-term business prospects. Our failure to comply with those covenants could result in an event of default which, if not cured or waived,
could result in the acceleration of all of our debt. Our 2017 Credit Facility contains a covenant which limits our debt to total tangible capitalization
(less noncontrolling interest) to a maximum 0.55 ratio. If we increase our indebtedness, including by borrowing under the 2017 Credit Facility,
or incur further losses without reducing our indebtedness or increasing capital by an equivalent amount, our debt to total tangible capitalization
ratio would increase.
To service our indebtedness, we will use a significant amount of cash. Our ability to generate cash to service our indebtedness depends
on many factors beyond our control.
Our ability to make payments on our indebtedness and to fund planned capital expenditures will depend on our ability to generate cash
in the future. This ability, to a certain extent, is subject to general economic, financial, competitive, legislative, regulatory and other factors that
are beyond our control. We cannot assure you that cash flow generated from our business and other sources of cash, including future
borrowings by Noble-Cayman and Noble International Finance Company, a Cayman Islands company and a wholly-owned indirect subsidiary
of Noble-Cayman (“NIFCO”), under our 2015 Credit Facility or by Noble Cayman Limited, a Cayman Islands company and a wholly-owned
indirect subsidiary of Noble-Cayman, and NIFCO under our 2017 Credit Facility, will be sufficient to enable us to pay our indebtedness and to
fund our other liquidity needs.
As a result of our significant cash flow needs, we may be required to raise funds through the issuance of additional debt or equity, and
in the event of lost market access, may have to delay or cancel discretionary capital expenditures.
Our cash flow needs, both in the short-term and long-term, may include the following:
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normal recurring operating expenses;
planned and discretionary capital expenditures; and
repayment of debt and interest.
In the future, we may require funding for capital expenditures that is beyond the amount available to us from cash generated by our operations,
cash on hand and borrowings under our existing Credit Facilities. We may raise such additional capital in a number of ways, including accessing
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capital markets, obtaining additional lines of credit or disposing of assets. However, we can provide no assurance that any of these options will
be available to us on terms acceptable to us or at all.
We may delay or cancel discretionary capital expenditures, which could have certain adverse consequences, including delaying upgrades
or equipment purchases that could make the affected rigs less competitive, adversely affect customer relationships and negatively impact our
ability to contract such rigs.
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:
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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, imposition of trade barriers and other forms of government regulation and
economic conditions that are beyond our control;
delays in implementing private commercial arrangements as a result of government oversight;
financial or operational difficulties in complying with foreign bureaucratic actions;
changing taxation rules or policies;
other forms of government regulation and economic conditions that are beyond our control and that create operational uncertainty;
governmental corruption;
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:
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procedural requirements for temporary import permits, which may be difficult to obtain;
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; and
ongoing claims in Brazil related to withholding taxes payable on our service contracts.
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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. Changes in, compliance with, or our failure to comply with the laws and regulations of the countries where we operate may
negatively impact our operations in those countries and 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 United Kingdom (“U.K.”) held a referendum in which voters approved an exit from the European Union (“E.U.”),
commonly referred to as “Brexit” and in March 2017 the U.K. formally started the process for the U.K. to leave the E.U. Given the lack of
comparable precedent, it is unclear how disruptive the withdrawal will be, including possible financial, trade, regulatory and legal implications.
Brexit creates 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. While our business is internationally diversified, the Company is incorporated and registered within the U.K.
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.
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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.
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. While we believe that the financial, commercial and risk allocation terms of these contracts and our operating safeguards mitigate
these risks, 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.
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. 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.
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 U.S. Foreign
Corrupt Practices Act of 1977 (the “FCPA”), the United Kingdom Bribery Act 2010 (the “U.K. Bribery Act”) and similar laws in other countries.
Any violation of the FCPA, U.K. 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:
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the importing, exporting, equipping and operation of drilling rigs;
currency exchange controls;
oil and gas exploration and development;
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taxation of offshore earnings and earnings of expatriate personnel; and
use and compensation of local employees and suppliers by foreign contractors.
Public and regulatory scrutiny of the energy industry has resulted in increased regulations being either proposed or 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 U.S., 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
U.S. 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.
However, in December 2017, BSEE published a proposed rule that would revise certain requirements from the September 2016 rule. The final
rule implementing these revisions was published in September 2018. In addition, in May 2018, BSEE published a proposed rule that would revise
several requirements of the blowout preventer systems and well control rule. A final rule has not yet been issued. BOEM also released a new
Notice to Lessees and Operators in the Outer Continental Shelf (“NTL”) in September 2016 that updates offshore bonding requirements. This
update eliminates waivers of supplemental bonding and prohibits a company from relying on the financial strength of co-lessees unless co-lessees
agree to allocate BOEM-determined self-insurance to the lease. In January 2017, BOEM extended the implementation timeline for the NTL by
six months. In May 2017, the Secretary of the Interior directed BOEM to review the NTL and provide a report describing the results of the review
and options for revising or rescinding the NTL. BOEM again extended the implementation timeline for the NTL in June 2017. Implementation
of the NTL is currently stayed pending further action by BOEM. However, these new bonding requirements may increase our customers’ operating
costs and impact our customers’ ability to obtain leases, thereby reducing demand for our services. We are also subject to increasing regulatory
requirements and scrutiny in the North Sea jurisdictions and other countries. These new rules, regulations and requirements, 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 U.S. 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, have impacted
and may continue to impact our operations by causing increased costs, delays and operational restrictions. In addition to these rules, regulations
and requirements, the U.S. federal government is considering new legislation that could impose additional equipment and safety requirements on
operators and drilling contractors in the United States, as well as regulations relating to the protection of the environment. If the new regulations,
policies, operating procedures and 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 to offshore operations by environmental groups and coastal states. 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 nine coastal states also sought to
intervene as plaintiffs. 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.
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.
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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 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 exceeding 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:
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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 were to exceed 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.
Our insurance carriers may interpret our insurance policies such that they do not cover losses for which we make claims. Our insurance
policies may also have exclusions of coverage for some losses. Uninsured exposures may include expatriate activities prohibited by U.S. laws,
radiation hazards, certain loss or damage to property onboard our rigs and losses relating to shore-based terrorist acts or strikes. 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 U.S. 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 U.S. Gulf of Mexico for named windstorm perils. We currently have U.S.
windstorm coverage for most of our U.S. fleet subject to limit, 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 U.S. 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 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.
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 rights to indemnity for all risks, including loss of hire insurance on most of the rigs in our fleet. Uninsured exposures
may include expatriate activities prohibited by U.S. 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. 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 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
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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. 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. Currently, we do not carry insurance for losses related to cybersecurity attacks, and may elect to
not obtain such insurance in the future.
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 U.S. 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.
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 will not recognize the benefit of income tax positions we
believe are more likely than not to be disallowed upon challenge by a tax authority. If any tax authority successfully challenges our operational
structure, intercompany pricing policies or the taxable presence of our subsidiaries in certain countries, if the terms of certain income tax treaties
are interpreted in a manner that is adverse to our structure, or if we lose a material tax dispute in any country, our effective tax rate on our worldwide
earnings could increase substantially and 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 UK, U.S. and other foreign 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.
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:
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the release of oil, drilling fluids, natural gas or other materials into the environment;
air emissions from our drilling rigs or our facilities;
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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.
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
U.S. waters and certain offshore areas, including the U.S. 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.
Reactivation, refurbishment, conversion or upgrades of rigs are subject to risks, including delays and cost overruns, which 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 continue to reactivate rigs that have been cold or warm stacked and make selective purchases of rigs, such as the Noble Johnny
Whitstine purchased in 2018 and the Noble Joe Knight, for which the purchase is expected to be completed in late February 2019. 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:
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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;
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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.
The failure to complete a rig reactivation, repair, upgrade, refurbishment or new construction on time, or at all, or the inability to complete
a rig conversion or new construction in accordance with its design specifications, may result in loss of revenues, penalties, or delay, renegotiation
or cancellation of a drilling contract or the recognition of an asset impairment. Additionally, capital expenditures for rig reactivation, repair,
upgrade, refurbishment and construction projects 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, as
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. As 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.
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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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. U.S. 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 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 U.S.
government or identified by the U.S. government as state sponsors of terrorism, such as the Crimean region of the Ukraine, Cuba, Iran, North
Korea, Sudan and Syria. The U.S. 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. Although
we believe that we will be in compliance with all applicable sanctions and embargo laws and regulations at the filing date, and intend to maintain
such compliance, 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 U.S. 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 U.S. 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.
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.
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.
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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.
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.
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. Our corporate headquarters
is located in London, England. We also maintain offices in Sugar Land, Texas, where significant worldwide global support activity occurs. 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 15— 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.
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
Noble-UK shares are listed and traded on the New York Stock Exchange under the symbol “NE.”
The declaration and payment of dividends require the authorization of the Board of Directors of Noble-UK, provided that such dividends
on issued share capital may be paid only out of Noble-UK’s “distributable reserves” on its statutory balance sheet in accordance with UK law.
Therefore, Noble-UK is 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 Board of Directors.
On February 19, 2019, there were 248,704,351 shares outstanding held by 167 shareholder accounts of record.
UK Tax Consequences to Shareholders of Noble-UK
The tax consequences discussed below do not reflect a complete analysis or listing of all the possible tax consequences that may be relevant
to shareholders of 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.
25
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 our
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 Noble—UK Shares
Shareholders who are neither UK tax residents nor holding their Noble-UK 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. Noble-UK 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 Noble-UK 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 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 Noble-UK. However, if those ordinary shares of Noble-UK 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, the Company is 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. During the years ended December 31, 2018, 2017 and 2016,
we did not repurchase any of our shares.
26
Stock Performance Graph
The chart below presents a comparison of the five-year cumulative total return, assuming $100 was invested on December 31, 2013 for
Noble-UK, the Standard & Poor's 500 Index, Dow Jones U.S. 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.
Company / Index
Noble-UK
S&P 500 Index
Dow Jones U.S. Oil Equipment & Services
Offshore Drillers Peer Group (1)
2014
2015
2016
2017
2018
$
$
52.76
113.69
82.78
53.21
$
36.60
115.26
64.17
33.16
$
21.00
129.05
81.70
29.95
$
16.03
157.22
68.05
21.05
9.29
150.33
39.22
12.16
INDEXED RETURNS
Year Ended December 31,
(1)
Our self-determined peer group is weighted according to market capitalization and consists of the Company and the following peer
companies: Atwood Oceanics (through October 5, 2017), Diamond Offshore Drilling Inc., Ensco plc, Rowan Companies plc, Seadrill
Ltd. and Transocean Ltd.
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.
27
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,
2018, 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.
Statement of Income Data
Operating revenues from continuing operations
Net income (loss) from continuing operations
attributable to Noble-UK (1)
Net income (loss) from continuing operations per
share attributable to Noble-UK:
Basic
Diluted
Balance Sheet Data (at end of period)
Cash and cash equivalents
Property and equipment, net
Total assets (2)
Long-term debt (2)
Total debt (3)
Total equity
Other Data
Net cash provided by operating activities
Net cash used in investing activities
Net cash provided by (used in) financing activities
Net cash used for capital expenditures (4)
Working capital (2)(5)
Cash distributions declared per share
Year Ended December 31,
2018
2017
2016
2015
2014
(In thousands, except per share amounts)
$
1,082,826
$
1,236,915
$
2,302,065
$
3,352,252
$
3,232,504
(885,050)
(516,511)
(929,580)
511,000
(152,011)
(3.59)
(3.59)
(2.11)
(2.11)
(3.82)
(3.82)
2.06
2.06
(0.60)
(0.60)
375,232
8,480,718
9,264,923
3,877,402
3,877,402
4,654,574
171,851
(189,377)
(269,396)
194,779
293,599
—
662,829
9,489,240
10,794,659
3,795,867
4,045,710
5,950,628
416,675
(118,325)
(361,243)
120,707
445,951
—
725,722
10,061,948
11,440,117
4,040,229
4,340,111
6,467,445
1,142,740
(686,595)
(242,668)
711,403
559,321
0.20
512,245
11,483,623
12,865,645
4,162,638
4,462,562
7,422,230
1,764,907
(432,537)
(888,635)
422,544
377,034
1.28
68,510
12,112,509
13,266,480
4,848,678
4,848,678
7,287,034
1,778,627
(2,109,268)
284,693
2,072,885
259,888
1.50
(1)
(2)
(3)
(4)
(5)
Results for 2018, 2017, 2016, 2015 and 2014 include impairment charges of $802.1 million, $121.6 million, $1.5 billion, $418.3 million
and $745.0 million, respectively.
Certain amounts in prior periods have been reclassified to conform to the current year presentation. In accordance with our adoption
of Accounting Standard Update No. 2015-3, unamortized debt issuance costs related to our senior notes are now shown as a direct
reduction of the carrying amount of the related debt. See Part II, Item 8, “Financial Statements and Supplementary Data, Note 1—
Organization and Significant Accounting Policies” and “Note 6— Loss on Impairment” for more information.
Consists of Long-term debt and Current maturities of long-term debt.
Capital expenditures includes expenditures made for rigs that were ultimately transferred to Paragon Offshore as part of the Spin-off
in August 2014.
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, 2018 and 2017, and our results
of operations for each of the years in the three-year period ended December 31, 2018. 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, 2018
filed by Noble-UK and Noble-Cayman.
28
Executive Overview
We provide contract drilling services to the international oil and gas industry with our global fleet of mobile offshore drilling units. As of
the filing date of this Annual Report on Form 10-K, our fleet of 24 drilling rigs consisted of eight drillships, four semisubmersibles and 12 jackups
strategically deployed worldwide in both established and emerging ultra-deepwater and shallow water locations. We typically employ each drilling
unit under an individual contract. Although the final terms of the contracts result from negotiations with our customers, many contracts are awarded
based upon a competitive bidding process.
Our 2018 financial and operating results from continuing operations include:
•
•
•
operating revenues totaling $1.1 billion;
net loss of $885.1 million, or 3.59 per diluted share, which includes a $802.1 million before-tax impairment charge recognized
on five of our rigs and certain capital spare equipment; and
net cash from operating activities totaling $171.9 million.
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.
Our floating and jackup drilling fleet is among the youngest, most modern and versatile in the industry. Our fleet consists predominately
of technologically advanced units, equipped with sophisticated systems and components capable of executing our customers' increasingly
complicated offshore drilling programs safely and with greater efficiency. A total of 15 of our drilling rigs have been delivered since 2011 following
their construction in quality shipyards located primarily in Korea and Singapore. The last of our new rig additions was delivered in July 2016, and
no further newbuild rig construction is in process. We have also retired or sold 11 drilling rigs since late 2014, due in part to advanced service
lives, high cost of operation and limited customer appeal. Current market conditions could lead to us stacking or retiring additional rigs.
On September 21, 2018, we purchased the Noble Johnny Whitstine, a new GustoMSC CJ46 design jackup rig, from the PaxOcean Group
(“PaxOcean”) in connection with a concurrently awarded drilling contract in the Middle East region. We paid $93.8 million for the rig, with $33.8
million paid in cash and the remaining $60.0 million of the purchase price financed by the seller. On February 14, 2019, we exercised our option
to purchase a second newbuild CJ46 jackup from PaxOcean, to be known as the Noble Joe Knight, and we expect to complete the purchase in late
February 2019. The purchase of the Noble Joe Knight will be funded with cash and seller financing on terms similar to the Noble Johnny Whitstine.
See “Part II, Item 8, “Financial Statements and Supplementary Data, Note 7— Debt” for additional information.
Market Outlook
During 2018, higher average crude oil prices led to a slight improvement in customer activity, most notably across the jackup fleet. However,
the challenging business environment for offshore drillers continued to persist due to an industry-wide rig supply imbalance that resulted from a
multi-year period of investment in new offshore drilling capacity and the sustained drop in oil prices. Following the period of industry expansion,
a period of oil price volatility compelled exploration and production companies to deemphasize offshore programs while focusing instead on land-
based opportunities, such as unconventional land opportunities. A portion of the newbuild capacity ordered prior to the decline in industry activity
continues to exit shipyards, while the delivery of other newbuild rigs has been delayed into the future. In either case, these rigs have added to the
prevailing supply imbalance. Since 2015, the industry has experienced a higher level of fleet attrition, as rigs are removed from the global supply
due to a number of factors, including advanced service life, high maintenance and reactivation costs and limited customer appeal, but the pace of
attrition is significantly less than what would be required to remedy the capacity imbalance. Additionally, our customers have adopted a cautious
approach to offshore spending due, in part, to volatility in crude oil prices over the past four years. We expect that the offshore drilling programs
of operators will remain somewhat curtailed, as our customers continue to favor cash flow realization over long cycle investment in offshore
production and exploration. During 2018, we recognized improvement in leading edge dayrates in the high specification jackup sector, especially
in regions such as the North Sea and Middle East where approximately 80 percent of our fleet is located. We remain cautiously optimistic that
this trend will continue into 2019. However, the floating sector did not enjoy the same pricing improvement as the jackup sector and additional
customer activity will be required before dayrates move higher.
In spite of the gradual improvement in offshore activities in 2018, we expect the business environment for 2019 to remain challenging. The
uncertainty of the viability and length of reductions in production agreed to by the Organization of Petroleum Exporting Countries (“OPEC”), the
incremental production capacity in non-OPEC countries, including growing production from U.S. shale activity, the current U.S. political
environment and fluid sentiment in oil markets are contributing to an uncertain oil price environment, leading to considerable uncertainty in our
customers’ production spending plans. However, steady oil demand growth, the lack of production investments in various countries around the
world and the production limits agreed to by OPEC and other significant oil producing countries should support higher sustained crude prices,
and lead to improved offshore spending by our customers over time. In general, recent contract awards have been subject to an extremely competitive
bidding process. As a result, the contracts have been for dayrates that are substantially lower than rates were for the same class of rigs before this
period of imbalance.
29
We cannot give any assurances as to when conditions in the offshore drilling market will improve, or when the oversupply of available
drilling rigs will end.
Due to numerous factors that influence our customers' annual global offshore spending patterns, including geopolitical events, we cannot
predict the future level of demand or dayrates for our services, or future conditions in the offshore contract drilling industry. However, we believe
the existence of certain factors should over time contribute to an improvement in the market for our services, driven in part by an acceleration in
customers’ offshore spending. These factors include:
•
•
•
•
•
•
•
sustained crude oil prices;
improved geologic success with regard to our customers’ exploration efforts;
greater customer access to areas with promising offshore resource potential;
advances in offshore technological applications which reduce offshore costs and improve project economics;
high rate of natural depletion relating to land-based sources of crude oil production;
deteriorating annual production and poor reserve replacement metrics caused, in part, by a period of sustained under-investment
by our customers; and
declining supply of rigs due to continued attrition.
We believe that we are strategically well positioned during this period of fundamental weakness for several reasons, including our substantial
backlog, modern fleet of high-specification rigs and strong operational capability. We also believe that these strengths will help us take advantage
of any future market upcycle. Although we plan to prioritize capital preservation and liquidity based on the challenging market conditions, from
time to time we will also continue to evaluate opportunities to enhance our fleet of floating and jackup rigs, particularly focusing on higher
specification rigs, to execute the increasingly complex drilling programs required by our customers.
Spin-off of Paragon Offshore plc
On August 1, 2014, Noble-UK 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. In February 2016, Paragon Offshore sought approval of a pre-negotiated plan of reorganization
(the “Prior Plan”) by filing for voluntary relief under Chapter 11 of the United States Bankruptcy Code. As part of the Prior Plan, we entered into
a settlement agreement with Paragon Offshore (the “Settlement Agreement”). The Prior Plan was rejected by the bankruptcy court in October
2016.
In April 2017, Paragon Offshore filed a revised plan of reorganization (the “New Plan”) in its bankruptcy proceeding. Under the New
Plan, Paragon Offshore no longer need the Mexican tax bonding that Noble-UK was to provide under the Settlement Agreement. Consequently,
Paragon Offshore abandoned the Settlement Agreement as part of the New Plan, and the Settlement Agreement was terminated at the time of the
filing of the New Plan. On May 2, 2017, Paragon Offshore announced that it had reached an agreement in principle with both its secured and
unsecured creditors to revise the New Plan to, among other things, create and fund a $10.0 million. litigation trust to pursue litigation against us.
On June 7, 2017, the revised New Plan was approved by the bankruptcy court and Paragon Offshore emerged from bankruptcy on July 18, 2017.
On December 15, 2017, the litigation trust filed claims relating to the Spin-off against us and certain of our current and former officers and
directors in the Delaware bankruptcy court that heard Paragon Offshore’s bankruptcy. The complaint alleges claims of alleged actual and constructive
fraudulent conveyance, unjust enrichment and recharacterization of intercompany notes as equity claims against Noble and claims of breach of
fiduciary duty and aiding and abetting breach of fiduciary duty against the officer and director defendants. The complaint states that the litigation
trust is seeking damages of approximately $1.7 billion from the Company, an amount equal to the amount borrowed by Paragon Offshore immediately
prior to the Spin-off, as well as unspecified amounts in respect of the claims against the officer and director defendants, all of whom have
indemnification agreements with us. We requested that the court dismiss the claims of breach of fiduciary duty, aiding and abetting breach of
fiduciary duty and unjust enrichment, and require such claims to be arbitrated under the master separation agreement (the “MSA”) entered into
between Noble and Paragon Offshore at the time of the Spin-off, as well as stay the other proceedings during the pendency of the arbitration. The
court ruled that the unjust enrichment claim be arbitrated and that the other claims proceed in bankruptcy court. We and the litigation trust have
mutually agreed to drop our respective appeals of the arbitration ruling and now all matters will be heard in court, which will streamline the case.
Discovery continues and the court has approved a litigation schedule, which could result in all pre-trial activity being completed by the end of
2019. A trial date has not yet been set.
We believe that Paragon Offshore, at the time of the Spin-off, was properly funded, solvent and had appropriate liquidity and that the claims
brought by the litigation trust are without merit. We intend to defend ourselves vigorously. However, there is inherent risk and substantial expense
in litigation, and the amount of damages the plaintiff is seeking is substantial. If any of the litigation trust’s claims are successful, or if we elect
30
to settle any claims (in part to reduce or eliminate the ongoing cost of defending the litigation and eliminate any risk of a larger judgment against
us), any damages or other amounts we would be required to or agree to pay could have a material adverse effect on our business, financial condition
and results of operations. Because of our view of the merits of the claims and the significant discovery still to be conducted in the litigation, we
are not currently able to make a reasonable estimation of the amount of possible loss we may incur, if any. Subsequent developments in the litigation
may make such an estimation possible, in which case we may record a charge against our income when a loss is reasonably estimable. This may
occur even though the litigation may still be ongoing. Any charge could be material and could have a material adverse effect on our financial
condition and results of operations. It may also be materially different than any amount we are required to pay once the litigation is concluded.
We have directors’ and officers’ indemnification coverage for the officers and directors who have been sued by the litigation trust. The
insurers have accepted coverage for the director and officer claims and we are continuing to discuss with them the scope of their reimbursement
of litigation expenses. In addition, at the time of the Spin-off, we had entity coverage, or “Side C” coverage, which was meant to cover certain
litigation claims up to the coverage limit of $150.0 million, including litigation expenses. We have made a claim for coverage of the litigation
trust’s claims against Noble under such entity insurance. The insurers have rejected coverage for these claims. We cannot predict the amount of
claims and expenses we may incur, pay or settle in the Paragon Offshore litigation that such insurance will cover, if any.
Prior to the completion of the Spin-off, Noble-UK 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 MSA and a Tax Sharing
Agreement (“the TSA”).
As part of its final bankruptcy plan, Paragon Offshore rejected the Separation Agreements. Accordingly, the indemnity obligations that
Paragon Offshore potentially would have owed us under the Separation Agreements have now terminated, including indemnities arising under
the MSA and the TSA in respect of obligations related to Paragon Offshore’s business that were incurred through Noble-retained entities prior to
the Spin-off. Likewise, any potential indemnity obligations that we would have owed Paragon Offshore under the Separation Agreements, including
those under the MSA and the TSA in respect of Noble-UK’s business that was conducted prior to the Spin-off through Paragon Offshore-retained
entities, are now also extinguished. In the absence of the Separation Agreements, liabilities relating to the respective parties will be borne by the
owner of the legal entity or asset at issue and neither party will look to an allocation based on the historic relationship of an entity or asset to one
of the party’s business, as had been the case under the Separation Agreements.
The rejection and ultimate termination of the indemnity and related obligations under the Separation Agreements resulted in a number of
accounting charges and benefits during the year ended December 31, 2017, and such termination may continue to affect us in the future as liabilities
arise for which we would have been indemnified by Paragon Offshore or would have had to indemnify Paragon Offshore. We do not expect that,
overall, the rejection of the Separation Agreements by Paragon Offshore will have a material adverse effect on our financial condition or liquidity.
However, any loss we experience with respect to which we would have been able to secure indemnification from Paragon Offshore under one or
more of the Separation Agreements could have an adverse impact on our results of operations in any period, which impact may be material
depending on our results of operations during this down-cycle.
During the year ended December 31, 2017, we recognized net charges of $15.9 million, with a non-cash loss of $1.5 million recorded in
“Net loss from discontinued operations, net of tax” on our Consolidated Statement of Operations relating to Paragon Offshore’s emergence from
bankruptcy.”
U.S. Federal Income Tax Reform
On December 22, 2017, the President of the United States signed into law legislation informally known as the Tax Cuts and Jobs Act (the
“Act”). The Act represents major tax reform legislation that, among other provisions, reduces the U.S. corporate tax rate. For more information
on the Act and its effect on our consolidated financial statements, see “—Critical Accounting Policies” and Part II, Item 8, “Financial Statements
and Supplementary Data, Note 11— Income Taxes.”
Impairment
As more thoroughly described in “Note 6— Loss on Impairment” to our consolidated financial statements, included in Part II, Item 8 of
this Annual Report on Form 10-K, we evaluate our property and equipment for impairment whenever there are changes in facts which 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, 2018, 2017 and 2016, we recognized non-cash, before-tax impairment charges of $802.1 million,
$121.6 million and $1.5 billion, 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.
31
There can be no assurance that we will not have to take additional impairment charges in the future if current depressed market conditions
persist.
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, 2018, 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 for the three rigs contracted with Royal Dutch Shell plc (“Shell”) mentioned below, we utilize the idle period
and floor rates as described in footnote (2) 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.
The table below presents the amount of our contract drilling services backlog and the percent of available operating days committed for
the periods indicated:
Contract Drilling Services Backlog
Semisubmersibles/Drillships (2)(3)
Jackups
Total (4)
Percent of Available Days Committed (5)
Semisubmersibles/Drillships
Jackups
Total
2019
2020
2021
2022
2023
Year Ending December 31, (1)
(In thousands)
$ 1,475,792
927,739
$ 2,403,531
$ 492,077
453,275
$ 945,352
$ 388,860
286,710
$ 675,570
$ 338,025
141,438
$ 479,463
$ 187,255
46,316
$ 233,571
$
$
69,575
—
69,575
49%
75%
62%
34%
38%
36%
27%
25%
26%
15%
7%
11%
6%
—%
3%
Total
(1)
(2)
(3)
(4)
(5)
Represents a twelve-month period beginning January 1, 2019.
As previously reported, three of our long-term drilling contracts with Shell, the Noble Bully II, 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. The contract amendments for the Noble Globetrotter I and Noble Globetrotter II provide a dayrate floor of
$275,000 per day. The Noble Bully II contract contains a dayrate floor of $200,000 per day plus daily operating expenses. The amendment
also provided Shell the right to idle the Noble Bully II for up to one year at a special stacking rate. The Noble Bully II was idled at a rate
of $200,000 per day, effective April 3, 2017. In April 2018, we agreed with Shell to extend the idle period for the Noble Bully II through
December 31, 2018 at a revised rate of $230,000 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 their respective
dayrate floor for the remaining contract term.
Noble and a subsidiary of Shell are involved in joint ventures that own and operate both the Noble Bully I and Noble Bully II. Pursuant
to these agreements, each party has an equal 50 percent share in both vessels. As of December 31, 2018, the backlog for the Noble Bully
II totaled $405.6 million, all of which is included in backlog. As of the same date, the Noble Bully I had no backlog. Noble’s proportional
interest in the backlog for these rigs totaled $202.8 million.
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.
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.
32
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, 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— Our current backlog of contract drilling revenue may not be ultimately realized.”
For the year ended December 31, 2018, Shell, Saudi Arabian Oil Company and Equinor ASA represented approximately 52.2 percent, 19.8
percent and 11 percent of our backlog, respectively.
Results of Operations
2018 Compared to 2017
Net loss from continuing operations attributable to Noble-UK for the year ended December 31, 2018 was $885.1 million, or $3.59 per
diluted share, on operating revenues of $1.1 billion, compared to a net loss from continuing operations for the year ended December 31, 2017 of
$515.0 million, or $2.10 per diluted share, on operating revenues of $1.2 billion.
As a result of Noble-UK conducting all of its business through Noble-Cayman and its subsidiaries, the financial position and results of
operations for Noble-Cayman, and the reasons for material changes in the amount of revenue and expense items between December 31, 2018 and
December 31, 2017, would be the same as the information presented below regarding Noble-UK in all material respects, with the exception of
operating income (loss). During the years ended December 31, 2018 and 2017, Noble-Cayman's operating loss was $40.7 million and $37.9 million
lower, respectively, than that of Noble-UK. The operating loss difference is primarily a result of administration and other costs directly attributable
to Noble-UK for operations support and stewardship-related services.
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, 2018 and 2017:
Average Rig Utilization (1)
December 31,
Operating Days (2)
December 31,
2018
2017
2018
2017
% Change
77%
15%
62%
61%
85%
17%
59%
63%
3,642
268
1,817
5,727
4,367
365
1,716
6,448
(17)% $
(27)%
6 %
(11)% $
Average Dayrates (3)
December 31,
2018
130,217
108,111
293,265
180,909
2017
126,109
155,919
349,244
187,181
$
$
% Change
3 %
(31)%
(16)%
(3)%
Jackups
Semisubmersibles
Drillships
Total
(1)
(2)
(3)
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.
Information reflects the number of days that our rigs were operating under contract.
Average dayrates for the year ended December 31, 2017 include the impact of the valuation of certain contingent payments for the Noble
Sam Croft and Noble Tom Madden contract settlement and termination by and among Freeport-McMoRan Inc., Freeport-McMoRan Oil
& Gas LLC and one of our subsidiaries (“FCX Settlement”). We recognized a $14.4 million loss to the termination date valuation of
certain contingent payments for the Noble Sam Croft and Noble Tom Madden related to the FCX Settlement. The loss in 2017 had a
negative impact on the drillships’ average dayrates.
33
Contract Drilling Services
The following table presents the operating results for our contract drilling services segment for the years ended December 31, 2018 and
2017 (dollars in thousands):
Operating revenues:
Contract drilling services
Reimbursables and other (1)
Operating costs and expenses:
Contract drilling services
Reimbursables (1)
Depreciation and amortization
General and administrative
Loss on impairment
Operating loss
Year Ended December 31,
2018
2017
Change
$
%
$
$
$
$
1,036,082
46,744
1,082,826
$
$
$
629,937
37,084
467,302
73,216
802,133
2,009,672
(926,846) $
1,207,026
29,889
1,236,915
$
$
$
642,937
18,435
524,752
71,634
121,639
1,379,397
(142,482) $
$
(170,944)
16,855
(154,089)
(13,000)
18,649
(57,450)
1,582
680,494
630,275
(784,364)
(14)%
56 %
(12)%
(2)%
101 %
(11)%
2 %
559 %
46 %
551 %
(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 $170.9 million decline in contract drilling services revenues for the year ended December 31, 2018 as compared
to the same period of 2017 was composed of a $135.0 million decline due to fewer operating days and a $35.9 million decline due to lower dayrates.
The decline in revenue was primarily due to our drillship and jackup fleet, which experienced declines in revenues of $66.5 million and $76.5
million, respectively. Our semisubmersible fleet also experienced a decline in revenue of $27.9 million.
The $66.5 million revenue decline in our drillship fleet consists of a $101.7 million decline from lower dayrates, which was partially offset
by a $35.2 million increase due to higher operating days for the year ended December 31, 2018 compared to the same period of 2017. The decline
in average dayrates was primarily related to the Noble Bully II, which remained idle during the current period but operated for a portion of the
prior period. The increase in operating days was primarily related to the reactivation of the Noble Tom Madden in the fourth quarter of 2018, offset
by the stacking of the Noble Bully I in the second quarter of 2017.
The $76.5 million revenue decline in our jackup fleet is primarily attributable to a $91.5 million decline in revenues due to certain of our
jackup rigs not operating for the year ended December 31, 2018, which was partially offset by a $15.0 million increase in revenues associated
with favorable dayrate changes across the jackup fleet. The decrease in operating days during the current period was the result of the retirement
and subsequent sale of the Noble David Tinsley, the retirement of the Noble Alan Hay and a decrease in operating days for the Noble Mick O'Brien
and for the Noble Sam Hartley, which was stacked in early 2018 and reactivated in late 2018. The $27.9 million decline in semisubmersible
revenues was primarily due to a decrease in both dayrate and operating days on the Noble Paul Romano, which was warm stacked in early 2018.
Operating Costs and Expenses. Contract drilling services costs decreased $13.0 million for the year ended December 31, 2018 as compared
to the same period of 2017. Rigs that were operating in the prior period, but were idle or stacked most of the current period contributed $20.5
million to the decrease in operating costs, and rigs that operated in the prior period but were subsequently retired contributed $18.7 million to the
decrease in operating costs. In addition to these rig costs declines, operations support costs decreased $9.2 million for the year ended December 31,
2018, of which $7.6 million related to reduction of employee-related expenses. These decreases were offset by $64.1 million of cost increases as
certain rigs prepared and returned to operations and experienced higher operating days in the current period. Operating costs increases were
recognized across all costs categories, but were primarily attributable to crew-related expenses ($48.4 million) and repairs, maintenance, and other
rig-related costs ($15.7 million). Contract Drilling Services costs in 2017 included non-recurring charges of $28.7 million related to damages
sustained by two rigs during Hurricane Harvey in the U.S. Gulf of Mexico region along with a charge related to the write-off an uncollectible
receivable held by a Paragon Offshore entity in Mexico that is expected to be liquidated.
Depreciation and amortization decreased $57.5 million for the year ended December 31, 2018 as compared to the same period of 2017.
The decline was due to the effect of rig impairments recorded during the second quarter of 2018 and the fourth quarter of 2017.
Loss on Impairments. We recorded a loss on impairment of $802.1 million for the year ended December 31, 2018 as compared to a loss
on impairment of $121.6 million for the same period of 2017. We evaluate our property and equipment for impairment whenever there are changes
34
in facts which suggest that the value of the asset is not recoverable. In connection with the preparation of our financial statements for the second
quarter of 2018 and the year ended December 31, 2018, we conducted a review of our fleet. The review included an assessment of certain
assumptions, including future marketability of each unit in light of its current technical specifications. Based upon our impairment analysis, we
impaired the carrying values to estimated fair values for the Noble Bully I, Noble Dave Beard, Noble Gene House, Noble Joe Beall, Noble Paul
Romano, and certain capital spare equipment. 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 increased $1.6 million during the year ended December 31,
2018 as compared to the same period of 2017, primarily due to higher employee-related costs.
Interest Expense. Interest expense increased $5.6 million during the year ended December 31, 2018 as compared to the same period of
2017. This increase was primarily due to the issuance of our Senior Notes due 2026 (the “2026 Notes”) in January 2018, an increase in interest
rates on certain of our senior notes due to the downgrading of our credit rating, the entry into the 2017 Credit Facility (as defined herein) on
December 21, 2017, and the entry into the seller-financed secured loan for the purchase of the Noble Johnny Whitstine. These increases were
partially offset by the retirement of a portion of various tranches of our senior notes as a result of tender offers and open market repurchases
throughout 2018, the maturity of our Senior Notes due 2018 (the “2018 Notes”) and the redemption of our remaining Senior Notes due 2019 (the
“2019 Notes”). For additional information, see Part II, Item 8, “Financial Statements and Supplementary Data, Note 7— Debt.”
Income Tax Provision. Our income tax provision decreased by $149.3 million for the year ended December 31, 2018 as compared to the
same period of 2017. The decrease was primarily due to prior period discrete tax items of $151.2 million related to tax restructuring and the impact
of the Act and to various tax benefits in the current period including the tax impact on asset impairments of $35.6 million, U.S. return-to-provision
adjustment of $24.9 million, UK return-to-provision adjustment of $9.1 million and a U.S. disallowed interest carryover of $51.4 million. These
decreases were partially offset by an $84.2 million increase in tax expense in the current period attributable to a higher pre-tax loss and a lower
worldwide effective tax rate as compared to the prior period. The increase in the current period pre-tax loss generated a $19.6 million tax benefit
and the lower current period worldwide effective tax rate reduced the tax benefit by $103.7 million. The decrease in the worldwide effective tax
rate in the current period is primarily a result of the geographic mix of income and sources of revenue.
2017 Compared to 2016
Net loss from continuing operations attributable to Noble-UK for the year ended December 31, 2017 was $515.0 million, or $2.10 per
diluted share, on operating revenues of $1.2 billion, compared to a net loss from continuing operations for the year ended December 31, 2016 of
$929.6 million, or $3.82 per diluted share, on operating revenues of $2.3 billion.
As a result of Noble-UK conducting all of its business through Noble-Cayman and its subsidiaries, the financial position and results of
operations for Noble-Cayman, and the reasons for material changes in the amount of revenue and expense items between December 31, 2017 and
December 31, 2016, would be the same as the information presented below regarding Noble-UK in all material respects, with the exception of
operating income (loss). During the years ended December 31, 2017 and 2016, Noble-Cayman’s operating loss was $37.9 million and $29.7 million
lower, respectively, than that of Noble-UK. The operating loss difference is primarily a result of administration and other costs directly attributable
to Noble-UK for operations support and stewardship-related services.
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, 2017 and 2016:
Average Rig Utilization (1)
Operating Days (2)
December 31,
December 31,
Average Dayrates
December 31,
Jackups
Semisubmersibles
Drillships
Total
2017
2016
2017
2016
% Change
85%
17%
59%
63%
83%
22%
82%
66%
4,367
365
1,716
6,448
3,966
649
2,408
7,023
10 % $
(44)%
(29)%
(8)% $
2017
126,109
155,919
349,244
187,181
(4)
$
$
2016
126,279
256,122
654,074
319,256
(3)
(4)
% Change
— %
(39)%
(47)%
(41)%
35
(1)
(2)
(3)
(4)
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.
Information reflects the number of days that our rigs were operating under contract.
Average dayrate for the year ended December 31, 2016 includes $16.4 million in contract drilling services revenue related to the Noble
Tom Prosser contract cancellation with Quadrant Energy Australia Limited. The additional contract drilling services revenue in 2016 had
a positive impact on the jackups’ average dayrates.
Average dayrates include a $14.4 million loss in the year ended December 31, 2017 and a $14.4 million gain in the year ended December
31, 2016, in respect of the termination date valuation of certain contingent payments for the Noble Sam Croft and Noble Tom Madden
related to the FCX Settlement. The loss in 2017 had a negative impact and the gain in 2016 had a positive impact on the drillships’ average
dayrates.
Contract Drilling Services
The following table presents the operating results for our contract drilling services segment for the years ended December 31, 2017 and
2016 (dollars in thousands):
Operating revenues:
Contract drilling services
Reimbursables and other (1)
Operating costs and expenses:
Contract drilling services
Reimbursables (1)
Depreciation and amortization
General and administrative
Loss on impairment
Operating income (loss)
Year Ended December 31,
Change
2017
2016
$
%
$
$
$
$
1,207,026
29,889
1,236,915
$
$
2,242,200
59,865
2,302,065
$ (1,035,174)
(29,976)
$ (1,065,150)
$
642,937
18,435
524,752
71,634
121,639
1,379,397
(142,482) $
$
877,689
45,608
587,999
69,258
1,458,749
3,039,303
(737,238) $
(234,752)
(27,173)
(63,247)
2,376
(1,337,110)
(1,659,906)
594,756
(46)%
(50)%
(46)%
(27)%
(60)%
(11)%
3 %
(92)%
(55)%
(81)%
(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 $1.0 billion decline in contract drilling services revenues for the year ended December 31, 2017 as compared to
the same period of 2016 was composed of an $851.6 million decline from lower dayrates and a $183.6 million decline due to fewer operating
days. The contract drilling services revenues decline was primarily due to our drillship and semisubmersible fleets, which experienced declines
in revenues of $975.7 million and $109.3 million, respectively, and was partially offset by revenue increases in our jackup fleet of $49.8 million.
The $975.7 million revenue decline in our drillship fleet for the year ended December 31, 2017 as compared to the same period of 2016
consists of a $523.1 million decline from lower dayrates and a $452.6 million decline due to fewer operating days. The decline in average dayrates
was primarily related to the payment of the $393.0 million FCX Settlement in 2016. Of the decline in revenue attributable to operating days,
$281.5 million is related to the Noble Bully I and Noble Bob Douglas operating for all of 2016, but being idle for the majority of 2017. The
remainder of the decline in operating days and the decline in average dayrates was attributable to the Noble Tom Madden and Noble Sam Croft,
whose contracts were terminated in May 2016.
The $109.3 million revenue decline in our semisubmersible fleet for the year ended December 31, 2017 as compared to the same period
of 2016 consists of a $36.6 million decline from lower dayrates and a $72.7 million decline due to fewer operating days. The decline in both
average dayrates and operating days as compared to 2016 was attributable to contract completions for the Noble Clyde Boudreaux, Noble Jim
Day, Noble Dave Beard, Noble Danny Adkins and Noble Amos Runner, none of which have returned to work since their respective contract
completions.
The $49.8 million revenue increase in our jackup fleet is primarily attributable to an increase in operating days on the Noble Mick O'Brien
and Noble Regina Allen as well as the startup of the newbuild Noble Lloyd Noble.
36
Operating Costs and Expenses. Contract drilling services costs decreased $234.8 million for the year ended December 31, 2017 as compared
to the same period of 2016. Of the decrease, $179.0 million was due to rigs that operated during 2016 being idle during 2017. An additional $113.1
million decrease in cost was due to continuing cost control measures, yielding reductions in labor and training related costs of approximately $53.8
million, operations support costs of $29.7 million, repair and maintenance costs of $28.1 million, and rig mobilization costs of $3.0 million. These
cost decreases were partially offset by the startup of the Noble Lloyd Noble, a greater number of operating days for contracted rigs during 2017
and the write-off of a $14.4 million customer receivable during 2017.
Depreciation and amortization decreased $63.2 million for the year ended December 31, 2017 as compared to the same period of 2016.
The decline was due to the effect of rig retirements and impairments during 2016, partially offset by the effect of the Noble Lloyd Noble being
placed into service during November 2016.
Other Income and Expenses
General and Administrative Expenses. General and administrative expenses increased $2.4 million during the year ended December 31,
2017 as compared to the same period of 2016, primarily due to higher professional fees.
Interest Expense, net of amount capitalized. Interest expense, net of amount capitalized, increased $69.1 million during the year ended
December 31, 2017 as compared to the same period of 2016. This increase was primarily due to the interest incurred during 2017 on the senior
notes issued in December 2016, the absence of capitalized interest during 2017 and an increase in interest rates on certain of our senior notes due
to the downgrading of our credit rating. These increases were partially offset by the retirement of a portion of our Senior Notes due 2020 (the
“2020 Notes”), Senior Notes due 2021 (the “2021 Notes”) and Senior Notes due 2022 (the “2022 Notes”) as a result of tender offers in 2016 and
the maturity of our Senior Notes due 2017 (the “2017 Notes”). For additional information see, Part II, Item 8, “Financial Statements and
Supplementary Data, Note 7— Debt.”
Income Tax Provision. Our income tax provision increased $151.8 million for the year ended December 31, 2017 as compared to the same
period of 2016. The increase was primarily due to a $260.7 million non-cash discrete tax item resulting from a tax restructuring in 2017. The effect
of this tax restructuring was to lower current tax expense. This increase was partially offset by the tax effect of the FCX Settlement of $27.2 million
in 2016. Excluding the impact of these items, taxes decreased by $86.0 million as a result of lower pre-tax income in 2017, primarily from our
geographical mix of pre-tax income.
Liquidity and Capital Resources
Overview
Net cash provided by operating activities was $171.9 million for the year ended December 31, 2018 and $416.7 million for the year ended
December 31, 2017. The decrease in net cash provided by operating activities for the year ended December 31, 2018 was primarily attributable
to a reduction in operating activity during 2018. We had working capital of $293.6 million and $446.0 million at December 31, 2018 and December
31, 2017, respectively.
Net cash used in investing activities for the year ended December 31, 2018 was $189.4 million as compared to $118.3 million for the year
ended December 31, 2017. The variance primarily relates to the purchase of the Noble Johnny Whitstine, the reactivation of the Noble Clyde
Boudreaux, Noble Tom Madden, and Noble Sam Croft and various major projects in the current period.
Net cash used in financing activities for the year ended December 31, 2018 was $269.4 million as compared to $361.2 million for the year
ended December 31, 2017. During the current period, our primary uses of cash included retirement of a portion of the 2020 Notes, 2021 Notes,
2022 Notes, Senior Notes due 2024 (the “2024 Notes”), Senior Notes due 2040 (the “2040 Notes”), Senior Notes due 2041 (the “2041 Notes”),
and Senior Notes due 2042 (the “2042 Notes”) in tender offers and open market purchases, repayment at maturity of the 2018 Notes and redemption
of the 2019 Notes, which amounts were partially offset by the issuance of the 2026 Notes.
Our principal source of capital in the current period was cash generated from operating activities coupled with the $750.0 million 2026
Notes offering in January 2018. Cash on hand during the current period was primarily used for the following:
•
•
•
normal recurring operating expenses;
retirement of a portion of various tranches of our senior notes in tender offers, repayment at maturity of the
2018 Notes and redemption of the 2019 Notes; 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.
37
We currently expect to fund these cash flow needs with cash generated by our operations, cash on hand, borrowings under our Credit
Facilities (as defined herein) and potential issuances of equity or long-term debt. However, to adequately cover our expected cash flow needs, we
may require capital in excess of the amount available from these sources, and we may seek additional sources of liquidity and/or delay or cancel
certain discretionary capital expenditures or other payments as necessary.
At December 31, 2018, we had a total contract drilling services backlog of approximately $2.4 billion, which includes a commitment of
62.0 percent of available days for 2019. For additional information regarding our backlog, see “—Contract Drilling Services Backlog.”
Capital Expenditures
Capital expenditures totaled $281.3 million, $111.1 million and $659.9 million for the years ended December 31, 2018, 2017 and 2016,
respectively. Capital expenditures during 2018 consisted of the following:
•
•
•
•
$82.7 million for sustaining capital;
$75.6 million in major projects, including reactivations;
$29.2 million in subsea and other related projects; and
$93.8 million to purchase the Noble Johnny Whitstine (inclusive of cash paid and seller financing).
Our total capital expenditure estimate for 2019 is approximately $303.9 million, which is currently anticipated to be spent as follows:
•
•
•
•
$90.3 million for sustaining capital;
$96.4 million in major projects, including reactivations;
$33.4 million in subsea and other related projects; and
$83.8 million to purchase the Noble Joe Knight (inclusive of cash paid and seller financing).
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, we will continue to evaluate acquisitions of drilling units from time to time. Other
factors that could cause actual capital expenditures to materially exceed plan include delays and cost overruns in shipyards (including costs
attributable to labor shortages), shortages of equipment, latent damage or deterioration to hull, equipment and machinery in excess of engineering
estimates and assumptions, changes in governmental regulations and requirements, possible refurbishment and reactivation of rigs and changes
in design criteria or specifications during repair or construction.
Share Capital
The declaration and payment of dividends require the authorization of the Board of Directors of Noble-UK, provided that such dividends
on issued share capital may be paid only out of Noble-UK’s “distributable reserves” on its statutory balance sheet in accordance with UK law.
Therefore, Noble-UK is 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 Board of Directors.
At our 2018 Annual General Meeting, shareholders approved a proposal to allow our Board of Directors to increase share capital through
the issuance of up to 82.2 million ordinary shares (at current nominal value of $0.01 per share). The right of our directors to allot shares will expire
at the end of our 2019 Annual General Meeting unless we seek an extension from shareholders at that time. No shares were allotted during the
year ended December 31, 2018.
Share Repurchases
Under UK law, the Company is 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. During the years ended December 31, 2018, 2017 and 2016,
we did not repurchase any of our shares.
Credit Facilities
2015 Credit Facility
At December 31, 2017, we had a five-year $2.4 billion senior unsecured credit facility that matures in January 2020 and is guaranteed by
our indirect, wholly-owned subsidiaries, Noble Holding (U.S.) LLC (“NHUS”) and Noble Holding International Limited (“NHIL”) (the “2015
Credit Facility”). At December 31, 2017, the 2015 Credit Facility also provided us with the ability to issue up to $500.0 million in letters of credit.
On December 19, 2017, we entered into the First Amendment and Consent and Successor Agent Agreement (the “Amendment”) amending
the 2015 Credit Facility. On January 3, 2018, the Amendment to the 2015 Credit Facility became fully effective. The Amendment caused, among
other things, a reduction in the aggregate principal amount of commitments under the 2015 Credit Facility to $300.0 million and the termination
of the 2015 Credit Facility's letter of credit sub-facility. The maturity of the 2015 Credit Facility remains January 2020. As a result of the 2015
38
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. At December 31, 2018, we had no borrowings outstanding or letters of credit issued under the 2015 Credit Facility.
2017 Credit Facility
On December 21, 2017, Noble Cayman Limited, a Cayman Islands company and a wholly-owned indirect subsidiary of Noble-Cayman
(“NCL”); Noble International Finance Company, a Cayman Islands company and a wholly-owned indirect subsidiary of Noble-Cayman (“NIFCO”);
and Noble Holding UK Limited, a company incorporated under the laws of England and Wales and a wholly-owned direct subsidiary of Noble-
UK (“NHUK”), as parent guarantor, entered into a new senior unsecured credit agreement (the “2017 Credit Facility” and, together with the 2015
Credit Facility, the “Credit Facilities”). The maximum aggregate amount of commitments under the 2017 Credit Facility is approximately $1.5
billion. Borrowings under the 2017 Credit Facility are subject to certain conditions precedent, including that there be no unused commitments to
advance loans under the 2015 Credit Facility. The 2017 Credit Facility will mature in January 2023. Borrowings may be used for working capital
and other general corporate purposes. The 2017 Credit Facility provides for a letter of credit sub-facility currently 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. At December 31, 2018, we had $3.4 million of
performance letters of credit outstanding under the 2017 Credit Facility. At December 31, 2018, other than the performance letters of credit, we
had no borrowings outstanding under the 2017 Credit Facility.
Both of our Credit Facilities have provisions which vary the applicable interest rates for borrowings based upon our debt ratings. We also
pay a facility fee under the 2015 Credit Facility on the full commitments thereunder (used or unused) and a commitment fee under the 2017 Credit
Facility on the daily unused amount of the underlying commitments, in each case which varies depending on our credit ratings. At December 31,
2018, the interest rates in effect under our Credit Facilities were the highest permitted interest rates under those agreements.
Debt Issuance
In January 2018, we issued $750.0 million aggregate principal amount of the 2026 Notes through our indirect wholly-owned subsidiary,
NHIL. The net proceeds of the offering of approximately $737.4 million, after expenses, were used to retire a portion of our near-term senior notes
in a related tender offer.
The indenture for the 2026 Notes contains certain covenants and restrictions, including, among others, restrictions on our subsidiaries’
ability to incur certain additional indebtedness. Additionally, the subsidiary guarantors must own, directly or indirectly, (i) assets comprising at
least 85% of the revenue of Noble-Cayman and its subsidiaries on a consolidated basis and (ii) jackups, semisubmersibles, drillships, submersibles
or other mobile offshore drilling units of material importance, the combined book value of which comprises at least 85% of the combined book
value of all such assets of Noble-Cayman and its subsidiaries on a consolidated basis, in each case, with respect to the most recently completed
fiscal year.
Seller Financing of Rig
In September 2018, we purchased the Noble Johnny Whitstine for $93.8 million with a $60.0 million seller-financed secured loan (the
“Seller Loan”). The Seller Loan has a term of four years and requires a 5% principal payment at the end of the third year with the remainder of
the principal due at the end of the term. The Seller Loan bears 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 Seller Loan. Based on the terms of the Seller Loan, the 1.25% paid-in-kind interest rate is accelerated into the
first year, resulting in an overall first year interest rate of 8.91%, of which only 4.25% is payable in cash. Thereafter, the paid-in-kind interest ends
and the cash interest rate of 4.25% is payable for the remainder of the term.
The Seller Loan is guaranteed by Noble-Cayman and is secured by a mortgage on the Noble Johnny Whitstine and by the pledge of the
shares of the single-purpose entity that owns the rig. The Seller Loan contains debt to total capitalization ratio and minimum liquidity financial
covenants substantially similar to the 2017 Credit Facility, and an asset and revenue covenant substantially similar to the 2026 Notes as well as
other covenants and provisions customarily found in secured transactions. The Seller Loan requires immediate repayment on the occurrence of
certain events, including the termination of the drilling contract entered into at the time of the purchase of the rig.
On February 14, 2019, we exercised our option to purchase a new jackup rig, to be known as the Noble Joe Knight, and we expect to
complete the purchase in late February 2019. The purchase of the Noble Joe Knight will be partially funded with cash and a seller loan on terms
similar to the Noble Johnny Whitstine.
Senior Notes Interest Rate Adjustments
During 2016 and 2017, we experienced debt rating downgrades by Moody’s Investors Service and S&P Global Ratings, which reduced our
debt ratings below investment grade. As a result of these downgrades, we experienced interest rate increases during 2016 and 2017 on the 2018
Notes, our Senior Notes due 2025 (the “2025 Notes”) and our Senior Notes due 2045 (the “2045 Notes”), all of which are subject to provisions
that vary the applicable interest rates based on our debt rating. On October 18, 2017, S&P Global Ratings further reduced our debt rating, which
39
increased the interest rates on the 2025 Notes and the 2045 Notes to 7.95% and 8.95%, respectively, effective April 2018. These senior notes have
reached the contractually defined maximum interest rate set for each rating agency and no further interest rate increases are possible. The interest
rates on these senior notes may be decreased if our debt ratings were to be raised by either rating agency above specified levels. Our other outstanding
senior notes do not contain provisions varying applicable interest rates based upon our credit ratings.
Debt Tender Offers, Repayments and Open Market Repurchases
In January 2018, we commenced cash tender offers for the 2018 Notes, 2019 Notes, 2020 Notes, 2021 Notes, 2022 Notes and 2024 Notes.
In February 2018, we purchased $754.2 million aggregate principal amount of these senior notes for $750.0 million, plus accrued interest, using
the net proceeds of the 2026 Notes issuance and cash on hand. As a result of this transaction, we recognized a net loss of approximately $3.5
million.
In February 2018, we redeemed the remaining principal amount of $61.9 million of the 2019 Notes for approximately $65.3 million, plus
accrued interest. As a result of this transaction, we recognized a net loss of approximately $3.5 million.
In March 2018, we repaid the remaining aggregate principal amount of $126.6 million of the 2018 Notes at maturity using cash on hand.
In March 2018, we purchased $9.5 million aggregate principal amount of various tranches of our senior notes for approximately $8.7
million, plus accrued interest, as open market repurchases and recognized a net gain of approximately $0.5 million.
In August 2018, we purchased $0.4 million aggregate principal amount of the 2042 Notes for approximately $0.3 million, plus accrued
interest, as open market repurchases and recognized a net gain of approximately $0.1 million.
In October 2018, we purchased $27.4 million aggregate principal amount of various tranches of our senior notes for approximately $20.2
million, plus accrued interest, as open market repurchases and recognized a net gain of approximately $6.9 million.
Covenants
The 2015 Credit Facility is guaranteed by NHUS and NHIL. The 2015 Credit Facility contains a covenant that limits our ratio of debt to
total tangible capitalization, as defined in the 2015 Credit Facility, to 0.60 at the end of each fiscal quarter.
The 2017 Credit Facility contains certain financial covenants applicable to NHUK and its subsidiaries, including (i) a covenant restricting
debt to total tangible capitalization to not greater than 0.55 at the end of each fiscal quarter, (ii) a minimum Liquidity requirement of $300.0 million,
(iii) a covenant that, beginning with the fiscal quarter ending March 31, 2018, the ratio of the Rig Value (as defined in the 2017 Credit Facility)
of Marketed Rigs (as defined in the 2017 Credit Facility) to the sum of commitments under the 2017 Credit Facility plus indebtedness for borrowed
money of the borrowers and guarantors, in each case, that directly own Marketed Rigs, is not less than 3:00 to 1:00 at the end of each fiscal quarter
and (iv) a covenant that, beginning with the fiscal quarter ending March 31, 2018, the ratio of (A) the Rig Value of the Closing Date Rigs (as
defined in the 2017 Credit Facility) that are directly wholly owned by the borrowers and guarantors to (B) the Rig Value of the Closing Date Rigs
owned by NHUK, subsidiaries of NHUK and certain local content affiliates, is not less than 80% at the end of each fiscal quarter (such covenants
described in (iii) and (iv) of this paragraph, the “Guarantor Ratio Covenants”). The 2017 Credit Facility also includes restrictions on borrowings
if, after giving effect to any such borrowings and the application of the proceeds thereof, the aggregate amount of Available Cash (as defined in
the 2017 Credit Facility) would exceed $200.0 million.
NHUK has guaranteed the obligations of the borrowers under the 2017 Credit Facility. In addition, on January 19, 2018, certain indirect
subsidiaries of Noble-UK became guarantors under the 2017 Credit Facility, including Noble Dave Beard Limited, Noble Drilling (TVL) Ltd.,
Noble Resources Limited, Noble SA Limited, Noble BD LLC, Noble Drilling Holding LLC, Noble Drilling International GmbH, Noble Leasing
(Switzerland) GmbH, and Noble Leasing III (Switzerland) GmbH. Certain other subsidiaries of Noble-UK may be required from time to time to
guarantee the obligations of the borrowers under the 2017 Credit Facility in order maintain compliance with the Guarantor Ratio Covenants.
The 2017 Credit Facility contains additional restrictive covenants generally applicable to NHUK and its subsidiaries, including restrictions
on the incurrence of liens and indebtedness, mergers and other fundamental changes, restricted payments, repurchases and redemptions of
indebtedness with maturities outside of the maturity of the 2017 Credit Facility, sale and leaseback transactions and transactions with affiliates.
In addition to the covenants from the Credit Facilities noted above, the covenants from the 2026 Notes described under “—Debt Issuance”
above and the covenants from the Seller Loan described under “—Seller Financing of Rig” above, the indentures governing our outstanding senior
unsecured notes contain covenants that place restrictions on certain merger and consolidation transactions, unless we are the surviving entity or
the other party assumes the obligations under the indenture, and on the ability to sell or transfer all or substantially all of our assets. There are also
restrictions on incurring or assuming certain liens and on entering into sale and lease-back transactions.
At December 31, 2018, our debt to total tangible capitalization ratio under our 2017 Credit Facility was approximately 0.48 and we were
in compliance with all applicable debt covenants. We continually monitor compliance with the covenants under our Credit Facilities, senior notes
and Seller Loan, and expect to remain in compliance throughout 2019.
40
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
2019
2020
2021
2022
2023
Thereafter
Other
Contractual Cash Obligations
Debt obligations
Interest payments
Operating leases (2)
Pension plan contributions
Tax reserves (1)
Total contractual cash
obligations
$ 3,934,553
3,613,160
36,888
147,609
183,786
— $
289,752
15,213
12,128
—
65,890
287,497
7,913
12,692
—
$
96,142
281,905
5,522
17,054
—
$
99,481
279,083
1,821
13,371
—
$
— $3,673,040
2,208,092
5,724
78,266
—
266,831
695
14,098
—
$
—
—
—
—
183,786
$ 7,915,996
$ 317,093
$ 373,992
$ 400,623
$ 393,756
$ 281,624
$5,965,122
$ 183,786
(1)
(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 11— Income Taxes.”
In February 2019, we amended the lease for our Sugar Land office to extend the lease for an additional ten years and to reduce the rented
space. The above table does not include this lease amendment.
At December 31, 2018, 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, 2018 (in thousands):
Total letters of credit and commercial
commitments
Critical Accounting Policies
Total
2019
2020
2021
2022
2023
Thereafter
Amount of Commitment Expiration Per Period
$ 14,655
$
9,437
$
1,535
$
— $
— $
8
$
3,675
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 U.S. (“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, those of our wholly-owned subsidiaries and entities in which we hold a
controlling financial interest. Our consolidated financial statements include the accounts of two joint ventures, in each of which we own a 50
percent interest. Our ownership interest meets the definition of variable interest under Financial Accounting Standards Board (“FASB”) codification
and we have determined that we are the primary beneficiary. Intercompany balances and transactions have been eliminated in consolidation.
The combined carrying amount of the Bully-class drillships at December 31, 2018 and 2017 totaled $0.7 billion and $1.3 billion, respectively.
These assets were primarily funded through partner equity contributions. Cash held by the Bully joint ventures totaled approximately $45.2 million
at December 31, 2018 as compared to approximately $41.6 million at December 31, 2017.
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Basis of Presentation-U.K. Companies Act 2006 Section 435 Statement
The accompanying consolidated financial statements have been prepared in accordance with US 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, 2018 and 2017, we had $209.1 million and $83.5 million
of construction-in-progress, respectively. Such amounts are included in “Property and equipment, at cost” in the accompanying 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, 2018, 2017 and 2016, there was $2.9 million, zero and $22.4 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 $146.3 million and $149.3 million at December 31, 2018 and 2017, respectively.
Depreciation expense from continuing operations related to overhauls and asset replacement totaled $66.9 million, $79.2 million and $86.0 million
for the years ended December 31, 2018, 2017 and 2016, 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, 2018, 2017 and 2016, we recognized a non-cash loss on impairment of $802.1 million, $121.6 million,
and $1.5 billion, 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
42
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.
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 $80.8 million and $114.3 million at December 31, 2018 and 2017, 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 $47.7 million at December 31, 2018 as compared to $55.7
43
million at December 31, 2017 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 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. We cannot predict or provide assurance as to the ultimate outcome of any existing or future assessments. Our net 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.
During 2014, the Internal Revenue Service (“IRS”) began its examination of our tax reporting in the U.S. for the taxable years ended
December 31, 2010 and 2011. The IRS examination team has completed its examination of our 2010 and 2011 U.S. tax returns and proposed
adjustments and deficiencies with respect to certain items that were reported by us for the 2010 and 2011 tax years. On December 19, 2016, we
received the Revenue Agent Report from the IRS. We believe that we have accurately reported all amounts in our tax returns, and have submitted
administrative protests with the IRS Office of Appeals contesting the examination team’s proposed adjustments. We intend to vigorously defend
our reported positions, and believe the ultimate resolution of the adjustments proposed by the IRS examination team will not have a material
adverse effect on our consolidated financial statements. During the third quarter of 2017, the IRS initiated its examination of our 2012, 2013, 2014
and 2015 tax returns.
Audit claims of approximately $50.7 million attributable to income and other business taxes were assessed against Noble entities in Mexico
related to tax years 2005 and 2007. 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.
On December 22, 2017, the President of the United States signed the into law legislation informally known as the Tax Cuts and Jobs Act
(the “Act”). The Act represents major tax reform legislation that, among other provisions, reduces the U.S. corporate tax rate. The Company
recognized the income tax effects of the Act in its 2017 financial statements, including $109.0 million of tax benefit related to the write-down of
our net deferred tax liabilities, in accordance with Accounting Standards Codification (“ASC”) Topic 740, Income Taxes, in the reporting period
in which the Act was enacted. During the fourth quarter of 2017, the Act resulted in the write-down of our U.S. net deferred tax liabilities. In
accordance with the guidance issued in Staff Accounting Bulletin No. 118, during the third quarter of 2018, we finalized our provisional amounts
recorded as we completed our technical analysis, computations and tax law interpretations and filed our 2017 U.S. tax return. As a result, we
recognized an additional tax benefit of $24.9 million.
The Act introduces a new anti-deferral provision, which subjects a U.S. parent shareholder to current tax on certain income referred to as
Global Intangible Low-Taxed Income, of its foreign subsidiaries. The Company has adopted a policy to treat tax due on future U.S. inclusions in
taxable income as period costs when incurred.
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, 2018 and 2017, loss reserves for personal injury and protection claims totaled $22.4 million and $22.0 million, respectively,
and such amounts are included in “Other current liabilities” 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
44
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 15— 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 in interest rates, currency
exchange rates or equity prices, as further described below.
Interest Rate Risk
We are subject to market risk exposure related to changes in interest rates on borrowings under the Credit Facilities. Interest on borrowings
under our Credit Facilities is at an agreed upon percentage point spread over LIBOR, or a base rate stated in the agreements. At December 31,
2018, we had no borrowings outstanding or letters of credit issued under the 2015 Credit Facility. At December 31, 2018, we had $3.4 million of
performance letters of credit outstanding under the 2017 Credit Facility. At December 31, 2018, other than the performance letters of credit, we
had no borrowings outstanding under the 2017 Credit Facility.
During 2016 and 2017, we experienced debt rating downgrades by Moody’s Investors Service and S&P Global Ratings, which reduced our
debt ratings below investment grade. As a result of these downgrades, we experienced interest rate increases during 2016 and 2017 on our Senior
Notes due 2018, our Senior Notes due 2025 (the “2025 Notes”) and our Senior Notes due 2045 (the “2045 Notes”), all of which are subject to
provisions that vary the applicable interest rates based on our debt rating. On October 18, 2017, S&P Global Ratings further reduced our debt
rating, which increased the interest rates on the 2025 Notes and the 2045 Notes to 7.95% and 8.95%, respectively, effective April 2018. These
senior notes have reached the contractually defined maximum interest rate set for each rating agency and no further interest rate increases are
possible. The interest rates on these senior notes may be decreased if our debt ratings were to be raised by either rating agency above specified
levels. Our other outstanding senior notes do not contain provisions varying applicable interest rates based upon our credit ratings.
We maintain certain debt instruments at a fixed rate whose fair value will fluctuate based on changes in market expectations for interest
rates and perceptions of our credit risk. The fair value of our total debt was $2.9 billion and $3.4 billion at December 31, 2018 and December 31,
2017, respectively. The decrease in the fair value of debt relates to a reduction in total principal amount outstanding due to our debt repayments
during 2018, partially offset by our debt issuance and changes in market expectations for interest rates and perceptions of our credit risk.
Foreign Currency Risk
Although we are a UK company, we define foreign currency as any non-U.S. denominated currency. Our functional currency is the U.S.
Dollar. However, outside the United States, a portion of our expenses are incurred in local currencies. Therefore, when the U.S. Dollar weakens
(strengthens) in relation to the currencies of the countries in which we operate, our expenses reported in U.S. 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 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. There were no foreign currency forward contracts
outstanding or entered into during the year ended December 31, 2018.
45
Market Risk
We have a U.S. noncontributory defined benefit pension plan that covers certain salaried employees and a U.S. 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 U.S. 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 U.S. plans when required.
The benefit amount that can be covered by the qualified U.S. 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 U.S. plan. We refer to the qualified U.S. plans and the excess benefit plan collectively as the “U.S. plans.”
In addition to the U.S. plans, Noble Drilling (Land Support) Limited, an indirect, wholly-owned subsidiary of Noble-UK, 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-U.S. plan”). Benefits are based on credited service and employees’ compensation, as defined by the non-U.S. plan.
Changes in market asset values related to the pension plans noted above could have a material impact upon our Consolidated Statements
of Comprehensive Income (Loss) and could result in material cash expenditures in future periods.
46
Item 8. Financial Statements and Supplementary Data.
The following financial statements are filed in this Item 8:
Report of Independent Registered Public Accounting Firm (Noble-UK)
Noble Corporation plc (Noble-UK) and Subsidiaries Consolidated Balance Sheet as of December 31, 2018 and
2017
Noble Corporation plc (Noble-UK) and Subsidiaries Consolidated Statements of Operations for the Years Ended
December 31, 2018, 2017 and 2016
Noble Corporation plc (Noble-UK) and Subsidiaries Consolidated Statements of Comprehensive Income (Loss) for
the Years Ended December 31, 2018, 2017 and 2016
Noble Corporation plc (Noble-UK) and Subsidiaries Consolidated Statements of Cash Flows for the Years Ended
December 31, 2018, 2017 and 2016
Noble Corporation plc (Noble-UK) and Subsidiaries Consolidated Statements of Equity for the Years Ended
December 31, 2018, 2017 and 2016
Report of Independent Registered Public Accounting Firm (Noble-Cayman)
Noble Corporation (Noble-Cayman) and Subsidiaries Consolidated Balance Sheet as of December 31, 2018 and
2017
Noble Corporation (Noble-Cayman) and Subsidiaries Consolidated Statements of Operations for the Years Ended
December 31, 2018, 2017 and 2016
Noble Corporation (Noble-Cayman) and Subsidiaries Consolidated Statements of Comprehensive Income (Loss)
for the Years Ended December 31, 2018, 2017 and 2016
Noble Corporation (Noble-Cayman) and Subsidiaries Consolidated Statements of Cash Flows for the Years Ended
December 31, 2018, 2017 and 2016
Noble Corporation (Noble-Cayman) and Subsidiaries Consolidated Statements of Equity for the Years Ended
December 31, 2018, 2017 and 2016
Notes to Consolidated Financial Statements
Page
48
50
51
52
53
54
55
57
58
59
60
61
62
47
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and
Shareholders of Noble Corporation plc
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Noble Corporation plc and its subsidiaries (the “Company”) as of
December 31, 2018 and 2017, and the related consolidated statements of operations, comprehensive income (loss), cash flows, and equity for
each of the three years in the period ended December 31, 2018, 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, 2018, 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, 2018 and 2017 and the results of its operations and its cash flows for each of the three years in the period ended
December 31, 2018 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, 2018, 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 as 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.
48
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.
/s/ PricewaterhouseCoopers LLP
Houston, Texas
February 21, 2019
We have served as the Company’s auditor since 1994.
49
NOBLE CORPORATION PLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
ASSETS
December 31,
2018
December 31,
2017
Current assets
Cash and cash equivalents
Accounts receivable, net
Taxes receivable
Prepaid expenses and other current assets
Total current assets
Property and equipment, at cost
Accumulated depreciation
Property and equipment, net
Other assets
Total assets
Current liabilities
Current maturities of long-term debt
Accounts payable
Accrued payroll and related costs
Taxes payable
Interest payable
Other current liabilities
Total current liabilities
Long-term debt
Deferred income taxes
Other liabilities
Total liabilities
LIABILITIES AND EQUITY
Commitments and contingencies (Note 15)
Shareholders' equity
Common stock, $0.01 par value, ordinary shares; 246,794 and 244,971 shares
outstanding as of December 31, 2018 and December 31, 2017, respectively.
Additional paid-in capital
Retained earnings
Accumulated other comprehensive loss
Total shareholders' equity
Noncontrolling interests
Total equity
Total liabilities and equity
See accompanying notes to the consolidated financial statements.
50
$
$
$
$
375,232
200,722
20,498
62,604
659,056
10,956,412
(2,475,694)
8,480,718
125,149
9,264,923
$
$
— $
125,557
50,284
29,386
100,100
60,130
365,457
3,877,402
91,695
275,795
4,610,349
662,829
204,696
105,345
66,105
1,038,975
12,034,331
(2,545,091)
9,489,240
266,444
10,794,659
249,843
84,032
54,904
34,391
98,189
71,665
593,024
3,795,867
164,962
290,178
4,844,031
2,468
699,409
3,608,366
(57,072)
4,253,171
401,403
4,654,574
9,264,923
$
2,450
678,922
4,637,677
(42,888)
5,276,161
674,467
5,950,628
10,794,659
NOBLE CORPORATION PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Operating revenues
Contract drilling services
Reimbursables and other
Operating costs and expenses
Contract drilling services
Reimbursables
Depreciation and amortization
General and administrative
Loss on impairment
Operating loss
Other income (expense)
Interest expense, net of amount capitalized
Gain (loss) on extinguishment of debt, net
Interest income and other, net
Loss from continuing operations before income taxes
Income tax benefit (provision)
Net loss from continuing operations
Net loss from discontinued operations, net of tax
Net loss
Net (income) loss attributable to noncontrolling interests
Net loss attributable to Noble Corporation plc
Net loss attributable to Noble Corporation plc
Loss from continuing operations
Net loss from discontinued operations, net of tax
Net loss attributable to Noble Corporation plc
Per share data
Basic:
Loss from continuing operations
Loss from discontinued operations
Net loss attributable to Noble Corporation plc
Diluted:
Loss from continuing operations
Loss from discontinued operations
Net loss attributable to Noble Corporation plc
Weighted- Average Shares Outstanding
Basic
Diluted
Year Ended December 31,
2018
2017
2016
$
$
1,036,082
46,744
1,082,826
$
1,207,026
29,889
1,236,915
629,937
37,084
486,530
73,216
802,133
2,028,900
(946,074)
(297,611)
(1,793)
8,302
(1,237,176)
106,641
(1,130,535)
—
(1,130,535)
245,485
(885,050) $
(885,050) $
—
(885,050) $
(3.59) $
—
(3.59) $
(3.59) $
—
(3.59) $
$
$
$
$
$
$
$
642,937
18,435
547,990
71,634
121,639
1,402,635
(165,720)
(291,989)
—
7,897
(449,812)
(42,629)
(492,441)
(1,486)
(493,927)
(22,584)
(516,511) $
(515,025) $
(1,486)
(516,511) $
(2.10) $
(0.01)
(2.11) $
(2.10) $
(0.01)
(2.11) $
2,242,200
59,865
2,302,065
877,689
45,499
611,067
69,258
1,458,749
3,062,262
(760,197)
(222,915)
17,814
(1,731)
(967,029)
109,156
(857,873)
—
(857,873)
(71,707)
(929,580)
(929,580)
—
(929,580)
(3.82)
—
(3.82)
(3.82)
—
(3.82)
246,614
246,614
244,743
244,743
243,127
243,127
See accompanying notes to the consolidated financial statements.
51
NOBLE CORPORATION PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Net loss
Other comprehensive income (loss)
Foreign currency translation adjustments
Net pension plan gain (loss) (net of tax provision (benefit) of ($1,828),
$523 and ($1,828) for the year ended December 31, 2018, 2017 and
2016, respectively)
Amortization of deferred pension plan amounts (net of tax provision
of $345, $623 and $1,635 for the year ended December 31, 2018, 2017
and 2016, respectively)
Net pension plan curtailment and settlement expense (net of tax
provision of $28, zero and $7,218 for the year ended December 31,
2018, 2017 and 2016, respectively)
Prior service cost arising during the period (net of tax provision (benefit)
of ($55), zero and $344 for the year ended December 31, 2018, 2017
and 2016, respectively)
Other comprehensive income (loss), net
Year Ended December 31,
2018
(1,130,535) $
$
2017
2016
(493,927) $
(857,873)
(2,729)
990
(19)
(7,099)
6,774
(8,237)
1,298
1,393
3,127
107
95
15,216
(221)
(8,644)
—
9,252
948
11,035
(71,707)
(918,545)
Net comprehensive (income) loss attributable to noncontrolling interests
Comprehensive loss attributable to Noble Corporation plc
$
245,485
(893,694) $
(22,584)
(507,259) $
See accompanying notes to the consolidated financial statements.
52
NOBLE CORPORATION PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Cash flows from operating activities
Net loss
Adjustments to reconcile net loss to net cash flow from operating
activities:
Depreciation and amortization
Loss on impairment
(Gain) loss on extinguishment of debt, net
Deferred income taxes
Amortization of share-based compensation
Other long-term asset write-off
Other costs, net
Changes in components of working capital
Change in taxes receivable
Net changes in other operating assets and liabilities
Net cash provided by operating activities
Cash flows from investing activities
Capital expenditures
Proceeds from disposal of assets, net
Net cash used in investing activities
Cash flows from financing activities
Issuance of senior notes
Repayments of debt
Debt issuance costs
Dividend payments
Dividends paid to noncontrolling interests
Tender offer premium
Taxes withheld on employee stock transactions
Net cash used in financing activities
Net increase (decrease) in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash, beginning of period
Cash, cash equivalents and restricted cash, end of period
$
Year Ended December 31,
2018
2017
2016
$
(1,130,535) $
(493,927) $
(857,873)
486,530
802,133
1,793
(68,416)
23,993
—
6,446
84,847
(34,940)
171,851
(194,779)
5,402
(189,377)
750,000
(972,708)
(15,639)
—
(27,579)
—
(3,470)
(269,396)
(286,922)
662,829
375,907
$
547,990
121,639
—
241,326
29,115
29,032
12,590
(49,865)
(21,225)
416,675
(120,707)
2,382
(118,325)
—
(300,000)
(42)
—
(56,881)
—
(4,320)
(361,243)
(62,893)
725,722
662,829
$
611,067
1,458,749
(17,814)
(189,897)
34,720
—
13,434
45
90,309
1,142,740
(711,403)
24,808
(686,595)
980,100
(1,049,338)
(12,111)
(47,534)
(85,944)
(24,649)
(3,192)
(242,668)
213,477
512,245
725,722
See accompanying notes to the consolidated financial statements.
53
NOBLE CORPORATION PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EQUITY
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Shares
Balance
Par Value
Additional Paid-
in Capital
Retained
Earnings
Accumulated
Other
Comprehensive
Loss
Noncontrolling
Interests
Total Equity
Balance at December 31, 2015
241,977
$
2,420
$
628,483
$
6,131,501
$
(63,175)
$
723,001
$
7,422,230
Employee related equity activity
Amortization of share-based compensation
Issuance of share-based compensation shares
Tax benefit of equity transactions
Net income (loss)
Dividends paid to noncontrolling interests
Dividends
Other comprehensive income, net
—
1,262
—
—
—
—
—
—
12
—
—
—
—
—
34,720
(3,625)
(5,410)
—
—
—
—
—
—
—
(929,580)
—
(47,700)
—
—
—
—
—
—
—
11,035
—
—
—
71,707
(85,944)
—
—
34,720
(3,613)
(5,410)
(857,873)
(85,944)
(47,700)
11,035
Balance at December 31, 2016
243,239
$
2,432
$
654,168
$
5,154,221
$
(52,140)
$
708,764
$
6,467,445
Employee related equity activity
Amortization of share-based compensation
Issuance of share-based compensation shares
Tax benefit of equity transactions
Net income (loss)
Dividends paid to noncontrolling interests
Dividends
Other comprehensive income, net
Balance at December 31, 2017
Tax effects of intra-entity asset transfers (Note 1)
Stranded tax effect resulting from the Act (Note 1)
Adjustment for adopting the revenue recognition
standard (Note 1)
—
1,732
—
—
—
—
—
—
18
—
—
—
—
—
$
244,971
—
$
2,450
—
—
—
—
—
29,115
(23)
(4,338)
—
—
—
—
678,922
—
—
—
Balance at January 1, 2018
244,971
2,450
678,922
4,493,336
Employee related equity activity
Amortization of share-based compensation
Issuance of share-based compensation shares
Tax benefit of equity transactions
Net loss
Dividends paid to noncontrolling interests
Dividends equivalents (1)
Other comprehensive loss, net
Balance at December 31, 2018
—
1,823
—
—
—
—
—
—
18
—
—
—
—
—
23,993
(18)
(3,488)
—
—
—
—
—
—
—
(885,050)
—
80
—
—
—
—
(516,511)
—
(33)
—
—
—
—
—
—
—
9,252
—
—
—
22,584
(56,881)
—
—
29,115
(5)
(4,338)
(493,927)
(56,881)
(33)
9,252
$
4,637,677
$
(42,888)
$
674,467
$
5,950,628
(148,393)
—
5,540
(1,488)
(5,540)
—
(48,428)
—
—
—
—
—
—
(8,644)
—
—
—
(148,393)
—
(1,488)
674,467
5,800,747
—
—
—
(245,485)
(27,579)
—
—
23,993
—
(3,488)
(1,130,535)
(27,579)
80
(8,644)
246,794
$
2,468
$
699,409
$
3,608,366
$
(57,072)
$
401,403
$
4,654,574
(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.
54
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and
Shareholder 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 and its subsidiaries (the “Company”) as of December 31,
2018 and 2017, and the related consolidated statements of operations, comprehensive income (loss), cash flows, and equity for each of the three
years in the period ended December 31, 2018, 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, 2018, 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, 2018 and 2017 and the results of its operations and its cash flows for each of the three years in the period ended
December 31, 2018 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, 2018, 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 as 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.
55
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.
/s/ PricewaterhouseCoopers LLP
Houston, Texas
February 21, 2019
We have served as the Company’s auditor since 1994.
56
NOBLE CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
ASSETS
December 31,
2018
December 31,
2017
Current assets
Cash and cash equivalents
Accounts receivable, net
Taxes receivable
Prepaid expenses and other current assets
Total current assets
Property and equipment, at cost
Accumulated depreciation
Property and equipment, net
Other assets
Total assets
Current liabilities
Current maturities of long-term debt
Accounts payable
Accrued payroll and related costs
Taxes payable
Interest payable
Other current liabilities
Total current liabilities
Long-term debt
Deferred income taxes
Other liabilities
Total liabilities
LIABILITIES AND EQUITY
Commitments and contingencies (Note 15)
Shareholder equity
Common stock, $0.10 par value, ordinary shares; 261,246 shares outstanding
as of December 31, 2018 and December 31, 2017
Capital in excess of par value
Retained earnings
Accumulated other comprehensive loss
Total shareholder equity
Noncontrolling interests
Total equity
Total liabilities and equity
See accompanying notes to the consolidated financial statements.
57
$
$
$
$
374,375
200,722
20,498
61,917
657,512
10,956,412
(2,475,694)
8,480,718
125,149
9,263,379
$
$
— $
125,237
50,284
29,386
100,100
60,012
365,019
3,877,402
91,695
275,795
4,609,911
662,011
204,696
105,345
65,441
1,037,493
12,034,331
(2,545,091)
9,489,240
266,528
10,793,261
249,843
83,873
54,904
33,965
98,189
71,466
592,240
3,795,867
164,962
290,178
4,843,247
26,125
647,082
3,635,930
(57,072)
4,252,065
401,403
4,653,468
9,263,379
$
26,125
623,137
4,669,173
(42,888)
5,275,547
674,467
5,950,014
10,793,261
NOBLE CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Operating revenues
Contract drilling services
Reimbursables and other
Operating costs and expenses
Contract drilling services
Reimbursables
Depreciation and amortization
General and administrative
Loss on impairment
Operating loss
Other income (expense)
Interest expense, net of amount capitalized
Gain (loss) on extinguishment of debt, net
Interest income and other, net
Loss from continuing operations before income taxes
Income tax benefit (provision)
Net loss from continuing operations
Net income from discontinued operations, net of tax
Net loss
Net (income) loss attributable to noncontrolling interests
Net loss attributable to Noble Corporation
Year Ended December 31,
2018
2017
2016
$
$
1,036,082
46,744
1,082,826
$
1,207,026
29,889
1,236,915
628,128
37,084
482,660
38,203
802,133
1,988,208
(905,382)
(297,611)
(1,793)
8,282
(1,196,504)
106,534
(1,089,970)
—
(1,089,970)
245,485
(844,485) $
640,483
18,435
543,119
41,087
121,639
1,364,763
(127,848)
(291,989)
—
7,733
(412,104)
(42,595)
(454,699)
2,967
(451,732)
(22,584)
(474,316) $
$
2,242,200
60,565
2,302,765
871,912
45,499
611,013
46,045
1,458,749
3,033,218
(730,453)
(222,915)
17,814
(1,616)
(937,170)
109,163
(828,007)
—
(828,007)
(71,707)
(899,714)
See accompanying notes to the consolidated financial statements.
58
NOBLE CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Net loss
Other comprehensive income (loss)
Foreign currency translation adjustments
Net pension plan gain (loss) (net of tax provision (benefit) of ($1,828),
$523 and ($1,828) for the year ended December 31, 2018, 2017 and
2016, respectively)
Amortization of deferred pension plan amounts (net of tax provision
of $345, $623 and $1,635 for the year ended December 31, 2018, 2017
and 2016, respectively)
Net pension plan curtailment and settlement expense (net of tax
provision of $28, zero and $7,218 for the year ended December 31,
2018, 2017 and 2016, respectively)
Year Ended December 31,
2018
(1,089,970) $
$
2017
2016
(451,732) $
(828,007)
(2,729)
990
(19)
(7,099)
6,774
(8,237)
1,298
1,393
3,127
107
95
15,216
Prior service cost arising during the period (net of tax provision (benefit)
of ($55), zero and $344 for the year ended December 31, 2018, 2017
and 2016, respectively)
Other comprehensive income (loss), net
Net comprehensive (income) loss attributable to noncontrolling interests
Comprehensive loss attributable to Noble Corporation
$
(221)
(8,644)
245,485
(853,129) $
—
9,252
(22,584)
(465,064) $
948
11,035
(71,707)
(888,679)
See accompanying notes to the consolidated financial statements.
59
NOBLE CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Cash flows from operating activities
Net loss
Adjustments to reconcile net loss to net cash flow from operating
activities:
Depreciation and amortization
Loss on impairment
(Gain) loss on extinguishment of debt, net
Deferred income taxes
Amortization of share-based compensation
Other long-term asset write-off
Other costs, net
Change in components of working capital
Change in taxes receivable
Net changes in other operating assets and liabilities
Net cash provided by operating activities
Cash flows from investing activities
Capital expenditures
Proceeds from disposal of assets
Net cash used in investing activities
Cash flows from financing activities
Issuance of senior notes
Repayments of debt
Debt issuance costs
Tender offer premium
Dividends paid to noncontrolling interests
Contributions (distributions) from (to) parent company, net
Net cash used in financing activities
Net increase (decrease) in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash, beginning of period
Cash, cash equivalents and restricted cash, end of period
$
Year Ended December 31,
2018
2017
2016
$
(1,089,970) $
(451,732) $
(828,007)
482,660
802,133
1,793
(68,416)
23,945
—
6,446
84,847
(30,679)
212,759
(194,779)
5,402
(189,377)
750,000
(972,708)
(15,639)
—
(27,579)
(44,417)
(310,343)
(286,961)
662,011
375,050
$
543,119
121,639
—
241,326
29,046
29,030
12,591
(49,865)
(20,080)
455,074
(120,707)
2,382
(118,325)
—
(300,000)
(42)
—
(56,881)
28,352
(328,571)
8,178
653,833
662,011
$
611,013
1,458,749
(17,814)
(189,897)
32,782
—
13,434
(38)
92,713
1,172,935
(711,403)
24,808
(686,595)
980,100
(1,049,338)
(12,111)
(24,649)
(85,944)
(152,360)
(344,302)
142,038
511,795
653,833
See accompanying notes to the consolidated financial statements.
60
NOBLE CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EQUITY
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Shares
Balance
Par Value
Capital in Excess
of Par Value
Retained
Earnings
Accumulated
Other
Comprehensive
Loss
Noncontrolling
Interests
Total Equity
Balance at December 31, 2015
261,246
$
26,125
$
561,309
$
6,167,211
$
(63,175)
$
723,001
$
7,414,471
Distributions to parent company, net
Capital contribution by parent - share-based
compensation
Net income (loss)
Dividends paid to noncontrolling interests
Other comprehensive income, net
—
—
—
—
—
—
—
—
—
—
—
32,782
—
—
—
(152,360)
—
(899,714)
—
—
—
—
—
—
11,035
—
—
71,707
(85,944)
—
(152,360)
32,782
(828,007)
(85,944)
11,035
Balance at December 31, 2016
261,246
$
26,125
$
594,091
$
5,115,137
$
(52,140)
$
708,764
$
6,391,977
Contributions from parent company, net
Capital contribution by parent - share-based
compensation
Net income (loss)
Dividends paid to noncontrolling interests
Other comprehensive income, net
—
—
—
—
—
—
—
—
—
—
—
29,046
—
—
—
28,352
—
(474,316)
—
—
—
—
—
—
9,252
—
—
22,584
(56,881)
—
28,352
29,046
(451,732)
(56,881)
9,252
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 (Note 1)
Stranded tax effect resulting from the Act (Note 1)
Adjustment for adopting the revenue recognition
standard (Note 1)
—
—
—
—
—
—
January 1, 2018
261,246
26,125
Distributions to parent company, net
Capital contribution by parent - share-based
compensation
Net loss
Dividends paid to noncontrolling interests
Other comprehensive loss, net
Balance at December 31, 2018
—
—
—
—
—
—
—
—
—
—
—
—
—
623,137
—
23,945
—
—
—
(148,393)
5,540
(1,488)
4,524,832
(44,417)
—
(844,485)
—
—
—
(5,540)
—
(48,428)
—
—
—
—
(8,644)
—
—
—
674,467
—
—
(245,485)
(27,579)
—
(148,393)
—
(1,488)
5,800,133
(44,417)
23,945
(1,089,970)
(27,579)
(8,644)
261,246
$
26,125
$
647,082
$
3,635,930
$
(57,072)
$
401,403
$
4,653,468
See accompanying notes to the consolidated financial statements.
61
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Note 1— Organization and Significant Accounting Policies
Noble Corporation plc, a public limited company incorporated under the laws of England and Wales (“Noble-UK”), 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. As of December 31, 2018, our fleet of 24 drilling rigs consisted of eight drillships, four semisubmersibles 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.
Noble Corporation, a Cayman Islands company (“Noble-Cayman”), is an indirect, wholly-owned subsidiary of Noble-UK, our publicly-
traded parent company. Noble-UK’s principal asset is all of the shares of Noble-Cayman. Noble-Cayman has no public equity outstanding. The
consolidated financial statements of Noble-UK include the accounts of Noble-Cayman, and Noble-UK conducts substantially all of its business
through Noble-Cayman and its subsidiaries.
Principles of Consolidation
The consolidated financial statements include our accounts, those of our wholly-owned subsidiaries and entities in which we hold a
controlling financial interest. Our consolidated financial statements also include the accounts of two joint ventures, in each of which we own a 50
percent interest. Our ownership interest meets the definition of variable interest under Financial Accounting Standards Board (“FASB”) codification
and we have determined that we are the primary beneficiary. Intercompany balances and transactions have been eliminated in consolidation.
The combined carrying amount of the Bully-class drillships at December 31, 2018 and 2017 totaled $0.7 billion and $1.3 billion, respectively.
These assets were primarily funded through partner equity contributions. Cash held by the Bully joint ventures totaled approximately $45.2 million
at December 31, 2018 as compared to approximately $41.6 million at December 31, 2017.
Revision of Prior Period Financial Statements
During the preparation of our 2018 financial statements, we identified a computational error that resulted in misstatements of certain line
items on the Consolidated Statements of Cash Flows for Noble Corporation plc and Noble Corporation (Cayman) for the years ended December 31,
2017 and 2016. These errors did not impact our cash, cash equivalents and restricted cash balances. We assessed the materiality of the misstatements
and concluded the misstatements were immaterial to the previously issued financial statements.
We have revised the Consolidated Statements of Cash Flows for the years ended December 31, 2017 and 2016. The impacts on the
Consolidated Statements of Cash Flows and related notes to the financial statements are presented below:
Cash flows from operating activities
Net change in other assets and liabilities
Net cash provided by operating activities
Cash flows from investing activities
Capital expenditures
Consolidated Statements of Cash Flows - Noble Corporation plc
Year Ended December 31, 2017
Year Ended December 31, 2016
As Reported
Adjustment
As Revised
As Reported
Adjustment
As Revised
$
16,038
$
(37,263) $
(21,225)
$
73,645
$
16,664
$
90,309
453,938
(37,263)
416,675
1,126,076
16,664
1,142,740
$
(157,970) $
37,263
$
(120,707)
$
(694,739) $
(16,664) $
(711,403)
Net cash used in investing activities
(155,588)
37,263
(118,325)
(669,931)
(16,664)
(686,595)
62
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Cash flows from operating activities
Net change in other assets and liabilities
Net cash provided by operating activities
Cash flows from investing activities
Capital expenditures
Consolidated Statements of Cash Flows - Noble Corporation (Cayman)
Year Ended December 31, 2017
Year Ended December 31, 2016
As Reported
Adjustment
As Revised
As Reported
Adjustment
As Revised
$
17,183
$
(37,263) $
(20,080)
$
76,049
$
16,664
$
92,713
492,337
(37,263)
455,074
1,156,271
16,664
1,172,935
$
(157,970) $
37,263
$
(120,707)
$
(694,739) $
(16,664) $
(711,403)
Net cash used in investing activities
(155,588)
37,263
(118,325)
(669,931)
(16,664)
(686,595)
Foreign Currency Translation
Although we are a UK company, our functional currency is the U.S. dollar, and we define any non-U.S. dollar denominated currency as
“foreign currencies.” In non-U.S. locations where the U.S. 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-U.S. 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 accounts from the functional currency
to the U.S. 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, 2018.
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, 2018, our restricted cash
balance consisted of $0.7 million of restricted cash accounts for interest payments associated with our financing of the Noble Johnny Whitstine,
recorded in Prepaid expenses and other current assets. As of December 31, 2017 and 2016, we had no restricted cash balances.
Accounts Receivable
We record accounts receivable at the amount we invoice our clients, net of allowance for doubtful accounts. We provide an allowance
for uncollectible accounts, as necessary. Our allowance for doubtful accounts as of December 31, 2018 and 2017 was $2.2 million and $20.8
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 $52.1 million and $25.5 million of capital accruals as of December 31, 2018 and 2017, respectively.
63
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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 which suggest that the value of the asset is
not recoverable. 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.
64
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar 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 $80.8 million and $114.3 million at December 31, 2018 and 2017, 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 $47.7 million at December 31, 2018 as compared to $55.7
million at December 31, 2017 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 U.S., UK or 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 laws in effect in various countries
65
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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.
On December 22, 2017, the President of the United States signed into law legislation informally known as the Tax Cuts and Jobs Act (the
“Act”). The Act represents major tax reform legislation that, among other provisions, reduces the U.S. corporate tax rate. The Company recognized
the income tax effects of the Act in its 2017 financial statements, including $109.0 million of tax benefit related to the write-down of our net
deferred tax liabilities, in accordance with Accounting Standards Codification (“ASC”) Topic 740, Income Taxes, in the reporting period in which
the Act was enacted. During the fourth quarter of 2017, the Act resulted in the write-down of our U.S. net deferred tax liabilities. In accordance
with the guidance issued in Staff Accounting Bulletin No. 118 (SAB No. 118), during the third quarter of 2018, we finalized our provisional
amounts recorded as we completed our technical analysis, computations and tax law interpretations and filed our 2017 U.S. tax return. As a result,
we recognized an additional tax benefit of $24.9 million. See “Note 11— Income Taxes,” for further information on the financial statement impact
of the Act.
The Act introduces a new anti-deferral provision, which subjects a U.S. parent shareholder to current tax on certain income referred to as
Global Intangible Low-Taxed Income, of its foreign subsidiaries. The Company has adopted a policy to treat tax due on future U.S. inclusions in
taxable income as period costs when incurred.
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, 2018 and 2017, loss reserves for personal injury and protection claims totaled $22.4 million and $22.0 million, respectively,
and such amounts are included in “Other current liabilities” 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.
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.
Discontinued Operations
On August 1, 2014, Noble-UK 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
66
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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, Noble-UK 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, 2017, we recorded a non-cash loss
of $1.5 million in “Net loss from discontinued operations, net of tax” on our Consolidated Statement of Operations from the effects of Paragon
Offshore's rejection of the Separation Agreements. For additional information related to the Spin-off, refer to “Note 15— 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 May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, which creates ASC Topic 606, “Revenue from Contracts
with Customers,” and supersedes the revenue recognition requirements in Topic 605, “Revenue Recognition,” including most industry-specific
revenue recognition guidance throughout the Industry Topics of the Codification. In addition, ASU No. 2014-09 supersedes the cost guidance in
Subtopic 605-35, “Revenue Recognition—Construction-Type and Production-Type Contracts,” and creates new Subtopic 340-40, “Other Assets
and Deferred Costs—Contracts with Customers.” Under the new guidance, revenue is recognized when a customer obtains control of promised
goods or services and in an amount that reflects the consideration the entity expects to receive in exchange for those goods or services.
We adopted ASU 2014-09 and its related amendments, or collectively Topic 606, effective January 1, 2018 using the modified retrospective
implementation method. Accordingly, we have applied the five-step method outlined in Topic 606 for determining when and how revenue is
recognized to all contracts that were not completed as of the date of adoption. Revenues for reporting periods beginning after January 1, 2018 are
presented under Topic 606, while prior period amounts have not been adjusted and continue to be reported under the previous revenue recognition
guidance. For contracts that were modified before the effective date, we have considered the modification guidance within the new standard and
determined that the revenue recognized and contract balances recorded prior to adoption for such contracts were not impacted. While Topic 606
requires additional disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, its
adoption has not had a material impact on the measurement or recognition of our revenues. Our modified retrospective adoption, for which we
were not required to make any material changes to the prior year presentation, did not have a material effect on our consolidated financial statements.
In October 2016, the FASB issued ASU No. 2016-16, which amends ASC Topic 740, “Income Taxes.” The amendments in this update
improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. This standard is effective for
interim and annual reporting periods beginning after December 15, 2017. We adopted the new standard effective January 1, 2018 under the modified
retrospective approach. Accordingly, we recorded deferred charges of approximately $148.4 million to “Retained earnings” on our Consolidated
Balance Sheets.
In March 2017, the FASB issued ASU No. 2017-07, which amends ASC Topic 715, “Compensation —Retirement Benefits; Improving the
Presentation of Net Periodic Pension Cost and Postretirement Benefits Cost.” The amendments in this update require that an employer disaggregate
the service cost component from the other components of net benefit cost for an entity's defined benefit pension and other postretirement plans.
The amendments also provide explicit guidance on how to present the service cost component and the other components of net benefit cost in the
income statement and allow only the service cost component of net benefit cost to be eligible for capitalization. The amendments in this update
require that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered
by the pertinent employees during the period. The other components of net benefit costs, as defined in paragraphs 715-30-35-4 and 715-60-35-9,
are required to be presented in the income statement separately from the service cost component and outside of income from operations. We
67
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
adopted ASU No. 2017-07 effective January 1, 2018 and accordingly, we have made certain reclassifications between our “Contract drilling
services” costs and “Interest income and other, net” on our Consolidated Statement of Operations.
In February 2018, the FASB issued ASU No. 2018-02, which amends ASC Topic 220, “Income Statement—Reporting Comprehensive
Income.” The amendments in this update allow for a reclassification from accumulated other comprehensive income to retained earnings for
stranded tax effects resulting from the Act. This standard is effective for interim and annual reporting periods beginning after December 15, 2018
with early application permitted. We elected to adopt the new standard effective January 1, 2018 under the modified retrospective approach. The
amendment should be applied on a retrospective basis to each period in which the effect of the change in the U.S. federal corporate income tax
rate in the Act was recognized. As a result of the retrospective application, we reduced “Accumulated other comprehensive loss” in our Consolidated
Balance Sheet with a cumulative adjustment to “Retained earnings” of approximately $5.5 million.
In August 2018, the FASB issued ASU No. 2018-15, which amends ASC Subtopic 350-40, “Intangibles—Goodwill and Other—Internal
—Use Software.” The amendments in this update require an entity in a hosting arrangement that is a service contract to capitalize implementation
costs. Entities are to follow the guidance in ASC Subtopic 350-40 to determine which implementation costs to capitalize as an asset related to the
service contract and which costs to expense. The amendment also requires the entity to expense these capitalized implementation costs over the
term of the hosting arrangement. We elected to early adopt ASU No. 2018-15 effective September 30, 2018, on a prospective basis. The adoption
of this guidance did not have a material impact on our consolidated financial statements.
Recently Issued Accounting Standards
In February 2016, the FASB issued ASU No. 2016-02 (Topic 842, “Leases”), as amended, which generally requires lessees to recognize
operating and financing lease liabilities and corresponding right-of-use assets on the balance sheet and to provide enhanced disclosures surrounding
the amount, time and uncertainty of cash flows arising from lease agreements. We expect to adopt this standard, on a modified retrospective basis,
effective January 1, 2019 and will not restate comparative periods.
With respect to leases in which we are the lessee, we expect to recognize a lease liability and a corresponding right-of-use asset of
approximately $28.0 million on our consolidated balance sheet as of January 1, 2019. We will elect the package of practical expedients that allows
us to not reassess: (1) whether any expired or existing contracts are or contain leases, (2) lease classification for any expired or existing leases and
(3) initial direct costs for any expired or existing leases. As lessee, we have taken the accounting policy election to not recognize an asset and
liability for leases with a term of 12 months or less. We will recognize lease payments in the Consolidated Statements of Operations on a straight-
line basis over the lease term.
Our drilling contracts contain a lease component related to the underlying drilling equipment, in addition to the service component provided
by our crews and our expertise to operate such drilling equipment. We have concluded that the non-lease service of operating our equipment and
providing expertise in the drilling of the client's well is predominant in our drilling contracts. We expect to apply the practical expedient to account
for the lease and associated non-lease operations as a single component. With the election of the practical expedient, we will continue to present
a single performance obligation under the new revenue guidance in ASC 606.
We are currently finalizing our evaluation of what other effect, if any, ASC 842 will have on our consolidated financial statements and
related disclosures. We do not expect our adoption to materially affect our Consolidated Balance Sheet, Consolidated Statement of Operations, or
Consolidated Statement of Cash Flows.
In August 2018, the FASB issued ASU No. 2018-14, which amends 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 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.
Note 2— Consolidated Joint Ventures
We maintain a 50 percent interest in two joint ventures, each with a subsidiary of Royal Dutch Shell plc (“Shell”), that own and operate
the two Bully-class drillships. We have determined that we are the primary beneficiary of the joint ventures. Accordingly, we consolidate the
entities in our consolidated financial statements after eliminating intercompany transactions. Shell’s equity interests are presented as noncontrolling
interests on our Consolidated Balance Sheets.
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NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
During the years ended December 31, 2018, 2017 and 2016, the Bully joint ventures approved and paid dividends totaling $55.2 million,
$113.8 million and $171.9 million, respectively. Of these amounts, 50 percent was paid to our joint venture partner.
The combined carrying amount of the Bully-class drillships at December 31, 2018 and 2017 totaled $0.7 billion and $1.3 billion, respectively.
These assets were primarily funded through partner equity contributions. During the year ended December 31, 2018, we recognized a $550.3
million impairment on the Noble Bully I, of which $250.3 million is attributable to our joint venture partner. See “Note 6— Loss on Impairment”
for additional information. Cash held by the Bully joint ventures totaled approximately $45.2 million at December 31, 2018 as compared to
approximately $41.6 million at December 31, 2017.
Note 3— Loss Per Share
The following table presents the computation of basic and diluted loss per share for Noble-UK:
Numerator:
Basic
Net loss from continuing operations
Net loss from discontinued operations, net of tax
Net loss attributable to Noble Corporation plc
Diluted
Net loss from continuing operations
Net loss from discontinued operations, net of tax
Net loss attributable to Noble Corporation plc
Denominator:
Weighted average shares outstanding - basic
Weighted average shares outstanding - diluted
Loss per share
Basic:
Loss from continuing operations
Loss from discontinued operations
Net loss attributable to Noble Corporation plc
Diluted:
Loss from continuing operations
Loss from discontinued operations
Net loss attributable to Noble Corporation plc
Dividends per share
Year Ended December 31,
2018
2017
2016
$
$
$
$
$
$
$
$
$
(885,050) $
—
(515,025) $
(1,486)
(929,580)
—
(885,050) $
(516,511) $
(929,580)
(885,050) $
—
(885,050) $
(515,025) $
(1,486)
(516,511) $
246,614
246,614
244,743
244,743
(929,580)
—
(929,580)
243,127
243,127
(3.59) $
—
(3.59) $
(3.59) $
—
(3.59) $
— $
(2.10) $
(0.01)
(2.11) $
(2.10) $
(0.01)
(2.11) $
— $
(3.82)
—
(3.82)
(3.82)
—
(3.82)
0.20
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,
2018, 2017 and 2016, 12.5 million, 12.0 million and 9.9 million share-based awards, respectively, were excluded from the diluted loss per share
since the effect would have been anti-dilutive.
Note 4— Receivables from Customers
At December 31, 2016, we had receivables of approximately $14.4 million related to the Noble Max Smith, which had been disputed by
our former customer, Petróleos Mexicanos (“Pemex”) and were classified as long-term and included in “Other assets” on our Consolidated Balance
Sheet. The receivables were related to lost revenues for downtime that occurred after our rig was damaged when one of Pemex's supply boats
collided with our rig in 2010. A Mexican subsidiary of Paragon Offshore, which had operated the Noble Max Smith, had been prosecuting the
claim against Pemex. As of December 31, 2017, Paragon Offshore announced that, as part of its bankruptcy plan, it will liquidate the Mexican
entity involved.
While Noble owns all rights to amounts from that claim and will take available actions to recover such amounts, we believe the announced
actions by Paragon Offshore create uncertainty relating to the prosecution of the claim and associated recovery, and accordingly, the disputed
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NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
amounts of approximately $14.4 million were written off through “Contract drilling services” costs on our Consolidated Statements of Operations
during the year ended December 31, 2017.
Note 5— Property and Equipment
Property and equipment, at cost, for Noble-UK consisted of the following:
Drilling equipment and facilities
Construction in progress
Other
Property and equipment, at cost
Year Ended December 31,
2018
2017
10,546,376
209,091
200,945
10,956,412
$
$
11,746,629
83,509
204,193
12,034,331
$
$
Capital expenditures, including capitalized interest, totaled $281.3 million, $111.1 million and $659.9 million for the years ended
December 31, 2018, 2017 and 2016, respectively. During the years ended December 31, 2018, 2017 and 2016, capitalized interest was $2.9
million, zero and $22.4 million, respectively.
During the year ended December 31, 2017, we recognized a $14.3 million charge in “Contract drilling services” costs related to damages
sustained on the Noble Danny Adkins and Noble Jim Day during Hurricane Harvey in the U.S. Gulf of Mexico region.
On September 21, 2018, we purchased the Noble Johnny Whitstine, a new GustoMSC CJ46 design jackup rig, from the PaxOcean Group
(“PaxOcean”) in connection with a concurrently awarded drilling contract in the Middle East region. We paid $93.8 million for the rig, with $33.8
million paid in cash and the remaining $60.0 million of the purchase price financed by the seller. See “Note 7— Debt” for additional information.
During the years ended December 31, 2018, 2017 and 2016, we recognized a non-cash loss on impairment of $802.1 million, $121.6 million
and $1.5 billion, respectively, related to our long-lived assets. See “Note 6— Loss on Impairment” for additional information.
Note 6— Loss on Impairment
Asset Impairments
In connection with the preparation of the consolidated financial statements included in this Annual Report, consistent with our accounting
policies discussed in “Note 1— Organization and Significant Accounting Policies,” we evaluate our property and equipment for impairment
whenever there are changes in facts which suggest that the value of the asset is not recoverable. In connection with the preparation of our financial
statements for the year ended December 31, 2018, we conducted a review of our fleet. The review included an assessment of certain assumptions,
including future marketability of each unit in light of its current technical specifications. Assumptions used in our assessment included, 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.
During the years ended December 31, 2018, 2017, and 2016, we recognized a non-cash loss on impairment of $802.1 million, $121.6 million
and $1.5 billion, respectively, related to certain rigs and related capital spares.
Based upon our impairment analysis, we impaired the carrying values to estimated fair values for the Noble Bully I, Noble Dave Beard,
Noble Gene House, Noble Joe Beall, Noble Paul Romano, 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 is attributable to our joint venture partner. See “Note 2— Consolidated Joint Ventures” for additional information.
During the year ended December 31, 2017, we identified indicators that certain assets in our fleet might not be recoverable. Such indicators
included additional customer suspensions of drilling programs, contract cancellations, a further reduction in the number of new contract
opportunities, resulting in reduced drilling contracts, and our belief that a drilling unit is no longer marketable and is unlikely to return to service.
As a result, we determined that the carrying amounts of the Noble Amos Runner, Noble Alan Hay, Noble David Tinsley and certain capital spares
were impaired and recorded an impairment charge of approximately $121.6 million.
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NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
During the year ended December 31, 2016, in connection with our impairment analysis, we impaired the carrying values to estimated fair
values for the Noble Amos Runner, Noble Clyde Boudreaux and Noble Dave Beard and recorded a charge of $1.0 billion related to these units. In
addition, we concluded that the semisubmersible, the Noble Homer Ferrington, and certain capital spare equipment would not be utilized in the
foreseeable future, and we recognized impairment charges of approximately $120.1 million and $170.5 million, respectively. Further, we decided
to retire our semisubmersible, Noble Max Smith, which was sold for $1.2 million after we recognized an impairment charge during the year of
approximately $164.8 million.
Note 7— Debt
Credit Facilities
2015 Credit Facility
At December 31, 2017, we had a five-year $2.4 billion senior unsecured credit facility that matures in January 2020 and is guaranteed by
our indirect, wholly-owned subsidiaries, Noble Holding (U.S.) LLC (“NHUS”) and Noble Holding International Limited (“NHIL”) (the “2015
Credit Facility”). At December 31, 2017, the 2015 Credit Facility also provided us with the ability to issue up to $500.0 million in letters of credit.
On December 19, 2017, we entered into the First Amendment and Consent and Successor Agent Agreement (the “Amendment”) amending
the 2015 Credit Facility. On January 3, 2018, the Amendment to the 2015 Credit Facility became fully effective. The Amendment caused, among
other things, a reduction in the aggregate principal amount of commitments under the 2015 Credit Facility to $300.0 million and the termination
of the 2015 Credit Facility's letter of credit sub-facility. The maturity of the 2015 Credit Facility remains January 2020. 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. At December 31, 2018, we had no borrowings outstanding or letters of credit issued under the 2015 Credit Facility.
2017 Credit Facility
On December 21, 2017, Noble Cayman Limited, a Cayman Islands company and a wholly-owned indirect subsidiary of Noble-Cayman
(“NCL”); Noble International Finance Company, a Cayman Islands company and a wholly-owned indirect subsidiary of Noble-Cayman (“NIFCO”);
and Noble Holding UK Limited, a company incorporated under the laws of England and Wales and a wholly-owned direct subsidiary of Noble-
UK (“NHUK”), as parent guarantor, entered into a new senior unsecured credit agreement (the “2017 Credit Facility” and, together with the 2015
Credit Facility, the “Credit Facilities”). The maximum aggregate amount of commitments under the 2017 Credit Facility is approximately $1.5
billion. Borrowings under the 2017 Credit Facility are subject to certain conditions precedent, including that there be no unused commitments to
advance loans under the 2015 Credit Facility. The 2017 Credit Facility will mature in January 2023. Borrowings may be used for working capital
and other general corporate purposes. The 2017 Credit Facility provides for a letter of credit sub-facility currently 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. At December 31, 2018, we had $3.4 million of
performance letters of credit outstanding under the 2017 Credit Facility. At December 31, 2018, other than the performance letters of credit, we
had no borrowings outstanding under the 2017 Credit Facility.
Both of our Credit Facilities have provisions which vary the applicable interest rates for borrowings based upon our debt ratings. We also
pay a facility fee under the 2015 Credit Facility on the full commitments thereunder (used or unused) and a commitment fee under the 2017 Credit
Facility on the daily unused amount of the underlying commitments, in each case which varies depending on our credit ratings. At December 31,
2018, the interest rates in effect under our Credit Facilities were the highest permitted interest rates under those agreements.
Debt Issuance
In January 2018, we issued $750.0 million aggregate principal amount of our Senior Notes due 2026 (the “2026 Notes”) through our indirect
wholly-owned subsidiary, NHIL. The net proceeds of the offering of approximately $737.4 million, after expenses, were used to retire a portion
of our near-term senior notes in a related tender offer.
The indenture for the 2026 Notes contains certain covenants and restrictions, including, among others, restrictions on our subsidiaries’
ability to incur certain additional indebtedness. Additionally, the subsidiary guarantors must own, directly or indirectly, (i) assets comprising at
least 85% of the revenue of Noble-Cayman and its subsidiaries on a consolidated basis and (ii) jackups, semisubmersibles, drillships, submersibles
or other mobile offshore drilling units of material importance, the combined book value of which comprises at least 85% of the combined book
value of all such assets of Noble-Cayman and its subsidiaries on a consolidated basis, in each case, with respect to the most recently completed
fiscal year.
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NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Seller Financing of Rigs
In September 2018, we purchased the Noble Johnny Whitstine for $93.8 million with a $60.0 million seller-financed secured loan (the
“Seller Loan”). The Seller Loan has a term of four years and requires a 5% principal payment at the end of the third year with the remainder of
the principal due at the end of the term. The Seller Loan bears 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 Seller Loan. Based on the terms of the Seller Loan, the 1.25% paid-in-kind interest rate is accelerated into the
first year, resulting in an overall first year interest rate of 8.91%, of which only 4.25% is payable in cash. Thereafter, the paid-in-kind interest ends
and the cash interest rate of 4.25% is payable for the remainder of the term.
The Seller Loan is guaranteed by Noble-Cayman and is secured by a mortgage on the Noble Johnny Whitstine and by the pledge of the
shares of the single-purpose entity that owns the rig. The Seller Loan contains debt to total capitalization ratio and minimum liquidity financial
covenants substantially similar to the 2017 Credit Facility, and an asset and revenue covenant substantially similar to the 2026 Notes as well as
other covenants and provisions customarily found in secured transactions. The Seller Loan requires immediate repayment on the occurrence of
certain events, including the termination of the drilling contract entered into at the time of the purchase of the rig.
On February 14, 2019, we exercised our option to purchase a new jackup rig, to be known as the Noble Joe Knight, and we expect to
complete the purchase in late February 2019. The purchase of the Noble Joe Knight will be partially funded with cash and seller loan on terms
similar to the Noble Johnny Whitstine.
Senior Notes Interest Rate Adjustments
During 2016 and 2017, we experienced debt rating downgrades by Moody’s Investors Service and S&P Global Ratings, which reduced our
debt ratings below investment grade. As a result of these downgrades, we experienced interest rate increases during 2016 and 2017 on our Senior
Notes due 2018 (the “2018 Notes”), our Senior Notes due 2025 (the “2025 Notes”) and our Senior Notes due 2045 (the “2045 Notes”), all of
which are subject to provisions that vary the applicable interest rates based on our debt rating. On October 18, 2017, S&P Global Ratings further
reduced our debt rating, which increased the interest rates on the 2025 Notes and the 2045 Notes to 7.95% and 8.95%, respectively, effective April
2018. These senior notes have reached the contractually defined maximum interest rate set for each rating agency and no further interest rate
increases are possible. The interest rates on these senior notes may be decreased if our debt ratings were to be raised by either rating agency above
specified levels. Our other outstanding senior notes do not contain provisions varying applicable interest rates based upon our credit ratings.
Debt Tender Offers, Repayments and Open Market Repurchases
In January 2018, we commenced cash tender offers for the 2018 Notes, our Senior Notes due 2019 (the “2019 Notes”), our Senior Notes
due 2020, our Senior Notes due 2021, our Senior Notes due 2022 and our Senior Notes due 2024. In February 2018, we purchased $754.2 million
aggregate principal amount of these senior notes for $750.0 million, plus accrued interest, using the net proceeds of the 2026 Notes issuance and
cash on hand. As a result of this transaction, we recognized a net loss of approximately $3.5 million.
In February 2018, we redeemed the remaining principal amount of $61.9 million of the 2019 Notes for approximately $65.3 million, plus
accrued interest. As a result of this transaction, we recognized a net loss of approximately $3.5 million.
In March 2018, we repaid the remaining aggregate principal amount of $126.6 million of the 2018 Notes at maturity using cash on hand.
In March 2018, we purchased $9.5 million aggregate principal amount of various tranches of our senior notes for approximately $8.7
million, plus accrued interest, as open market repurchases and recognized a net gain of approximately $0.5 million.
In August 2018, we purchased $0.4 million aggregate principal amount of our Senior Notes due 2042 for approximately $0.3 million, plus
accrued interest, as open market repurchases and recognized a net gain of approximately $0.1 million.
In October 2018, we purchased $27.4 million aggregate principal amount of various tranches of our senior notes for approximately $20.2
million, plus accrued interest, as open market repurchases and recognized a net gain of approximately $6.9 million.
Covenants
The 2015 Credit Facility is guaranteed by NHUS and NHIL. The 2015 Credit Facility contains a covenant that limits our ratio of debt to
total tangible capitalization, as defined in the 2015 Credit Facility, to 0.60 at the end of each fiscal quarter.
The 2017 Credit Facility contains certain financial covenants applicable to NHUK and its subsidiaries, including (i) a covenant restricting
debt to total tangible capitalization to not greater than 0.55 at the end of each fiscal quarter, (ii) a minimum Liquidity requirement of $300.0 million,
(iii) a covenant that, beginning with the fiscal quarter ending March 31, 2018, the ratio of the Rig Value (as defined in the 2017 Credit Facility)
of Marketed Rigs (as defined in the 2017 Credit Facility) to the sum of commitments under the 2017 Credit Facility plus indebtedness for borrowed
money of the borrowers and guarantors, in each case, that directly own Marketed Rigs, is not less than 3:00 to 1:00 at the end of each fiscal quarter
72
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
and (iv) a covenant that, beginning with the fiscal quarter ending March 31, 2018, the ratio of (A) the Rig Value of the Closing Date Rigs (as
defined in the 2017 Credit Facility) that are directly wholly owned by the borrowers and guarantors to (B) the Rig Value of the Closing Date Rigs
owned by NHUK, subsidiaries of NHUK and certain local content affiliates, is not less than 80% at the end of each fiscal quarter (such covenants
described in (iii) and (iv) of this paragraph, the “Guarantor Ratio Covenants”). The 2017 Credit Facility also includes restrictions on borrowings
if, after giving effect to any such borrowings and the application of the proceeds thereof, the aggregate amount of Available Cash (as defined in
the 2017 Credit Facility) would exceed $200.0 million.
NHUK has guaranteed the obligations of the borrowers under the 2017 Credit Facility. In addition, on January 19, 2018, certain indirect
subsidiaries of Noble-UK became guarantors under the 2017 Credit Facility, including Noble Dave Beard Limited, Noble Drilling (TVL) Ltd.,
Noble Resources Limited, Noble SA Limited, Noble BD LLC, Noble Drilling Holding LLC, Noble Drilling International GmbH, Noble Leasing
(Switzerland) GmbH, and Noble Leasing III (Switzerland) GmbH. Certain other subsidiaries of Noble-UK may be required from time to time to
guarantee the obligations of the borrowers under the 2017 Credit Facility in order maintain compliance with the Guarantor Ratio Covenants.
The 2017 Credit Facility contains additional restrictive covenants generally applicable to NHUK and its subsidiaries, including restrictions
on the incurrence of liens and indebtedness, mergers and other fundamental changes, restricted payments, repurchases and redemptions of
indebtedness with maturities outside of the maturity of the 2017 Credit Facility, sale and leaseback transactions and transactions with affiliates.
In addition to the covenants from the Credit Facilities noted above, the covenants from the 2026 Notes described under “—Debt Issuance”
above, and the covenant from the Seller Loan described under “—Seller Financing of Rig” above, the indentures governing our outstanding senior
unsecured notes contain covenants that place restrictions on certain merger and consolidation transactions, unless we are the surviving entity or
the other party assumes the obligations under the indenture, and on the ability to sell or transfer all or substantially all of our assets. There are also
restrictions on incurring or assuming certain liens and on entering into sale and lease-back transactions.
At December 31, 2018, our debt to total tangible capitalization ratio under our 2017 Credit Facility was approximately 0.48 and we were
in compliance with all applicable debt covenants. We continually monitor compliance with the covenants under our Credit Facilities, senior notes
and Seller Loan and expect to remain in compliance throughout 2019.
Five-year debt obligations
At December 31, 2018, aggregate principal repayments of total debt for the next five years and thereafter are as follows:
2019
2020
2021
2022
2023
Thereafter
$
— $
65,890
$
96,142
$
99,481
$
— $
3,673,040
$
Total
3,934,553
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NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar 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 14— 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:
Senior unsecured notes
5.75% Senior Notes due March 2018
7.50% Senior Notes due March 2019
4.90% Senior Notes due August 2020
4.625% Senior Notes due March 2021
3.95% Senior Notes due March 2022
7.75% Senior Notes due January 2024
7.95% Senior Notes due April 2025
7.875% Senior Notes due February 2026
6.20% Senior Notes due August 2040
6.05% Senior Notes due March 2041
5.25% Senior Notes due March 2042
8.95% Senior Notes due April 2045
Other:
Seller-financed secured loan due September 2022
Total debt
Less: Current maturities of long-term debt
Long-term debt
Note 8— Equity
Share Capital
December 31, 2018
December 31, 2017
Carrying Value
Estimated Fair
Value
Carrying Value
Estimated Fair
Value
$
— $
—
65,810
92,967
41,617
783,350
446,517
738,075
390,454
389,693
477,996
390,672
— $
—
60,177
84,931
37,096
613,719
339,035
647,085
245,242
247,171
277,056
311,392
$
249,843
201,535
167,422
208,095
125,307
971,498
446,106
—
396,738
394,514
494,063
390,589
250,830
206,881
163,283
195,687
107,348
861,160
380,732
—
274,988
273,988
315,430
320,396
60,251
3,877,402
—
3,877,402
$
57,902
2,920,806
—
2,920,806
$
—
4,045,710
249,843
3,795,867
$
—
3,350,723
250,830
3,099,893
$
As of December 31, 2018, Noble-UK had approximately 246.8 million shares outstanding and trading as compared to approximately 245.0
million shares outstanding and trading at December 31, 2017. At our 2018 Annual General Meeting, shareholders approved a proposal to allow
our Board of Directors to increase share capital through the issuance of up to 82.2 million ordinary shares (at current nominal value of $0.01 per
share) The right of our directors to allot shares will expire at the end of our 2019 Annual General Meeting unless we seek an extension from
shareholders at that time. No shares were allotted during the year ended December 31, 2018.
The declaration and payment of dividends require the authorization of the Board of Directors of Noble-UK, provided that such dividends
on issued share capital may be paid only out of Noble-UK’s “distributable reserves” on its statutory balance sheet in accordance with UK law.
Therefore, Noble-UK is 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 Board of Directors.
Share Repurchases
Under UK law, the Company is 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. During the years ended December 31, 2018, 2017 and 2016,
we did not repurchase any of our shares.
74
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Share-Based Compensation Plans
Stock Plans
During 2015, Noble Corporation plc shareholders approved a new equity plan, the Noble Corporation plc 2015 Omnibus Incentive Plan
(the “2015 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 2015 Incentive Plan.
Neither consultants nor non-employee directors are eligible for awards under the 2015 Incentive Plan.
During 2018, 2017 and 2016, the 2015 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 2015 Incentive Plan by 5.0 million, 3.7 million and 9.5
million shares, respectively. The maximum aggregate number of ordinary shares that may be granted for any and all awards under the 2015
Incentive Plan will not exceed 25.5 million shares and at December 31, 2018, we had 11.5 million shares remaining available for grants to
employees.
The Noble Corporation 1991 Stock Option and Restricted Stock Plan, as amended (the “1991 Plan”), provides for the granting of options
to purchase our shares, with or without stock appreciation rights, and the awarding of restricted shares or units to selected employees. Upon
shareholder approval of the 2015 Incentive Plan, as described above, the 1991 Plan was terminated and equity based awards to employees are
now made only through the 2015 Incentive Plan. Equity based awards previously granted under the 1991 Plan remain outstanding in accordance
with their terms, which include the 1991 Plan.
Prior to 2017, we used the Noble Corporation 1992 Nonqualified Stock Options and Share Plan for Non-Employee Directors (the “1992
Plan”), to issue stock awards to non-employee directors. During 2017, upon shareholder approval, the Noble Corporation plc 2017 Director
Omnibus Plan (the “Director Plan”) replaced the 1992 Plan. At the same time, the 1992 Plan was terminated and equity based awards to non-
employee directors are now made only through the Director Plan.
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 both the 1991 Plan and 1992 Plan as of December 31, 2018, 2017 and
2016 and the changes during the year ended on those dates is presented below:
Outstanding at beginning of year
Expired
Outstanding at end of year (1)
Exercisable at end of year (1)
2018
2017
2016
Number of
Shares
Underlying
Options
1,313,155
(209,913)
1,103,242
1,103,242
$
$
Weighted
Average
Exercise
Price
29.51
33.56
28.74
28.74
Number of
Shares
Underlying
Options
1,420,175
(107,020)
1,313,155
1,313,155
$
$
Weighted
Average
Exercise
Price
29.52
29.74
29.51
29.51
Number of
Shares
Underlying
Options
1,677,154
(256,979)
1,420,175
1,420,175
$
$
Weighted
Average
Exercise
Price
29.48
29.22
29.52
29.52
(1) Options outstanding and exercisable at December 31, 2018 had no intrinsic value.
The following table summarizes additional information about stock options outstanding at December 31, 2018:
$20.49 to $25.41
$25.42 to $30.59
$30.60 to $32.78
Total
Options Outstanding and Exercisable
Number of
Shares
Underlying
Options
Weighted
Average
Remaining
Life (Years)
Weighted
Average
Exercise
Price
290,962
334,958
477,322
1,103,242
0.69
3.10
1.70
1.86
$
$
21.40
30.59
31.91
28.74
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
75
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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
U.S. Treasury yield curve in effect at the time of grant.
There were no non-vested stock option balances at December 31, 2018 or any changes during the year ended December 31, 2018. No new
stock options were granted during the years ended December 31, 2018, 2017 and 2016.
There was no compensation cost recognized during the years ended December 31, 2018, 2017 and 2016, respectively, related to stock
options.
Restricted Stock Units (“RSUs”)
We have awarded both Time Vested RSUs (“TVRSUs”) and Performance Vested (“PVRSUs”) under the 1991 Plan and the 2015 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:
Valuation assumptions:
Expected volatility
Expected dividend yield
Risk-free interest rate
2018
2017
2016
61.8%
—%
2.31%
56.4%
—%
1.49%
40.7%
—%
0.97%
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, 2018, 2017 and 2016 is as follows:
TVRSU
Units awarded
Weighted-average share price at award date
Weighted-average vesting period (years)
PVRSU
Units awarded
Weighted-average share price at award date
Three-year performance period ended December 31
Weighted-average award-date fair value
2018
2017
2016
3,578,212
4.71
3.0
2,733,906
4.55
2020
2.96
$
$
$
3,231,225
6.96
3.0
2,474,978
7.28
2019
4.37
$
$
$
3,624,182
7.78
3.0
2,914,044
7.79
2018
3.81
$
$
$
During the years ended December 31, 2018, 2017 and 2016, we awarded 267,204, 197,316 and 227,937 shares, respectively, to our non-
employee directors.
76
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
A summary of the status of non-vested RSUs at December 31, 2018 and changes during the year ended December 31, 2018 is presented
below:
Non-vested RSUs at January 1, 2018
Awarded
Vested
Forfeited
Non-vested RSUs at December 31, 2018
TVRSUs
Outstanding
5,043,502
$
3,578,212
(2,342,503)
(1,054,808)
5,224,403
$
Weighted
Average
Award-Date
Fair Value
7.95
4.71
8.67
6.43
5.71
PVRSUs
Outstanding (1)
5,645,454
2,733,906
(403,553)
(1,784,740)
6,191,067
$
$
Weighted
Average
Award-Date
Fair Value
4.98
4.87
9.12
5.97
4.38
(1)
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.
At December 31, 2018, there was $15.8 million of total unrecognized compensation cost related to the TVRSUs, which is expected to be
recognized over a remaining weighted-average period of 1.6 years. The total award-date fair value of TVRSUs vested during the year ended
December 31, 2018 was $20.3 million.
At December 31, 2018, there was $6.7 million of total unrecognized compensation cost related to the PVRSUs, which is expected to be
recognized over a remaining weighted-average period of 1.1 years. The total potential compensation for PVRSUs is recognized over the service
period regardless of whether the performance thresholds are ultimately achieved. In February 2019, 1,450,802 PVRSUs for the 2016-2018
performance period were forfeited.
Share-based amortization recognized during the years ended December 31, 2018, 2017 and 2016 related to all restricted stock totaled $24.0
million ($21.9 million net of income tax), $29.1 million ($26.3 million net of income tax) and $34.7 million ($31.0 million net of income tax),
respectively. During the years ended December 31, 2018 and 2017, capitalized share-based amortization was zero. During the year ended
December 31, 2016, capitalized share-based amortization totaled approximately $0.2 million.
77
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Note 9— Accumulated Other Comprehensive Income (Loss)
The following table presents the changes in the accumulated balances for each component of AOCI for the years ended December 31, 2018
and 2017. All amounts within the tables are shown net of tax.
Unrealized Gains /
(Losses) on Cash
Flow Hedges (1)
Defined Benefit
Pension Items (2)
Foreign Currency
Items
Total
Balance at December 31, 2016
Activity during period:
Other comprehensive income before reclassifications
Amounts reclassified from AOCI
Net other comprehensive income
Balance at December 31, 2017
Activity during period:
Stranded tax effect resulting from the Act (Note 1)
Balance at January 1, 2018
Activity during period:
Other comprehensive income before reclassifications
Amounts reclassified from AOCI
Net other comprehensive loss
Balance at December 31, 2018
$
$
$
— $
(35,865) $
(16,275) $
(52,140)
1,239
(1,239)
—
— $
—
—
—
—
—
— $
6,630
1,632
8,262
(27,603) $
(5,540)
(33,143)
—
(5,915)
(5,915)
(39,058) $
990
—
990
(15,285) $
—
(15,285)
(2,729)
—
(2,729)
(18,014) $
8,859
393
9,252
(42,888)
(5,540)
(48,428)
(2,729)
(5,915)
(8,644)
(57,072)
(1)
(2)
Unrealized losses on cash flow hedges are related to foreign currency forward contracts. Reclassifications from AOCI are recognized
through “Contract drilling services” costs on our Consolidated Statements of Operations. See “Note 13— Derivative Instruments and
Hedging Activities” for additional information.
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 either “Contract drilling services” or “General and
administrative.” See “Note 12— 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.
78
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
The following table provides information about contract assets and contract liabilities from contracts with customers:
Current contract assets
Noncurrent contract assets
Total contract assets
Current contract liabilities (deferred revenue)
Noncurrent contract liabilities (deferred revenue)
Total contract liabilities
December 31, 2018
January 1, 2018
$
$
$
25,298
22,366
47,664
(32,906)
(47,847)
(80,753) $
21,229
34,520
55,749
(35,422)
(73,439)
(108,861)
Significant changes in the remaining performance obligation contract assets and the contract liabilities balances for the year ended
December 31, 2018 are as follows:
Net balance at January 1, 2018
Amortization of deferred costs
Additions to deferred costs
Amortization of deferred revenue
Additions to deferred revenue
Total
Contract Assets
$
55,749
Contract Liabilities
$
(108,861)
(32,420)
24,335
—
—
(8,085)
—
—
47,798
(19,690)
28,108
Net balance at December 31, 2018
$
47,664
$
(80,753)
We have elected, as a practical expedient, not to disclose significant changes in the remaining performance obligation for the year ended
December 31, 2017, which was before our adoption date of January 1, 2018.
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.
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:
Drillships
Semisubmersibles
Jackups
Total
Year Ending December 31,
2019
2020
2021
2022
2023 and
beyond
Total
$
$
20,658
363
11,868
32,889
$
$
15,677
—
3,672
19,349
$
$
15,677
—
—
15,677
$
$
9,266
—
—
9,266
$
$
3,572
—
—
3,572
$
$
64,850
363
15,540
80,753
79
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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, 2018. 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.
Our revenue recognition pattern under ASC 606 is materially equivalent to revenue recognition under the previous guidance. For the year
ended December 31, 2018, there were no material effects to our Consolidated Balance Sheets, Consolidated Statements of Operations, or
Consolidated Statements of Cash Flows.
Disaggregation of Revenue
The following table provides information about contract drilling revenue by rig types:
Drillships
Semisubmersibles
Jackups
Total
Note 11— Income Taxes
Three Months Ended
December 31, 2018
Twelve Months Ended
December 31, 2018
$
$
$
155,305
10,344
126,400
532,833
28,992
474,257
292,049
$
1,036,082
Noble-UK is a company which is a tax resident in the UK and, as such, will be 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. Prior to the redomiciliation, Noble-Swiss was the group holding company and was exempt from Swiss cantonal
and communal income tax on its worldwide income or loss, and was also granted participation relief from Swiss federal tax for qualifying dividend
income and capital gains related to the sale of qualifying participations. It is expected that the participation relief will result in a full exemption
of participation income from Swiss federal income tax. We do not expect the redomiciliation from Switzerland to the UK to have a material impact
on our effective tax rate.
Consequently, we have taken account of those tax exemptions 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.
On December 22, 2017, the President of the United States signed the Act into law. The Act makes significant changes to various areas of
U.S. federal income tax law by, among other things, lowering corporate income tax rates, implementing the territorial tax system, and rules limiting
base erosion, and imposing a repatriation tax on deemed repatriated earnings of foreign subsidiaries of U.S parent shareholders.
During the fourth quarter of 2017, the Act resulted in the write-down of our U.S. net deferred tax liabilities. In accordance with the guidance
issued in SAB No. 118, during the third quarter of 2018, we finalized our provisional amounts recorded as we completed our technical analysis,
computations and tax law interpretations and filed our 2017 U.S. tax return. As a result, we recognized an additional tax benefit of $24.9 million.
The Company has considered new provisions of The Act that became effective in 2018. Two such provisions, which had an impact on the
Company’s financial results for the current period, are as follows:
•
•
The Act limits the deduction of interest paid or accrued on indebtedness. This limitation results in a deferral for U.S. federal
income tax purposes and requires the recording of a deferred tax asset for the benefit of the interest deduction carryforward.
The interest deduction carryforward has an indefinite life.
The Act eliminates the U.S. federal income tax carryback provision for net operating losses (“NOLs”) and limits the taxpayer’s
ability to utilize NOL carryforwards to 80 percent of taxable income. The NOL carryforward has an indefinite life.
The Act also introduces a new anti-deferral provision, which subjects a U.S. parent shareholder to current tax on certain income, referred
to as Global Intangible Low-Taxed Income, of its foreign subsidiaries. The Company has adopted a policy to treat tax due on future U.S. inclusions
in taxable income as period costs when incurred.
The Company continues to monitor developments in regulations.
80
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
The components of the net deferred taxes are as follows:
Deferred tax assets
United States
Net operating loss carry forwards
Disallowed interest deduction carryforwards
Deferred pension plan amounts
Accrued expenses not currently deductible
Other
Non-U.S.
Net operating loss carry forwards
Disallowed interest deduction carryforwards
Deferred pension plan amounts
Other
Deferred tax assets
Less: valuation allowance
Net deferred tax assets
Deferred tax liabilities
United States
Excess of net book basis over remaining tax basis
Other
Non-U.S.
Excess of net book basis over remaining tax basis
Other
Deferred tax liabilities
Net deferred tax liabilities
2018
2017
95,577
51,423
11,887
9,688
1,936
26,441
6,254
670
—
203,876
(12,306)
191,570
$
$
(254,669) $
(6,482)
(1,066)
(1,596)
(263,813)
(72,243) $
—
—
10,758
11,585
2,150
—
—
134
14,085
38,712
—
38,712
(182,401)
(6,652)
—
(402)
(189,455)
(150,743)
$
$
$
$
Income (loss) from continuing operations before income taxes consists of the following:
United States
Non-U.S.
Total
Year Ended December 31,
2018
2017
2016
$
$
(136,083) $
(1,101,093)
(1,237,176) $
(81,329) $
(368,485)
(449,814) $
(428,087)
(538,942)
(967,029)
81
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
The income tax provision (benefit) for continuing operations consists of the following:
Current- United States
Current- Non-U.S.
Deferred- United States
Deferred- Non-U.S.
Total
Year Ended December 31,
2018
2017
2016
$
$
(56,574) $
18,348
(67,371)
(1,044)
(106,641) $
(227,707) $
29,010
257,432
(16,106)
42,629
$
61,928
18,813
(189,880)
(17)
(109,156)
The following is a reconciliation of our reserve for uncertain tax positions, excluding interest and penalties. In 2016, we released an uncertain
tax position in Libya in the gross amount of $40 million coupled with a related tax benefit of $13 million.
Gross balance at January 1,
Additions based on tax positions related to current year
Additions for tax positions of prior years
Reductions for tax positions of prior years
Expiration of statutes
Tax settlements
Gross balance at December 31,
Related tax benefits
Net reserve at December 31,
2018
2017
2016
$
$
174,437
97
25
(12,806)
(497)
—
161,256
(1,008)
160,248
$
$
159,826
14,187
1,284
(860)
—
—
174,437
(1,008)
173,429
$
$
169,687
15,665
18,662
(43,701)
(487)
—
159,826
(1,008)
158,818
The liabilities related to our reserve for uncertain tax positions are comprised of the following:
Reserve for uncertain tax positions, excluding interest and penalties
Interest and penalties included in “Other liabilities”
Reserve for uncertain tax positions, including interest and penalties
2018
2017
160,248
23,538
183,786
$
$
173,429
18,431
191,860
$
$
At December 31, 2018, the reserves for uncertain tax positions totaled $183.8 million (net of related tax benefits of 1.0 million). If a portion
or all of the December 31, 2018 reserves are not realized, the provision for income taxes could be reduced by up to $183.8 million. At December 31,
2017, the reserves for uncertain tax positions totaled $191.9 million (net of related tax benefits of 1.0 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. However, we cannot reasonably estimate a range of
changes in our existing liabilities due to various uncertainties, such as the unresolved nature of various audits.
We include, as a component of our “Income tax provision,” potential interest and penalties related to recognized tax contingencies within
our global operations. Interest and penalties resulted in an income tax expense of $5.1 million in 2018, an income tax expense of $4.7 million in
2017 and an income tax benefit of $2.7 million in 2016.
During the year ended December 31, 2018, our income tax provision included non-cash items of $35.6 million related to the impairment
of three rigs and certain capital spares. See “Note 6— Loss on Impairment” for additional information.
We conduct business globally and, as a result, we file numerous income tax returns in U.S. and in non-U.S. 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, Hungary, Malta, Mexico, Nigeria, Norway, Saudi Arabia, Argentina, Australia, Denmark, Gabon, Luxembourg,
Malaysia, the Netherlands, Oman, Qatar, Tanzania, Singapore, Suriname, Switzerland, the United Kingdom and the United States. We are no
longer subject to U.S. Federal income tax examinations for years before 2010 and non-U.S. income tax examinations for years before 2000.
82
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Noble-UK conducts substantially all of its business through Noble-Cayman 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 Noble-UK effective rate for continuing
operations is shown below:
Effect of:
Tax rates which are different than the UK and Cayman Island rates
Tax impact of asset impairment
Tax impact of tax restructuring
Tax impact of the Act
Reserve for (resolution of) tax authority audits
Total
Year Ended December 31,
2018
2017
2016
4.0 %
2.9 %
— %
2.1 %
(0.4)%
8.6 %
23.4 %
11.7 %
(76.1)%
33.4 %
(1.9)%
(9.5)%
8.4 %
3.9 %
— %
— %
(1.0)%
11.3 %
Due to foreign tax credit limitation constraints, in 2018, 2017 and 2016, the Company has made the determination to take foreign tax
expense as a deduction against U.S. taxable income.
At December 31, 2018, the Company asserted that the investment in foreign subsidiaries is permanent in nature, and estimated that there
are no net cumulative earnings in its foreign subsidiaries.
For interim and annual reporting periods beginning after December 15, 2017, ASU No. 2016-16 will be applied on a modified retrospective
basis to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. As the result of the
application of this standard, we recorded deferred charges of $148.4 million in to “Retained earnings” on our Consolidated Balance Sheets.
During the fourth quarter of 2017, the Act resulted in the write-down of our U.S. net deferred tax liabilities. In accordance with the guidance
issued in SAB No. 118, during the third quarter of 2018, we finalized our provisional amounts recorded as we completed our technical analysis,
computations and tax law interpretations and filed our 2017 U.S. tax return. As a result, we recognized an additional tax benefit of $24.9 million.
Note 12— Employee Benefit Plans
Defined Benefit Plans
Noble Drilling (Land Support) Limited, an indirect, wholly-owned subsidiary of Noble-UK (“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-U.S. plan”).
In addition to the non-U.S. plan discussed above, we have a U.S. noncontributory defined benefit pension plan that covers certain salaried
employees and a U.S. 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 U.S. 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 U.S. plans when required. The benefit amount that can be covered by the qualified U.S. 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 U.S. plan. We refer to the qualified U.S. plans and the
excess benefit plan collectively as the “U.S. plans.”
During the fourth quarter of 2016, we approved amendments, effective as of December 31, 2016, to our non-U.S. and U.S. 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.
83
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
A reconciliation of the changes in projected benefit obligations (“PBO”) for our non-U.S. and U.S. plans is as follows:
Benefit obligation at beginning of year
Service cost
Interest cost
Actuarial loss (gain)
Plan amendments
Benefits paid
Settlements and curtailments
Foreign exchange rate changes
Benefit obligation at end of year
2018
Non-U.S.
61,952
—
1,747
(2,683)
285
(3,282)
—
(3,121)
54,898
$
$
$
$
Years Ended December 31,
U.S.
235,175
—
8,179
(20,673)
—
(7,218)
(4,519)
—
210,944
$
$
2017
Non-U.S.
72,347
—
2,151
(11,265)
—
(2,836)
(4,825)
6,380
61,952
$
$
U.S.
216,577
—
8,593
19,113
—
(6,795)
(2,313)
—
235,175
A reconciliation of the changes in fair value of plan assets is as follows:
Fair value of plan assets at beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Settlement and curtailment
Foreign exchange rate changes
Fair value of plan assets at end of year
The funded status of the plans is as follows:
Funded status
Amounts recognized in the Consolidated Balance Sheets consist of:
Other assets (noncurrent)
Other liabilities (current)
Other liabilities (noncurrent)
Net amount recognized
2018
Non-U.S.
77,141
(1,366)
—
(3,282)
—
(3,896)
68,597
$
$
$
$
Years Ended December 31,
U.S.
189,240
(16,326)
4,553
(7,218)
(4,519)
—
165,730
$
$
2017
Non-U.S.
71,286
5,594
651
(2,836)
(4,597)
7,043
77,141
$
$
U.S.
171,240
24,760
2,348
(6,795)
(2,313)
—
189,240
Years Ended December 31,
2018
2017
Non-U.S.
$
13,699
$
U.S.
(45,214) $
Non-U.S.
15,189
$
U.S.
(45,935)
Years Ended December 31,
2018
2017
Non-U.S.
U.S.
Non-U.S.
U.S.
$
$
13,699
—
—
13,699
$
$
— $
(1,062)
(44,152)
(45,214) $
15,189
—
—
15,189
$
$
—
(2,312)
(43,623)
(45,935)
84
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Amounts recognized in AOCI consist of:
Net actuarial loss
Prior service cost
Deferred income tax asset
Accumulated other comprehensive loss
Pension costs include the following components:
Years Ended December 31,
2018
2017
Non-U.S.
U.S.
Non-U.S.
U.S.
$
$
3,622
273
(670)
3,225
$
$
45,358
—
(9,524)
35,834
$
$
2,258
—
(375)
1,883
$
$
39,569
—
(13,849)
25,720
Service cost
Interest cost
Return on plan assets
Amortization of prior service cost
Recognized net actuarial loss
Settlement and curtailment gains
Net pension benefit cost (gain)
Years Ended December 31,
2018
2017
2016
Non-U.S.
U.S.
Non-U.S.
U.S.
Non-U.S.
U.S.
$
$
— $
1,747
(2,762)
—
—
—
(1,015) $
— $
8,179
(11,914)
—
1,642
135
(1,958) $
— $
2,151
(2,879)
—
743
(838)
(823) $
— $
8,593
(11,764)
—
1,464
82
(1,625) $
2,914
2,412
(3,393)
104
142
600
2,779
$
$
6,647
9,557
(12,389)
118
4,398
200
8,531
There is less than $0.1 million and $2.8 million estimated net actuarial losses and prior service costs for the non-U.S. plan and the U.S.
plans, respectively, that will be amortized from AOCI into net periodic pension cost in 2019.
During the years ended December 31, 2018, 2017 and 2016, 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 2018, 2017 and 2016 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 U.S. plans by approximately $0.6 million, $1.6 million and
$2.9 million as of December 31, 2018, 2017 and 2016.
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-U.S. plan, and the impact is included as a prior service cost as of December 31, 2018, 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-U.S. and U.S. plans is summarized below:
Projected benefit obligation
Accumulated benefit obligation
Fair value of plan assets
Years Ended December 31,
$
2018
Non-U.S.
$
54,898
54,898
68,597
U.S.
210,944
210,944
165,730
$
2017
Non-U.S.
$
61,952
61,952
77,141
U.S.
235,175
235,175
189,240
85
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar 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,
2018 and 2017. 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, 2016.
Projected benefit obligation
Fair value of plan assets
Years Ended December 31,
Non-U.S.
$
2018
— $
—
Non-U.S.
U.S.
210,944
165,730
$
2017
— $
—
U.S.
235,175
189,240
The PBO for the unfunded excess benefit plan was $10.5 million at December 31, 2018 as compared to $16.4 million in 2017, and is
included under “U.S.” 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, 2018 and 2017. 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.
Accumulated benefit obligation
Fair value of plan assets
Years Ended December 31,
Non-U.S.
$
2018
— $
—
Non-U.S.
U.S.
210,944
165,730
$
2017
— $
—
U.S.
235,175
189,240
The ABO for the unfunded excess benefit plan was $10.5 million at December 31, 2018 as compared to $16.4 million in 2017, and is
included under “U.S.” in the above tables.
Defined Benefit Plans—Key Assumptions
The key assumptions for the plans are summarized below:
Weighted-average assumptions used to determine benefit obligations:
Discount Rate
Rate of compensation increase
Years Ended December 31,
2018
2017
Non-U.S.
U.S.
Non-U.S.
U.S.
2.90%
N/A
3.65% - 4.29%
N/A
2.60%
N/A
2.84% - 3.66%
N/A
2018
2017
2016
Non-U.S.
U.S.
Non-U.S.
U.S.
Non-U.S.
U.S.
Years Ended December 31,
Weighted-average assumptions used to determine
periodic benefit cost:
Discount Rate
Expected long-term return on assets
Rate of compensation increase
2.60%
3.70%
N/A
2.84% - 3.66%
2.48% - 2.70%
3.00% - 4.24%
2.15% - 3.90%
3.09% - 4.48%
5.75% - 6.50%
N/A
4.10%
N/A
6.00% - 6.50%
1.60% - 5.00%
N/A
3.60% - 4.20%
7.00%
N/A
The discount rates used to calculate the net present value of future benefit obligations for our U.S. 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 cash
outflows on our plans reasonably match this index. For our non-U.S. 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
86
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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 U.S. and non-U.S. plans that use a portfolio return model.
Defined Benefit Plans—Plan Assets
Non-U.S. Plan
The NDLS pension Scheme targets an asset allocation of 48.0% return-seeking securities (Growth) and 52.0% debt securities (Matching).
The trustees have decided to implement a 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 - 0.45% 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-U.S. plan are as follows:
Year Ended December 31, 2018
Estimated Fair Value Measurements
Cash and cash equivalents
Equity securities:
International companies
Fixed income securities:
Corporate bonds
Total
Cash and cash equivalents
Equity securities:
International companies
Fixed income securities:
Corporate bonds
Other
Total
U.S. Plans
Carrying Amount
151
$
25,585
42,861
68,597
$
Carrying Amount
280
$
Quoted Prices in
Active Markets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
$
$
151
$
25,585
42,861
68,597
$
Significant
Unobservable
Inputs (Level 3)
—
— $
—
—
— $
—
—
—
Year Ended December 31, 2017
Estimated Fair Value
Measurements
Quoted Prices in
Active Markets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
$
280
$
— $
Significant
Unobservable
Inputs (Level 3)
—
54,145
54,145
22,716
—
22,716
—
—
—
—
$
77,141
$
77,141
$
— $
—
—
—
—
The fundamental objective of the 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 31.5% equity securities, 67.3% fixed income securities, and 1.2% in cash and equivalents.
87
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
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 three to five 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, 2018 or 2017.
The actual fair values of U.S. plan assets are as follows:
Cash and cash equivalents
Equity securities:
United States
International
Fixed income securities:
Corporate bonds
Treasury bonds
Total
Cash and cash equivalents
Equity securities:
United States
International
Fixed income securities:
Corporate bonds
Treasury bonds
Total
Year Ended December 31, 2018
Estimated Fair Value
Measurements
Carrying
Amount
Quoted
Prices in
Active
Markets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
$
4,801
$
4,801
$
— $
47,950
17,838
16,775
17,838
64,802
30,339
165,730
$
59,648
30,339
129,401
$
$
31,175
—
5,154
—
36,329
$
—
—
—
—
—
—
Year Ended December 31, 2017
Estimated Fair Value
Measurements
Carrying
Amount
Quoted
Prices in
Active
Markets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
$
3,275
$
3,275
$
— $
43,535
17,712
16,430
17,712
40,793
83,925
189,240
$
40,793
83,925
162,135
$
$
27,105
—
—
—
27,105
$
—
—
—
—
—
—
As of December 31, 2018, no single security made up more than 10 percent of total assets of either the U.S. or the non-U.S. plans.
Defined Benefit Plans—Cash Flows
In 2018, we made no contributions to our non-U.S. plan and contributions of $4.6 million to our U.S. plans. In 2017, we made total
contributions of $0.7 million and $2.3 million to our non-U.S. and U.S. plans, respectively. In 2016, we made total contributions of $2.8 million
and $0.4 million to our non-U.S. and U.S. plans, respectively. We expect our aggregate minimum contributions to our non-U.S. and U.S. plans in
2019, subject to applicable law, to be zero and $1.1 million, respectively. We continue to monitor and evaluate funding options based upon market
conditions and may increase contributions at our discretion.
88
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
The following table summarizes our estimated benefit payments at December 31, 2018:
Estimated benefit payments
Non-U.S. plans
U.S. plans
Total estimated benefit payments
Other Benefit Plans
Total
2019
2020
2021
2022
2023
Thereafter
Payments by Period
$
$
38,334
109,275
147,609
$
$
3,255
8,873
12,128
$
$
3,372
9,320
12,692
$
$
3,492
13,562
17,054
$
$
3,617
9,754
13,371
$
$
3,747
10,351
14,098
$
$
20,851
57,415
78,266
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 both December 31, 2018 and 2017, our liability for the 401(k) Restoration Plan was $8.2 million and $8.8 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. 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 $2.3 million, $3.1 million
and $6.0 million, respectively, for three years ended December 31, 2018, 2017 and 2016.
We sponsor other retirement, health and welfare plans and a 401(k) savings plan for the benefit of our employees. The cost of maintaining
these plans for continuing operations aggregated approximately $25.0 million, $27.6 million and $37.2 million in 2018, 2017 and 2016, respectively.
We do not provide post-retirement benefits (other than pensions) or any post-employment benefits to our employees.
Note 13— Derivative Instruments and Hedging Activities
We periodically enter into derivative instruments to manage our exposure to fluctuations in interest rates and foreign currency exchange
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.
On May 10, 2016, Freeport-McMoRan Inc. (“Freeport”), Freeport-McMoRan Oil & Gas LLC and one of our subsidiaries entered into an
agreement terminating the contracts on the Noble Sam Croft and Noble Tom Madden (“FCX Settlement”), which were scheduled to end in July
2017 and November 2017, respectively. The FCX Settlement included two contingent payments, which are further discussed below. We accounted
for these contingent payments as derivative instruments that did not qualify under the FASB standards for hedge accounting treatment, and therefore,
changes in fair values were recognized as a loss in our accompanying Consolidated Statements of Operations.
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. There were no foreign currency forward contracts
outstanding or entered into during the year ended December 31, 2018.
89
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
FCX Settlement
Pursuant to the FCX Settlement, Noble could have received contingent payments from the FCX Settlement on September 30, 2017, depending
on the average price of oil over a 12-month period from June 30, 2016 through June 30, 2017. The average price of oil was calculated using the
daily closing price of West Texas Intermediate crude oil (“WTI”) (CL1) on the New York Mercantile Exchange for the period of June 30, 2016
through June 30, 2017. If the price of WTI averaged more than $50 per barrel during such period, Freeport would have paid $25.0 million to
Noble. In addition to the $25.0 million contingent payment, if the price of WTI averaged more than $65 per barrel during such period, Freeport
would have paid an additional $50.0 million to Noble. These contingent payments did not qualify for hedge accounting treatment under FASB
standards, and therefore, the change in fair value was recognized as a loss in our Consolidated Statements of Operations. These contingent payments
are referred to as non-designated derivatives in the following table.
The price of WTI did not average more than $50 per barrel during the 12-month period. As of June 30, 2017, the fair value of these contingent
payments was reduced to zero, as the period for earning the contingent payments had ended.
Financial Statement Presentation
The following table, together with “Note 14— 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,
2018 and 2017:
Year Ended December 31,
2018
2017
2018
2017
2018
2017
Unrealized gain/(loss) recognized
through AOCI
Gain/(loss) reclassified from AOCI
to “Contract drilling services”
costs
Gain/(loss) recognized through
“Contract drilling services”
revenue
Cash flow hedges
Foreign currency forward contracts
Non-designated derivatives
FCX Settlement
$
$
— $
(1,239) $
— $
— $
— $
— $
— $
— $
— $
1,239
— $
(14,400)
There were no foreign currency forward contracts outstanding or entered into during the year ended December 31, 2018.
Note 14— 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:
Assets -
Marketable securities
Assets -
Marketable securities
December 31, 2018
Estimated Fair Value Measurements
Carrying Amount
Quoted Prices in
Active Markets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
$
8,659
$
8,659
$
— $
—
December 31, 2017
Estimated Fair Value Measurements
Carrying Amount
Quoted Prices in
Active Markets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
$
7,321
$
7,321
$
— $
—
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.
90
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Note 15— Commitments and Contingencies
Transocean Ltd.
In January 2017, a subsidiary of Transocean Ltd. (“Transocean”) filed suit against us and certain of our subsidiaries for patent infringement
in a Texas federal court. The suit claims that five of our newbuild rigs that operated in the U.S. Gulf of Mexico violated Transocean patents relating
to what is generally referred to as dual-activity drilling. We were aware of the patents when we constructed the rigs. The patents are now expired
in the United States and most other countries. While there is inherent risk in litigation, we do not believe that our rigs infringe the Transocean
patents. Transocean also recently added another claim alleging that we breached a 2007 settlement agreement we entered into with Transocean
relating to patent claims in respect of another Noble rig. We also do not believe there has been any breach of the 2007 agreement. The litigation
continues, and we believe the court could set a trial date for the third quarter of 2019. We continue to defend ourselves vigorously against this
claim.
Brazil commercial agent
We previously used a commercial agent in Brazil in connection with our Petróleo Brasileiro S.A. (“Petrobras”) drilling contracts. This agent
represented a number of different companies in Brazil over many years, including several offshore drilling contractors. In November 2015, this
agent pled guilty in Brazil in connection with the award of a drilling contract to a competitor and implicated a Petrobras official as part of a wider
investigation of Petrobras’ business practices. Following news reports relating to the agent’s involvement in the Brazil investigation in connection
with his activities with other companies, we conducted a review, which was substantially completed in 2017, of our relationship with the agent
and with Petrobras. We have been in contact and cooperated with the SEC, the Brazilian federal prosecutor’s office and the U.S. Department of
Justice (“DOJ”) about this matter, and in December 2018, the SEC and the DOJ each advised us that they had closed their file on this matter. We
have remained in contact with the Brazilian federal prosecutor’s office, who is aware of our internal review, and continue to cooperate with any
questions or requests they may have. To our knowledge, neither the agent, nor the government authorities investigating the matter, has alleged
that the agent or Noble acted improperly in connection with our contracts with Petrobras.
Paragon Offshore
On August 1, 2014, Noble-UK completed the Spin-off of a majority of its standard specification offshore drilling business through a pro
rata distribution of all of the ordinary shares of its wholly-owned subsidiary, Paragon Offshore, to the holders of Noble’s ordinary shares. In
February 2016, Paragon Offshore sought approval of a pre-negotiated plan of reorganization (the “Prior Plan”) by filing for voluntary relief under
Chapter 11 of the United States Bankruptcy Code. As part of the Prior Plan, we entered into a settlement agreement with Paragon Offshore (the
“Settlement Agreement”). The Prior Plan was rejected by the bankruptcy court in October 2016.
In April 2017, Paragon Offshore filed a revised plan of reorganization (the “New Plan”) in its bankruptcy proceeding. Under the New
Plan, Paragon Offshore no longer need the Mexican tax bonding that Noble-UK was to provide under the Settlement Agreement. Consequently,
Paragon Offshore abandoned the Settlement Agreement as part of the New plan, and the Settlement Agreement was terminated at the time of the
filing of the New Plan. On May 2, 2017, Paragon Offshore announced that it had reached an agreement in principle with both its secured and
unsecured creditors to revise the New Plan to, among other things, create and fund a $10.0 million. litigation trust to pursue litigation against us.
On June 7, 2017, the revised New Plan was approved by the bankruptcy court and Paragon Offshore emerged from bankruptcy on July 18, 2017.
On December 15, 2017, the litigation trust filed claims relating to the Spin-off against us and certain of our current and former officers and
directors in the Delaware bankruptcy court that heard Paragon Offshore’s bankruptcy. The complaint alleges claims of alleged actual and constructive
fraudulent conveyance, unjust enrichment and recharacterization of intercompany notes as equity claims against Noble and claims of breach of
fiduciary duty and aiding and abetting breach of fiduciary duty against the officer and director defendants. The complaint states that the litigation
trust is seeking damages of approximately $1.7 billion from the Company, an amount equal to the amount borrowed by Paragon Offshore immediately
prior to the Spin-off, as well as unspecified amounts in respect of the claims against the officer and director defendants, all of whom have
indemnification agreements with us. We requested that the court dismiss the claims of breach of fiduciary duty, aiding and abetting breach of
fiduciary duty and unjust enrichment, and require such claims to be arbitrated under the MSA entered into between Noble and Paragon Offshore
at the time of the Spin-off, as well as stay the other proceedings during the pendency of the arbitration. The court ruled that the unjust enrichment
claim be arbitrated and that the other claims proceed in bankruptcy court. We and the litigation trust have mutually agreed to drop our respective
appeals of the arbitration ruling and now all matters will be heard in court, which will streamline the case. Discovery continues and the court has
approved a litigation schedule, which could result in all pre-trial activity being completed by the end of 2019. A trial date has not yet been set.
We believe that Paragon Offshore, at the time of the Spin-off, was properly funded, solvent and had appropriate liquidity and that the claims
brought by the litigation trust are without merit. We intend to defend ourselves vigorously. However, there is inherent risk and substantial expense
in litigation, and the amount of damages the plaintiff is seeking is substantial. If any of the litigation trust’s claims are successful, or if we elect
91
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
to settle any claims (in part to reduce or eliminate the ongoing cost of defending the litigation and eliminate any risk of a larger judgment against
us), any damages or other amounts we would be required to or agree to pay could have a material adverse effect on our business, financial condition
and results of operations. Because of our view of the merits of the claims and the significant discovery still to be conducted in the litigation, we
are not currently able to make a reasonable estimation of the amount of possible loss we may incur, if any. Subsequent developments in the litigation
may make such an estimation possible, in which case we may record a charge against our income when a loss is reasonably estimable. This may
occur even though the litigation may still be ongoing. Any charge could be material and could have a material adverse effect on our financial
condition and results of operations. It may also be materially different than any amount we are required to pay once the litigation is concluded.
We have directors’ and officers’ indemnification coverage for the officers and directors who have been sued by the litigation trust. The
insurers have accepted coverage for the director and officer claims and we are continuing to discuss with them the scope of their reimbursement
of litigation expenses. In addition, at the time of the Spin-off, we had entity coverage, or “Side C” coverage, which was meant to cover certain
litigation claims up to the coverage limit of $150.0 million, including litigation expenses. We have made a claim for coverage of the litigation
trust’s claims against Noble under such entity insurance. The insurers have rejected coverage for these claims. We cannot predict the amount of
claims and expenses we may incur, pay or settle in the Paragon Offshore litigation that such insurance will cover, if any.
Prior to the completion of the Spin-off, Noble-UK and Paragon Offshore entered into the Separation Agreements to effect the separation
and Spin-off and govern the relationship between the parties after the Spin-off, including the MSA and the TSA.
As part of its final bankruptcy plan, Paragon Offshore rejected the Separation Agreements. Accordingly, the indemnity obligations that
Paragon Offshore potentially would have owed us under the Separation Agreements have now terminated, including indemnities arising under
the MSA and the TSA in respect of obligations related to Paragon Offshore’s business that were incurred through Noble-retained entities prior to
the Spin-off. Likewise, any potential indemnity obligations that we would have owed Paragon Offshore under the Separation Agreements, including
those under the MSA and the TSA in respect of Noble-UK’s business that was conducted prior to the Spin-off through Paragon Offshore-retained
entities, are now also extinguished. In the absence of the Separation Agreements, liabilities relating to the respective parties will be borne by the
owner of the legal entity or asset at issue and neither party will look to an allocation based on the historic relationship of an entity or asset to one
of the party’s business, as had been the case under the Separation Agreements.
The rejection and ultimate termination of the indemnity and related obligations under the Separation Agreements resulted in a number of
accounting charges and benefits during the year ended December 31, 2017, and such termination may continue to affect us in the future as liabilities
arise for which we would have been indemnified by Paragon Offshore or would have had to indemnify Paragon Offshore. We do not expect that,
overall, the rejection of the Separation Agreements by Paragon Offshore will have a material adverse effect on our financial condition or liquidity.
However, any loss we experience with respect to which we would have been able to secure indemnification from Paragon Offshore under one or
more of the Separation Agreements could have an adverse impact on our results of operations in any period, which impact may be material
depending on our results of operations during this down-cycle.
During the year ended December 31, 2017, we recognized net charges of $15.9 million, with a non-cash loss of $1.5 million recorded in
“Net loss from discontinued operations, net of tax” on our Consolidated Statement of Operations relating to Paragon Offshore’s emergence from
bankruptcy.”
Tax matters
During 2014, the Internal Revenue Service (“IRS”) began its examination of our tax reporting in the U.S. for the taxable years ended
December 31, 2010 and 2011. The IRS examination team has completed its examination of our 2010 and 2011 U.S. tax returns and proposed
adjustments and deficiencies with respect to certain items that were reported by us for the 2010 and 2011 tax year. On December 19, 2016, we
received the Revenue Agent Report from the IRS. We believe that we have accurately reported all amounts in our tax returns, and have submitted
administrative protests with the IRS Office of Appeals contesting the examination team’s proposed adjustments. We intend to vigorously defend
our reported positions, and believe the ultimate resolution of the adjustments proposed by the IRS examination team will not have a material
adverse effect on our consolidated financial statements. During the third quarter of 2017, the IRS initiated its examination of our 2012, 2013, 2014
and 2015 tax returns.
Audit claims of approximately $50.7 million attributable to income and other business taxes were assessed against Noble entities in Mexico
related to tax years 2005 and 2007. 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. We cannot predict or provide assurance as to the ultimate outcome of any existing or future assessments.
92
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Other contingencies
We have entered into agreements with certain of our executive officers, as well as certain other employees. These agreements become
effective upon a change of control of Noble-UK (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 remain effective for three years thereafter. These agreements provide for compensation and
certain other benefits under such circumstances.
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.
We lease certain office space and warehouse facilities under cancelable and non-cancelable leases. Rent expense under these arrangements
totaled $7.5 million, $8.3 million and $7.8 million for the years ended December 31, 2018, 2017 and 2016, respectively.
The table below depicts future minimum rental commitments under our operating leases as of December 31, 2018:
$
(1)
2019
2020
2021
2022
2023
Thereafter
(1)
Total
15,213
$
7,913
$
5,522
$
1,821
$
695
$
5,724
$
36,888
In February 2019, we amended the lease of our Sugar Land office to extend the lease for an additional ten years and to reduce the rented
space. The above table does not include this lease amendment.
Note 16— 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, 2018, our contract drilling services segment conducts
contract drilling operations in Canada, Far East Asia, the Middle East, the North Sea, Oceania, the Black Sea, South America and the U.S. Gulf
of Mexico.
The following table presents revenues and identifiable assets by country based on the location of the service provided:
Argentina
Australia
Brazil
Brunei
Bulgaria
Canada
Curacao
Denmark
East Timor
Egypt
Gabon
Guyana
Malaysia
Mexico
Myanmar
Qatar
Saudi Arabia
Singapore
Revenues for Year Ended December 31,
Identifiable Assets as of December 31,
2018
2017
2016
2018
2017
$
— $
—
—
3,080
84,757
47,085
—
35,855
33,733
112,473
—
50,839
91,052
—
16,572
35,180
156,989
1,769
93
— $
12,262
—
45,450
55,145
1,639
—
44,671
—
—
—
—
131,696
—
—
16,488
140,453
—
51,627
89,847
27,640
42,710
78,985
—
—
46,342
—
—
23,385
—
168,826
—
—
608
120,132
—
$
— $
243,388
13,299
—
645,689
219,421
82,521
242,831
—
689,965
8,065
1,250,390
665,822
27,542
152,629
478,708
380,421
125,574
—
257,415
25,645
119
657,806
238,902
647,554
250,851
—
—
8,378
—
293,297
27,391
—
—
455,296
911,515
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
South Africa
Suriname
Tanzania
The Netherlands
Turkey
United Arab Emirates
United Kingdom
United States
Other
Total
—
(3)
381
—
—
(17)
194,602
218,479
—
1,082,826
$
48,228
13,034
1,526
—
(3)
99,825
209,338
417,163
—
1,236,915
$
1,803
—
48,394
42
—
86,446
95,621
1,404,365
15,292
2,302,065
$
—
—
—
—
—
45,205
1,152,596
2,840,857
—
9,264,923
—
—
—
—
—
590,863
894,902
5,534,725
—
$ 10,794,659
$
Note 17— Supplemental Financial Information
Consolidated Balance Sheets Information
Deferred revenues from drilling contracts totaled $80.8 million and $114.3 million at December 31, 2018 and 2017, 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 $47.7 million at December 31,
2018 as compared to $55.7 million at December 31, 2017, 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.
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:
Accounts receivable
Other current assets
Other assets
Accounts payable
Other current liabilities
Other liabilities
Total net change in assets and
liabilities
Noble-UK
December 31,
Noble-Cayman
December 31,
$
$
2018
3,974
(2,722)
(10,378)
14,955
(13,940)
(26,829)
$
2017
114,456
26,155
(89,021)
(14,625)
33,906
(92,096)
$
2016
179,779
81,657
138,210
(68,209)
(209,739)
(31,389)
$
2018
3,974
(2,700)
(6,424)
14,795
(13,495)
(26,829)
$
2017
114,456
23,309
(91,236)
(14,429)
35,033
(87,213)
2016
179,779
79,720
136,130
(66,421)
(203,763)
(32,732)
$
(34,940) $
(21,225) $
90,309
$
(30,679) $
(20,080) $
92,713
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, 2018, December 31, 2017 and December 31, 2016 were $52.1 million, $25.5 million and $35.1 million, respectively.
We entered into a $60.0 million Seller Loan to finance a portion of the purchase price for the Noble Johnny Whitstine in September
2018. See “Note 7— Debt” for additional information.
94
Additional cash flow information is as follows:
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Noble - UK
December 31,
Noble - Cayman
December 31,
2018
2017
2016
2018
2017
2016
Cash paid during the period for:
Interest, net of amounts capitalized
$
286,506
$
246,960
$
232,907
$
(107,554)
30,590
100,544
286,506
(107,554)
$
246,960
$
232,907
30,590
100,717
Income taxes (net of refunds)
Non-cash activities during the
period:
Spin-off of Paragon Offshore
N/A
N/A
N/A
N/A
N/A
N/A
In accordance with our adoption of ASU No. 2016-09, prior period excess tax benefits, which were previously classified as a
financing activity in “Employee stock transactions,” are now classified as an operating activity in “Net change in other assets and liabilities”
on our Consolidated Statement of Cash Flows and current period excess tax benefits are now recognized in our Consolidated Statement
of Operations through income taxes. Additionally, shares withheld for taxes on employee stock transactions, which were previously
classified as an operating activity in “Net change in other assets and liabilities,” are now classified as a financing activity in “Employee
stock transactions” on our Consolidated Statement of Cash Flows.
Revision of Prior Period Financial Statements
During the preparation of our 2018 financial statements, we identified a computational error that resulted in misstatements of certain
line items on the Consolidated Statements of Cash Flows for Noble Corporation plc and Noble Corporation (Cayman) for the years ended
December 31, 2017 and 2016. These errors did not impact our cash, cash equivalents and restricted cash balances. We assessed the
materiality of the misstatements and concluded the misstatements were immaterial to the previously issued financial statements.
We have revised the Consolidated Statements of Cash Flows for the years ended December 31, 2017 and 2016. The impacts on the
Consolidated Statements of Cash Flows and related notes to the financial statements are presented below:
Consolidated Statements of Cash Flows - Noble Corporation plc
Year Ended December 31, 2017
Year Ended December 31, 2016
As Reported
Adjustment
As Revised
As Reported
Adjustment
As Revised
Accounts payable
$
22,638
Net effect of changes in other assets and liabilities
16,038
$ (37,263) $ (14,625) $ (84,873) $
(21,225)
(37,263)
73,645
16,664
$ (68,209)
16,664
90,309
Consolidated Statements of Cash Flows - Noble Corporation (Cayman)
Year Ended December 31, 2017
Year Ended December 31, 2016
As Reported
Adjustment
As Revised
As Reported
Adjustment
As Revised
Accounts payable
$
22,834
Net effect of changes in other assets and liabilities
17,183
$ (37,263) $ (14,429) $ (83,085) $
(20,080)
(37,263)
76,049
16,664
$
(66,421)
16,664
92,713
95
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands
Note 18— Condensed Consolidating Financial Information
Guarantees of Registered Securities
Noble-Cayman, or one or more 100 percent owned subsidiaries of Noble-Cayman, is an issuer, co-issuer or full and unconditional guarantor
or otherwise obligated as of December 31, 2018 with respect to registered securities as follows (see “Note 7— Debt” for additional information):
Notes (1)
5.75% Senior Notes due 2018
7.50% Senior Notes due 2019 (2)
4.90% Senior Notes due 2020
4.625% Senior Notes due 2021
3.95% Senior Notes due 2022
7.75% Senior Notes due 2024
7.95% Senior Notes due 2025
6.20% Senior Notes due 2040
6.05% Senior Notes due 2041
5.25% Senior Notes due 2042
8.95% Senior Notes due 2045
Issuer
(Co-Issuer(s))
NHIL
NHUS
Noble Drilling Holding, LLC (“NDH”)
Noble Drilling Services 6 LLC (“NDS6”)
NHIL
NHIL
NHIL
NHIL
NHIL
NHIL
NHIL
NHIL
NHIL
Guarantor
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
Noble-Cayman
(1) Our 2026 Notes are excluded from this list as they are unregistered securities issued in a non-public offering.
(2) In February 2018, the entire remaining principal amount of 2019 Notes were redeemed and, as a result, we have prospectively eliminated NHUS,
NDH, and NDS6 as guarantors in the current year presentation of the Condensed Consolidating Financial Information. However, prior year
information is presented as previously reported.
The following condensed consolidating financial statements of Noble-Cayman, NHUS, NDH, NHIL, NDS6 and all other subsidiaries
present investments in both consolidated and unconsolidated affiliates using the equity method of accounting.
96
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
December 31, 2018
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Noble -
Cayman
NHIL
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
ASSETS
Current assets
Cash and cash equivalents
Accounts receivable
Taxes receivable
Short-term notes receivable from affiliates
Accounts receivable from affiliates
Prepaid expenses and other current assets
Total current assets
Property and equipment, at cost
Accumulated depreciation
Property and equipment, net
Notes receivable from affiliates
Investments in affiliates
Other assets
Total assets
LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables to affiliates
Accounts payable
Accrued payroll and related costs
Accounts payable to affiliates
Taxes payable
Interest payable
Other current liabilities
Total current liabilities
Long-term debt
Notes payable to affiliates
Deferred income taxes
Other liabilities
Total liabilities
Commitments and contingencies
Total shareholder equity
Noncontrolling interests
Total equity
$
— $
17,818
$
356,557
$
—
—
—
275,726
—
275,726
—
—
—
5,145
7,716,068
609
—
—
—
61,046
—
78,864
—
—
—
—
12,300,840
200,722
20,498
3,175,662
4,823,902
61,917
8,639,258
10,956,412
(2,475,694)
8,480,718
—
—
—
124,540
— $
—
—
(3,175,662)
(5,160,674)
—
(8,336,336)
—
—
—
(5,145)
(20,016,908)
—
$
$
7,997,548
$
12,379,704
$
17,244,516
$
(28,358,389)
$
— $
3,175,662
$
— $
(3,175,662)
$
45
—
—
—
3,725,506
1,098,395
—
3
—
3,725,554
—
—
—
19,929
3,745,483
4,252,065
—
4,252,065
—
99,997
—
4,374,054
3,817,153
—
—
—
8,191,207
4,188,497
—
4,188,497
125,192
50,284
336,773
29,386
100
60,012
601,747
60,249
5,145
91,695
255,866
1,014,702
15,828,411
401,403
16,229,814
—
—
(5,160,674)
—
—
—
(8,336,336)
—
(5,145)
—
—
(20,016,908)
—
(20,016,908)
374,375
200,722
20,498
—
—
61,917
657,512
10,956,412
(2,475,694)
8,480,718
—
—
125,149
9,263,379
—
125,237
50,284
—
29,386
100,100
60,012
365,019
3,877,402
—
91,695
275,795
4,252,065
401,403
4,653,468
9,263,379
(8,341,481)
4,609,911
Total liabilities and equity
$
7,997,548
$
12,379,704
$
17,244,516
$
(28,358,389)
$
97
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
December 31, 2017
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
662,011
204,696
105,345
—
—
—
249,843
83,873
54,904
—
33,965
98,189
71,466
ASSETS
Current assets
Cash and cash equivalents
$
Accounts receivable
Taxes receivable
Short-term notes receivable from
affiliates
11
—
—
—
Accounts receivable from affiliates
594,456
Prepaid expenses and other current
assets
Total current assets
Property and equipment, at cost
Accumulated depreciation
Property and equipment, net
Notes receivable from affiliates
Investments in affiliates
Other assets
—
594,467
—
—
—
3,177,248
4,933,978
2,663
$
— $
23,160
$
29,324
$
— $
609,516
$
— $
—
93,302
—
1,454
—
94,756
—
—
—
—
4,550,358
16,775
24,722
3
119,476
144,367
1,477
313,205
857,784
(110,005)
747,779
1,199,815
5,252,135
8,372
—
—
—
—
—
179,974
12,040
—
—
2,373,452
—
(2,492,928)
60,945
465,749
5,813,846
(7,080,817)
—
1
63,963
—
65,441
90,269
2,839,202
6,679,339
(9,573,745)
1,037,493
—
—
—
—
12,560,598
—
—
—
3,943,299
7,237,474
11,176,547
(2,435,086)
8,741,461
1,175,300
—
—
—
(9,495,662)
—
(34,534,543)
12,034,331
(2,545,091)
9,489,240
—
—
—
—
238,718
—
266,528
Total assets
$
8,708,356
$
4,661,889
$
7,521,306
$
12,650,867
$
14,019,975
$
16,834,818
$
(53,603,950)
$
10,793,261
LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables to affiliates
$
— $
1,605,243
$
— $
— $
— $
887,685
$
(2,492,928)
$
Current maturities of long-term debt
Accounts payable
Accrued payroll and related costs
—
—
—
—
—
—
—
1,467
4,780
249,843
—
—
Accounts payable to affiliates
3,410,669
393,073
1,770,066
661,375
Taxes payable
Interest payable
Other current liabilities
—
2,211
—
—
—
—
—
—
5,169
Total current liabilities
3,412,880
1,998,316
1,781,482
Long-term debt
Notes payable to affiliates
Deferred income taxes
Other liabilities
—
—
—
19,929
—
700,000
—
—
—
474,637
5
30,330
—
83,960
—
995,178
3,594,332
3,175,663
—
—
—
—
—
—
—
12,018
—
12,018
201,535
—
—
—
—
82,406
50,124
845,634
33,965
—
66,297
—
—
—
(7,080,817)
—
—
—
1,966,111
(9,573,745)
592,240
—
—
3,795,867
5,145,362
(9,495,662)
164,957
239,919
—
—
—
164,962
290,178
Total liabilities
3,432,809
2,698,316
2,286,454
7,765,173
213,553
7,516,349
(19,069,407)
4,843,247
Commitments and contingencies
Total shareholder equity
5,275,547
1,963,573
5,234,852
4,885,694
13,806,422
8,644,002
(34,534,543)
5,275,547
Noncontrolling interests
Total equity
—
—
—
—
—
674,467
—
674,467
5,275,547
1,963,573
5,234,852
4,885,694
13,806,422
9,318,469
(34,534,543)
5,950,014
Total liabilities and equity
$
8,708,356
$
4,661,889
$
7,521,306
$
12,650,867
$
14,019,975
$
16,834,818
$
(53,603,950)
$
10,793,261
98
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS and COMPREHENSIVE INCOME (LOSS)
Year Ended December 31, 2018
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Noble-
Cayman
NHIL
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
Operating revenues
Contract drilling services
Reimbursables and other
Total operating revenues
Operating costs and expenses
Contract drilling services
Reimbursables
Depreciation and amortization
General and administrative
Loss on impairment
Total operating costs and expenses
Operating loss
Other income (expense)
Income (loss) of unconsolidated affiliates - continuing
operations
Interest expense, net of amounts capitalized
Gain (loss) on extinguishment of debt, net
Interest income and other, net
Income (loss) before income taxes
Income tax benefit (provision)
Net income (loss)
Net income attributable to noncontrolling interests
Net income (loss) attributable to Noble Corporation
Other comprehensive income (loss), net
Comprehensive income (loss) attributable to Noble
Corporation
$
— $
— $
1,036,082
$
— $
—
—
2
—
—
57
—
59
(59)
(2,738,475)
(1,324)
(2,336)
1,897,709
(844,485)
—
(844,485)
—
(844,485)
(8,644)
—
—
(22)
—
—
214
—
192
(192)
(258,687)
(449,824)
12,651
(74)
(696,126)
—
(696,126)
—
(696,126)
—
46,744
1,082,826
628,148
37,084
482,660
37,932
802,133
1,987,957
(905,131)
—
(1,911,822)
(12,108)
176,006
(2,653,055)
106,534
(2,546,521)
245,485
(2,301,036)
(8,644)
—
—
—
—
—
—
—
—
—
2,997,162
2,065,359
—
(2,065,359)
2,997,162
—
2,997,162
—
2,997,162
8,644
1,036,082
46,744
1,082,826
628,128
37,084
482,660
38,203
802,133
1,988,208
(905,382)
—
(297,611)
(1,793)
8,282
(1,196,504)
106,534
(1,089,970)
245,485
(844,485)
(8,644)
$
(853,129)
$
(696,126)
$
(2,309,680)
$
3,005,806
$
(853,129)
99
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS and COMPREHENSIVE INCOME (LOSS)
Year Ended December 31, 2017
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
Operating revenues
Contract drilling services
$
— $
— $
168,592
$
— $
— $
1,086,320
$
(47,886)
$
1,207,026
Reimbursables and other
Total operating revenues
Operating costs and expenses
Contract drilling services
Reimbursables
Depreciation and amortization
General and administrative
Loss on impairment
Total operating costs and expenses
Operating income (loss)
Other income (expense)
Income (loss) of unconsolidated
affiliates - continuing operations
Income (loss) of unconsolidated
affiliates - discontinued operations,
net of tax
Interest expense, net of amounts
capitalized
Interest income and other, net
—
—
304
—
—
129
—
433
(433)
—
—
12,090
—
—
5,761
—
17,851
(17,851)
3,443
172,035
43,161
1,992
58,236
—
45,012
148,401
23,634
—
—
3,115
—
—
1,588
—
4,703
(4,703)
—
—
—
—
—
9
—
9
26,446
1,112,766
—
29,889
(47,886)
1,236,915
629,699
16,443
484,883
33,600
76,627
(47,886)
—
—
—
—
640,483
18,435
543,119
41,087
121,639
1,241,252
(47,886)
1,364,763
(9)
(128,486)
—
(127,848)
(476,382)
(528,702)
82,596
188,809
17,874
2,967
4,566
—
—
—
—
—
715,805
(7,533)
341,603
(341,603)
708,272
—
—
—
(291,989)
7,733
(412,104)
(42,595)
Income (loss) before income taxes
(474,316)
(574,966)
Income tax benefit (provision)
—
241,960
(10,951)
10,483
(32,838)
(141)
(13,493)
(430,580)
(15,288)
(130,442)
87,287
180,024
(440)
4,771
(241,703)
—
224,772
227,349
—
22,164
(236,764)
(284,115)
Net income (loss) from continuing
operations
Net income (loss) from discontinuing
operations, net of tax
(474,316)
(333,006)
179,584
(241,703)
227,349
(520,879)
708,272
(454,699)
—
(1,598)
—
—
—
4,565
—
2,967
Net income (loss)
(474,316)
(334,604)
179,584
(241,703)
227,349
(516,314)
708,272
(451,732)
—
—
—
—
—
(20,589)
(1,995)
(22,584)
Net income attributable to
noncontrolling interests
Net income (loss) attributable to Noble
Corporation
Other comprehensive income (loss), net
9,252
—
—
—
—
9,252
(474,316)
(334,604)
179,584
(241,703)
227,349
(536,903)
706,277
(9,252)
(474,316)
9,252
Comprehensive income (loss) attributable
to Noble Corporation
$
(465,064)
$
(334,604)
$
179,584
$
(241,703)
$
227,349
$
(527,651)
$
697,025
$
(465,064)
100
Reimbursables
Depreciation and amortization
General and administrative
Loss on impairment
Total operating costs and expenses
Operating income (loss)
Other income (expense)
Income (loss) of unconsolidated
affiliates
Interest expense, net of amounts
capitalized
Gain on extinguishment of debt, net
Interest income and other, net
Income (loss) before income taxes
Income tax benefit (provision)
Net income (loss)
Net (income) loss attributable to
noncontrolling interests
Net income (loss) attributable to Noble
Corporation
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF INCOME and COMPREHENSIVE INCOME (LOSS)
Year Ended December 31, 2016
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
Operating revenues
Contract drilling services
$
— $
— $
250,049
$
— $
— $
2,086,848
$
(94,697)
$
2,242,200
Reimbursables and other
Total operating revenues
Operating costs and expenses
—
—
—
—
Contract drilling services
4,532
18,902
9,190
259,239
70,801
8,231
91,802
—
—
170,834
88,405
—
—
84,309
—
—
40,082
—
124,391
(124,391)
—
—
—
—
—
1
—
1
51,375
2,138,223
788,065
37,268
519,211
(4,018)
1,458,749
2,799,275
—
60,565
(94,697)
2,302,765
(94,697)
—
—
—
—
(94,697)
871,912
45,499
611,013
46,045
1,458,749
3,033,218
(1)
(661,052)
—
(730,453)
—
—
1,264
—
5,796
(5,796)
—
—
8,716
—
27,618
(27,618)
(962,662)
(257,142)
(980,099)
(333,446)
515,518
—
2,017,831
—
(27,891)
(70,494)
(11,461)
(228,423)
(15,117)
(122,345)
252,816
(222,915)
—
96,635
(899,714)
—
(899,714)
—
120
(355,134)
(42,522)
(397,656)
—
12,616
17,814
20,412
(890,539)
(648,034)
—
15,058
515,458
—
—
106,359
(252,816)
(677,038)
2,017,831
163
—
—
151,522
—
(890,376)
(648,034)
515,458
(525,516)
2,017,831
17,814
(1,616)
(937,170)
109,163
(828,007)
—
—
—
—
—
(39,294)
(32,413)
(71,707)
(899,714)
(397,656)
(890,376)
(648,034)
515,458
(564,810)
1,985,418
(899,714)
Other comprehensive income (loss), net
11,035
—
—
—
—
11,035
(11,035)
11,035
Comprehensive income (loss) attributable
to Noble Corporation
$
(888,679)
$
(397,656)
$
(890,376)
$
(648,034)
$
515,458
$
(553,775)
$
1,974,383
$
(888,679)
101
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
Year Ended December 31, 2018
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Cash flows from operating activities
Net cash provided by (used in) operating activities
$
1,920,724
$
(426,298)
$
(1,281,667)
$
— $
212,759
Noble-
Cayman
NHIL
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
Cash flows from investing activities
Capital expenditures
Proceeds from disposal of assets
Net cash used in investing activities
Cash flows from financing activities
Issuance of senior notes
Repayment of long-term debt
Debt issuance costs
Dividends paid to noncontrolling interests
Distribution to parent company, net
Advances (to) from affiliates
Net cash provided by (used in) financing activities
Net change in cash, cash equivalents and restricted cash
Cash, cash equivalents and restricted cash, beginning of period
—
—
—
—
—
(845)
—
(44,417)
(1,875,473)
(1,920,735)
(11)
11
—
—
—
750,000
(759,053)
(13,027)
—
—
436,872
414,792
(11,506)
29,324
(194,779)
5,402
(189,377)
—
(213,655)
(1,767)
(27,579)
—
1,438,601
1,195,600
(275,444)
632,676
—
—
—
—
—
—
—
—
—
—
—
—
Cash, cash equivalents and restricted cash, end of period
$
— $
17,818
$
357,232
$
— $
(194,779)
5,402
(189,377)
750,000
(972,708)
(15,639)
(27,579)
(44,417)
—
(310,343)
(286,961)
662,011
375,050
102
Cash flows from operating activities
Net cash provided by (used in)
operating activities
Cash flows from investing activities
Capital expenditures
Proceeds from disposal of assets
Net cash used in investing activities
Cash flows from financing activities
Repayment of long-term debt
Debt issuance costs on senior notes and
credit facilities
Dividends paid to noncontrolling
interests
Net cash provided by (used in)
financing activities
Net change in cash, cash
equivalents and restricted cash
Cash, cash equivalents and restricted cash,
beginning of period
Cash, cash equivalents and restricted cash,
end of period
Contributions from parent company, net
Advances (to) from affiliates
28,352
(63,073)
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
Year Ended December 31, 2017
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
$
32,195
$
100,883
$
209,898
$
(403,391)
$
217,080
$
298,409
$
— $
455,074
—
—
—
—
—
—
—
—
—
—
—
—
—
(3,622)
46
(3,576)
—
—
—
—
—
—
—
(300,000)
(42)
—
—
—
—
—
—
—
—
—
(117,085)
2,336
(114,749)
—
—
(56,881)
—
(100,883)
(194,017)
732,757
(217,080)
(157,704)
(34,721)
(100,883)
(194,017)
432,715
(217,080)
(214,585)
(2,526)
2,537
—
—
12,305
29,324
10,855
—
—
—
(30,925)
640,441
—
—
—
—
—
—
—
—
—
—
—
(120,707)
2,382
(118,325)
(300,000)
(42)
(56,881)
28,352
—
(328,571)
8,178
653,833
$
11
$
— $
23,160
$
29,324
$
— $
609,516
$
— $
662,011
103
NOBLE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
Year Ended December 31, 2016
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other
Non-guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
Cash flows from operating activities
Net cash provided by (used in)
operating activities
Cash flows from investing activities
Capital expenditures
Proceeds from disposal of assets
Net cash provided by (used in)
investing activities
Cash flows from financing activities
Repayment of long-term debt
Issuance of senior notes
Tender offer premium
Debt issuance costs on senior notes and
credit facilities
Dividends paid to noncontrolling
interests
Distributions to parent company, net
Advances (to) from affiliates
Net cash provided by (used in)
financing activities
Net change in cash, cash
equivalents and restricted cash
Cash, cash equivalents and restricted cash,
beginning of period
Cash, cash equivalents and restricted cash,
end of period
$
97,388
$
(150,735)
$
149,431
$
(344,112)
$
(60)
$
1,421,023
$
— $
1,172,935
—
—
—
—
—
—
—
—
(152,360)
55,882
—
—
—
—
—
—
—
—
—
(492,985)
—
(492,985)
—
—
—
—
—
—
—
—
—
(1,049,338)
980,100
(24,649)
(12,111)
—
—
150,735
352,308
450,110
(96,478)
150,735
352,308
344,112
910
1,627
—
—
8,754
2,101
—
—
—
—
—
—
—
—
—
—
—
60
60
—
—
(218,418)
24,808
(193,610)
—
—
—
—
(85,944)
—
(1,009,095)
(1,095,039)
132,374
508,067
—
—
—
—
—
—
—
—
—
—
—
—
—
(711,403)
24,808
(686,595)
(1,049,338)
980,100
(24,649)
(12,111)
(85,944)
(152,360)
—
(344,302)
142,038
511,795
$
2,537
$
— $
10,855
$
— $
— $
640,441
$
— $
653,833
104
Revision of Prior Period Financial Statements
During the preparation of our 2018 financial statements, we identified a computational error that resulted in misstatements of certain line
items on the Consolidated Statements of Cash Flows for Noble Corporation (Cayman) for the years ended December 31, 2017 and 2016. These
errors did not impact our cash, cash equivalents and restricted cash balances. We assessed the materiality of the misstatements and concluded the
misstatements were immaterial to the previously issued financial statements.
We have revised the Consolidated Statements of Cash Flows for the years ended December 31, 2017 and 2016. The impacts on the
Consolidated Statements of Cash Flows and related notes to the financial statements are presented below:
Year Ended December 31, 2017
As Reported - Noble Corporation (Cayman)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other Non-
guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
$
32,195
$
100,883
$
209,898
$
(403,391)
$
217,080
$
335,672
$
— $
492,337
Noble-
Cayman
—
—
—
—
—
—
—
(3,622)
(3,576)
—
—
—
—
(154,348)
(152,012)
—
—
(157,970)
(155,588)
Adjustments - Noble Corporation (Cayman)
NHUS
NDH
NHIL
NDS6
Other Non-
guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
—
—
—
—
—
—
—
—
—
—
(37,263)
—
—
37,263
37,263
—
—
—
(37,263)
37,263
37,263
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other Non-
guarantor
Subsidiaries
of Noble
Consolidating
Adjustments
Total
As Revised - Noble Corporation (Cayman)
32,195
100,883
209,898
(403,391)
217,080
298,409
—
455,074
—
—
—
—
(3,622)
(3,576)
—
—
—
—
(117,085)
(114,749)
—
—
(120,707)
(118,325)
Cash flow from operating activities
Net cash provided by (used in) operating
activities
Cash flows from investing activities
Capital expenditures
Net cash used in investing activities
Cash flow from operating activities
Net cash provided by (used in) operating
activities
Cash flows from investing activities
Capital expenditures
Net cash used in investing activities
Cash flow from operating activities
Net cash provided by (used in) operating
activities
Cash flows from investing activities
Capital expenditures
Net cash used in investing activities
105
Year Ended December 31, 2016
As Reported - Noble Corporation (Cayman)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other Non-
guarantor
Subsidiaries of
Noble
Consolidating
Adjustments
Total
$
97,388
$
(150,735)
$
149,431
$
(344,112)
$
(60)
$
1,404,359
$
— $
1,156,271
—
—
—
—
(492,985)
(492,985)
—
—
—
—
(201,754)
(176,946)
—
—
(694,739)
(669,931)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other Non-
guarantor
Subsidiaries of
Noble
Consolidating
Adjustments
Total
Adjustments - Noble Corporation (Cayman)
$
— $
— $
— $
— $
— $
16,664
$
— $
16,664
—
—
—
—
—
—
—
—
—
—
(16,664)
(16,664)
—
—
(16,664)
(16,664)
Noble-
Cayman
NHUS
NDH
NHIL
NDS6
Other Non-
guarantor
Subsidiaries of
Noble
Consolidating
Adjustments
Total
As Revised - Noble Corporation (Cayman)
$
97,388
$
(150,735)
$
149,431
$
(344,112)
$
(60)
$
1,421,023
$
— $
1,172,935
—
—
—
—
(492,985)
(492,985)
—
—
—
—
(218,418)
(193,610)
—
—
(711,403)
(686,595)
Cash flow from operating activities
Net cash provided by (used in) operating
activities
Cash flows from investing activities
Capital expenditures
Net cash used in investing activities
Cash flow from operating activities
Net cash provided by (used in) operating
activities
Cash flows from investing activities
Capital expenditures
Net cash used in investing activities
Cash flow from operating activities
Net cash provided by (used in) operating
activities
Cash flows from investing activities
Capital expenditures
Net cash used in investing activities
106
NOBLE CORPORATION PLC AND SUBSIDIARIES
NOBLE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands)
Note 19— Unaudited Interim Financial Data
Unaudited interim consolidated financial information from continuing operations for Noble-UK is as follows:
2018
Operating revenues
Operating loss
Net loss from continuing operations
Net loss per share from continuing operations attributable to Noble-UK (1)
Basic
Loss from continuing operations
Diluted
Loss from continuing operations
2017
Operating revenues
Operating loss
Net loss from continuing operations
Net loss from discontinued operations, net of tax
Net loss per share from continuing operations attributable to Noble-UK (1)
Basic
Loss from continuing operations
Loss from discontinued operations
Diluted
Loss from continuing operations
Loss from discontinued operations
March 31
June 30
September 30
December 31
Quarters Ended
$
$
235,157
(56,880)
(142,334)
$
258,369
(845,606)
(628,063)
$
279,408
(21,843)
(81,591)
309,892
(21,745)
(33,062)
(0.58)
(0.58)
(2.55)
(2.55)
(0.33)
(0.33)
(0.13)
(0.13)
March 31
June 30
September 30
December 31
Quarter Ended
$
$
362,976
(45,463)
(301,694)
—
$
278,142
(44,285)
(91,864)
(1,486)
$
266,212
(56,604)
(96,792)
—
329,585
(110,294)
(24,675)
—
(1.24)
—
(1.24)
—
(0.37)
(0.01)
(0.37)
(0.01)
(0.40)
—
(0.40)
—
(0.10)
—
(0.10)
—
(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.
Note 20— Subsequent Events
Purchase of Noble Joe Knight
On February 14, 2019, we exercised an option to purchase another GustoMSC CJ46 rig, to be known as the Noble Joe Knight, and we
expect to close the purchase agreement in late February 2019. The purchase of the Noble Joe Knight is expected to be $83.8 million, of which,
$30.1 million will be funded with cash and $53.8 million will be funded with seller financing on terms similar to the Noble Johnny Whitstine.
107
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
Item 9A. Evaluation of Disclosure Controls and Procedures
Julie J. Robertson, Chairman, President and Chief Executive Officer of Noble-UK, and Adam C. Peakes, Senior Vice President and Chief
Financial Officer of Noble-UK, have evaluated the disclosure controls and procedures of Noble-UK as of the end of the period covered by this
report. On the basis of this evaluation, Ms. Robertson and Mr. Peakes have concluded that Noble-UK’s disclosure controls and procedures were
effective as of December 31, 2018. Noble-UK’s disclosure controls and procedures are designed to ensure that information required to be disclosed
by Noble-UK 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.
Julie J. Robertson, President and Chief Executive Officer of Noble-Cayman, and Adam C. Peakes, Director, Vice President and Chief
Financial Officer of Noble-Cayman, have evaluated the disclosure controls and procedures of Noble-Cayman as of the end of the period covered
by this report. On the basis of this evaluation, Ms. Robertson and Mr. Peakes have concluded that Noble-Cayman’s disclosure controls and
procedures were effective as of December 31, 2018. Noble-Cayman’s disclosure controls and procedures are designed to ensure that information
required to be disclosed by Noble-Cayman 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 either Noble-UK’s or Noble-Cayman’s internal control over financial reporting that occurred during the year
ended December 31, 2018 that have materially affected, or are reasonably likely to materially affect, the internal control over financial reporting
of each of Noble-UK or Noble-Cayman.
Management’s Annual Report on Internal Control Over Financial Reporting
The management of Noble-UK and Noble-Cayman 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 U.S. 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-UK and Noble-Cayman, both Noble-UK and Noble-Cayman maintained effective internal control over financial reporting
as of December 31, 2018.
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, 2018 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.
108
Item 9B. Other Information.
None.
PART III
Item 10. Directors, Executive Officers and Corporate Governance.
The sections entitled “Election of Directors,” “Continuing Directors,” “Board Committees, Meetings and Other Governance Matters,”
“Section 16(a) Beneficial Ownership Reporting Compliance” and “Other Matters” appearing in the proxy statement for the 2019 annual general
meeting of shareholders (the “2019 Proxy Statement”), will set forth certain information with respect to directors, certain corporate governance
matters and reporting under Section 16(a) of the Securities Exchange Act of 1934, and are incorporated in this report by reference.
Executive Officers of the Registrant
The following table presents certain information as of February 21, 2019 with respect to our executive officers:
Name
Julie J. Robertson
Adam C. Peakes
William E. Turcotte
Robert W. Eifler
Scott W. Marks
Laura D. Campbell
Age
62
45
55
39
59
46
Position
Chairman, President and Chief Executive Officer
Senior Vice President and Chief Financial Officer
Senior Vice President and General Counsel
Vice President and General Manager - Marketing and Contracts
Senior Vice President - Engineering
Vice President and Controller
Julie J. Robertson was named Chairman of the Board, President and Chief Executive Officer of the Company in January 2018. Previously,
Ms. Robertson served as Executive Vice President of the Company from February 2006 and as Senior Vice President - Administration from July
2001 to February 2006. Ms. Robertson also served continuously as Corporate Secretary of the Company from December 1993 until assuming the
Chairman’s role in 2018. Ms. Robertson has also served as Vice President - Administration of Noble Drilling from 1996 to July 2001 and as Vice
President - Administration of Noble Drilling Services Inc beginning in 1994. From 1989 to 1994, Ms. Robertson served consecutively as Manager
of Benefits and Director of Human Resources for Noble Drilling Services Inc. Prior to 1989, Ms. Robertson served consecutively in the positions
of Risk and Benefits Manager and Marketing Services Coordinator for a predecessor subsidiary of Noble, beginning in 1979.
Adam C. Peakes was named Senior Vice President and Chief Financial Officer effective January 23, 2017. Prior to joining Noble, Mr.
Peakes served as Managing Director and Head of OFS Investment Banking since 2011 at Tudor, Pickering, Holt & Company, an integrated
investment and merchant bank serving the energy industry. Prior to that time, Mr. Peakes served in various roles at Goldman Sachs & Company
from 1999 to 2011, including most recently as Managing Director, Global Natural Resources in the Investment Banking Division.
William E. Turcotte was named Senior Vice President and General Counsel effective December 16, 2008. Prior to joining Noble, Mr.
Turcotte served as Senior Vice President, General Counsel and Corporate Secretary of Cornell Companies, Inc., a private corrections company,
since March 2007. He served as Vice President, Associate General Counsel and Assistant Secretary of Transocean, Inc., an offshore oil and gas
drilling contractor, from October 2005 to March 2007 and as Associate General Counsel and Assistant Secretary from January 2000 to October
2005. From 1992 to 2000, Mr. Turcotte served in various legal positions with Schlumberger Limited in Houston, Caracas and Paris. Mr. Turcotte
was in private practice prior to joining Schlumberger.
Robert W. Eifler was named Vice President and General Manager - Marketing and Contracts effective July 17, 2017. Before assuming his
currently role, Mr. Eifler led Noble's marketing and contracts efforts for the Eastern Hemisphere while based in London. From November 2013
to March 2015, Mr. Eifler worked for Hercules Offshore, Inc., an offshore driller, as Director International Marketing. Mr. Eifler originally joined
Noble in February 2005 as part of the management development program and held numerous operational and marketing roles with increasing
responsibility around the world until joining Hercules in 2013.
Scott W. Marks was named Senior Vice President – Engineering effective January 1, 2007. Mr. Marks served as Vice President – Project
Management and Construction from August 2006 to January 2007, as Vice President – Support Engineering from September 2005 to August 2006
and as Director of Engineering from January 2003 to September 2005. Mr. Marks has been with Noble since 1991, serving as a Project Manager
and as a Drilling Superintendent prior to 2003.
Laura D. Campbell was named Vice President and Controller effective August 1, 2018. Ms. Campbell is also the Company's Principal
Accounting Officer. Prior to joining Noble, Ms. Campbell served as Assistant Controller, Policy and Corporate Reporting at Chevron Phillips
109
Chemical Company LLC, a petrochemical company, from March 2017 until July 2018. Prior to that time, Ms. Campbell worked at the Company
from 2007 to March 2017, serving in the positions of Assistant Controller and Director of Corporate Accounting.
We have adopted a Code of Business Conduct and Ethics that applies to directors, officers and employees, including our principal executive
officer, principal financial officer and principal accounting officer. Our Code of Business Conduct and Ethics is posted on our website at http://
www.noblecorp.com in the “Governance” area. Changes to and waivers granted with respect to our Code of Business Conduct and Ethics related
to the officers identified above, and our other executive officers and directors, that we are required to disclose pursuant to applicable rules and
regulations of the SEC will also be posted on our website.
Item 11. Executive Compensation.
The sections entitled “2018 Compensation Information,” “Compensation Discussion and Analysis” and “Compensation Committee Report”
appearing in the 2019 Proxy Statement set forth certain information with respect to the compensation of our management and our compensation
committee report, and are incorporated in this report by reference.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
The sections entitled “Equity Compensation Plan Information” and “Security Ownership of Certain Beneficial Owners and Management”
appearing in the 2019 Proxy Statement set forth certain information with respect to securities authorized for issuance under equity compensation
plans and the ownership of our voting securities and equity securities, and are incorporated in this report by reference.
Item 13. Certain Relationships and Related Transactions and Director Independence.
The sections entitled “Board Independence” and “Policies and Procedures Relating to Transactions with Related Persons” appearing in the
2019 Proxy Statement set forth certain information with respect to director independence and transactions with related persons, and are incorporated
in this report by reference.
Item 14. Principal Accounting Fees and Services.
The section entitled “Auditors” appearing in the 2019 Proxy Statement sets forth certain information with respect to accounting fees and
services, and is incorporated in this report by reference.
PART IV
Item 15. Exhibits, Financial Statement Schedules.
(a)
The following documents are filed as part of this report:
(1)
(2)
(3)
A list of the financial statements filed as a part of this report is set forth in Item 8 on page 47 and is incorporated
herein by reference.
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.
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.
110
Exhibit
Number
Exhibit
Index to Exhibits
2.1
2.2
2.3
3.1
3.2
4.1
4.2
4.3
4.4
4.5
Merger Agreement, dated as of June 30, 2013, between Noble Corporation, a Swiss corporation (“Noble-Swiss”) and Noble
Corporation Limited (filed as Exhibit 2.1 to Noble-Swiss’ Current Report on Form 8-K filed on July 1, 2013 and incorporated
herein by reference).
Agreement and Plan of Merger, Reorganization and Consolidation, dated as of December 19, 2008, among Noble Corporation,
a Swiss corporation, Noble Corporation, a Cayman Islands company (“Noble-Cayman”), and Noble Cayman Acquisition Ltd.
(filed as Exhibit 1.1 to Noble-Cayman’s Current Report on Form 8-K filed on December 22, 2008 and incorporated herein
by reference).
Amendment No. 1 to Agreement and Plan of Merger, Reorganization and Consolidation, dated as of February 4, 2009, among
Noble-Swiss, Noble-Cayman and Noble Cayman Acquisition Ltd. (filed as Exhibit 2.2 to Noble-Cayman’s Current Report
on Form 8-K filed on February 4, 2009 and incorporated herein by reference).
Composite Copy of Articles of Association of Noble Corporation plc, a company incorporated under the laws of England and
Wales (“Noble-UK”), as of June 10, 2014 (filed as Exhibit 3.1 to Noble-UK’s Quarterly Report on Form 10-Q for the quarter
ended March 30, 2014 and incorporated herein by reference).
Memorandum and Articles of Association of Noble-Cayman (filed as Exhibit 3.1 to Noble-Cayman’s Current Report on Form
8-K filed on March 30, 2009 and incorporated herein by reference).
Indenture, dated as of March 1, 1999, between Noble Drilling Corporation, as Issuer, and JPMorgan Chase Bank, N.A.
(formerly Chase Bank of Texas, N.A.), as Trustee (filed as Exhibit 4.1 to Noble Drilling Corporation’s Current Report on
Form 8-K filed on March 23, 1999 and incorporated herein by reference).
First Supplemental Indenture, dated as of March 16, 1999, between Noble Drilling Corporation, as Issuer, and JPMorgan
Chase Bank, N.A. (formerly Chase Bank of Texas, N.A.), as Trustee, relating to 7.50% Senior Notes due 2019 of Noble
Drilling Corporation (filed as Exhibit 4.2 to Noble Drilling Corporation’s Current Report on Form 8-K filed on March 23,
1999 and incorporated herein by reference).
Second Supplemental Indenture, dated as of April 30, 2002, between Noble Drilling Corporation, as Issuer, Noble Holding
(U.S.) Corporation, as Guarantor, and Noble-Cayman, as Guarantor, and JPMorgan Chase Bank, N.A., as Trustee, relating
to 7.50% Senior Notes due 2019 of Noble Drilling Corporation (filed as Exhibit 4.6 to Noble-Cayman’s Quarterly Report
on Form 10-Q for the quarter ended March 31, 2002 and incorporated herein by reference).
Third Supplemental Indenture, dated as of December 20, 2005, between Noble Drilling Corporation, as Issuer, Noble
Drilling Holding LLC, as Co-Issuer, Noble Holding (U.S.) Corporation, as Guarantor, Noble-Cayman, as Guarantor, and
JPMorgan Chase Bank, N.A., as Trustee, relating to 7.50% Senior Notes due 2019 of Noble Drilling Corporation (filed as
Exhibit 4.14 to Noble-Cayman’s Registration Statement on Form S-3 (No. 333-131885) and incorporated herein by
reference).
Fourth Supplemental Indenture, dated as of September 25, 2009, among Noble Drilling Corporation, as Issuer, Noble
Drilling Holding LLC, as Co-Issuer, Noble Drilling Services 1 LLC, as Co-Issuer, Noble Holding (U.S.) Corporation, as
Guarantor, Noble-Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to
7.50% Senior Notes due 2019 of Noble Drilling Corporation (filed as Exhibit 4.1 to Noble-Swiss’ Current Report on Form
8-K filed on October 1, 2009 and incorporated herein by reference).
111
Exhibit
Number
4.6
4.7
4.8
4.9
4.10
4.11
4.12
4.13
Exhibit
Fifth Supplemental Indenture, dated as of October 1, 2009, among Noble Drilling Corporation, as Issuer, Noble Drilling
Holding LLC, as Co-Issuer, Noble Drilling Services 6 LLC, as Co-Issuer, Noble Holding (U.S.) Corporation, as Guarantor,
Noble-Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 7.50%
Senior Notes due 2019 of Noble Drilling Corporation (filed as Exhibit 4.2 to Noble-Swiss’ Current Report on Form 8-K
filed on October 1, 2009 and incorporated herein by reference).
Sixth Supplemental Indenture, dated as of May 7, 2014, among Noble Drilling Corporation, as Issuer, Noble Holding
(U.S.) Corporation, as Successor Issuer, Noble Drilling Services 6 LLC, as Co-Issuer, Noble Drilling Holding LLC, as Co-
Issuer, Noble-Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to
7.50% Senior Notes due 2019 of Noble Holding (U.S.) Corporation (filed as Exhibit 4.1 to Noble-UK’s Current Report on
Form 8-K filed on May 7, 2014 and incorporated herein by reference).
Seventh Supplemental Indenture, dated as of March 8, 2017, among Noble Holding (U.S.) LLC, as Successor Issuer, Noble
Drilling Services 6 LLC, as Co-Issuer, Noble Drilling Holding LLC, as Co-Issuer, Noble-Cayman, as Guarantor, and The
Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 7.50% Senior Notes due 2019 of Noble Holding
(U.S.) LLC (filed as Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K/A filed on March 14, 2017 and incorporated
herein by reference).
Eighth Supplemental Indenture, dated as of January 31, 2018, among Noble Holding (U.S.) LLC, as Successor Issuer,
Noble Drilling Services 6 LLC, as Co-Issuer, Noble Drilling Holding LLC, as Co-Issuer, Noble-Cayman, as Guarantor,
and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 7.50% Senior Notes due 2019 of Noble
Holding (U.S.) LLC (filed as Exhibit 4.4 to Noble-UK’s Current Report on Form 8-K filed on January 31, 2018 and
incorporated herein by reference).
Indenture, dated as of November 21, 2008, between Noble Holding International Limited, as Issuer, and The Bank of New
York Mellon Trust Company, N.A., as Trustee (filed as Exhibit 4.1 to Noble-Cayman’s Current Report on Form 8-K filed
on November 21, 2008 and incorporated herein by reference).
First Supplemental Indenture, dated as of November 21, 2008, among Noble Holding International Limited, as Issuer,
Noble-Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 7.375%
Senior Notes due 2014 of Noble Holding International Limited (filed as Exhibit 4.2 to Noble-Cayman’s Current Report on
Form 8-K filed on November 21, 2008 and incorporated herein by reference).
Second Supplemental Indenture, dated as of July 26, 2010, among Noble Holding International Limited, as Issuer, Noble-
Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 3.45% Senior
Notes due 2015 of Noble Holding International Limited, 4.90% Senior Notes due 2020 of Noble Holding International
Limited, and 6.20% Senior Notes due 2040 of Noble Holding International Limited (filed as Exhibit 4.2 to Noble-
Cayman’s Current Report on Form 8-K filed on July 26, 2010 and incorporated herein by reference).
Third Supplemental Indenture, dated as of February 3, 2011, among Noble Holding International Limited, as Issuer, Noble-
Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 3.05% Senior
Notes due 2016 of Noble Holding International Limited, 4.625% Senior Notes due 2021 of Noble Holding International
Limited, and 6.05% Senior Notes due 2041 of Noble Holding International Limited (filed as Exhibit 4.2 to Noble-
Cayman’s Current Report on Form 8-K filed on February 3, 2011 and incorporated herein by reference).
112
Exhibit
Number
4.14
4.15
4.16
4.17
4.18
4.19
4.20
Exhibit
Fourth Supplemental Indenture, dated as of February 10, 2012, among Noble Holding International Limited, as Issuer,
Noble-Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 2.50%
Senior Notes due 2017 of Noble Holding International Limited, 3.95% Senior Notes due 2022 of Noble Holding
International Limited, and 5.25% Senior Notes due 2042 of Noble Holding International Limited (filed as Exhibit 4.2 to
Noble-Cayman’s Current Report on Form 8-K filed on February 13, 2012 and incorporated herein by reference).
Fifth Supplemental Indenture, dated as of January 31, 2018, among Noble Holding International Limited, as Issuer, Noble-
Cayman, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 4.90% Senior
Notes due 2020 of Noble Holding International Limited, 4.625% Senior Notes due 2021 of Noble Holding International
Limited, and 3.95% Senior Notes due 2022 of Noble Holding International Limited (filed as Exhibit 4.5 to Noble-UK’s
Current Report on Form 8-K filed on January 31, 2018 and incorporated herein by reference).
Revolving Credit Agreement, dated as of January 26, 2015, among Noble-Cayman and Noble International Finance
Company, a Cayman Islands company, as borrowers; JPMorgan Chase Bank, N.A., as administrative agent and a swingline
lender; Wells Fargo Bank, N.A., as a swingline lender; the lenders party thereto; Barclays Bank PLC, Citibank, N.A., DNB
Bank ASA New York Branch, HSBC Bank USA, N.A., SunTrust Bank and Wells Fargo Bank, N.A., as co-syndication
agents; BNP Paribas, Credit Suisse AG, Cayman Islands Branch and Mizuho Bank, Ltd, as co-documentation agents; and
J.P. Morgan Securities LLC, Barclays Bank PLC, Citigroup Global Markets Inc., DNB Markets, Inc., HSBC Securities
(USA) Inc., SunTrust Robinson Humphrey, Inc. and Wells Fargo Securities, LLC, as joint lead arrangers and joint lead
bookrunners (filed as Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K filed on January 29, 2015 and incorporated
herein by reference).
First Amendment and Consent to Revolving Credit Agreement and Successor Agent Agreement, dated as of December 19,
2017, among Noble-Cayman and Noble International Finance Company, as borrowers; JPMorgan Chase Bank, N.A., as
administrative agent and a swingline lender; Wilmington Trust, National Association, as successor administrative agent;
the lenders party thereto; and the other parties party thereto (filed as Exhibit 4.2 to Noble-UK’s Current Report on Form 8-
K filed on December 22, 2017 and incorporated herein by reference).
Indenture, dated as of March 16, 2015, between Noble Holding International Limited, as Issuer, and Wells Fargo Bank,
N.A., as Trustee (filed as Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K filed on March 16, 2015 and
incorporated herein by reference).
First Supplemental Indenture, dated as of March 16, 2015, among Noble Holding International Limited, as Issuer, Noble-
Cayman, as Guarantor, and Wells Fargo Bank, N.A., as Trustee, relating to 4.000% Senior Notes due 2018 of Noble
Holding International Limited, 5.950% Senior Notes due 2025 of Noble Holding International Limited, and 6.950% Senior
Notes due 2045 of Noble Holding International Limited (filed as Exhibit 4.2 to Noble-UK’s Current Report on Form 8-K
filed on March 16, 2015 and incorporated herein by reference).
Second Supplemental Indenture, dated as of December 28, 2016, among Noble Holding International Limited, as Issuer,
Noble-Cayman, as Guarantor, and Wells Fargo Bank, N.A., as Trustee, relating to 7.750% Senior Notes due 2024 of Noble
Holding International Limited (filed as Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K filed on December 28,
2016 and incorporated herein by reference).
113
Exhibit
Number
4.21
Exhibit
Revolving Credit Agreement, dated as of December 21, 2017, among Noble Cayman Limited and Noble International
Finance Company, as borrowers, Noble Holding UK Limited, as parent guarantor; the subsidiary guarantors from time to
time party thereto; JPMorgan Chase Bank, N.A., as administrative agent, a swingline lender, lead arranger and lead
bookrunner; Wells Fargo Bank, N.A., as a swingline lender; the lenders party thereto; SunTrust Bank, Wells Fargo Bank,
N.A., Citibank, N.A., HSBC Bank USA, N.A., Barclays Bank PLC and DNB Bank ASA New York Branch, as co-
syndication agents; and Credit Suisse AG, Cayman Islands Branch and BNP Paribas, as co-documentation agents (filed as
Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K filed on December 22, 2017 and incorporated herein by reference).
Indenture, dated as of January 31, 2018, among Noble Holding International Limited, as Issuer, Noble-Cayman, as Parent
Guarantor, the Subsidiary Guarantors (as defined therein) and Wells Fargo Bank, N.A., as Trustee, relating to 7.875%
Senior Guaranteed Notes due 2026 of Noble Holding International Limited (filed as Exhibit 4.1 to Noble-UK’s Current
Report on Form 8-K filed on January 31, 2018 and incorporated herein by reference).
Noble Drilling Corporation Equity Compensation Plan for Non-Employee Directors (filed as Exhibit 4.1 to Noble Drilling
Corporation’s Registration Statement on Form S-8 (No. 333-17407) dated December 6, 1996 and incorporated herein by
reference)
Amendment to the Noble Drilling Corporation Equity Compensation Plan for Non-Employee Directors, effective as of
May 1, 2002 (filed as Exhibit 10.1 to Post-Effective Amendment No. 1 to Noble-Cayman’s Registration Statement on
Form S-8 (No. 333-17407) and incorporated herein by reference).
Amendment No. 2 to the Noble Corporation Equity Compensation Plan for Non-Employee Directors, dated February 4,
2005 (filed as Exhibit 10.20 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2004 and
incorporated herein by reference).
Amendment to the Noble Corporation Equity Compensation Plan for Non-Employee Directors, dated December 31, 2008
(filed as Exhibit 10.29 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2008 and
incorporated herein by reference).
Amended and Restated Noble Corporation Equity Compensation Plan for Non-Employee Directors, effective March 27,
2009 (filed as Exhibit 10.5 to Noble-Swiss’ Annual Report on Form 10-K for the year ended December 31, 2010 and
incorporated herein by reference).
Noble Corporation Equity Compensation Plan for Non-Employee Directors, effective as of November 20, 2013 (filed as
Exhibit 10.7 to Noble-UK’s Current Report on Form 8-K filed on November 20, 2013 and incorporated herein by
reference).
Noble Drilling Corporation 401(k) Savings Restoration Plan (filed as Exhibit 10.1 to Noble Drilling Corporation’s
Registration Statement on Form S-8 dated January 18, 2001 (No. 333-53912) and incorporated herein by reference)
Amendment No. 1 to the Noble Drilling Corporation 401(k) Savings Restoration Plan (filed as Exhibit 10.1 to Post-
Effective Amendment No. 1 to Noble-Cayman’s Registration Statement on Form S-8 (No. 333-53912) and incorporated
herein by reference).
Amendment No. 2 to the Noble Drilling Corporation 401(k) Savings Restoration Plan, dated February 25, 2003 (filed as
Exhibit 10.30 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2005 and incorporated
herein by reference).
114
4.22
10.1*
10.2*
10.3*
10.4*
10.5*
10.6*
10.7*
10.8*
10.9*
Exhibit
Number
10.10*
10.11*
10.12*
10.13*
10.14*
10.15*
10.16*
10.17*
10.18*
10.19*
10.20*
10.21*
10.22*
Exhibit
Amendment No. 3 to the Noble Drilling Corporation 401(k) Savings Restoration Plan, dated March 9, 2005 (filed as
Exhibit 10.31 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2005 and incorporated
herein by reference).
Amendment No. 4 to the Noble Drilling Corporation 401(k) Savings Restoration Plan, dated March 30, 2007 (filed as
Exhibit 10.41 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2007 and incorporated
herein by reference).
Amendment No. 5 to the Noble Drilling Corporation 401(k) Savings Restoration Plan, effective May 1, 2010 (filed as
Exhibit 10.11 to Noble-Swiss’ Annual Report on Form 10-K for the year ended December 31, 2010 and incorporated
herein by reference).
Noble Drilling Corporation Retirement Restoration Plan, dated April 27, 1995 (filed as Exhibit 10.2 to Noble Drilling
Corporation’s Quarterly Report on Form 10-Q for the quarter ended March 31, 1995 and incorporated herein by reference).
Amendment No. 1 to the Noble Drilling Corporation Retirement Restoration Plan, dated January 29, 1998 (filed as Exhibit
10.18 to Noble Drilling Corporation’s Annual Report on Form 10-K for the year ended December 31, 1997 and
incorporated herein by reference).
Amendment No. 2 to the Noble Drilling Corporation Retirement Restoration Plan dated June 28, 2004, effective as of July
1, 2004 (filed as Exhibit 10.32 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2005
and incorporated herein by reference).
Noble Drilling Corporation Retirement Restoration Plan dated December 29, 2008, effective as of January 1, 2009 (filed as
Exhibit 10.32 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2008 and incorporated
herein by reference).
Amendment No. 1 to the Noble Drilling Corporation Retirement Restoration Plan, dated July 10, 2009 (filed as Exhibit
10.16 to Noble-Swiss’ Annual Report on Form 10-K for the year ended December 31, 2010 and incorporated herein by
reference).
Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Restricted Share Plan for Non-Employee
Directors, dated February 4, 2005 (filed as Exhibit 10.21 to Noble-Cayman’s Annual Report on Form 10-K for the year
ended December 31, 2004 and incorporated herein by reference).
Second Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Share Plan for Non-Employee
Directors, dated as of October 25, 2007 (filed as Exhibit 10.2 to Noble-Cayman’s Quarterly Report on Form 10-Q for the
quarter ended September 30, 2007 and incorporated herein by reference).
Amendment to the Second Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Share Plan for
Non-Employee Directors, dated December 31, 2008 (filed as Exhibit 10.28 to Noble-Cayman’s Annual Report on Form
10-K for the year ended December 31, 2008 and incorporated herein by reference).
Third Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Share Plan for Non-Employee
Directors, effective March 27, 2009 (filed as Exhibit 10.20 to Noble-Cayman’s Annual Report on Form 10-K for the year
ended December 31, 2010 and incorporated herein by reference).
Fourth Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Share Plan for Non-Employee
Directors, effective February 1, 2013 (filed as Exhibit 10.1 to Noble-Swiss’ Current Report on Form 8-K filed on February
5, 2013 and incorporated herein by reference).
115
Exhibit
Number
Exhibit
10.23*
10.24*
10.25*
10.26*
10.27*
10.28*
10.29*
10.30*
10.31*
10.32*
10.33*
10.34*
Fifth Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Share Plan for Non-Employee
Directors, effective as of November 20, 2013 (filed as Exhibit 10.6 to Noble-UK’s Current Report on Form 8-K filed on
November 20, 2013 and incorporated herein by reference).
Sixth Amended and Restated Noble Corporation 1992 Nonqualified Stock Option and Share Plan for Non-Employee
Directors, effective as of January 30, 2014 (filed as Exhibit 10.24 to Noble-UK’s Annual Report on Form 10-K for the year
ended December 31, 2013 and incorporated herein by reference).
Composite Copy of the Noble Corporation 1991 Stock Option and Restricted Stock Plan, dated as of February 6, 2010
(filed as Exhibit 10.18 to Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2009 and
incorporated herein by reference).
Third Amendment to the Noble Corporation 1991 Stock Option and Restricted Stock Plan, effective as of February 3, 2012
(filed as Exhibit 10.2 to Noble-Swiss’ Current Report on Form 8-K filed on February 7, 2012 and incorporated herein by
reference).
Amended and Restated Noble Corporation 1991 Stock Option and Restricted Stock Plan, effective as of April 27, 2012
(filed as Exhibit 10.2 to Noble-Swiss’ Current Report on Form 8-K filed on April 30, 2012 and incorporated herein by
reference).
Noble Corporation 1991 Stock Option and Restricted Stock Plan, effective as of November 20, 2013 (filed as Exhibit 10.5
to Noble-UK’s Current Report on Form 8-K filed on November 20, 2013 and incorporated herein by reference).
Noble Corporation 1991 Stock Option and Restricted Stock Plan, effective as of January 30, 2014 (filed as Exhibit 10.29 to
Noble-UK’s Annual Report on Form 10-K for the year ended December 31, 2013 and incorporated herein by reference).
Noble Drilling Corporation 2009 401(k) Savings Restoration Plan, effective January 1, 2009 (filed as Exhibit 10.31 to
Noble-Cayman’s Annual Report on Form 10-K for the year ended December 31, 2008 and incorporated herein by
reference).
Amendment No. 1 to the Noble Drilling Corporation 2009 401(k) Savings Restoration Plan, effective May 1, 2010 (filed as
Exhibit 10.23 to Noble-Swiss’ Annual Report on Form 10-K for the year ended December 31, 2010 and incorporated
herein by reference).
Amendment No. 2 to the Noble Drilling Corporation 2009 401(k) Savings Restoration Plan, effective November 1, 2013
(filed as Exhibit 10.32 to Noble-UK’s Annual Report on Form 10-K for the year ended December 31, 2013 and
incorporated herein by reference).
Noble Corporation Summary of Directors’ Compensation (filed as Exhibit 10.33 to Noble UK's Annual Report on Form
10-K for the year ended December 31, 2017 and incorporated herein by reference).
Form of Noble Corporation Performance-Vested Restricted Stock Unit Agreement under the Noble Corporation 1991
Stock Option and Restricted Stock Plan (filed as Exhibit 10.2 to Noble-Cayman’s Quarterly Report on Form 10-Q for the
quarter ended March 31, 2011 and incorporated herein by reference).
116
Exhibit
Number
10.35*
10.36*
10.37*
10.38*
10.39*
10.40*
10.41*
10.42*
10.43*
10.44*
10.45*
10.46*
10.47*
Exhibit
Form of Noble Corporation Time-Vested Restricted Stock Unit Agreement under the Noble Corporation 1991 Stock
Option and Restricted Stock Plan (filed as Exhibit 10.2 to Noble-Swiss’ Current Report on Form 8-K filed on January 13,
2012 and incorporated herein by reference).
Form of Noble Corporation Nonqualified Stock Option Agreement under the Noble Corporation 1991 Stock Option and
Restricted Stock Plan (filed as Exhibit 10.3 to Noble-Swiss’ Current Report on Form 8-K filed on January 13, 2012 and
incorporated herein by reference).
Form of Noble Corporation Performance-Vested Restricted Stock Unit Agreement under the Noble Corporation 1991
Stock Option and Restricted Stock Plan (filed as Exhibit 10.7 to Noble-Cayman’s Quarterly Report on Form 10-Q for the
quarter ended March 31, 2012 and incorporated herein by reference).
Form of Noble Corporation Performance-Vested Restricted Stock Unit Agreement under the Noble Corporation 1991
Stock Option and Restricted Stock Plan (filed as Exhibit 10.39 to Noble-Swiss’ Annual Report on Form 10-K for the year
ended December 31, 2012 and incorporated herein by reference).
Form of Noble Corporation Performance-Vested Restricted Stock Unit Award under the Noble Corporation 1991 Stock
Option and Restricted Stock Plan (filed as Exhibit 10.39 to Noble-UK’s Annual Report on Form 10-K for the year ended
December 31, 2013 and incorporated herein by reference).
Form of Noble Corporation Time-Vested Restricted Stock Unit Award under the Noble Corporation 1991 Stock Option and
Restricted Stock Plan (filed as Exhibit 10.40 to Noble-UK’s Annual Report on Form 10-K for the year ended December
31, 2013 and incorporated herein by reference).
Amended and Restated Form of Noble-UK 2013 Performance-Vested Restricted Stock Unit Award under the Noble-UK
1991 Stock Option and Restricted Stock Plan (filed as Exhibit 10.1 to Noble-UK’s Current Report on Form 8-K for the
year filed on October 16, 2014 and incorporated herein by reference).
Amended and Restated Form of Noble-UK 2014 Performance-Vested Restricted Stock Unit Award under the Noble-UK
1991 Stock Option and Restricted Stock Plan (filed as Exhibit 10.2 to Noble-UK’s Current Report on Form 8-K for the
year filed on October 16, 2014 and incorporated herein by reference).
Noble Corporation 2015 Omnibus Incentive Plan, effective May 1, 2015 and most recently restated as of May 1, 2018
(filed as Exhibit 10.1 to Noble-UK’s Current Report on Form 8-K filed on May 1, 2018 and incorporated herein by
reference).
Noble Corporation plc 2017 Director Omnibus Plan, effective as of May 1, 2017 (filed as Exhibit 10.2 to Noble-UK’s
Current Report on Form 8-K filed on May 2, 2017 and incorporated herein by reference).
Form of Noble Corporation Time-Vested Restricted Stock Unit Award under the Noble Corporation 2015 Omnibus
Incentive Plan (filed as Exhibit 10.44 to Noble-UK’s Annual Report on Form 10-K for the year ended December 31, 2015
and incorporated herein by reference).
Form of Noble Corporation Performance-Vested Restricted Stock Unit Award under the Noble Corporation 2015 Omnibus
Incentive Plan (filed as Exhibit 10.45 to Noble-UK’s Annual Report on Form 10-K for the year ended December 31, 2015
and incorporated herein by reference).
Noble Corporation 2012 Short Term Incentive Plan (filed as Exhibit 10.6 to Noble-Cayman’s Quarterly Report on Form
10-Q for the quarter ended March 31, 2012 and incorporated herein by reference).
117
Exhibit
Number
Exhibit
10.48*
10.49*
10.50*
10.51*
10.52*
10.53*
10.54*
10.55*
10.56*
10.57*
10.58*
10.59*
10.60*
10.61*
10.62*
Noble Corporation 2013 Short Term Incentive Plan (filed as Exhibit 10.41 to Noble-Swiss’ Annual Report on Form 10-K
for the year ended December 31, 2012 and incorporated herein by reference).
Noble Corporation 2013 Short Term Incentive Plan, effective as of November 20, 2013 (filed as Exhibit 10.8 to Noble-
UK’s Current Report on Form 8-K filed on November 20, 2013 and incorporated herein by reference).
Noble Corporation 2014 Short-Term Incentive Plan (filed as Exhibit 10.5 to Noble-UK’s Quarterly Report on Form 10-Q
for the quarter ended September 30, 2014 and incorporated herein by reference).
Noble Corporation 2015 Short-Term Incentive Plan (filed as Exhibit 10.5 to Noble-UK’s Quarterly Report on Form 10-Q
for the quarter ended March 31, 2015 and incorporated herein by reference).
Noble Corporation 2016 Short-Term Incentive Plan (filed as Exhibit 10.51 to Noble-UK’s Annual Report on Form 10-K
for the year ended December 31, 2015 and incorporated herein by reference).
Noble Corporation 2017 Short-Term Incentive Plan (filed as Exhibit 10.52 to Noble-UK’s Annual Report on Form 10-K
for the year ended December 31, 2016 and incorporated herein by reference).
Noble Corporation 2018 Short-Term Incentive Plan (filed as Exhibit 10.4 to Noble Noble-UK's Quarterly Report on Form
10-Q for the quarter ended March 31, 2018 and incorporated herein by reference)
Form of Restated Employment Agreement and Guaranty Agreement (2009 Form) (filed as Exhibit 10.2 to Noble-UK’s
Current Report on Form 8-K filed on November 20, 2013 and incorporated herein by reference).
Form of Restated Employment Agreement and Guaranty Agreement (2011 Form) (filed as Exhibit 10.3 to Noble-UK’s
Current Report on Form 8-K filed on November 20, 2013 and incorporated herein by reference).
Form of Restated Employment Agreement and Guaranty Agreement (2012 Form) (filed as Exhibit 10.4 to Noble-UK’s
Current Report on Form 8-K filed on November 20, 2013 and incorporated herein by reference).
Form of Commercial Paper Dealer Agreement dated as of September 19, 2012 between Noble Corporation, a Cayman
Islands company, Noble Holding International Limited, a Cayman Islands company, Noble Drilling Corporation, a
Delaware corporation, and certain investment banks (filed as Exhibit 10.1 to Noble-Swiss’ Current Report on Form 8-K
filed on September 20, 2012 and incorporated herein by reference).
Form of Commercial Paper Issuing and Paying Agent Agreement dated as of September 19, 2012 between Noble
Corporation, a Cayman Islands company, and the Issuing and Paying Agent (filed as Exhibit 10.2 to Noble-Swiss’ Current
Report on Form 8-K filed on September 20, 2012 and incorporated herein by reference).
Form of Indemnity Agreement (filed as Exhibit 10.1 to Noble-UK’s Current Report on Form 8-K filed on November 20,
2013 and incorporated herein by reference).
General Release Agreement and Special Release Agreement, each dated February 27, 2016, between Noble Drilling
Services Inc. and James MacLennan (filed as Exhibit 10.5 to Noble-UK's Quarterly Report on Form 10-Q for the quarter
ended March 31, 2016 and incorporated herein by reference).
Settlement and Termination Agreement, dated as of May 10, 2016, by and among Freeport-McMoRan Inc., Freeport-
McMoRan Oil & Gas, LLC and Noble Drilling (U.S.) LLC (filed as Exhibit 10.1 to Noble-UK’s Current Report on Form
8-K filed on May 10, 2016 and incorporated herein by reference).
118
Exhibit
Number
10.63*
10.64*
10.65*
10.66*
21.1
23.1
23.2
31.1
31.2
32.1+
32.2+
Exhibit
Termination Letter, dated April 21, 2017, by and between Paragon Offshore plc and Noble-UK (filed as Exhibit 10.12 to
Noble-UK’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2017 and incorporated herein by reference).
Separation Agreement, effective on January 11, 2018, between David W. Williams, Noble-UK and Noble Drilling Services
Inc. (filed as Exhibit 10.1 to Noble-UK’s Current Report on Form 8-K filed on January 12, 2018 and incorporated herein
by reference).
Inducement Agreement, effective on January 11, 2018, by and among Julie J. Robertson, Noble-UK and Noble Drilling
Services Inc. (filed as Exhibit 10.2 to Noble-UK’s Current Report on Form 8-K filed on January 12, 2018 and incorporated
herein by reference).
Restated Employment Agreement by and between Julie J. Robertson and Noble Drilling Services Inc., executed as of
February 21, 2018 (filed as Exhibit 10.66 to Noble UK's Annual Report on Form 10-K for the year ended December 31,
2017 and incorporated herein by reference).
Subsidiaries of Noble-UK and Noble-Cayman.
Consent of PricewaterhouseCoopers LLP.
Consent of PricewaterhouseCoopers LLP.
Certification of Julie J. Robertson pursuant to the U.S. Securities Exchange Act of 1934, as amended (“Exchange Act”),
Rule 13a-14(a) or Rule 15d-14(a).
Certification of Adam C. Peakes pursuant to Exchange Act Rule 13a-14(a) or Rule 15d-14(a).
Certification of Julie J. Robertson pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
Certification of Adam C. Peakes pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-
Oxley Act of 2002.
101
Interactive Data File
______________________________________________________
*
+
Management contract or compensatory plan or arrangement.
Furnished in accordance with Item 601(b)(32)(ii) of Regulation S-K.
119
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.
SIGNATURES
Noble Corporation plc, a company registered under the laws of England and Wales
February 21, 2019
By:
/s/ Julie J. Robertson
Julie J. Robertson
Chairman, 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/Julie J. Robertson
Julie J. Robertson
Chairman, President and Chief Executive Officer
(Principal Executive Officer)
/s/ Adam C. Peakes
Adam C. Peakes
Senior Vice President and Chief Financial Officer
(Principal Financial Officer)
/s/ Laura D. Campbell
Laura D. Campbell
Vice President and Controller
(Principal Accounting Officer)
/s/ Julie H. Edwards
Julie H. Edwards
Director
/s/ Gordon T. Hall
Gordon T. Hall
Director
/s/ Roger W. Jenkins
Roger W. Jenkins
Director
/s/ Scott D. Josey
Scott D. Josey
Director
120
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
/s/ Jon A. Marshall
Jon A. Marshall
Director
/s/ Mary P. Ricciardello
Mary P. Ricciardello
Director
February 21, 2019
Date
February 21, 2019
Date
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
February 21, 2019
By:
/s/ Julie J. Robertson
Julie J. Robertson
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/ Julie J. Robertson
Julie J. Robertson
President and Chief Executive Officer
(Principal Executive Officer)
/s/ Adam C. Peakes
Adam C. Peakes
Director, Vice President and Chief Financial Officer
(Principal Financial Officer)
/s/ Laura D. Campbell
Laura D. Campbell
Vice President and Controller
(Principal Accounting Officer)
/s/ David M.J. Dujacquier
David M.J. Dujacquier
Director
/s/ Alan R. Hay
Alan R. Hay
Director
121
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
February 21, 2019
Date
Noble Corporation plc Financial Highlights
Operating Revenues
From Continuing Operations
Net Income / (Loss)
From Continuing Operations
Diluted Income / (Loss)
From Continuing Operations Per Share
2018 (1)
1,082,826
2017 (1)
1,236,915
2016 (1)
$2,302,065
2015 (1)
$3,352,252
2014 (1)
$3,232,504
Year Ended December 31,
(885,050)
(515,025)
(929,580)
511,000
(152,011)
(3.59)
(2.10)
(3.82)
2.06
(0.60)
Cash Flow from Operations (2)
171,851
416,675
1,142,740
1,764,907
1,778,627
Total Assets (3)
Total Debt (3) (4)
Total Equity
9,264,923
10,794,659
11,440,117
12,865,645
13,266,480
3,877,402
4,045,710
4,340,111
4,462,562
4,848,678
4,654,574
5,950,628
6,467,445
7,422,230
7,287,034
All numbers in thousands, except per share data
(1) Results for 2018, 2017, 2016, 2015, and 2014 include impairment charges of $802 million, $122 million, $1.5 billion, $418 million
and $745 million, respectively.
(2) Certain amounts in prior periods have been reclassified to conform to the current year presentation. In accordance with our adoption of
Accounting Standard Update No. 2016-9, excess tax benefits are now classified as an operating activity and employee taxes paid for share-based
payment arrangements are now classified as a financing activity on the Consolidated Statement of Cash Flows.
(3) Certain amounts in prior periods have been reclassified to conform to the current year presentation. In accordance with our adoption of
Accounting Standard Update No. 2015-3, unamortized debt issuance costs related to our senior notes are now shown as a direct reduction
of the carrying amount of the related debt.
(4) Consists of Long-term debt and Current maturities of long-term debt.
On the cover: Sunrise off the bow of the Noble Clyde Boudreaux, a recently reactivated
semisubmersible operating offshore Myanmar for PTTEP.
The ultra-deepwater drillship Noble Tom Madden
operating offshore Guyana for ExxonMobil.
Investor Information
Shareholders, brokers, securities analysts or portfolio managers
seeking information about Noble Corporation plc should
contact Jeff Chastain, Vice President – Investor Relations, Noble
Drilling Services Inc., by phone at 281-276-6100 or by e-mail at
jlchastain@noblecorp.com.
Forward Looking Statements
Any statements included in this 2018 Annual Report that are not
historical facts, including without limitation regarding future
market trends and results of operations are forward-looking
statements within the meaning of the applicable securities law.
Please see “Forward-Looking Statements” in this 2018 Annual
Report for more information.
Corporate Information
Transfer Agent and Registrar
Computershare Trust Company, N.A.
Canton, Massachusetts
Independent Registered Public Accounting Firm
PricewaterhouseCoopers LLP
Houston, Texas
Independent Auditors
PricewaterhouseCoopers LLP
London, UK
Shares Listed on
New York Stock Exchange
Trading Symbol “NE”
Form 10-K
A copy of Noble Corporation plc’s 2018 Annual Report on Form
10-K, as filed with the U.S. Securities and Exchange Commission,
will be furnished without charge to any shareholder upon written
request to:
William E. Turcotte
General Counsel & Corporate Secretary
Noble Corporation plc
10 Brook Street
London W1S 1BG
Annual Meeting
The Annual Meeting of Shareholders of Noble Corporation plc
will be held on April 26, 2019, at 3:00 p.m. local time at The Ritz
Hotel in London, England.
Contact the Board
If you would like to contact the Noble Corporation plc Board of
Directors, send an e-mail to nobleboard@noblecorp.com
or write to:
Noble Corporation plc
Board of Directors
10 Brook Street
London W1S 1BG
For additional information about Noble Corporation plc, please
refer to our proxy statement which is being mailed or made
available with this Annual Report.
Board of Directors
Julie H. Edwards 2, 3, 4
Former Senior Vice President & Chief Financial Officer
Southern Union Company
Director since 2006.
Gordon T. Hall 2, 3, 4, 6
Chairman of the Board
Archrock, Inc.
Director since 2009.
Roger W. Jenkins 1, 5
President and Chief Executive Officer
Murphy Oil Corporation
Director since 2018.
Scott D. Josey 1, 5
Chairman & Chief Executive Officer
Sequitur Energy Resources, LLC
Director since 2014.
Jon A. Marshall 2, 3, 5
Former President & Chief Operating Officer
Transocean Inc.
Director since 2009.
Mary P. Ricciardello 1, 4
Former Senior Vice President & Chief Accounting Officer
Reliant Energy, Inc.
Director since 2003.
Julie J. Robertson
Chairman, President & Chief Executive Officer
Noble Corporation plc
Director since 2017.
1 Audit Committee
3 Finance Committee
5 Health, Safety, Environment and Engineering Committee
6 Lead Director
2 Compensation Committee
4 Nominating and Corporate Governance Committee
Corporate Officers
Julie J. Robertson
Chairman, President & Chief Executive Officer
Adam C. Peakes
Senior Vice President & Chief Financial Officer
William E. Turcotte
Senior Vice President, General Counsel & Corporate Secretary
Scott W. Marks
Senior Vice President – Engineering
Robert W. Eifler
Senior Vice President – Marketing & Contracts
Laura D. Campbell
Vice President and Controller
Noble Corporation plc
10 Brook Street
London W1S 1BG
www.noblecorp.com
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Noble Corporation plc
2018 Annual Report