2020 ANNUAL REPORT
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
(cid:1409)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2020
(cid:1407)
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 001-32657
NABORS INDUSTRIES LTD.
(Exact name of registrant as specified in its charter)
Bermuda
(State or Other Jurisdiction of
Incorporation or Organization)
Crown House Second Floor
4 Par-la-Ville Road
Hamilton, HM08
Bermuda
(Address of principal executive offices)
98-0363970
(I.R.S. Employer
Identification No.)
N/A
(Zip Code)
Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:
(441) 292-1510
(Registrant’s telephone number, including area code)
Title of each class
Common shares, $.05 par value per share
Preferred shares, 6.00% Mandatory Convertible Preferred Shares,
Trading Symbol(s)
NBR
NBR.PRA
Name of each exchange on which registered
New York Stock Exchange
Series A, $.001 par value per share
New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Securities Exchange Act of 1934: None.
Indicate by check mark whether the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. YES (cid:1409) NO (cid:1407)
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 (cid:1407) NO (cid:1409)
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934
during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for
the past 90 days. YES (cid:1409) NO (cid:1407)
d
Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to file such reports). YES (cid:1409) NO (cid:1407)
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of
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. (cid:1409)
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See
definition of “large accelerated filer”, “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer (cid:1407)
Accelerated Filer (cid:1409)
Non-accelerated Filer (cid:1407)
Smaller Reporting Company (cid:1407)
Emerging Growth Company (cid:1407)
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
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revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. (cid:1407)
Indicate by check mark whether the Registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control
over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit
report. (cid:1409)
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES (cid:1407) NO (cid:1409)
The aggregate market value of the 6,880,196 common shares held by non-affiliates of the registrant outstanding as of the last b
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usiness day of our most
recently completed second fiscal quarter, June 30, 2020, based on the closing price of our common shares as of such date of $37.02 per share as reported on the New
York Stock Exchange, was $254,704,856. Common shares held by each officer and director and by each pe
shares have been excluded in that such persons may be deemed affiliates. This determination of affiliate status is not necessarily a conclusive determination for other
purposes.
rson who owns 5% or more of the outstanding common
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The number of common shares outstanding as of February 19, 2021 was 7,359,588, excluding 1,090,003 common shares held by our subsidiaries, or
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8,449,591 in the aggregate.
DOCUMENTS INCORPORATED BY REFERENCE
Specified portions of the definitive Proxy
Statement to be distributed in connection with our 2021 Annual General Meeting of Shareholders (Part III).
NABORS INDUSTRIES LTD.
Form 10-K Annual Report
For the Year Ended December 31, 2020
Table of Contents
PART I
Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 1.
Item 1A. Risk Factors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 1B. Unresolved Staff Comments. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 2.
Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 3.
Mine Safety Disclosures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 4.
PART II
Item 5.
Market Price of and Dividends on the Registrant’s Common Equity, Related Shareholder
Matters and Issuer Purchases of Equity Securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Selected Financial Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 6.
Item 7.
Management’s Discussion and Analysis of Financial Condition and Results of Operations . . . . . . .
Item 7A. Quantitative and Qualitative Disclosures About Market Risk . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 8.
Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Changes in and Disagreements With Accountants on Accounting and Financial Disclosure . . . . . . .
Item 9.
Item 9A. Controls and Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 9B. Other Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
PART III
Item 10.
Item 11.
Directors, Executive Officers and Corporate Governance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Security Ownership of Certain Beneficial Owners and Management and Related Shareholder
Item 12.
Item 13.
Item 14.
Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Certain Relationships and Related Transactions and Director Independence . . . . . . . . . . . . . . . . . . . .
Principal Accounting Fees and Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Item 15.
Item 16.
Exhibits, Financial Statement Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Form 10-K Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
PART IV
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Our internet address is www.nabors.com. We make available free of charge through our website 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 Securities Exchange Act of 1934, as amended (the “Exchange
Act”), as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and
Exchange Commission (the “SEC”). Reference in this document to our website address does not constitute incorporation
by reference of the information contained on the website into this annual report on Form 10-K. The SEC maintains an
internet site (www.sec.gov) that contains reports, proxy and information statements and other information regarding
issuers that file electronically with the SEC. In addition, documents relating to our corporate governance (such as
committee charters, governance guidelines and other internal policies) can be found on our website.
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FORWARD-LOOKING STATEMENTS
We discuss expectations regarding our future markets, demand for our products and services, and our
performance in our annual, quarterly and current reports, press releases, and other written and oral statements.
Statements relating to matters that are not historical facts are ‘‘forward-looking statements’’ within the meaning of the
safe harbor provisions of Section 27A of the Securities Act and Section 21E of the Securities Exchange Act of 1934, as
amended (the ‘‘Exchange Act’’). These ‘‘forward-looking statements’’ are based on an analysis of currently available
competitive, financial and economic data and our operating plans. They are inherently uncertain and investors should
recognize that events and actual results could turn out to be significantly different from our expectations. By way of
illustration, when used in this document, words such as ‘‘anticipate,’’ ‘‘believe,’’ ‘‘expect,’’ ‘‘plan,’’ ‘‘intend,’’
‘‘estimate,’’ ‘‘project,’’ ‘‘will,’’ ‘‘should,’’ ‘‘could,’’ ‘‘may,’’ ‘‘predict’’ and similar expressions are intended to
identify forward-looking statements.
Factors to consider when evaluating these forward-looking statements include, but are not limited to:
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the novel coronavirus (“COVID-19”) pandemic and its impact on our operations as well as oil and gas
markets and prices;
fluctuations and volatility in worldwide prices of and demand for oil and natural gas;
fluctuations in levels of oil and natural gas exploration and development activities;
fluctuations in the demand for our services;
competitive and technological changes and other developments in the oil and gas and oilfield services
industries;
our ability to renew customer contracts in order to maintain competitiveness;
the existence of operating risks inherent in the oil and gas and oilfield services industries;
the possibility of the loss of one or a number of our large customers;
the impact of long-term indebtedness and other financial commitments on our financial and operating
flexibility;
our access to and the cost of capital, including the impact of a further downgrade in our credit rating,
covenant restrictions, availability under our secured revolving credit facility, and future issuances of debt
or equity securities;
our dependence on our operating subsidiaries and investments to meet our financial obligations;
our ability to retain skilled employees;
our ability to complete, and realize the expected benefits of, strategic transactions;
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changes in tax laws and the possibility of changes in other laws and regulations;
the possibility of political or economic instability, civil disturbance, war or acts of terrorism in any of the
countries in which we do business;
the possibility of changes to U.S. trade policies and regulations, including the imposition of trade
embargoes, sanctions or tariffs; and
general economic conditions, including the capital and credit markets.
Our business depends, to a large degree, on the level of spending by oil and gas companies for exploration,
development and production activities. Therefore, a sustained increase or
has a material impact on exploration, development and production activities, could also materially affect our financial
position, results of operations and cash flows.
decrease in the price of oil or natural gas, that
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The above description of risks and uncertainties is by no means all-inclusive, but highlights certain factors that
we believe are important for your consideration. For a more detailed description of risk factors, please refer to
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Part I, Item 1A.—Risk Factors.
ITEM 1. BUSINESS
PART I
Nabors Industries, Ltd. (NYSE: NBR) was formed as a Bermuda exempted company on December 11, 2001.
Unless the context requires otherwise, references in this annual report to “we,” “us,” “our,” “the Company,” or “Nabors”
mean Nabors Industries Ltd., together with our subsidiaries where the context requires. References in this annual report
to “Nabors Delaware” mean Nabors Industries, Inc., a wholly owned subsidiary of Nabors.
Overview
Tracing its origins back to 1952, Nabors has grown from a small land drilling business in Canada to one of the
world’s largest drilling contractors. Today, Nabors owns and operates one of the world’s largest land-based drilling rig
fleets and is a provider of offshore rigs in the United States and several international markets. Nabors also provides
directional drilling services, tubular running services, performance tools, and innovative technologies for its own rig
fleet and those operated by third parties. In today’s performance-driven environment, we believe we are well positioned
to seamlessly integrate downhole hardware, surface equipment and software solutions into our AC rig designs.
Leveraging our advanced drilling automation capabilities, Nabors’ highly skilled workforce continues to set new
standards for operational excellence and transform our industry.
Our business is comprised of our global land-based and offshore drilling rig operations and other rig related
services and technologies. These services include tubular running services, wellbore placement solutions, directional
drilling, measurement-while-drilling (“MWD”), logging-while-drilling (“LWD”) systems and services, equipment
manufacturing, rig instrumentation and optimization software.
Our business consists of five reportable segments: U.S. Drilling, Canada Drilling, International Drilling,
Drilling Solutions and Rig Technologies.
With operations in approximately 20 countries, we are a global provider of drilling and drilling-related services
for land-based and offshore oil and natural gas wells, with a fleet of rigs and drilling-related equipment which, as of
December 31, 2020 included:
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354 actively marketed rigs for land-based drilling operations in the United States, Canada and
approximately 14 other countries throughout the world; and
29 actively marketed rigs for offshore platform drilling operations in the United States and multiple
international markets.
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The following table presents our average rigs working (a measure of activity and utilization over the year) for
the years ended December 31, 2020, 2019 and 2018:
Year Ended December 31,
2019
2018
2020
Average Rigs Working:
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
67.9
9.0
75.7
152.6
115.3
10.9
88.3
214.5
113.2
16.9
92.9
223.0
Average rigs working represents a measure of the number of equivalent rigs operating during a given period.
For example, one rig operating 182.5 days during a 365-day period represents 0.5 average rigs working.
Additional information regarding the geographic markets in which we operate and our business segments can
be found in Note 19—Segment Information in Part II, Item 8.—Financial Statements and Supplementary Data.
U.S. Drilling
Operating one of the largest land-based drilling rig fleets in the U.S., Nabors continues to drive innovation and
integration in the industry. Nabors offers a full suite of options including performance tools and innovations developed
by our team of internal engineers who are wholly focused on advanced technologies. We maintain activities in the lower
48 states and Alaska as well as offshore in the Gulf of Mexico. Our U.S. fleet consists of 188 AC rigs and 14 SCR rigs
land rigs, which were actively marketed as of December 31, 2020.
Since our first AC land rig was built in 2002, we have continued to develop industry-leading breakthroughs. As
the industry shifted to multi-well pad drilling, we anticipated the appetite for greater efficiencies and adaptability
through batch drilling. As a result, we developed our suite of PACE® drilling rigs. In 2013, we introduced our PACE®-
X800 rig equipped with an advanced walking system with multidirectional capabilities that enable the rig to move
efficiently over existing wells on a pad. Because the ancillary equipment accompanies the rig, it moves easily between
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adjacent rows of wells. In 2016, we introduced our PACE®-M800 and PACE®-M1000 rigs which complement our
existing PACE®-X800 rigs. The PACE®-M800 rig is designed for lower-density multi-well pads whereas the PACE®-
M1000 is designed for higher density pads. Both are designed to move rapidly between pads. Featuring the same
advanced walking capabilities as the PACE®-X800 rig, the PACE®-M800 rig can quickly move efficiently on pads and
over short distances, with minimal rig-up and rig-down components.
In addition to land drilling operations throughout the lower 48 states and Alaska, we also actively marketed 12
platform rigs in the U.S. Gulf of Mexico as of December 31, 2020.
In recent years we have deployed a full suite of technology supporting Nabors and third party rigs. By seizing
the opportunity to move forward, faster, Nabors has employed automation to increase safety, instill efficient processes
and build agility for our customers. See Drilling Solutions below for more information.
Canada Drilling
The focus of the Canadian drilling market is almost exclusively on horizontal wells. To align with this market,
our Canadian rig fleet is concentrated on larger, more agile rigs. As of December 31, 2020 our rig fleet consisted of 35
land-based drilling rigs in Canada.
International Drilling
We conduct activities in major oil and gas markets, most notably including Saudi Arabia, Argentina, Colombia,
Mexico and Kazakhstan. Many of our rigs are designed to address the challenges of working in specific operating
environments, such as desert climates, mountainous regions, and tropical zones.
As of December 31, 2020, our international fleet consisted of 116 land-based drilling rigs located in
approximately 14 countries. At the same time, we actively marketed 15 platforms rigs in the international offshore
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drilling markets. In prior years, we increased the utilization of the PACE®-X800 rigs in international markets through
deployments in Latin America.
Drilling Solutions
Through Nabors Drilling Solutions, we offer specialized drilling technologies, such as patented steering
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systems and rig instrumentation software systems that enhance drilling performance and wellbore placement.
Nabors specializes in wellbore placement solutions and is a leading provider of directional drilling and MWD
systems and services. Our tools are ideal for applications where high reliability, precise wellbore placement and drilling
efficiency are crucial. Some of the Nabors Drilling Solutions products and services are listed below.
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REVit® is an automated real time stick-slip mitigation system that preserves bit cutting structure, increases
rates of penetration, and reduces unplanned trips
ROCKit® is a user friendly directional steering control system that increases performance of slide drilling,
through drill string oscillation and precise toolface control;
SmartNAV™ collaborative guidance and advisory platform that delivers automated directional drilling
information and instructions to drive consistent decision making, transparency, and improved performance;
SmartSLIDE™ is an advanced directional steering control system that automates slide drilling to
consistently deliver high performance; and
RigCLOUD® provides the tools and infrastructure to integrate applications to deliver real-time insight into
operations across the rig fleet.
Nabors’ offers a full range of tubular running services to match operators’ requirements and preferences.
Tubular running services (TRS) primarily include casing running, tubing running and torque monitoring. Managed
pressure drilling (MPD) primarily includes drives, manifolds, tanks, pumps and gas handling equipment. Our propriety
software empowers the driller to deliver these services with consistency and repeatability. Both TRS and MPD integrate
with the rig eliminating the need for third party services hence improving efficiencies and reducing cost.
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Rig Technologies
Our Rig Technologies segment is primarily comprised of Canrig, which manufactures and sells top drives,
catwalks, wrenches, drawworks and other drilling related equipment such as robotic systems and downhole tools which
are installed on both onshore and offshore drilling rigs. Rig Technologies also provides aftermarket sales and services
for the installed base of its equipment.
Our Business Strategy
Our business strategy is to build shareholder value and enhance our competitive position by:
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achieving superior operational and health, safety and environmental performance;
leveraging our existing global infrastructure and operating reputation to capitalize on growth opportunities;
continuing to develop our existing portfolio of value-added services to our customers;
enhancing our technology position and advancing drilling technology both on the rig and downhole; and
achieving financial returns in excess of our cost of capital.
During the past several years we have transformed our fleet in the Lower 48 into what we believe is the most
capable, modern fleet in the market. Our customer base recognizes the quality of our assets, the competency of our
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crews, our industry leading operational performance and the value added by our performance software and our services
integration.
We believe our drilling technology portfolio positions us well to address the changing market dynamic both in
the United States and internationally. Our technological development efforts drive toward a seamless integration of the
rig’s operations with downhole sensing. Additionally, we have added complementary services to our traditional rig
offering, in many cases replacing third-party providers of these complementary services as a single service provider.
Drilling Contracts
Our drilling contracts are typically daywork contracts. A daywork contract generally provides for a basic rate
per day when drilling (the dayrate for providing a rig and crew) and for lower rates when the rig is moving between
drilling locations, or when drilling operations are interrupted or restricted by equipment breakdowns, adverse weather
conditions or other conditions beyond our control. In addition, daywork contracts may provide for a lump-sum fee for
the mobilization and demobilization of the rig, which in most cases approximates our anticipated costs. A daywork
contract differs from a footage contract (in which the drilling contractor is paid on the basis of a rate per foot drilled) and
a turnkey contract (in which the drilling contractor is paid for drilling a well to a specified depth for a fixed price). We
also offer performance enhancing drilling services, performance software and equipment such as managed pressure
services, directional drilling, rotary steering systems and measurement while drilling. These additional products and
services are additive to our rig charges.
Our contracts for land-based and offshore drilling have durations that are single-well, multi-well or term. Term
contracts generally have durations ranging from six months to five years. Under term contracts, our rigs are committed
to one customer. Offshore workover projects are often contracted on a single-well basis.
We generally receive drilling
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contracts through competitive bidding, although we occasionally enter into contracts by direct negotiation. Most of our
single-well contracts are subject to termination by the customer on short notice, while multi-well contracts and term
contracts may provide us with early termination compensation in certain circumstances. Such payments may not fully
compensate us for the loss of a contract, and in certain circumstances the customer may not be obligated, able or willing
to make an early termination payment to us. Contract terms and rates differ depending on a variety of factors, including
competitive conditions, the geographical area, the geological formation to be drilled, the equipment and services to be
supplied, the on-site drilling conditions and the anticipated duration of the work to be performed.
Our Customers
Our customers include major international, national and independent oil and gas companies. One customer,
Saudi Aramco, accounted for approximately 29%, 22% and 24% of our consolidated operating revenues during the years
ended December 31, 2020, 2019 and 2018, respectively, which operating revenues are primarily included in the results
of our International Drilling reportable segment. Our contracts with Saudi Aramco are on a per rig basis. These contracts
are primarily operated through SANAD, our joint venture with Saudi Aramco. See Part I, Item 1A.—Risk Factors—The
loss of one or a number of our large customers could have a material adverse effect on our business, financial condition
and results of operations.
Human Capital
As of December 31, 2020, we employed approximately 10,000 employees worldwide, approximately 7,000 of
which are employed internationally. We believe we have generally good relations with all our employees worldwide.
Diversity and Inclusion
We endeavor to create an environment rich in diversity that welcomes those of all backgrounds, ethnicities and
experiences. All told, our employee base represents 72 nationalities.
Traditionally the oil and gas industry has been male dominated. By implementing strategic recruiting efforts,
employee development streams and retention practices, we have been able to achieve diversity that we believe outpaces
not just the industry, but the business world in general. Based on our most recent employee engagement survey
performed in 2020, we learned that:
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87% of women in our workforce feel supported by their manager;
73% of women of color have strong allies on their team; and
48% of new external hires were women.
By recognizing disparate voices, we foster a more cohesive, high performing and productive company.
Training and Talent Management
We are dedicated to the development and training of our worldwide employee base. Training begins at
onboarding, where employees receive job-specific instruction with a focus on safety, corporate ethics and maintaining a
safe and inclusive workplace. Ongoing training includes a focus on career development and advancement. A key focus
is the career development offered to women and employees of color.
Educational Assistance
In 2009, our former Chairman and CEO, Eugene M. Isenberg, established the Isenberg Education Fund
Scholarship Program, the purpose of which is to provide educational assistance to talented, high-achieving individuals
who demonstrate strong academic performance and dedicated community service, and who need financial aid. Aid is
available to employees and their family members, including spouses, children and grandchildren. To date, the program
has provided over $3.8 million in educational assistance to employees and their families.
Employee Recognition
Annual Innovation Awards are given to recognize exceptional innovation, ingenuity and intellectual capital
insight of our employees. Recipients have included employees in many different departments, including engineering,
information technologies, controls and automation and business development. In addition, we hold quarterly Service
Award events to recognize employment milestones met by employees.
Health, Welfare and Retirement
We provide employees health and welfare benefits standard for the industry and their location of employment.
U.S. employees and their families receive medical, dental and vision insurance, life insurance and long-term disability
plans, and health and dependent care flexible spending accounts. All U.S. full-time employees also receive a 401(k) plan
with a Company match.
Seasonality
Our operations are subject to seasonal factors. Specifically, our drilling operations in Canada and Alaska
generally experience reduced levels of activity and financial results during the second quarter of each year, due to the
annual spring thaw. In addition, our U.S. offshore market can be impacted during summer months by tropical weather
systems in the Gulf of Mexico. Global climate change could lengthen these periods of reduced activity, but we cannot
currently estimate to what degree. Our overall financial results reflect the seasonal variations experienced in these
operations, but seasonality does not materially impact the remaining portions of our business.
Industry/Competitive Conditions
To a large degree, our businesses depend on the level of capital spending by oil and gas companies for
exploration, development and production activities. The level of exploration, development and production activities is to
a large extent tied to the prices of oil and natural gas, which can fluctuate significantly and are highly volatile. Relatedly,
customers may have difficulty accessing capital markets due to poor historical returns for their investments and due to
certain instutional investors choosing not to invest in fossil fuel industries. A decrease or prolonged decline in the price
of oil or natural gas or in the exploration, development and production activities of our customers could result in a
corresponding decline in the demand for our services and/or a reduction in dayrates and utilization, which could have a
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material adverse effect on our financial position, results of operations and cash flows. See Part I, Item 1A.—Risk
Factors— Fluctuations in oil and natural gas prices could adversely affect drilling activity and our revenues, cash flows
and profitability, and—Our drilling contracts may in certain instances be renegotiated, suspended or terminated without
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an early termination payment and Item 7.— Management’s Discussion and Analysis of Financial Condition and Results
of Operations.
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The markets in which we provide our services are highly competitive. We believe that competitive pricing is a
significant factor in determining which service provider is awarded a job in these markets and customers are increasingly
sensitive to pricing during periods of market instability. Historically, the number of available rigs and drilling-related
equipment has exceeded demand in many of the markets in which we operate, resulting in strong price competition. This
is due in part to the fact that most rigs and drilling-related equipment can be moved from one region to another in
response to changes in the levels of exploration, development and production activities and market conditions, which
may result in an oversupply of rigs and drilling-related equipment in certain areas.
Although many rigs can be moved from one region to another in response to changes in levels of activity,
competition has increased based on the supply of existing and new rigs across all our markets. Most available contracts
for our services are currently awarded on a bid basis, which further increases competition based on price.
In addition to price, other competitive factors in the markets we serve are the overall quality of service and
safety record, the technical specification and condition of equipment, the availability of skilled personnel and the ability
to offer ancillary services. Our drilling business is subject to certain additional competitive factors. For example, we
believe our ability to deliver rigs with new technology and features and, in certain international markets, our experience
operating in certain environments and strong customer relationships have been significant factors in the selection of
Nabors for the provision of drilling services. We expect that the market for our drilling services will continue to be
highly competitive. See Part I, Item 1A.—Risk Factors—
t
capacity, which may adversely affect our results of operations.
We operate in a highly competitive industry with excess drilling
t
The global market for drilling and related products and services is competitive. Certain competitors are present
in more than one of the markets in which we operate, although no one competitor operates in all such markets. Our
strategy combines advanced drilling rig designs – complete with integrated downhole tools, surface equipment, and
software – with operational performance, industry-leading safety, and an innovative technology roadmap.
Significant competitors in our U.S. Drilling segment include: Helmerich & Payne Inc., Patterson-UTI Energy
Inc., Precision Drilling Corp., and Ensign Energy Services Inc. In the U.S. Lower 48 land drilling market, we also
compete with numerous smaller or regional drilling contractors. In our International segment, significant competitors
with operations in multiple countries include KCA Deutag Drilling Limited, Saipem S.p.A, as well as many contractors
with regional or local rig operations.
Our Rig Technologies segment competes primarily with National Oilwell Varco Inc., Bentec GmbH, and
several smaller rig equipment suppliers. Our Drilling Solutions segment competes with services provided by Baker
Hughes Co., Halliburton Co., Schlumberger Ltd., Frank’s International NV, Weatherford International plc., as well as
several of our drilling competitors and smaller, specialized service providers.
Acquisitions and Divestitures
We have grown from a land drilling business centered in the U.S. Lower 48, Canada and Alaska to an
international business with operations on land and offshore in most of the major oil and gas markets in the world. This
growth was fueled in part by strategic acquisitions. While we continuously consider and review strategic opportunities,
including acquisitions, divestitures, joint ventures, alliances and other strategic transactions, there can be no assurance
that such opportunities will continue to be available, that the pricing will be economical or that we will be successful in
completing and realizing the expected benefits of such transactions in the future.
t
We may sell a subsidiary or group of assets outside of our core markets or business if it is strategically or
economically advantageous for us to do so.
In October 2018, we purchased PetroMar Technologies, a developer and operator of LWD downhole tools
focusing on high-value formation data to facilitate completion optimization particularly in unconventional reservoirs.
The tools complement our existing wellbore placement capabilities and are included in our Drilling Solutions operating
segment. Under the terms of the transaction, we paid an initial purchase price of $25.0 million. We may also be required
to make future payments that are contingent upon the future financial performance of this operation.
9
Environmental Compliance
Sustainability is an essential part of the corporate culture at Nabors and an integral part of our strategic plans.
We know that our success is directly linked to implementing and executing a broad range of sustainable practices.
Through technological innovation, environmental impact planning, corporate safety initiatives and community
relations activities, Nabors understands that how we conduct business is of equal importance to our results. Corporate
responsibility guides every aspect of our daily activities and is the key to our continued success.
We do not anticipate that compliance with currently applicable environmental rules and regulations and controls
will significantly change our competitive position, capital spending or earnings during 2021. We believe we are in
material compliance with applicable environmental rules and regulations and that the cost of such compliance is not
material to our business or financial condition. For a more detailed description of the environmental rules and
regulations applicable to our operations, see Part I, Item 1A.—Risk Factors—Changes to or noncompliance with laws
and regulations or exposure to environmental liabilities could adversely affect our results of operations.
ITEM 1A. RISK FACTORS
In addition to the other information set forth elsewhere in this annual report, the following factors should be
n
carefully considered when evaluating Nabors. The risks described below are not the only ones we face. Additional risks
not presently known to us or that we currently deem immaterial may also impair our business operations.
Risk Factors Summary
The following is a summary of the principal risks included in this annual report that we believe could adversely affect
our business, operations, and financial results.
Business and Operational Risks
•
Fluctuations in oil and natural gas prices could adversely affect drilling activity and our revenues, cash
flows and profitability.
• Our customers and thereby our business and profitability could be adversely affected by low oil prices
and/or turmoil in the global economy.
• We operate in a highly competitive industry with excess drilling capacity, which may adversely affect our
results of operations.
• We must renew customer contracts to remain competitive.
•
The nature of our operations presents inherent risks of loss, including weather-related risks, that could
adversely affect our results of operations.
• Our drilling contracts may in certain instances be renegotiated, suspended or terminated without an early
•
•
termination payment.
The loss of one or a number of our large customers could have a material adverse effect on our business,
financial condition and results of operations.
The profitability of our operations could be adversely affected by war, civil disturbance, terrorist activity or
other political or economic instability, fluctuation in currency exchange rates and local import and export
uu
controls.
ff
• We rely on third-party suppliers, manufacturers and service providers to secure equipment, components
and parts used in rig operations, conversions, upgrades and construction.
• Our contracts with national oil companies may expose us to greater risks than we normally assume in
•
contracts with non-governmental customers.
Control of oil and natural gas reserves by state-owned oil companies may impact the demand for our
services and products and create additional risks in our operations.
• Our operating expense includes fixed costs that may not decline in proportion to decreases in rig utilization
and dayrates.
• Actions of and disputes with our joint venture partners could have a material adverse effect on the business
and results of operations of our joint ventures and, in turn, our business and consolidated results of
operations.
10
•
Failure to realize the anticipated benefits of acquisitions, divestitures, investments, joint ventures and other
strategic transactions may adversely affect our business, results of operations and financial position.
• Decisions by internet service, cloud hosting service and related providers to restrict or ban our ability to use
their platforms could adversely affect our ability to promote and conduct our business and inform investors.
Financial Risks
• We may record additional losses or impairment charges related to sold or idle drilling rigs and other assets.
• Our financial and operating flexibility could be affected by our long-term debt and other financial
commitments.
• Our ability to access capital markets could be limited.
Technology Risks
•
• New technologies may cause our drilling methods and equipment to become less competitive and it may
become necessary to incur higher levels of operating and capital expenditures in order to keep pace with
the disruptive trends in the drilling industry. Growth through the building of new drilling rigs and
improvement of existing rigs is not assured.
Limitations on our ability to obtain, maintain, protect or enforce our intellectual property rights, including
our trade secrets, could cause a loss in revenue and any competitive advantage we hold.
Technology disputes could negatively impact our operations or increase our costs.
Improvements in or new discoveries of alternative energy technologies could have a material adverse effect
on our financial condition and results of operations.
•
•
Legal and Regulatory Risks
•
•
•
•
•
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Changes to United States tax, tariff and import/export regulations may have a negative effect on global
economic conditions, financial markets and our business.
The Company’s ability to use its net operating loss carryforwards, and possibly other tax attributes, to
offset future taxable income for U.S. federal income tax purposes may be significantly limited due to
various circumstances, including future transactions involving the sale or issuance of Company equity
securities, or if taxable income does not reach sufficient levels.
Changes to or noncompliance with laws and regulations or exposure to environmental liabilities could
adversely affect our results of operations.
The physical effects of climate change and the regulation of greenhouse
could have a negative impact on our business.
Legal proceedings and governmental investigations could affect our financial condition and results of
operations.
aa
gas emissions and climate change
Share Capital and Corporate Structure Risks
Significant issuances of common shares could adversely affect the market price of our common shares.
•
• Our common share price has been and may continue to be volatile.
•
Provisions in our organizational documents may be insufficient to thwart a coercive hostile takeover
attempt; conversely, these provisions and those in our outstanding debt and Saudi joint venture documents
may deter a change of control transaction and decrease the likelihood of a shareholder receiving a change
of control premium.
• As a holding company, we depend on our operating subsidiaries and investments to meet our financial
obligations.
11
General Risks
• Our business, results of operations and financial condition have been and may continue to be adversely
impacted by global public health epidemics, including the strain of coronavirus known as COVID-19, and
future adverse impacts could be material and difficult to predict.
• Our business is subject to cybersecurity risks.
•
The loss of key executives or inability to attract and retain experienced technical personnel could reduce
our competitiveness and harm prospects for future success.
• A downgrade in our credit rating could negatively impact our cost of and ability to access capital markets
•
or other financing sources.
Changes in the method of determining London Interbank Offered Rate ("LIBOR"), or the replacement of
LIBOR with an alternative reference rate, may adversely affect interest expense related to outstanding debt.
• We may be subject to changes in tax laws and have additional tax liabilities.
• Our international operations expose us to compliance obligations and risks under the Foreign Corrupt
Practices Act and other applicable anti-corruption laws, and violations of these laws could have a negative
impact on our business.
For a more complete discussion of the risks facing our business, see below.
Business and Operational Risks
Fluctuations in oil and natural gas prices could adversely affect drilling activity and our revenues, cash flows and
profitability.
Our operations, demand for our services, and the rates we are able to charge for such services depend on the
level of spending by oil and gas companies for exploration, development and production activities. Both short-term and
long-term trends in oil and natural gas prices affect these activity levels. Oil and natural gas prices, as well as the level of
drilling, exploration and production activity, have been highly volatile for several years and are expected to continue to
be volatile for the foreseeable future. In addition to the COVID-19 outbreak contributing to a significant decline in oil
prices, declines in oil prices are primarily caused by, among other things, an excess of supply of crude oil in relation to
demand. Worldwide military, political, public health, and economic events, including initiatives by the Organization of
Petroleum Exporting Countries (“OPEC”) and OPEC+, uncertainty in capital and commodities markets and the ability of
oil and natural gas producers to access capital, and the extent to which they are willing or able to deploy capital, affect
both the supply of and demand for oil and natural gas. In addition, weather conditions, governmental regulation (both in
the United States and elsewhere), levels of consumer demand for oil and natural gas, general and global economic
conditions, oil and gas production levels by non-OPEC countries, decisions by oil and gas producers to continue
producing oil and gas despite excess supply, the availability and demand for drilling equipment and pipeline capacity,
availability and pricing of alternative energy sources, and other factors beyond our control may also affect the supply of
and demand for oil and natural gas, and thereby affect the price of oil and natural gas.
Lower oil and natural gas prices also could adversely impact our cash forecast models used to determine
whether the carrying values of our long-lived assets exceed our future cash flows, which could result in future
impairment to our long-lived assets. Lower oil and natural gas prices also could affect our ability to retain skilled rig
personnel and affect our ability to access capital to finance and grow our business. There can be no assurances as to the
future level of demand for our services or future conditions in the oil and natural gas and oilfield services industries.
Our customers and thereby our business and profitability could be adversely affected by low oil prices and/or turmoil
in the global economy.
aa
Changes in general economic and political conditions may negatively impact our business, financial condition,
results of operations and cash flows. As a result of the volatility of oil and natural gas prices, we are unable to fully
aa
predict the level of exploration, drilling and production activities of our customers and whether our customers and/or
vendors will be able to sustain their operations and fulfill their commitments and obligations. If oil prices remain at the
current relatively low levels or decrease and/or global economic conditions deteriorate, there could be a material adverse
impact on the liquidity and operations of our customers, vendors and other worldwide business partners, which in turn
could have a material impact on our results of operations and liquidity. Furthermore, these conditions may result in
aa
certain of our customers experiencing an inability to pay vendors, including us. In addition, we may experience
12
difficulties forecasting future capital expenditures by our customers, which in turn could lead to either over capacity or,
in the event of further recovery in oil prices and the worldwide economy, under capacity, either of which could adversely
affect our operations. There can be no assurance that the global economic environment will not deteriorate again in the
future due to one or more factors.
We operate in a highly competitive industry with excess drilling capacity, which may adversely affect our results of
operations.
The oilfield services industry is very competitive with a significant amount of excess capacity, especially in low
oil price environments. Contract drilling companies compete primarily on a regional basis, and competition may vary
significantly from region to region at any particular time. Most rigs and drilling-related equipment can be moved from
one region to another in response to changes in levels of activity and market conditions, which may result in an
oversupply of such rigs and drilling-related equipment in certain areas, and accordingly, increased price competition. In
addition, an important factor in determining job awards is our ability to maintain a strong safety record. If we are unable
to remain competitive based on these and/or other competitive factors, we may be unable to increase or even maintain
our market share, utilization rates and/or day rates for our services, which could adversely affect our business, financial
condition, results of operations and cash flows.
We must renew customer contracts to remain competitive.
Our ability to renew existing customer contracts, or obtain new contracts, and the terms of any such contracts
depends on market conditions and our customers’ future drilling plans, which are subject to change. Due to the highly
competitive nature of the industry, which can be exacerbated during periods of depressed market conditions, we may not
be able to renew or replace expiring contracts or, if we are able to, we may not be able to secure or improve existing
dayrates or other material terms, which could have an adverse effect on our business, financial condition and results of
operations.
The nature of our operations presents inherent risks of loss, including weather-related risks, that could adversely
affect our results of operations.
Our operations are subject to many hazards inherent in the drilling industry, including environmental pollution,
blowouts, cratering, explosions, fires, loss of well control, loss of or damage to the wellbore or underground reservoir,
damaged or lost drilling equipment and damage or loss from inclement weather or natural disasters. Any of these hazards
could result in personal injury or death, damage to or destruction of equipment and facilitie
s, suspension of operations,
environmental and natural resources damage and damage to the property of others. Our offshore operations involve the
additional hazards of marine operations including pollution of coastal waters, damage to wildlife and natural habitats,
capsizing, grounding, collision, damage from hurricanes and heavy weather or sea conditions, such as sea level rise,
coastal storm surge, inland flooding, and unsound ocean bottom conditions.
tt
Accidents may occur, we may be unable to obtain desired contractual indemnities, and our insurance may prove
t
inadequate in certain cases. The occurrence of an event for which we are not sufficiently insured or indemnified against,
or the failure or inability of a customer or insurer to meet its indemnification or insurance obligations, could result in
substantial losses that could adversely affect our business, financial condition and liquidity. In addition, insurance may
not be available to cover any or all these risks. Our insurance also may not cover losses associated with pandemics such
as the COVID-19 pandemic. Even if available, insurance may be inadequate or insurance premiums or other costs may
increase significantly in the future, making insurance prohibitively expensive. We expect to continue facing upward
pressure in our insurance renewals, our premiums and deductibles may be higher, and some insurance coverage may
either be unavailable or more expensive than it has been in the past. Moreover, our insurance coverage generally
provides that we assume a portion of the risk in the form of a deductible or self-insured retention. We may choose to
increase the levels of deductibles (and thus assume a greater degree of risk) from time to time in order to minimize our
overall costs, which could exacerbate the impact of our losses on our financial condition and liquidity.
r
Our drilling contracts may in certain instances be renegotiated, suspended or terminated without an early termination
payment.
Most of our multi-well and term drilling contracts require that an early termination payment be made to us if a
contract is terminated by the customer prior to its expiration. However, such payments may not fully compensate us for
13
the loss of a contract, and in certain circumstances such as, but not limited to, non-performance caused by significant
operational or equipment issues (such as destruction of a drilling rig that is not replaced within a specified period of
time), sustained periods of downtime due to a force majeure event, or other events beyond our control or some other
breach of our contractual obligations, our customers may not be obligated to make an early termination payment to us at
all. In addition, some contracts may be suspended, rather than terminated early, for an extended period of time, in some
cases without adequate compensation. The early termination or suspension of a contract may result in a rig being idle for
an extended period of time, which could have a material adverse effect on our business, financial condition and results of
operations.
During periods of depressed market conditions, we may be subject to an increased risk of our customers
(including government-controlled entities) seeking to renegotiate, repudiate or terminate their contracts and/or to
otherwise exert commercial influence to our disadvantage. The downturn in the oil price environment resulted in
downward pricing pressure and decreased demand for our drilling services with existing customers, resulting in
renegotiations of pricing and other terms in our drilling contracts with certain customers and early termination of
contracts by others. Our customers’ ability to perform their obligations under the contracts, including their ability to pay
us or fulfill their indemnity obligations, may also be impacted by an economic or industry downturn or other adverse
d
conditions in the oil and gas industry. If we were to sustain a loss and our customers were unable to honor their
indemnification and/or payment obligations, it could adversely affect our liquidity. If our customers cancel some of our
contracts, and we are unable to secure new contracts on a timely basis and/or on substantially similar terms, or if
contracts are suspended for an extended period of time with or without adequate compensation or renegotiated with
pricing or other terms less favorable to us, it could adversely affect our financial condition and results of operations.
The loss of one or a number of our large customers could have a material adverse effect on our business, financial
condition and results of operations.
In 2020, 2019 and 2018, we received approximately 49%, 41% and 41%, respectively, of our consolidated
operating revenues from our three largest contract drilling customers (including their affiliates), with our largest
customer and partner in our SANAD joint venture, Saudi Aramco, representing 29%, 22% and 24% of our consolidated
operating revenues, respectively, for these periods. The loss of one or more of our larger customers would have a
material adverse effect on our business, financial condition, results of operations and prospects. In addition, if a
significant customer experiences liquidity constraints or other financial difficulties it may be unable to make required
payments or seek to renegotiate contracts, which could adversely affect our liquidity and profitability. Financial
difficulties experienced by customers could also adversely affect our utilization rates in the affected market and may
cause our counterparties to seek modifications to our contracts with them. Furthermore, potential consolidation among
tt
oil and natural gas exploration and production companies may reduce the number of available customers.
ff
The profitability of our operations could be adversely affected by war, civil disturbance, terrorist activity or other
political or economic instability, fluctuation in currency exchange rates and local import and export controls.
d
We derive a significant portion of our business from global markets, including major operations in the Middle
East, South America, the Far East, North Africa and Russia. These operations are subject to various risks, including war,
civil disturbances, labor strikes, nationalization, terrorist activity and governmental actions that may limit or disrupt
markets, restrict the movement of funds or result in limits or restrictions in our ability to operate or compete, the
deprivation of contractual rights or the taking of property without fair compensation, particularly in respect of contracts
with foreign national oil companies. In some countries, our operations may be subject to the additional risk of fluctuating
currency values and exchange controls. We also are subject to various laws and regulations that govern the operation and
taxation of our business and the import and export of our equipment from country to country, the imposition, application
and interpretation of which can prove to be uncertain.
For example, we previously operated in Venezuela, and were exposed to risks related to political instability
there. On January 28, 2019, the United States Treasury Department’s Office of Foreign Assets Control designated
Petroleos de Venezuela S.A. (“PdVSA”) as a Specially Designated National under Executive Order 13850 (the “Order”).
The Order prohibited, among other things, business dealings with PdVSA or any entity in which PdVSA owns, directly
or indirectly, a 50 percent or greater interest. We were forced to cease operations in Venezuela, and during the second
quarter of 2020 we wrote off all remaining value on our rig and drilling related equipment in the country.
14
The future occurrence of one or more international events arising from the types of risks described above could
have a material adverse impact on our business, financial condition and results of operations.
We rely on third-party suppliers, manufacturers and service providers to secu
u
used in rig operations, conversions, upgrades and construction.
re equipment, components and parts
Our reliance on third-party suppliers, manufacturers and service providers to provide equipment and services
exposes us to volatility in the quality, price and availability of such items. Certain components, parts and equipment that
we use in our operations may be available only from a small number of suppliers, manufacturers or service providers.
The failure of one or more third-party suppliers, manufacturers or service providers to provide equipment, components,
parts or services, whether due to capacity constraints, production or delivery disruptions, price increases, quality control
issues, recalls or other decreased availability of parts and equipment, is beyond our control and could materially disrupt
our operations or result in the delay, renegotiation or cancellation of drilling contracts, thereby causing a loss of contract
drilling backlog and/or revenue to us, as well as an increase in operating costs.
d
Additionally, our suppliers, manufacturers, and service providers could be negatively impacted by changes in
f
industry conditions or global economic conditions. If certain of our suppliers, manufacturers or
service providers were to
curtail or discontinue their business as a result of such conditions, it could result in a reduction or interruption in supplies
or equipment available to us and/or a significant increase in the price of such supplies and equipment, which could
adversely impact our business, financial condition and results of operations.
Our contracts with national oil companies may expose us to greater risks than we normally assume in contracts with
non-governmental customers.
y
We currently own and operate rigs and rig-related equipment under contracts with foreign national oil
companies. In the future, we may expand our international solutions operations and enter into additional, significant
contracts with national oil companies. The terms of these contracts may contain non-negotiable provisions and may
expose us to greater commercial, political, operational and other risks than we assume in other contracts. Foreign
contracts may expose us 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 customer without cause on short-term notice, contractually or by governmental action, or under certain conditions
that may not provide us with an early termination payment. We can provide no assurance that increased risk exposure
will not have an adverse impact on our future operations or that we will not increase the number of rigs contracted, or the
amount of technology deployed, to national oil companies with commensurate additional contractual risks. Risks that
accompany contracts with national oil companies could ultimately have a material adverse impact
t
financial condition and results of operations.
on our business,
aa
Control of oil and natural gas reserves by state-owned oil companies may impact the demand for our services and
products and create additional risks in our operations.
Much of the world’s oil and natural gas reserves are controlled by state-owned oil companies. State-owned oil
companies may require their contractors to meet local content requirements or other local standards, such as conducting
our operations through joint ventures with local partners that could be difficult or undesirable for us to meet. The failure
to meet the local content requirements and other local standards may adversely impact our operations in those countries.
In addition, our ability to work with state-owned oil companies is subject to our ability to negotiate and agree upon
acceptable contract terms.
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Our operating expense includes fixed costs that may not decline in proportion to decreases in rig utilization and
dayrates.
Our operating expense includes all direct and indirect costs associated with the operation, maintenance and
support of our drilling and related equipment, which are not affected by changes in dayrates and some of which are not
affected by utilization. During periods of reduced revenue and/or activity, certain of our fixed costs (such as
depreciation) may not decline and often we may incur additional costs. During times of reduced utilization, reductions
in costs may not be immediate as we may not be able to fully reduce the cost of our support operations in a particular
geographic region due to the need to support the remaining drilling rigs in that region. Accordingly, a decline in revenue
15
due to lower dayrates and/or utilization may not be offset by a corresponding decrease in drilling services and solutions
expense, which could have a material adverse impact on our business, financial condition and results of operations.
Actions of and disputes with our joint venture partners could have a material adverse effect on the business and
results of operations of our joint ventures and, in turn, our business and consolidated results of operations.
We conduct some operations through joint venturesl. As with any joint venture arrangement, differences in
views among the joint venture participants may result in delayed decisions, the joint venture operating in a manner that
is contrary to our preference or in failures to agree on major issues. We also cannot control the actions of our joint
venture partners, including any nonperformance, default, or bankruptcy of our joint venture partners. These factors could
have a material adverse effect on the business and results of operations of our joint ventures and, in turn, our business
and consolidated results of operations.
Failure to realize the anticipated benefits of acquisitions, divestitures, investm
transactions may adversely affect our business, results of operations and financial position.
e
ents, joint ventures and other strategic
We undertake from time to time acquisitions, divestitures, investments, joint ventures, alliances and other
strategic transactions that we expect to further our business objectives. For example, in October 2016, we announced an
agreement to form a new joint venture in the Kingdom of Saudi Arabia, which commenced operations in December,
2017. The long-term success of the Saudi joint venture depends, to a large degree, on the satisfactory performance of our
joint venture partner’s obligations, including contributions of capital, drilling units and rela
ted equipment, and our ability
f
to maintain an effective, working relationship with our joint venture partner.
We also completed the acquisition of Tesco in December 2017. We have been unable to obtain regulatory
approvals to recognize our acquisition of the Tesco subsidiary in Russia.
f
The anticipated benefits of the Saudi joint venture, the Tesco acquisition, and other strategic transactions may
not be fully realized, or may be realized more slowly than expected, and may result in operational and financial
consequences, including, but not limited to, the loss of key customers, suppliers or employees, or the disposition of
certain assets or operations, which may have an adverse effect on our business, financial condition and results of
operations.
Decisions by internet service, cloud host service and related providers to restrict or ban our ability to use their
platforms could adversely affect our ability to promote and conduct our business and inform investors.
tt
We utilize the internet to provide services and to promote our business and services to current and potential
customers and to provide information and updates to our investors. Internet service providers, cloud hosting services,
social media companies and website providers that currently allow us to utilize their platforms to communicate with
customers and the public may decide that our business or the industry in whic
h we operate negatively impacts their
business or may make business decisions or changes to their policies that negatively impact us. Such actions could
include placing restrictions on our use of their platforms or banning us from utilizing their services altogether. Our
inability to use these platforms may have a negative impact on the way we are perceived in the industry or in the media
and may adversely affect our business, financial condition, results of operations and cash flows.
t
Financial Risks
We may record additional losses or impairment charges related to sold or idle drilling rigs and other assets.
In 2020, 2019 and 2018, we recognized impairment charges of $390.0 million, $290.5 million and $124.9
million, respectively, related to tangible assets and equipment. Prolonged periods of low utilization or low dayrates, the
cold stacking of idle assets, the sale of assets below their then carrying value or the decline
in market value of our assets
n
may cause us to experience further losses. If future cash flow estimates, based upon information available to
management at the time, including oil and gas prices and expected utilization levels, indicate that the carrying value of
any of our rigs may not be recoverable or if we sell assets for less than their then carrying value, we may recognize
additional impairment charges on our fleet.
16
Our financial and operating flexibility could be affected by our long-term debt and other financial commitments.
h
The 2018 Revolving Credit Facility is partially secured with a first lien security interest on drilling rigs in the
U.S. and Canada in an amount not less than $545.8 million. Under the facility, we are required to maintain “minimum
liquidity” of no less than $160.0 million at all times, and an asset to debt coverage ratio of at least 4.25:1 as of the end of
each calendar quarter. Minimum liquidity is defined to mean, generally, a consolidated cash balance consisting of (a)
the aggregate amount of unrestricted cash and cash equivalents maintained in a deposit account U.S. or Canadian branch
of a commercial bank, plus (b) the lesser of $75 million or an amount equal to 75% of the aggregate amount of
unrestricted cash and cash equivalents held in deposit account of a commercial bank outside of the U.S. or Canada, plus
(c) available commitments under the 2018 Revolving Credit Facility. The asset-to-debt coverage ratio is calculated by
dividing (x) drilling-related fixed assets wholly owned by certain of Nabors’ subsidiaries that are guaranteeing the 2018
Revolving Credit Facility (the ‘‘2018 Revolver Guarantors’’) or wholly owned subsidiaries of the 2018 Revolver
Guarantors by (y) the commitments under the 2018 Revolving Credit Facility and certain other indebtedness up to $100
million. The asset to debt coverage ratio applies only during the period which Nabors Delaware fails to maintain an
investment grade rating from at least two rating agencies, which was the case as of the date of this report. The minimum
liquidity requirement and the asset-to-debt coverage ratio are not measures of operating performance or liquidity defined
by U.S. GAAP and may not be comparable to similarly titled measures presented by other companies.
As of December 31, 2020, our consolidated total outstanding indebtedness was $3.0 billion. We also have
various financial commitments, such as leases, contracts and purchase commitments. Our ability to service our debt and
other financial obligations depends in large part upon the level of cash flows generated by our operating subsidiaries’
operations, our ability to monetize and/or divest non-core assets, availability under our unsecured revolving credit
facilities and our ability to access the capital markets and/or other sources of financing. If we cannot repay or refinance
our debt as it becomes due, we may be forced to sell assets or reduce funding in the future for working capital, capital
expenditures and general corporate purposes, any of which could negatively impact our stock price or financial
condition.
t
Our ability to access capital markets could be limited.
From time to time, we may need to access capital markets to obtain long-term and short-term financing.
r
However, our ability to access capital markets could be limited or adversely affected by, amon
g other things, oil and gas
prices, our existing capital structure, our credit ratings, interest rates and the health or market perceptions of the drilling
and overall oil and gas industry and the global economy. In addition, many of the factors that affect our ability to access
capital markets, including the liquidity of the overall capital markets, the state of the economy and oil and gas industry
and the impact of COVID-19, among others, are outside of our control. There have also been efforts in recent years
aimed at the investment community, including investment advisors, sovereign wealth funds, public pension funds,
universities and other groups, promoting the divestment of fossil fuel equities as well as to pressure lenders and other
financial services companies to limit or curtail activities with companies engaged in the extraction of fossil fuel reserves,
which, if successful, could limit our ability to access capital markets. No assurance can be given that we will be able to
access capital markets on terms acceptable to us when required to do so, which could adversely affect our business,
financial condition and results of operations.
ff
Technology Risks
New technologies may cause our drilling methods and equipment to become less competitive and it may become
necessary to incur higher levels of operating and capital expenditures in order to keep pace with the disruptive trends
ee
in the drilling industry. Growth through the building of new drilling rigs and improvement of existing rigs is not
assured.
The market for our services is characterized by continual technological developments that have resulted in, and
will likely continue to result in, substantial improvements in the functionality and performance of rigs and equipment.
Our customers increasingly demand the services of newer, higher specification drilling rigs and related equipment.
Accordingly, we may have to allocate a higher proportion of our capital expenditures to maintain and improve existing
rigs and other equipment, purchase and construct newer, higher specification drilling rigs and other equipment to meet
the increasingly sophisticated needs of our customers, and develop new and improved technology and data analytics.
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Although we take measures to ensure that we develop and use advanced oil and natural gas drilling technology,
changes in technology or improvements by competitors could make our equipment less competitive. There can be no
assurance that we will:
•
•
•
•
have sufficient capital resources to improve existing rigs or build new, technologically advanced drilling rigs;
avoid cost overruns inherent in large fabrication projects resulting from numerous factors such as shortages or
unscheduled delays in delivery of equipment or materials, inadequate levels of skilled labor, unanticipated
increases in costs of equipment, materials and labor, design and engineering problems, and financial or other
difficulties;
successfully deploy idle, stacked, new or upgraded drilling rigs;
effectively manage the size or growth of our organization and drilling fleet;
• maintain crews necessary to operate existing or additional drilling rigs; or
•
successfully improve our financial condition, results of operations, business or prospects as a result of
improving existing drilling rigs or building new drilling rigs.
In the event that we are successful in developing new technologies for use in our business, there is no guarantee
of future demand for those technologies. Customers may be reluctant or unwilling to adopt our new technologies. We
may also have difficulty negotiating satisfactory terms for our technology services or may be unable to secure prices
sufficient to obtain expected returns on our investment in the research and development of new technologies.
Development of new technology is critical to maintaining our competitiveness. There can be no assurance that
If we are not successful keeping pace
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we will be able to successfully develop technology that our customers demand.
with technological advances and trends (including trends in favor of emissions reducing technologies) or if we fail to
n
deliver such technologies to our customers in a timely and cost-effective manner suitable to their needs, demand for our
services could decline and we could lose market share. Furthermore, if our equipment or proprietary technologies
become obsolete, the value of our intellectual property may be reduced, or one or more technologies that we may
implement in the future may not work as we expect and our business, financial condition, results of operations and
reputation could be adversely affected as a result. Additionally, new technologies, services or standards could render
some of our services, drilling rigs or equipment obsolete, which could reduce our competitiveness and have a material
adverse impact on our business, financial condition and results of operations.
Limitations on our ability to obtain, maintain, protect or enforce our intellectual property rights, including our trade
secrets, could cause a loss in revenue and any competitive advantage we hold.
e
There can be no assurance that the steps we take to obtain, maintain, protect and enforce our intellectual
property rights will be adequate. Some of our products or services, and the processes we use to produce or provide them,
have been granted patent protection, have patent applications pending, or are trade secrets. Our business may be
adversely affected when our patents are unenforceable, the claims allowed under our patents are not sufficient to protect
our technology, our patent applications are denied, or our trade secrets are not adequately protected. Patent protection on
some types of technology, such as software or machine learning processes, may no
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which we operate. Our competitors may also be able to develop technology independently that is similar to ours without
infringing on our patents or gaining access to our trade secrets, which could adversely affect our financial condition,
results of operations and cash flows.
t be available in certain countries in
uu
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Technology disputes could negatively impact our operations or increase our costs.
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Our services and products use proprietary technology and equipment, which can involve potential infringement
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of a third party’s rights, or a third party’s infringement of our rights, including patent rights. The majority of the
intellectual property rights relating to our drilling rigs and related services are owned by us or certain of our supplying
vendors. However, in the event that we or one of our customers or supplying vendors becomes involved in a dispute over
infringement of intellectual property rights relating to equipment or technology owned or used by us, services performed
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by us or products provided by us, we may lose access to important equipment or technology or our ability to provide
services or products, or we could be required to cease use of some equipment or technology or be forced to invest or
develop replacement technologies to enhance our equipment, technology, services or products. We could also be
required to pay license fees or royalties for the use of equipment or technology or provision of services or products. In
addition, we may lose a competitive advantage in the event we are unsuccessful in enforcing our rights against third
parties. Regardless of the merits, any such claims generally result in significant legal and other costs, including
reputational harm, and may distract management from running our business. Technology disputes involving us or our
customers or supplying vendors could have a material adverse impact on our business, financial condition, cash flows
and results of operations.
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Improvements in or new discoveries of alternative energy technologies could have a material adverse effect on our
financial condition and results of operations.
Since our business depends on the level of activity in the oil and natural gas industry, any improvement in or
new discoveries of alternative energy technologies that increase the use of alternative forms of energy and reduce the
demand for oil and natural gas could have a material adverse effect on our business, financial condition and results of
operations.
Legal and Regulatory Risks
Changes to United States tax, tariff and import/export regulations may have a negative effect on global economic
conditions, financial markets and our business.
There have been ongoing discussions and commentary regarding potential significant changes to the United
States trade policies, treaties, tariffs and taxes, including trade policies and tariffs regarding China. In 2018, the Office of
the U.S. Trade Representative (the “USTR”) enacted tariffs on imports into the U.S. from China. In September 2018, the
USTR enacted another tariff on the import of other Chinese products with an additional combined import value of
approximately $200 billion. The tariff became effective on September 24, 2018, with an initial rate of 10%, with the
potential for significant increases if the U.S. and China do not reach a new trade deal in the near term. There is
significant uncertainty about the future relationship between the United States and other countries with respect to the
trade policies, treaties, taxes, government regulations and tariffs that would be applicable. It is unclear what changes
might be considered or implemented and what response to any such changes may be by the governments of other
countries. Significant tariffs or other restrictions placed on Chinese imports and any related counter-measures that are
taken by China could have an adverse effect on our financial condition or results of operations. Even in the absence of
further tariffs, the related uncertainty and the market's fear of an escalating trade war might create forecasting difficulties
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for us and cause our customers and business partners to place fewer orders for our products and services, which could
have a material adverse effect on our business, liquidity, financial condition, and/or results of operations. These
developments, or the perception that any of them could occur, may have a material adverse effect on global economic
conditions and the stability of global financial markets, and may significantly reduce global trade and, in particular, trade
between these nations and the United States. Any of these factors could depress economic activity and restrict our access
to suppliers or customers and have a material adverse effect on our business, financial condition and results of operations
and affect our strategy around the world. Given the relatively fluid regulatory environment in China and the United
States and relative uncertainty with respect to tariffs, international trade agreements and policies, a trade war, further
governmental action related to tariffs or international trade policies, or additional tax or other regulatory changes in the
future could directly and adversely impact our financial results and results of operations.
The Company’s ability to use its net operating loss carryforwards, and possibly other tax attributes, to offset future
taxable income for U.S. federal income tax purposes may be significantly limited due to various circumstances,
a
including future transactions involving the sale or issuance of Company equity securities, or if taxable income does
not reach sufficient levels.
As of December 31, 2020, the Company reported consolidated federal net operating loss (“NOL”)
carryforwards of approximately $670.3 million and certain other favorable federal income tax attributes. The Company’s
ability to use its NOL carryforwards and certain other attributes may be limited if it experiences an “ownership change”
as defined in Section 382 (“Section 382”) of the Internal Revenue Code of 1986, as amended (the “Code”). An
ownership change generally occurs if there is a more than 50 percentage point increase in the aggregate equity
ownership of the Company by one or more “5 percent shareholders” (as that term is defined for purposes of Sections 382
19
and 383 of the Code) in any testing period, which is generally the three-year period preceding any potential ownership
change, measured against their lowest percentage ownership at any time during such period.
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There is no assurance that the Company will not experience an ownership change under Section 382 as a result
of future actions that may significantly limit or possibly eliminate its ability to use its NOL carryforwards and potentially
certain other tax attributes. Potential future transactions involving the sale, issuance, redemption or other disposition of
common or preferred shares or other equity-based securities, the exercise of conversion or exchange options under the
terms of any convertible or exchangeable debt, the repurchase of any such debt with Company shares, in each case, by a
person owning, or treated as owning, 5% or more of the Company’s shares, or a combination of such transactions, may
cause or increase the possibility that the Company will experience an ownership change under Section 382. Under
Section 382, an ownership change would subject the Company to an annual limitation that applies to the amount of pre-
ownership change NOLs (and possibly certain other tax attributes) that may be used to offset post-ownership change
taxable income. If a Section 382 limitation applies, the limitation could cause the Company’s U.S. federal income taxes
to be greater, or to be paid earlier, than they otherwise would be, and could cause all or a portion of the Company’s NOL
carryforwards to expire unused. Similar rules and limitations may apply for state income tax purposes. The Company’s
ability to use its NOL carryforwards will also depend on the amount of taxable income it generates in future periods. The
Company’s NOL carryforwards may expire before it can generate sufficient taxable income to use them in full.
Changes to or noncompliance with laws and regulations or exposure to environmental liabilities could adversely
affect our results of operations.
Drilling of oil and natural gas wells is subject to various laws and regulations in the jurisdictions where we
operate, including comprehensive and frequently changing laws and regulations relating to the protection of human
health and the environment, including those regulating the transport, storage, use, treatment, disposal and remediation of,
and exposure to, solid and hazardous wastes and materials. In addition, the Outer Continental Shelf Lands Act provides
the federal government with broad discretion in regulating the leasing of offshore oil and gas production sites. Our costs
to comply with these laws and regulations may be substantial. Violation of environmental laws or regulations could lead
to the imposition of administrative, civil or criminal penalties, capital expenditures, delays in the permitting or
performance of projects, and in some cases injunctive relief. Violations may also result in liabilities for personal injuries,
property and natural resource damage and other costs and claims. We are not always successful in allocating all risks of
these environmental liabilities to customers, and it is possible that customers who assume the risks will be financially
unable to bear any resulting costs.
In addition, U.S. federal laws and the laws of other jurisdictions regulate the prevention of oil spills and the
release of hazardous substances, and may impose liability for removal costs and natural resource, real or personal
property and certain economic damages arising from any spills. Some of these laws may impose strict and/or joint and
several liability for clean-up costs and damages without regard to the conduct of the parties. As an owner and operator of
onshore and offshore rigs and other equipment, we may be deemed to be a responsible party under federal law. In
addition, we are subject to various laws governing the containment and disposal of hazardous substan
and other waste materials and the use of underground storage tanks.
ces, oilfield waste
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The expansion of the scope of laws or regulations protecting the environment has accelerated in recent years,
particularly outside the United States, and we expect this trend to continue. For example, the U.S. Environmental
Protection Agency (“EPA”) has promulgated final rules requiring the reporting of greenhouse gas emissions applicable
to certain offshore oil and natural gas production and onshore oil and natural gas production, processing, transmission,
storage and distribution facilities. In June 2016, the EPA published final standards to reduce methane emissions for
certain new, modified, or reconstructed facilities in the oil and gas industry and established NSPS Subpart OOOOa that
set new standards and required certain new, modified or reconstructed facilities in the oil and natural gas sector to reduce
methane gas and VOC emissions (the “2016 New Source Rule”). In August 2020, the EPA finalized a rule that rolled
back the 2016 New Source Rule, which was subsequently stayed temporarily by the D.C. Circuit Court. The Biden
administration has indicated that it would likely repeal the August 2020 rule on methane emissions and evaluate a new
regulatory approach going forward. Accordingly, the future status of methane emissions standards is unclear.
Changes in environmental laws and regulations may also negatively impact the operations of oil and natural gas
exploration and production companies, which in turn could have an adverse effect on us. For example, drilling fluids,
produced water and most of the other wastes associated with the exploration, development and production of oil or gas,
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if properly handled, are currently exempt from regulation as hazardous waste under the Resource Conservation and
Recovery Act (“RCRA”) and instead, are regulated under RCRA’s less stringent non-hazardous waste provisions.
However, in response to a lawsuit in the U.S. District Court for the District of Columbia in May 2016 alleging that the
EPA failed to timely assess its RCRA Subtitle D criteria regulations for oil and gas wastes, the EPA and several
environmental groups entered into an agreement that was finalized in a Consent Decree issued by the District Court on
December 28, 2016. Based on its review required by the Consent Decree, in April 2019, the EPA made a final
determination that revision of the RCRA regulations was unn
ecessary. Any future reclassification of oil and gas wastes
as RCRA hazardous waste could result in more stringent and costly handling, disposal and clean-up requirements and
could have a material adverse effect on the Company’s results of operations and financial position..
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The EPA has issued rules requiring monitoring and reporting of greenhouse gas emissions from the oil and
natural gas sector, including onshore and offshore production activities. In November 2016, the BLM issued a rule
requiring reductions in methane emissions from venting, flaring, and leaking activities on public lands (the “Waste
Prevention Rule”). Although the BLM issued a rule in September 2018 that rescinded critical portions of the Waste
Prevention Rule, the 2018 rule was vacated by order of the U.S. District Court for the Northern District of California in
July 2020. Subsequently, in October 2020, the Waste Prevention Rule was largely vacated by the U.S. District Court for
the State of Wyoming. In addition, several states may seek to regulate methane emissions by state law. The Biden
administration has indicated that it intends to craft a new rule for regulating methane waste management. Since any such
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rule will likely be challenged, there is a considerable amount of uncertainty in this area of environmental regulation.
Future or more stringent federal or state regulation could dramatically increase operating costs for oil and natural gas
companies, curtail production and demand for oil and natural gas in areas of the world where our customers operate, and
reduce the market for our services by making wells and/or oilfields uneconomical to operate, which may in turn
adversely affect results of operations.
The physical effects of climate change and the regulation of greenhouse gas emissions and climate change could
have a negative impact on our business.
t
The physical and regulatory effects of climate change could have a negative impact on our operations, our
customers’ operations and the overall demand for our customers' products and services. Scientific studies have suggested
that emissions of certain gases, commonly referred to as “greenhouse gases” (“GHGs”) and including carbon dioxide
and methane, may be contributing to warming of the earth’s atmosphere and other climatic changes. In response to such
studies, the issue of climate change and the effect of GHG emissions, in particular emissions from fossil fuels, is
attracting increasing attention worldwide.
We are aware of the increasing focus of local, state, regional, national and international regulatory bodies on
GHG emissions and climate change issues. There has been a wide-ranging policy debate, both in the United States and
internationally, regarding the impact of GHG emissions and possible means for their regulation. Some of the proposals
would require industries to meet stringent standards that would require substantial reductions in GHG emissions. Those
reductions could be costly and difficult to implement. Legislation to regulate GHG emissions has periodically been
introduced in the U.S. Congress and such legislation may be proposed or adopted in the future.
The U.S. Congress has considered, but not adopted, legislation designed to reduce emission of greenhouse
gases, and some states in which we operate have passed legislation or adopted initiatives, such as the Regional
Greenhouse Gas Initiative in the Northeastern United States, which establishes greenhouse gas inventories and/or cap-
and-trade programs. In addition, the EPA has published findings that emissions of greenhouse gases present an
endangerment to public health and the environment, which could lead to further regulation of greenhouse gas emissions
under the Clean Air Act.
In December 2015, the United States joined the international community at the 21st Conference of the Parties
of the United Nations Framework Convention on Climate Change (the “UNFCCC”) in Paris, France in creating an
agreement (the “Paris Agreement”) that requires member countries to review and “represent a progression” in their
intended nationally determined GHG contributions, which set GHG emission reduction goals every five years beginning
in 2020. The agreement entered into full force in November 2016. Although the prior administration formally withdrew
the United States from the Paris Agreement effective November 4, 2020, the new Administration issued an executive
order to rejoin the Paris climate agreement on January 20, 2021. It will take 30 days for the United States to officially
rejoin.
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The aim of the Paris Agreement is to hold the increase in the average global temperature to well below
m
2ºC (3.6ºF) above pre-industrial levels with efforts to limit the rise to 1.5ºC (2.7ºF) to protect against the more severe
consequences of climate forecasted by scientific studies. These consequences include increased coastal flooding,
droughts and associated wildfires, heavy precipitation events, stresses on water supply and agriculture, increased
poverty, and negative impacts on health. In
invited the Intergovernmental Panel on Climate Change (the “IPCC”) to prepare a special report focused on the impacts
of an increase in the average global temperature of 1.5ºC above pre-industrial levels and related GHG emission
pathways. The 2018 IPCC Report concludes that the measures set forth in the Paris Agreement are insufficient and that
more aggressive targets and measures will be needed. The 2018 IPCC Report indicates that GHGs must be reduced from
2010 levels by 45 percent by 2030 and 100 percent by 2050 to prevent global warming of 1.5ºC above pre-industrial
levels.
connection with the decision to adopt the Paris Agreement, the UNFCCC
It is not possible at this time to predict the timing and effect of climate change or whether additional GHG
legislation, regulations or other measures will be adopted at the federal, state or local levels. However, more aggressive
efforts by governments and non-governmental organizations to reduce GHG emissions appear likely and any such future
laws and regulations could result in increased compliance costs, additional operating restrictions or affect the demand for
our customers' products and, accordingly, our services. For example, the California governor issued an executive order
on September 23, 2020 ordering actions to pursue GHG emissions reductions, including a direction to the California
State Air Resources Board to develop and propose regulations to require increasing volumes of new zero-emission
passenger vehicles and trucks sold in California over time, with a targeted ban of the sale of new gasoline vehicles by
2035. If we are unable to recover or pass through a significant level of our costs related to complying with climate
ff
change regulatory requirements imposed on us, it could have a material adverse impact on our business, financial
condition and results of operations. Further, to the extent financial markets view climate change and GHG emissions as a
financial risk, this could negatively impact our cost of or access to capital. Climate ch
also negatively impact the drilling programs of our customers and, consequently, delay, limit or reduce the services we
provide. An increased focus by the public on the reduction of GHG emissions as well as the results of the physical
impacts of climate change could affect the demand for our customers’ products and have a negative effect on our
business.
ange and GHG regulation could
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The cost of complying with any new law, regulation or treaty will depend on the details of the particular
program. We will continue to monitor and assess any new policies, legislation or regulations in the areas where we
operate to determine the impact of GHG emissions and climate change on our operations and take appropriate actions,
where necessary. Any direct and indirect costs of meeting these requirements may adversely affect our business, results
of operations and financial condition. Because our business depends on the level of activity in the oil and natural gas
industry, existing or future laws or regulations related to GHGs and climate change, including incentives to conserve
energy or use alternative energy sources, could have a negative impact on our business if such laws or regulations reduce
demand for oil and natural gas.
In addition to the regulatory efforts described above, there have also been efforts in recent years aimed at the
investment community, including investment advisors, sovereign wealth funds, public pension funds, universities and
other groups, promoting the divestment of fossil fuel equities as well as to pressure lenders and other financial services
companies to limit or curtail activities with companies engaged in the extraction of fossil fuel reserves. If these efforts
are successful, our ability and the ability of our customers to access capital markets may be limited and our stock price
may be negatively impacted.
Members of the investment community have recently increased their focus on sustainability practices with
regard to the oil and gas industry, including practices related to GHGs and climate change. An increasing percentage of
the investment community considers sustainability factors in making investment decisions, and an increasing number of
our customers consider sustainability factors in awarding work. These developments, and public perception relating to
climate change, may curtail production and demand for hydrocarbons such as oil and natural gas by shifting demand
towards and investment in relatively lower carbon energy sources such as wind, solar and other renewables. The
renewable energy industry is developing enhanced technologies and becoming more competitive with fossil-fuel energy.
If renewable energy becomes more competitive than fossil-fuel energy, particularly during periods of higher oil and
natural gas prices, it could have a material effect on our results of operations. If we are unable to successfully continue
our sustainability enhancement efforts, we may lose customers, our stock price may be negatively impacted, our
reputation may be negatively affected, and it may be more difficult for us to effectively compete.
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Beyond financial and regulatory impacts, the projected severe effects of climate change have the potential to
directly affect our facilities and operations and those of our customers.
Legal proceedings and governmental investigations could affect our financial condition and results of operations.
We are subject to legal proceedings and governmental investigations from time to time that include
employment, tort, intellectual property and other claims, and purported class action and shareholder derivative actions.
We are also subject to complaints and allegations from former, current or prospective employees from time to time,
alleging violations of employment-related laws or other whistle blower-related matters. Lawsuits or claims could result
in decisions against us that could have an adverse effect on our financial condition or results of operations. See ‘‘Item
3—Legal Proceedings’’ for a discussion of certain existing legal proceedings.
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Share Capital and Corporate Structure Risks
Significant issuances of common shares could adversely affect the market price of our common shares.
As of February 19, 2021, we had 32,000,000 authorized common shares, of which 8,449,591 shares were
outstanding and entitled to vote, including 1,090,003 million held by our subsidiaries. In addition, 387,640 common
shares were reserved for issuance pursuant to stock option and employee benefit plans and 741,934 common shares were
reserved for issuance upon conversion of outstanding mandatory convertible preferred shares. The sale, or availability
for sale, of substantial amounts of our common shares in the public market, whether directly by us or resulting from the
exercise of options (and, where applicable, sales pursuant to Rule 144 under the Securities Act) or the exchange of
Exchangeable Notes or the conversion of mandatory convertible preferred shares for common shares, would be dilutive
to existing shareholders, could adversely affect the prevailing market price of our common shares and could impair our
ability to raise additional capital through the sale of equity securities.
Our common share price has been and may continue to be volatile.
The trading price of our common shares has fluctuated in the past and is subject to significant fluctuations in
response to the following factors, some of which are beyond our control:
•
•
•
•
•
•
•
•
variations in quarterly operating results;
deviations in our earnings from publicly disclosed forward-looking guidance;
variability in our revenues;
our announcements of significant contracts, acquisitions, strategic partnerships or joint ventures;
general conditions in and market perceptions of the oil and gas industry;
uncertainty about current global economic conditions;
fluctuations in stock market price and volume; and
other general economic conditions.
The trading market for our common stock is influenced by the research and reports that industry or securities
analysts may publish about us, our business, our markets or our competitors. We do not have any control over these
analysts and we cannot provide any assurance that analysts will cover us or provide favorable coverage. If any of the
analysts who may cover us adversely change their recommendation regarding our stock, or provide more favorable
relative recommendations about our competitors, our stock price could materially decline. If any analyst who may cover
us were to cease coverage of our Company or fail to regularly publish reports on us, we could lose visibility in the
financial markets, which in turn could cause our stock price or trading volume to materially decline.
During 2020, our stock price on the NYSE ranged from a high of $166.50 per common share to a low of $10.50
per common share. In recent years, the stock market in general has experienced extreme price and volume fluctuations
23
that have affected the market price for many companies in industries similar to ours. Some of these fluctuations have
been unrelated to the operating performance of the affected companies. These market fluctuations may decrease the
market price of our common shares in the future.
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Provisions in our organizational documents may be insufficient to thwart a coercive hostile takeover attempt;
conversely, these provisions and those in our outstanding debt and Saudi joint venture documents may deter a change
of control transaction and decrease the likelihood of a shareholder receiving a change of
control premium.
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Companies generally seek to prevent coercive takeovers by parties unwilling to pay fair value for the enterprise
they acquire. Provisions in our organizational documents that are meant to help us avoid a coercive takeover include:
• Authorizing the Board to issue a significant number of common shares and up to 25,000,000 preferred
shares, as well as to determine the price, rights (including voting rights), conversion ratios, preferences and
privileges of the preferred shares, in each case without any vote or action by the holders of our common
shares;
•
Limiting the ability of our shareholders to call or bring business before special meetings;
• Adopting a shareholder rights plan that limits the number of our common shares a potential acquiror can
purchase without either securing the approval of our Board or having their voting interest severely diluted;
the plan is sscheduled to expire in April 2021 unless it is extended;
•
•
•
Prohibiting our shareholders from taking action by written consent in lieu of a meeting unless the consent is
signed by all the shareholders then entitled to vote;
Requiring advance notice of shareholder proposals for business to be conducted at general meetings and for
nomination of candidates for election to our Board; and
Reserving to our Board the ability to determine the number of directors comprising the full Board and to
fill vacancies or newly created seats on the Board.
Certain actions taken by us could make it easier for another party to acquire control of the Company. For
instance, in June 2012 we adopted an amendment to our bye-laws to declassify the Board and in 2017 we amended our
policy regarding nomination and proxy access for director candidates recommended by shareholders. Conversely, the
provisions designed to prevent hostile takeovers, or protect holders of our debt instruments and our joint venture partner,
may deter transactions in which shareholders would receive a change of control premium. For example, certain change
of control transactions could accelerate the principal amounts outstanding, and require premiums payments, under our
debt instruments, or trigger a call option to purchase our interest in SANAD, our joint venture with Saudi Aramco.
As a holding company, we depend on our operating subsidiaries and investments to meet our financial obligations.
We are a holding company with no significant assets other than the stock of our subsidiaries. In order to meet
our financial needs and obligations, we rely exclusively on repayments of interest and principal on intercompany loans
that we have made to operating subsidiaries and income from dividends and other cash flow from such subsidiaries.
There can be no assurance that such operating subsidiaries will generate sufficient net income to pay dividends or
sufficient cash flow to make payments of interest and principal to Nabors in respect of intercompany loans. In addition,
from time to time, such operating subsidiaries may enter into financing arrangements that contractually restrict or
prohibit these types of upstream payments to Nabors. Nabors’ debt instruments do not contain covenants prohibiting any
such contractual restrictions. There may also be adverse tax consequences associated with such operating subsidiaries
paying dividends. Finally, the ability of our subsidiaries to make distributions to us, may be restricted by the laws of the
applicable subsidiaries’ jurisdictions of organization and other laws and regulations. If subsidiaries are unable to
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distribute or otherwise make payments to us, we may not be able to pay interest or principal on obligations when due,
and we cannot assure you that we will be able to obtain the necessary funds from other sources.
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General Risks
Our business, results of operations and financial condition have been and may continue to be adversely impacted by
global public health epidemics, including the strain of coronavirus known as
COVID-19, and future adverse impacts
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could be material and difficult to predict.
The global spread of the strain of coronavirus known as COVID-19 and its variants, which was declared a
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global pandemic by the World Health Organization on March 11, 2020, has adversely impacted our operations and the
operations of our customers. The outbreak triggered a sharp sell-off in energy commodities markets during the first
quarter of 2020, as economic activity tumbled as a result of government impositions of mandatory closures, quarantines
and other restrictions on, or advisories with respect to, travel, business operations and public gatherings or interactions.
Certain jurisdictions recently have begun re-opening only to return to restrictions in the face of increases in new
COVID-19 cases, while other jurisdictions are continuing to re-open or have nearly completed the re-opening process
despite increases in COVID-19 cases. The pandemic may significantly worsen during the upcoming months, which may
cause governmental authorities to reconsider restrictions on business, travel, and other activities.
The significant weakness in oil and natural gas prices resulting from the COVID-19 pandemic has resulted in
sharp reductions in the exploration and production capital and operating budgets of our customers. Demand for our
services and associated product offerings, and the rates we are able to charge to customers, is closely tied to such
exploration and production activities and the significant price weakness and associated volatility surrounding these
events has had, and is likely to continue to have, an adverse impact on the demand for our services.
Future increases in commodity prices may not necessarily translate into the resumption of exploration and
production activities (and a corresponding demand for our services) because our customers’ expectations of future prices
may also influence or limit their activity. As a result of these factors, lower demand for drilling and drilling related
services may persist for a significant time, which would continue to materially adversely affect the rates that we are able
to charge our customers and the demand for our services.
The spread of the virus into our workforce may also prevent us from meeting the demands of our customers in
the future. For example, if the COVID-19 pandemic were to significantly impact a location where we have a high
concentration of business and resources, our local workforce could be affected by the outbreak, which could
significantly disrupt our operations or lead to a shutdown of operations in the impacted location.
Our business is subject to cybersecurity risks.
Our operations are increasingly dependent on information technologies and services. Threats to information
technology systems associated with cybersecurity risks and cyber incidents or attacks continue to grow, and include,
among other things, storms and natural disasters, terrorist attacks, utility outages, theft, viruses, phishing, malware,
design defects, human error, and complications encountered as existing systems are maintained, repaired, replaced, or
upgraded. Risks associated with these threats include, among other things:
•
•
•
•
•
•
•
theft or misappropriation of funds;
loss, corruption, or misappropriation of intellectual property, or other proprietary, confidential or personally
identifiable information (including customer, supplier, or employee data);
disruption or impairment of our and our customers’ business operations and safety procedures;
damage to our reputation with our customers and the market;
the perception of our products or services as having security vulnerabilities
exposure to litigation and legal and regulatory costs;
loss or damage to our worksite data delivery systems; and
25
•
increased costs to prevent, respond to or mitigate cybersecurity events.
Although we utilize various procedures and controls to mitigate our exposure to such risk, cybersecurity attacks
and other cyber events are evolving and unpredictable. Moreover, we have no control over the information technology
systems of our customers, suppliers, and others with which our systems may connect and communicate. As a result, the
occurrence of a cyber incident could go unnoticed for a period time.
We do not presently maintain insurance coverage to protect against cybersecurity risks. If we procure such
coverage in the future, we cannot ensure that it will be sufficient to cover any particular losses we may experience as a
ff
result of such cyberattacks. Any cyber incident could have a material adverse effect on our business, financial condition
and results of operations.
The loss of key executives or inability to attract and retain experienced technical personnel could reduce our
competitiveness and harm prospects for future success.
s
The successful execution of our business strategies depends, in part, on the continued service of certain key
executive officers and employees. We have employment agreements with some of our key personnel within the
company, but no assurance can be given that any employee will remain with us, whether or not they have entered into an
employment agreement. We do not carry key man insurance. In addition, our operations depend, in part, on our ability to
attract and retain experienced technical professionals. Competition for such professionals is intense. The loss of key
executive officers and/or our inability to retain or attract experienced technical personnel, could reduce our
competitiveness and harm prospects for future success, which may adversely affect our business, financial condition and
results of operations.
A downgrade in our credit rating could negatively impact our cost of and ability to access capital markets or other
financing sources.
Our ability to access capital markets or to otherwise obtain sufficient financing may be affected by our senior
unsecured debt ratings as provided by major U.S. credit rating agencies. Factors that may impact our credit ratings
include debt levels, asset purchases or sales, as well as near-term and long-term growth opportunities and industry
conditions. Liquidity, asset quality, cost structure, market diversity, and commodity pricing levels and other factors,
including the impact of COVID-19, are also considered by the rating agencies. Our senior unsecured debt has a non-
investment grade rating. Further ratings downgrades may impact our cost of capital and ability to access capital markets
or other financing sources, any of which could adversely affect our financial condition, results of operations and cash
ff
flows.
Changes in the method of determining LIBOR, or the replacement of LIBOR with an alternative reference rate, may
adversely affect interest expense related to outstanding debt.
Amounts drawn under the 2018 Revolving Credit Facility bear interest rates in relation to LIBOR. On July 27,
2017, the Financial Conduct Authority in the United Kingdom announced that it would phase out LIBOR as a
benchmark by the end of 2021. The date has since been extended, with the ICE Benchmark Administration, which
administers LIBOR, together with the United States Federal Reserve and the United Kingdom’s Financial Conduct
Authority, announcing plans to consult on ceasing publication of U.S. dollar LIBOR on December 31, 2021 for only the
one week and two month U.S. dollar LIBOR tenors, and on June 30, 2023 for all other U.S. dollar LIBOR tenors. The
United States Federal Reserve concurrently issued a statement advising banks to stop new US dollar LIBOR issuances
by the end of 2021.It is unclear whether new methods of calculating LIBOR will be established such that it continues to
exist after 2021. The U.S. Federal Reserve is considering replacing U.S. dollar LIBOR with a newly created index called
the Secured Overnight Financing Rate, calculated with a broad set of short-term repurchase agreements backed by
treasury securities. If LIBOR ceases to exist and a generally accepted market replacement is not available, we may need
to renegotiate the 2018 Revolving Credit Facility and may not able to do so with terms that are favorable to us. The
overall financial markets may be disrupted as a result of the phase-out or replacement of LIBOR. Disruption in the
financial market or the inability to renegotiate the 2018 Revolving Credit Facility with favorable terms could have a
material adverse effect on our financial condition, results of operations and cash flows.
f
26
We may be subject to changes in tax laws and have additional tax liabilities.
We operate through various subsidiaries in numerous countries throughout the world. Consequently, we are
subject to changes in tax laws, treaties or regulations or the interpretation or enforcement thereof in the United States or
jurisdictions in which we or any of our subsidiaries operate or are organized.
The Tax Cuts and Jobs Act of 2017 (“Tax Reform Act”) adopted sweeping changes to the U.S. Internal
Revenue Code which also could have a material adverse effect on our financial condition and results of operations. In
addition to lowering the U.S. corporate income tax rate and numerous other changes, the law imposes more stringent
limitations on the deductibility of interest expense and net operating losses, and imposes a type of minimum tax designed
to reduce the benefits derived from intercompany transactions and payments that result in base erosion. Tax laws,
treaties and regulations are highly complex and subject to interpretation. Our income tax expense is based upon our
interpretation of the tax laws in effect in various countries at the time that the expense was incurred. Although the Tax
Reform Act has not had a material impact on our financial statements to date, if these tax laws, treaties or regulations
change or any tax authority successfully challenges our assessment of the effects of such laws, treaties and regulations in
any country, including our operational structure, intercompany pricing policies or the taxable presence of our
subsidiaries in certain countries, this could have a material adverse effect on us, resulting in a higher effective tax rate on
our consolidated earnings or a reclassification of the tax impact of our significant corpor
ate restructuring transactions.
m
Our international operations expose us to compliance obligations and risks under the Fo
reign Corrupt Practices Act
i
and other applicable anti-corruption laws, and violations of these laws could have a negative impact on our business.
A significant portion of our revenue is derived from operations outside the United States, which exposes us to
compliance obligations and risks arising under complex foreign and U.S. regulations, which are inherent in engaging in
cross-border business and impact our operations in each of the countries in which we transact business. We are subject to
the United States Foreign Corrupt Practices Act (‘‘FCPA’’) and other similar anti-corruption laws, such as the Bermuda
Bribery Act (2016), which generally prohibit companies and their intermediaries from making improper payments to
foreign government officials for the purpose of obtaining or retaining business. The SEC and U.S. Department of Justice
have continued to focus on enforcement activities with respect to the FCPA. While our employees and agents are
required to comply with applicable anti-corruption laws, and we have adopted policies and procedures and related
training programs designed to promote and achieve compliance, we cannot ensure that our internal policies, procedures
and programs will always protect us from risks associated with unlawful acts carried out by our employees or agents.
Violations of these laws may result in significant criminal or civil penalties. The occurrence or allegation of violations
may adversely affect our business, financial condition and results of operations.
ITEM 1B. UNRESOLVED STAFF COMMENTS
Not applicable.
ITEM 2. PROPERTIES
Nabors’ principal executive offices are located in Hamilton, Bermuda. We own or lease executive and
administrative office space in Houston, Texas; Anchorage, Alaska; Calgary, Canada; Dubai in the United Arab Emirates;
Bogota, Colombia; Dhahran, Saudi Arabia; and Sandnes, Norway. Our principal physical properties are rigs which are
more fully described in Part I, Item 1.—Business.
Many of the international drilling rigs and some of the Alaska rigs in our fleet are supported by mobile camps
which house the drilling crews and a significant inventory of spare parts and supplies. In addition, we own various
f
trucks, forklifts, cranes, earth-moving and other construction and transportation equipment, which are used to support
our operations. We also own or lease a number of facilities and storage yards used in support of operations in each of our
geographic markets.
We own certain mineral interests in connection with our investment in development and production of natural
gas, oil and natural gas liquids in the United States.
27
ITEM 3. LEGAL PROCEEDINGS
Nabors and its subsidiaries are defendants or otherwise involved in a number of lawsuits in the ordinary course
of business. We estimate the range of our liability related to pending litigation when we believe the amount and range of
loss can be estimated. We record our best estimate of a loss when the loss is considered probable. When a liability is
probable and there is a range of estimated loss with no best estimate in the range, we record the minimum estimated
liability related to the lawsuits or claims. As additional information becomes available, we assess the potential liability
related to our pending litigation and claims and revise our estimates. Due to uncertainties related to the resolution of
lawsuits and claims, the ultimate outcome may differ from our estimates. For matters where an unfavorable outcome is
reasonably possible and significant, we disclose the nature of the matter and a range of potential exposure, unless an
estimate cannot be made at the time of disclosure. In the opinion of mana
provided, our ultimate exposure with respect to these pending lawsuits and claims is not expected to have a material
adverse effect on our consolidated financial position or cash flows, although they could have a material adverse effect on
our results of operations for a particular reporting period. See Note 15 — Commitments and Contingencies in Part II,
Item 8.—Financial Statements and Supplementary Data for a description of such proceedings.
gement and based on liability accruals
aa
f
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
PART II
ITEM 5. MARKET PRICE OF AND DIVIDENDS ON THE REGISTRANT’S COMMON EQUITY, RELATED
N
SHAREHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information.
Our common shares, par value $0.05 per share, are publicly traded on the New York Stock Exchange (the
“NYSE”) under the symbol “NBR”.
On February 19, 2021, the closing price of our common shares as reported on the NYSE was $87.47.
Holders.
At February 19, 2021, there were approximately 1,774 shareholders of record of our common shares.
Dividends.
On February 23, 2021, our Board declared cash dividends of $0.75 per outstanding share of our 6.00%
Mandatory Convertible Preferred Shares, Series A, par value $0.001 per share, which will be paid on May 3, 2021, to
holders presenting the Preferred Shares for conversion.
The declaration and payment of future dividends will be at the discretion of the Board and will depend, among
other things, on future earnings, general financial condition and liquidity, success in business activities, capital
requirements and general business conditions in addition to legal requirements.
—
investments to meet our financial obligations.
See Part I, Item 1A.—Risk Factors—As a holding company, we depend on our operating subsidiaries and
28
Issuer Purchases of Equity Securities.
The following table provides information relating to our repurchase of common shares during the three months
ended December 31, 2020:
Period
(In thousands, except per share amounts)
October 1 - Octobe
r 31 . . . . . . . . . . . . . . . . . . .
November 1 - November 30 . . . . . . . . . . . . . . .
r
December 1 - Decembe
r 31 . . . . . . . . . . . . . . .
r
r
Average
Total
Number of
Shares
Price
Paid per
Repurchased Share (1)
Total Number
of Shares
Purchased as
Part of Publicly
Announced
Program
Approximated
Dollar Value of
Shares that May
Yet Be
Purchased
Under the
Program (2)
1 $
—
— $
—
— $
24.41
38.32
52.46
—
—
—
—
—
—
278,914
278,914
278,914
(1)
(2)
Shares were withheld from employees and directors to satisfy certain tax withholding obligations due in
connection with grants of shares under our Amended and Restated 2016 Stock Plan. Each of the Amended and
Restated 2016 Stock Plan, the 2003 Employee Stock Plan and the 1999 Stock Option Plan for Non-Employee
Directors provide for the withholding of shares to satisfy tax obligations, but do not specify a maximum number
of shares that can be withheld for this purpose. These shares were not purchased as part of a publicly announced
program to purchase common shares.
In August 2015, our Board authorized a share repurchase program under which we may repurchase up to
$400.0 million of our common shares in the open market or in privately negotiated transactions. The program
was renewed by the Board in February 2019. Through December 31, 2020, we had repurchased 0.3 million of
our common shares for an aggregate purchase price of approximately $121.1 million under this program. As of
December 31, 2020, we had approximately $278.9 million that remained authorized under the program that
may be used to repurchase shares. The repurchased shares are held by certain of our Bermuda subsidiaries and
are registered and tradable subject to applicable securities law limitations and have the same voting, dividend
and other rights as other outstanding shares. As of December 31, 2020, our subsidiaries held 1.1 million of our
common shares.
29
Performance Graph
The following graph illustrates comparisons of five-year cumulative total returns among Nabors, the S&P 500
r
Index, S&P SmallCap 600 Index, Russell 3000 Index and Dow Jones Oil Equipment and Services Index. We present all
these indices. Total return assumes $100 invested on December 31, 2015 in shares of Nabors and in the aforementioned
indices noted above assuming reinvestment of dividends at the end of each calendar year, presented in the table below.
200
150
100
50
s
r
a
l
l
o
D
0
2015
2016
2017
2018
2019
2020
Nabors Industries Ltd.
S&P SmallCap 600 Index
Dow Jones Oil Equipment and Services Index
S&P 500 Index
Russell 3000 Index
As of December 31,
2015 2016 2017 2018 2019 2020
16
Nabors Industries Ltd. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 197
S&P 500 Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 112 136 130 171 203
S&P SmallCap 600 Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 127 143 131 161 179
Russell 3000 Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 113 137 129 170 205
Dow Jones Oil Equipment and Services Index . . . . . . . . . . . . . . . . . . . . . . . . . .
40
100 127 106
85
61
66
26
38
The foregoing graph is based on historical data and is not necessarily indicative of future performance. This
graph shall not be deemed to be “soliciting material” or “filed” with the SEC or subject to Regulations 14A or 14C under
the Exchange Act or to the liabilities of Section 18 under the Exchange Act.
Related Shareholder Matters
Bermuda has exchange controls which apply to residents in respect of the Bermuda dollar. As an exempted
company, Nabors is designated as non-resident for Bermuda exchange control purposes by the Bermuda Monetary
Authority. Pursuant to our non-resident status, there are no Bermuda restrictions on our ability to transfer funds (other
than funds denominated in Bermuda dollars) in and out of Bermuda or to pay dividends to non-residents who are holders
of our common shares in all other currencies, including currency of the United States.
30
There is no reciprocal tax treaty between Bermuda and the United States. Under current Bermuda law, there is
no Bermuda withholding tax on dividends or other distributions, nor any Bermuda tax computed on profit or income
payable by Nabors or its operations. Furthermore, no Bermuda tax is levied on the sale or transfer (including by gift
and/or on the death of the shareholder) of Nabors common shares (other than by shareholders resident in Bermuda).
Nabors has received an undertaking from the Minister of Finance in Bermuda that, in the event of any taxes being
imposed, Nabors will be exempt from taxation in Bermuda until March 31, 2035.
ITEM 6. SELECTED FINANCIAL DATA
The following table summarizes selected financial information and should be read in conjunction with
Part II, Item 7.—Management’s Discussion and Analysis of Financial Condition and Results of Operations and our
consolidated financial statements and related notes thereto included under Part II, Item 8.—Financial Statements and
Supplementary Data.
Operating Data (1)(2)
Operating revenues . . . . . . . . . . . . . . . . . . . . . . $ 2,134,043 $ 3,043,383 $ 3,057,619 $ 2,564,285 $ 2,227,839
Income (loss) from continuing operations,
2020
Year Ended December 31,
2018
(In thousands, except per share amounts and ratio data)
2017
2019
2016
net of tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(762,853)
(680,498)
(598,063)
(497,114)
(1,011,244)
Income (loss) from discontinued operations,
net of tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net income (loss) . . . . . . . . . . . . . . . . . . . . . . .
Less: Net (income) loss attributable to
noncontrolling interest . . . . . . . . . . . . . . . . . .
Net income (loss) attributable to Nabors . . . . .
Less: Preferred stock dividend . . . . . . . . . . . . .
Net income (loss) attributable to Nabors
7
(762,846)
(12)
(680,510)
(14,663)
(612,726)
(43,519)
(540,633)
(18,363)
(1,029,607)
(42,795)
(805,641)
(14,611)
(22,375)
(702,885)
(17,244)
(28,222)
(640,948)
(12,305)
(6,178)
(546,811)
—
(135)
(1,029,742)
—
common shareholders . . . . . . . . . . . . . . . . . .
(820,252)
(720,129)
(653,253)
(546,811)
(1,029,742)
Earnings (losses) per share:
Basic from continuing operations . . . . . . . . $ (118.69) $ (105.39) $
Basic from discontinued operations . . . . . .
—
—
—
Total Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (118.69) $ (105.39) $
Diluted from continuing operations . . . . . . $ (118.69) $ (105.39) $
Diluted from discontinued operations . . . . .
—
—
—
Total Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (118.69) $ (105.39) $
(97.42) $
(2.19)
(99.61) $
(87.31) $
(7.75)
(95.06) $
(178.80)
(3.32)
(182.12)
(97.42) $
(2.19)
(99.61) $
(87.31) $
(7.75)
(95.06) $
(178.80)
(3.32)
(182.12)
Weighted-average number of common
shares outstanding:
Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7,059
7,059
7,032
7,032
6,688
6,688
5,613
5,613
5,530
5,530
Cash dividends declared per common share . . $
0.50 $
2.00 $
12.00 $
12.00 $
12.00
Capital expenditures and acquisitions of
businesses (3) . . . . . . . . . . . . . . . . . . . . . . . . . $ 189,706 $ 423,967 $ 478,435 $ 769,848 $
414,379
31
Balance Sheet Data (1)(2)
Cash, cash equivalents and short-term
2020
2019
As of December 31,
2018
(In thousands, except ratio data)
2017
2016
investments . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 481,746 $ 452,496 $
Working capital . . . . . . . . . . . . . . . . . . . . . . . . .
Property, plant and equipment, net . . . . . . . . .
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . .
Shareholders’ equitytt . . . . . . . . . . . . . . . . . . . . .
t
615,996
3,985,
707
5,503,428
2,968,701
1,151,384
592,118
4,930,549
6,760,658
3,333,220
1,982,811
481,802 $
761,486
5,467,870
7,853,944
3,585,884
2,700,850
365,366 $
527,860
6,109,565
8,401,984
4,027,766
2,911,816
295,202
333,905
6,267,583
8,187,015
3,578,335
3,247,025
(1)
(2)
All periods present the operating activities of most of our wholly owned oil and gas businesses and our
previously held equity interests in oil and gas joint ventures in Canada and Colombia as discontinued
operations.
Our acquisitions’ results of operations and financial position have been included beginning on the respective
dates of acquisition and include PetroMar Technologies (October 2018), SANAD (December 2017), Tesco
(December 2017), and RDS (September 2017). Following consummation of the merger of our Completion &
Production Services business with C&J Energy (March 2015), we ceased consolidating that business’s results
with our results of operations and began reporting our share of the earnings (losses) of CJES through earnings
(losses) from unconsolidated affiliates in our consolidated statements of income (loss). As a result of the CJES
Chapter 11 filing, we ceased accounting for our investment in CJES under the equity method of accounting
beginning on July 20, 2016.
(3)
Represents capital expenditures and the total purchase price of acquisitions.
32
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
The following discussion and analysis of our financial condition and results of operations is based on, and
should be read in conjunction with, our consolidated financial statements and the related notes thereto included under
Part II, Item 8.—Financial Statements and Supplementary Data. This discussion and analysis contains forward-looking
statements that involve risks and uncertainties. Actual results may differ materially from those anticipated in these
forward-looking statements as a result of certain factors, including those set forth under Part I, Item 1A.—Risk Factors
and elsewhere in this annual report. See “Forward-Looking Statements.”
Management Overview
We own and operate one of the world’s largest land-based drilling rig fleets and provide offshore rigs in the
United States and numerous international markets. Our business is comprised of our global land-based and offshore
drilling rig operations and other rig related services and technologies. These services include tubular services, wellbore
placement solutions, directional drilling, measurement-while-drilling, logging-while-drilling systems and services,
equipment manufacturing, rig instrumentation and optimization software.
dd
Outlook
The demand for our services is a function of the level of spending by oil and gas companies for exploration,
development and production activities. The primary driver of customer spending is their cash flow and earnings which
are largely driven by oil and natural gas prices and customers’ production volumes. The oil and natural gas markets have
traditionally been volatile and tend to be highly sensitive to supply and demand cycles.
During 2020, the oil markets experienced unprecedented volatility. The COVID-19 outbreak, and its
development into a pandemic, along with policies and actions taken by governments and companies and behaviors of
customers around the world, had a significant negative impact on demand for oil. Additionally, production decisions by
large oil and natural gas producing countries taken around the start of the pandemic led to increased oil production and
supply. These actions drove oil prices down, leading many of our customers to make significant cuts in their activity,
which has negatively affected our operating results and cash flow. The Lower-48 rig market began to stabilize during
the second half of 2020. We expect measured but steady increases in activity throughout 2021 for the Lower-48 market.
Our International markets have also experienced factors and conditions that have led to similar reductions in activity
throughout 2020, but the impact has varied considerably from country to country. Activity declined more rapidly in
some jurisdictions than others throughout the year. We believe that activity is going to increase modestly throughout
2021, and we have already started to see a return to activity from some of the stricter governmental restrictions in some
countries already.
Recent Developments
In January 2020, Nabors completed a private offering of $600.0 million aggregate principal amount of 7.25%
f
senior guaranteed notes due 2026 (the “2026 Notes”) and $400.0 million aggregate principal amount of 7.50% senior
guaranteed notes due 2028 (the “2028 Notes” and, together with the 2026 Notes, the “2026/2028 Notes”). 2026/2028
Notes are fully and unconditionally guaranteed by certain of Nabors’ indirect wholly owned subsidiaries (the
“2026/2028 Notes Guarantors”). The proceeds from the offering were used primarily to repurchase approximately
$952.9 million aggregate principal amount, for a net premium of $2.7 million (excluding accrued interest), of certain of
Nabors Delaware’s senior notes in a tender offer (the “January 2020 Tender Offers”). The aggregate principal amounts
repurchased in the January 2020 Tender Offers included approximately (i)$407.7 million of Nabors Delaware’s 5.50%
senior notes due 2023, (ii) $379.7 million of Nabors Delaware’s 4.625% senior notes due 2021 and (iii) $165.5 million
of Nabors Delaware’s 5.10% senior notes due 2023. The remaining proceeds were available for transaction expenses and
for general corporate purposes, including the repayment of certain other debt. See Note 10 – Debt to the consolidated
financial statements included in Item 8 of the report for additional information regarding the issuance of the 2026/2028
Notes and the January 2020 Tender Offers.
At a special meeting of shareholders held April 20, 2020, our shareholders authorized a reverse stock split (the
“Reverse Stock Split”) at a ratio of not less than 1-for-15 and not greater than 1-for-50, with the exact ratio to be set
within that range at the sole direction of our Board. On April 20, 2020, the Board set the Reverse Stock Split ratio at 1-
33
for-50. As a result of the Reverse Stock Split, 50 pre-reverse split common shares were automatically combined into one
new common share, without any action on the part of the shareholders. Our authorized number of common shares were
also proportionally decreased from 800,000,000 to 16,000,000 common shares. Subsequently, the par value of each
common share was proportionally increased from $0.001 to $0.05. In addition, at the special meeting, the shareholders
authorized an increase in our common share capital by 100% following the Reverse Stock Split, to $1,600,000, resulting
in an increase in the number of authorized shares to 32,000,000. No fractional common shares were issued as a result of
the Reverse Stock Split. Any fractional common shares of registered holders resulting from the Reverse Stock Split were
rounded up to the nearest whole share. Unless otherwise noted, all share and per share information included in this
annual report has been retrospectively adjusted to reflect this Reverse Stock Split.
t
On May 5, 2020, our Board adopted a shareholder rights plan and declared a dividend of one right (a “Right”)
for each outstanding common share to shareholders of record on May 15, 2020. Each Right entitles the holder to
purchase from Nabors one one-thousandth of a Series B Junior Participating Preferred Share, par value $0.001 per share
(the “Series B Preferred Shares’), of Nabors at a price of $58.08 per one one-thousandth of a Series B Preferred Share,
subject to adjustment. The description of the Rights are set forth in a Rights Agreement, dated May 5, 2020 (the “Rights
Agreement”), by and between Nabors and Computershare Trust Company, N.A., as Rights Agent. See Note 12 –
Shareholders’ Equity in Part II, Item 8.—Financial Statements and Supplementary Data for additional information
regarding the shareholder rights plan.
During the fourth quarter of 2020, we entered into a series of public and private exchange transactions (the
“2020 Exchanges”) whereby Nabors Delaware exchanged certain aggregate principal amounts of newly issued 6.5%
Senior Priority Guaranteed Notes due 2025 (the “6.5% Exchange Notes”) and certain aggregate principal amounts of
newly issued 9.0% Senior Priority Guaranteed Notes due 2025 (the “9.0% Exchange Notes,” and collectively, the
“Exchange Notes”) in exchange for various series and principal amounts of our and Nabors Delaware’s previously
outstanding debt securities. Each series of Exchange Notes was guaranteed by (i) the Company, (ii) each of the
2026/2028 Notes Guarantors and (iii) certain lower tier subsidiaries of the Company that guarantee the Company’s 2018
Revolving Credit Facility but do not guarantee the 2026/2028 Notes (the “Lower Tier Guarantors,” and together with the
Company and the 2026/2028 Guarantors, the “Exchange Notes Guarantors”). Nabors Delaware did not receive any cash
proceeds from the issuance of the Exchange Notes. The guarantees of the Exchange Notes by the Lower Tier Guarantors
are contractually subordinate in right of payment to such subsidiaries’ guarantee of certain senior guaranteed debt,
including obligations under our 2018 Revolving Credit Facility.
The 2020 Exchanges collectively resulted in the exchange of $526.8 million aggregate principal amount of
various series of existing debt for $50.5 million aggregate principal amount of newly issued 6.5% Exchange Notes and
$192.0 million aggregate principal amount of newly issued 9.0% Exchange Notes. See Note 10 – Debt in Part II, Item
8—Financial Statements and Supplementary Data,for additional information regarding the exchange.
In January 2021, Nabors Delaware completed additional exchange transactions whereby (i) $35.0 million
aggregate principal amount of its 0.75% Senior Exchangeable Notes due 2024 (the “0.75% Exchangeable Notes”) and
(ii) $5.0 million of its 5.75% Senior Notes due 2025 (the “5.75% Senior Notes”) were exchanged for an additional
issuance of $26.05 million of 9.0% Exchange Notes.
Financial Results
Comparison of the years ended December 31, 2020 and 2019
Operating revenues in 2020 totaled $2.1 billion, representing a decrease of $909.3 million from 2019. The
primary driver was a decrease in U.S. activity in response to the rapid decline in global market conditions as previously
discussed. This is evidenced by the 41% decline in average rigs working within our U.S. Drilling operating segment.
This market decline led to a decrease in operating revenue across virtually all our operating segments. Our segments
where the activity is predominately located in the U.S. experienced a 40% -50% decline in revenue while our
International and Canada segments experienced a less dramatic decline in the range of 15%-20%. For a more detailed
aa
description of operating results see —Segment Results of Operations, below.
Net loss from continuing operations attributable to Nabors common shareholders totaled $820.3 million for
2020 ($118.69 per diluted share) compared to a net loss from continuing operations attributable to Nabors common
shareholders of $720.1 million ($105.39 per diluted share) in 2019, or a $100.1 million increase in the net loss. This
34
increase in the net loss is primarily due to the previously discussed weakened global market conditions, brought about in
part by the outbreak of COVID-19, and the resultant unprecedented volatility in the oil markets. These factors led to a
significant decline in oil prices resulting from oversupply and demand weakness, which in turn has had a significant
impact on our operating results. Also contributing to the higher net loss was a $108.7 million increase in Impairments
and other charges taken in 2020 compared to 2019, due in large part to the market conditions experienced during 2020.
The $228.3 million of gains realized from the exchange transactions and repurchases of debt, partially offset these items.
General and administrative expenses in 2020 totaled $203.5 million, representing a decrease of $55.2 million,
or 21% from 2019. This is reflective of a reduction in workforce and general cost-reduction efforts across our operating
segments and our corporate offices due to current industry market conditions.
Research and engineering expenses in 2020 totaled $33.6 million, representing a decrease of $16.8 million, or
33%, from 2019. The decrease is attributable to reductions in staffing levels and other cost control efforts across many of
our research and engineering projects and initiatives due to current industry market conditions.
Depreciation and amortization expense in 2020 was $853.7 million, representing a decrease of $22.4 million, or
3%, from 2019. The decrease is primarily due to reduction in rig activity, limited capital expenditures over recent years
and the effect of recent impairments and retirements of long-lived assets.
Segment Results of Operations
Our business consists of five reportable segments: U.S. Drilling, Canada Drilling, International Drilling,
Drilling Solutions and Rig Technologies.
Management evaluates the performance of our reportable segments using adjusted operating income (loss),
which is our segment performance measure, because it believes that this financial measure reflects our ongoing
profitability and performance. In addition, securities analysts and investors use this measure as one of the metrics on
which they analyze our performance. Adjusted operating income (loss) represents income (loss) from continuing
operations before income taxes, interest expense, earnings (losses) from unconsolidated affiliates, investment income
(loss), (gain)/loss on debt buybacks and exchanges, impairments and other charges and other, net. A reconciliation of
adjusted operating income to net income (loss) from continuing operations before income taxes can be found in Note
19—Segment Information in Part II, Item 8. —Financial Statements and Supplementary Data.
t
35
The following tables set forth certain information with respect to our reportable segments and rig activity:
U.S. Drilling
Year Ended December 31,
2020
2019
Increase/(Decrease)
2020 to 2019
(In thousands, except percentages and rig activity)
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 713,057 $ 1,240,936 $ (527,879)
64,313 $ (160,489)
Adjusted operating income (loss) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(47.4)
Average rigs working (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(96,176) $
67.9
115.3
(43)%
(250)%
(41)%
Canada Drilling
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Adjusted operating income (loss) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Average rigs working (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
54,753 $
(11,766) $
9.0
68,274 $ (13,521)
2,717
(14,483) $
(1.9)
10.9
(20)%
19 %
(17)%
International Drilling
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,131,673 $ 1,324,142 $ (192,469)
(8,903) $ (47,302)
Adjusted operating income (loss) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(12.6)
Average rigs working (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(56,205) $
75.7
88.3
(15)%
(531)%
(14)%
Drilling Solutions
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 149,834 $
6,167 $
Adjusted operating income (loss) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
252,790 $ (102,956)
59,465 $ (53,298)
(41)%
(90)%
Rig Technologies
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 131,555 $
(13,481) $
Adjusted operating income (loss) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
260,226 $ (128,671)
(2,234)
(11,247) $
(49)%
(20)%
(1)
(2)
Adjusted operating income (loss) is our measure of segment profit and loss. See Note 19 – Segment
Information to the consolidated financial statements included in Item 8 of the report.
Represents a measure of the number of equivalent rigs operating during a given period. For example, one rig
operating 182.5 days during a 365-day period represents 0.5 average rigs working.
U.S. Drilling
due to a
Operating revenues decreased by $527.9 million or 43% in 2020 compared to 2019 primarily due to a
significant decrease in activity brought about by the weakened market conditions discussed above. This is reflected by a
. This is reflected by a
41% decrease in the average number of rigs working. The reduction in revenues was partially offset by significant cost
e number of rigs working. The reduction in revenues was partially offset by significant cost
reductions, which are also related to the drop in activity.
reductions, which are also related to the drop in activity.
Canada Drilling
Operating revenues decreased by $13.5 million or 20% in 2020 compared to 2019 primarily due to a decline in
activity as a result of the weakened global market conditions. This is reflected by the 19% decline in average rigs
working and decreased day rates. However, cost reduction actions more than offset the drop in revenue.
International Drilling
primarily due to reduced
Operating revenues decreased by $192.5 million or 15% in 2020 compared to 2019 primarily due to reduced
activity, as reflected by the 14% decrease in the average number of rigs working, as certain countries implemented
ber of rigs working, as certain countries implemented
measures to counter COVID-19. The reduction in revenues was partially offset by significant cost reductions related to
measures to counter COVID-19. The reduction in revenues was partially offset by significant cost reductions related to
the drop in activity.
the drop in activity.
Drilling Solutions
primarily due to the reduced
Operating revenues decreased by $103.0 million or 41% in 2020 compared to 2019 primarily due to the reduced
activity across the U.S. as the market softened in response to
The reduction in activity and operating revenues was partially o
labor and repair and maintenance costs as well as an overall reduction in administrative expenses.
reduced oil prices and market conditions discussed above.
ffset by cost management initiatives mainly focusing on
g
y
g
y
36
Rig Technologies
Operating revenues decreased $128.7 million or 49%
Operating revenues decreased $128.7 million or 49% in 20
20 compared to 2019 due to the overall decline in
activity in the U.S. as mentioned previously. Despite the
activity in the U.S. as mentioned previously
reduction measures to mitigate almost all the impact.
drop in revenues, this segment enacted significant cost
Other Financial Information
Interest expense
Interest expense for 2020 was $206.3 million, representing an increase of $2.0 million, or 1%, compared to
2019. The increase was primarily due to the higher interest rates on the 2026 Notes and the 2028 Notes, which were
issued in January 2020, compared to the lower interest rate debt that was repurchased in the January 2020 Tender Offers
using the proceeds from that offering.
Gain on debt buybacks and exchanges
Gain on debt buybacks and exchanges was $228.3 million, representing an increase of $216.8 million compared
to 2019. Approximately $161.8 million of this amount is due to the debt exchanges completed in the fourth quarter of
2020. The remaining $66.5 million is primarily attributable to open market purchases of debt throughout the year.
Impairments and other charges
Impairments and other charges for 2020 was $410.6 million. The increase was due to the outbreak of COVID-
19 and the oil market experiencing unprecedented volatility leading to a significant decline in oil prices resulting from
oversupply and demand weakness in early 2020. These charges included impairment charges, and retirement provisions
of long-lived assets of $260.5 million comprised of underutilized rigs and drilling-related equipment across all our
operating segments. We also recognized $111.4 million in impairments to our remaining goodwill and intangible asset
balances in our Drilling Solutions and Rig Technologies operating segments.
Impairments and other charges for 2019 were $301.9 million, which primarily consisted of $203.7 million of
impairments to goodwill and intangible assets primarily as the result of a sustained decline in our market capitalization
and lower future cash flow projections due to expectations for future commodity prices below previous projections and
the resulting impact on the lower demand projections for our products and services within these reporting units. We
recognized goodwill impairments for the remaining balances of $75.6 million attributable to our International Drilling
operating segment, $52.2 million attributable to our U.S. Drilling operating segment and $28.1 million attributable to the
acquisition of 2TD reported within our Rig Technologies operating segment. Additionally, we recognized an impairment
of $47.7 million to write off the intangible asset due to uncertainty in commercialization and demand stemming from
lower commodity prices and rig counts.
The balance of $98.3 million consisted of impairments and retirement provisions for several tangible and other
assets. These assets included some of our older and smaller rigs in our Canada and International Drilling rig fleets of
$17.8 million and $17.9 million, respectively, $11.4 reserve for inventory obsolescence in our Rig Technologies segment
and $43.2 million in various receivables or other assets impacted by foreign sanctions or other political risk issues,
bankruptcies or other financial problems.
Other, net
Other, net for 2020 was $28.6 million of loss, which included foreign currency exchange loss of $13.2 million,
net losses on sales and disposals of assets of approximately $12.4 million and an increase in litigation reserves of $4.2
million.
Other, net for 2019 was $33.2 million of expense, which included foreign currency exchange losses of $20.9
million, net losses on sales and disposals of assets of approximately $7.1 million and an increase in litigation reserves of
$5.2 million.
37
Income taxes
Our worldwide income tax expense for 2020 was $57.3 million compared to $91.6 million for 2019. The
decrease in tax expense was primarily attributable to a decrease in operating income in the jurisdictions in which we
operate, as well as the change in our geographic mix of our pre-tax earnings (losses) . The decrease was partially offset
by the gain related to our debt exchange transaction and the resulting utilization of net operating losses.
Liquidity and Capital Resources
Financial Condition and Sources of Liquidity
Our primary sources of liquidity are cash and investments, availability under our revolving credit facility and
cash generated from operations. As of December 31, 2020, we had cash and short-term investments of $481.7 million
and working capital of $616.0 million. As of December 31, 2019, we had cash and short-term investments of $452.5
million and working capital of $592.1 million.
At December 31, 2020, we had $672.5 million of borrowings outstanding under the 2018 Revolving Credit
Facility, which has a total borrowing capacity of $1.014 billion. The 2018 Revolving Credit Facility requires us to
maintain “minimum liquidity” of no less than $160.0 million at all times, and an asset to debt coverage ratio of at least
4.25:1 as of the end of each calendar quarter. Minimum liquidity is defined to mean, generally, a consolidated cash
balance consisting of (a) the aggregate amount of unrestricted cash and cash equivalents maintained in a deposit account
U.S. or Canadian branch of a commercial bank, plus (b) the lesser of $75 million or an amount equal to 75% of the
aggregate amount of unrestricted cash and cash equivalents held in deposit account of a commercial bank outside of the
U.S. or Canada, plus (c) available commitments under the 2018 Revolving Credit Facility. The asset to debt coverage
ratio applies only during the period which Nabors Delaware fails to maintain an investment grade rating from at least
two rating agencies, which was the case as of the date of this report. As of December 31, 2020, we were in compliance
with both the minimum liquidity and asset to debt coverage ratio requirements under the 2018 Revolving Credit Facility.
We also had $57.6 million of letters of credit outstanding under the 2018 Revolving Credit Facility.
As of the date of this report, we were in compliance with all covenants under the 2018 Revolving Credit
Facility. If we fail to perform our obligations under the covenants, the revolving credit commitments under the 2018
Revolving Credit Facility could be terminated, and any outstanding borrowings under the facilities could be declared
immediately due and payable. If necessary, we have the ability to manage our covenant compliance by taking certain
actions including reductions in discretionary capital or other types of controllable expenditures, monetization of assets,
amending or renegotiating the revolving credit agreement, accessing capital markets through a variety of alternative
methods, or any combination of these alternatives. We expect to remain in compliance with all covenants under the 2018
Revolving Credit Facility during the twelve month period following the date of this report based on our current
operational and financial projections. However, we can make no assurance of continued compliance if our current
projections or material underlying assumptions prove to be incorrect. If we fail to comply with the covenants, the
revolving credit commitment could be terminated, and any outstanding borrowings under the facility could be declared
immediately due and payable.
Our ability to access capital markets or to otherwise obtain sufficient financing may be affected by our senior
unsecured debt ratings as provided by the major credit rating agencies in the United States and our historical ability to
access these markets as needed. While there can be no assurances that we will be able to access these markets in the
future, we believe that we will be able to access capital markets or otherwise obtain financing in order to satisfy any
payment obligation that might arise upon maturity, exchange or purchase of our notes and our debt facilities, loss of
availability of our revolving credit facilities and our A/R Agreement (see—Accounts Receivable Sales Agreement,
t
below), and that any cash payment due, in addition to our other cash obligations, would not ultimately have a material
adverse impact on our liquidity or financial position. The major U.S. credit rating agencies have previously downgraded
a
our senior unsecured debt rating to non-investment grade. These and any further ratings downgrades could adversely
impact our ability to access debt markets in the future, increase the cost of future debt, and potentially require us to post
letters of credit for certain obligations. See Part I, Item 1A.—Risk Factors—A downgrade in our credit rating could
negatively impact our cost of and ability to access capital markets or other financing sources.
—
rr
r
38
We had 18 letter-of-credit facilities with various banks outstanding as of December 31, 2020. Availability under
these facilities was as follows:
Credit available . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: Letters of credit outstanding, inclusive of financial and performance guarantees . . . . . . . . . . . . . .
Remaining availabilitytt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
December 31,
2020
(In thousands)
630,552
$
114,984
515,569
$
We are a holding company and therefore rely exclusively on repayments of interest and principal on
intercompany loans that we have made to our operating subsidiaries and income from dividends and other cash flows
from our operating subsidiaries. There can be no assurance that our operating subsidiaries will generate sufficient net
income to pay us dividends or sufficient cash flows to make payments of interest and principal to us. See Part I.,
Item 1A.—Risk Factors—As a holding company, we depend on our operating subsidiaries and investments to meet our
financial obligations.
—
Accounts Receivable Sales Agreement
On September 13, 2019, we entered into a $250.0 million accounts receivable sales agreement (the “A/R
Agreement”) whereby certain U.S. operating subsidiaries of the Company (collectively, the “Originators”) sold or
contributed, and will on an ongoing basis continue to sell or contribute, certain of its domestic trade accounts receivables
to a wholly owned, bankruptcy-remote, special purpose entity (the “SPE”). The SPE would in turn, sell, transfer, convey
and assign to third-party financial institutions (the “Purchasers”), all the rights, title and interest in and to its pool of
eligible receivables. The sale of these receivables qualified for sale accounting treatment in accordance with ASC 860.
The amount available for purchase under the A/R Agreement fluctuates over time based on the total amount of
eligible receivables generated during the normal course of business after excluding excess concentrations and certain
other ineligible receivables. The maximum purchase commitment of the Purchasers under the A/R Agreement is
approximately $250.0 million, and the amount of receivables purchased by the Purchasers as of December 31, 2020 was
$54.0 million. As of December 31, 2020, the total amount of eligible receivables available for purchase by the
Purchasers was $67.0 million. See further details at Note 4 — Accounts Receivable Sale Agreement in Part II, Item 8. —
Financial Statements and Supplementary Data.
Future Cash Requirements
Our current cash and investments, projected cash flows from operations, proceeds from equity or debt issuances
and our 2018 Revolving Credit Facility are expected to adequately finance our purchase commitments, capital
expenditures, acquisitions, scheduled debt service requirements, and all other expected cash requirements for the next 12
months including the $86.5 million outstanding of the 4.625% senior notes due September 2021. However, we can
make no assurances that our current operational and financial projections will prove to be correct, especially in light of
the effects the COVID-19 pandemic has on oil and natural gas prices and, in turn, our business. A sustained period of
COVID-19 pandemic has on oil and natural gas prices and, in turn, our business. A sustained period of
highly depressed oil and natural gas prices could have a significant effect on our customers’ capital expenditure spending
highly depressed oil and natural gas prices could have a significant effect on our customers’ capital expenditure spending
and therefore our operations, cash flows and liquidity.
y
Purchase commitments outstanding at December 31, 2020 totaled approximately $110.1 million, primarily for
rig-related enhancements, sustaining capital expenditures, operating expenses and purchases of inventory. We can
reduce planned expenditures if necessary or increase them if market conditions and new business opportunities warrant
f
it. The level of our outstanding purchase commitments and our expected level of capital expenditures over the next 12
months represent a number of capital programs that are currently underway or planned.
We may from time to time seek to retire or purchase our outstanding debt through cash purchases and/or
exchanges for equity securities, both in open-market purchases, privately negotiated transactions or otherwise. Such
repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual
restrictions and other factors and may involve material amounts.
39
See our discussion of guarantees issued by Nabors that could have a potential impact on our financial position,
results of operations or cash flows in future periods included below under “Off-Balance Sheet Arrangements (Including
Guarantees)”.
The following table summarizes our contractual cash obligations as of December 31, 2020:
Total
< 1 Year
1-3 Years
3-5 Years
More than 5 years
Payments due by Period
(In thousands)
Contractual cash obligations:
Long-term debt: (1)
Principal . . . . . . . . . . . . . . . . . . . . . $ 3,036,105 $ 86,500 (2) $ 822,361 (3) $ 1,177,657 (4) $
Interest . . . . . . . . . . . . . . . . . . . . . .
Operating leases (6) . . . . . . . . . . . . .
Purchase commitments (7) . . . . . . .
313,141
11,775
324
163,434
10,030
109,138
794,309
41,812
110,123
224,383
4,831
—
—
949,587 (5)
93,351
15,176
661
The table above excludes liabilities for uncertain tax positions totaling $26.7 million as of December 31, 2020 because
we are unable to make reasonably reliable estimates of the timing of cash settlements with the respective taxing
aa
authorities. Further details on the uncertain tax positions can be found in Note 11—Income Taxes in Part II, Item 8.—
Financial Statements and Supplementary Data.
(1)
(2)
(3)
(4)
(5)
(6)
(7)
See Note 10—Debt in Part II, Item 8.—Financial Statements and Supplementary Data.
Represents the aggregate principal amount of Nabors Delaware’s 4.625% senior notes due September 2021.
Represents the aggregate principal amount of Nabors Delaware’s 5.50% senior notes due January 2023, our
5.10% senior notes due September 2023 and our 2018 Revolving Credit Facility due October 2023.
Represents Nabors Delaware’s 0.75% senior exchangeable notes due January 2024, 5.75% senior notes due
January 2025, 6.5% senior priority guaranteed notes due February 2025 and 9.0% senior priority guaranteed
notes due February 2025.
Represents our 7.25% senior guaranteed noted due January 2026 and our 7.50% senior guaranteed noted due
January 2028.
See Note 21—Leases in Part II, Item 8.—Financial Statements and Supplementary Data.
Purchase commitments include agreements to purchase goods or services that are enforceable and legally
binding and that specify all significant terms, including fixed or minimum quantities to be purchased; fixed,
minimum or variable pricing provisions; and the approximate timing of the transaction.
During the three months ended December 31, 2020, our Board declared a cash dividend of $0.75 per mandatory
convertible preferred share, which was paid on February 1, 2021 to shareholders of record at the close of business on
January 15, 2021 in the amount of $3.7 million. During the year ended December 31, 2020, we paid cash dividends
ertible preferred share was
d
totaling $49.6 million. On February 23, 2021, a cash dividend of $0.75 per mandatory conv
declared for shareholders which will be paid on May 3, 2021, to holders presenting the Preferred Shares for conversion.
ff
See Part II, Item 5.—Market Price of and Dividends on the Registrant’s Common Equity, Related Shareholder Matters
and Issuer Purchases of Equity—Dividends.
Cash Flows
Our cash flows depend, to a large degree, on the level of spending by oil and gas companies for exploration,
development and production activities. Sustained decreases in the price of oil or natural gas could have a material impact
on these activities, and could also materially affect our cash flows. Certain sources and uses of cash, such as the level of
discretionary capital expenditures or acquisitions, purchases and sales of investments, loans, issuances and repurchases
of debt and of our common shares are within our control and are adjusted as necessary based on market conditions. We
discuss our 2020 and 2019 cash flows below.
f
40
Operating Activities. Net cash provided by operating activities totaled $349.8 million during 2020, compared
to net cash provided of $684.6 million during 2019. Operating cash flows are our primary source of capital and liquidity.
The decrease in cash flows from operations is primarily attributable to decreases in activity and margins in our U.S.
Drilling operating segment. Changes in working capital items such as collection of receivables, other deferred revenue
arrangements and payments of operating payables are significant factors affecting operating cash flows. Changes in
working capital items used $8.4 million in cash flows during 2020 and provided $136.7 million in cash flows during
2019.
a
Investing Activities. Net cash used for investing activities totaled $165.5 million during 2020 compared to net
cash used of $355.9 million in 2019. Our primary use of cash for investing activities is for capital expenditures related to
rig-related enhancements, new construction and equipment, as well as sustaining capital expenditures. During 2020 and
2019, we used cash for capital expenditures totaling $195.5 million and $427.7 million, respectively.
We received $27.4 million in proceeds from insurance claims and sales of assets during 2020 compared to
$60.3 million in 2019.
Financing Activities. Net cash used for financing activities totaled $148.0 million during 2020. During 2020,
we received net proceeds of $317.2 million in amounts borrowed under our revolving credit facilities, partially offset by
a $1.3 billion repayment on our senior notes. Additionally, we paid dividends totaling $22.5 million to our common and
preferred shareholders.
Net cash used for financing activities totaled $331.6 million during 2019. During 2019, we received net
proceeds of $185.0 million in amounts borrowed under our revolving credit facilities, partially offset by a $455.4 million
repayment on our senior notes. Additionally, we paid dividends totaling $49.6 million to our common and preferred
shareholders.
Summarized Combined Financial Information for Guarantee of Securities of Subsidiaries
Nabors Delaware is an indirect, wholly-owned subsidiary of Nabors. Nabors fully and unconditionally
guarantees the due and punctual payment of the principal of, premium, if any, and interest on Nabors Delaware’s
registered notes, which are its (i) 4.625% Senior Notes due 2021 (the “2021 Notes”), (ii) 5.10% Senior Notes due 2023
(the “2023 Notes”), (iii) 5.50% Senior Notes due 2023 (the “5.50 2023 Notes”) and (iv) 5.75% Senior Notes due 2025
(the “2025 Notes” and, together with the 2021 Notes, the 2023 Notes, the 5.50% 2023 Notes and the 2025 Notes, the
“Registered Notes”), and any other obligations of Nabors Delaware under the Registered Notes when and as they
become due and payable, whether at maturity, upon redemption, by acceleration or otherwise, if Nabors Delaware is
unable to satisfy these obligations. Nabors' guarantee of Nabors Delaware's obligations under the Registered Notes are
its unsecured and unsubordinated obligation and have the same ranking with respect to Nabors' indebtedness as the
Registered Notes have with respect to Nabors Delaware's indebtedness. In the event that Nabors is required to withhold
or deduct on account of any Bermudian taxes due from any payment made under or with respect to its guarantees,
subject to certain exceptions, Nabors will pay additional amounts so that the net amount received by each holder of
Registered Notes will equal the amount that such holder would have received if the Bermudian taxes had not been
required to be withheld or deducted.
The following summarized financial information is included so that separate financial statements of Nabors
Delaware are not required to be filed with the SEC. The condensed consolidating financial statements present
investments in both consolidated and unconsolidated affiliates using the equity method of accounting.
In lieu of providing separate financial statements for issuers and guarantors (the “Obligated Group”), we have
presented the accompanying supplemental summarized combined balance sheet and income statement information for
the Obligated Group based on Rule 13-01 of the SEC’s Regulation S-X that we early adopted effective April 1, 2020.
All significant intercompany items among the Obligated Group have been eliminated in the supplemental
summarized combined financial information. The Obligated Group’s investment balances in Subsidiary Non-Guarantors
have been excluded from the supplemental combined financial information. Significant intercompany balances and
activity for the Obligated Group with other related parties, including Subsidiary Non-Guarantors (referred to as
“affiliates”), are presented separately in the accompanying supplemental summarized financial information.
41
Summarized combined Balance Sheet and Income Statement information for the Obligated Group is as follows
(in thousands):
Summarized Combined Balance Sheet Information
December 31,
2020
2019
Assets
Current Assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Non-Current Assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Noncurrent assets - affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total Assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
27,432 $
415,768
7,226,211
7,669,411
407
431,540
7,782,314
8,214,261
Liabilities and Stockholders' Equity
Current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Noncurrent liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Noncurrent liabilities - affiliates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total Liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Stockholders' Equityt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total Liabilities and Stockholders' Equitytt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
71,605
3,086,794
494,589
3,652,988
4,016,423
7,669,411
60,409
3,369,876
242,267
3,672,552
4,541,709
8,214,261
Summarized Combined Income Statement Information
Total revenues, earnings (loss) from consolidated affiliates and other income . . . . . . . . . . . . . . . . . $
Income from continuing operations, net of tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Dividends on preferred stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net income (loss) attributable to Nabors common shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
k
Off-Balance Sheet Arrangements (Including Guarantees)
Year Ended
December 31,
2020
(554,953)
(581,521)
(14,611)
(596,132)
We are a party to transactions, agreements or other contractual arrangements defined as “off-balance sheet
arrangements” that could have a material future effect on our financial position, results of operations, liquidity and
capital resources. The most significant of these off-balance sheet arrangements include the A/R Agreement (see —
Accounts Receivable Sale Agreement, above) and certain agreements and obligations under which we provide financial
or performance assurance to third parties. Certain of these financial or performance assurances serve as guarantees,
including standby letters of credit issued on behalf of insurance carriers in conjunction with our workers’ compensation
insurance program and other financial surety instruments such as bonds. In addition, we have provided indemnifications,
which serve as guarantees, to some third parties. These guarantees include indemnification provided by us to our share
transfer agent and our insurance carriers. We are not able to estimate the potential future maximum payments that might
be due under our indemnification guarantees. Management believes the likelihood that we would be required to perform
or otherwise incur any material losses associated with any of these guarantees is remote.
The following table summarizes the total maximum amount of financial guarantees issued by Nabors:
Financial standby letters of credit and other financial surety
instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 184,675
—
— 112
1,140 $ 185,927
Maximum Amount
2021
2022
2023 Thereafter Total
(In thousands)
Other Matters
Recent Accounting Pronouncements
See Note 2—Summary of Significant Accounting Policies in Part II, Item 8.—Financial Statements and
Supplementary Data.
42
Critical Accounting Estimates
The preparation of our financial statements in conformity with U.S. GAAP requires management to make
certain estimates and assumptions. These estimates and assumptions affect the reported amounts of assets and liabilities,
the disclosures of contingent assets and liabilities at the balance sheet date and the amounts of revenues and expenses
recognized during the reporting period. We analyze our estimates based on our historical experience and various other
assumptions that we believe to be reasonable under the circumstances. However, actual results could differ from our
estimates. The following is a discussion of our critical accounting estimates. Management considers an accounting
estimate to be critical if:
•
•
it requires assumptions to be made that were uncertain at the time the estimate was made; and
changes in the estimate or different estimates that could have been selected could have a material impact on
our consolidated financial position or results of operations.
d
For a summary of all our significant accounting policies, see Note 2—Summary of Significant Accounting
Policies in Part II, Item 8.—Financial Statements and Supplementary Data.
Depreciation of Property, Plant and Equipment. The drilling and drilling services industries are very capital
intensive. Property, plant and equipment represented 72% of our total assets as of December 31, 2020, and depreciation
and amortization constituted 30% of our total costs and other deductions in 2020.
Depreciation for our primary operating assets, drilling rigs, is calculated based on the units-of-production
method. For each day a rig is operating, we depreciate it over an approximate 4,927-day period, with the exception of
our jackup rigs which are depreciated over an 8,030-day period, after provision for salvage value. For each day a rig
asset is not operating, it is depreciated over an assumed depreciable life of 20 years, with the exception of our jackup
rigs, where a 30-year depreciable life is typically used, after provision for salvage value.
Depreciation on our buildings, oilfield hauling and mobile equipment, aircraft equipment, and other machinery
and equipment is computed using the straight-line method over the estimated useful life of
salvage value (buildings—10 to 30 years; aircraft equipment—5 to 20 years; oilfield hauling and mobile equipment and
other machinery and equipment—3 to 10 years).
the asset after provision for
r
These depreciation periods and the salvage values of our property, plant and equipment were determined
through an analysis of the useful lives of our assets and based on our experience with the salvage values of these assets.
Periodically, we review our depreciation periods and salvage values for reasonableness given current conditions.
Depreciation of property, plant and equipment is therefore based upon estimates of the useful lives and salvage value of
those assets. Estimation of these items requires significant management judgment. Accordingly, management believes
that accounting estimates related to depreciation expense recorded on property, plant and equipment are critical.
t
There have been no factors related to the performance of our portfolio of assets, changes in technology or other
factors indicating that these estimates do not continue to be appropriate. Accordingly, for the years ended December 31,
2020, 2019 and 2018, no significant changes have been made to the depreciation rates applied to property, plant and
equipment, the underlying assumptions related to estimates of depreciation, or the methodology applied. However,
t
certain events could occur that would materially affect our estimates and assumptions related to depreciation.
Unforeseen changes in operations or technology could substantially alter management’s assumptions regarding our
u
ability to realize the return on our investment in operating assets and therefore affect the useful lives and salvage values
of our assets.
Impairment of Long-Lived Assets. As discussed above, the drilling and drilling services industries are very
capital intensive. We review our assets for impairment when events or changes in circumstances indicate that their
carrying amounts may not be recoverable. If the estimated undiscounted future cash flows are not sufficient to support
the asset’s recorded value, an impairment charge is recognized to the extent the carrying amount of the long-lived asset
exceeds its estimated fair value determined utilizing either a discounted cash flows or market approach model.
Management considers a number of factors such as estimated future cash flows from the assets, appraisals and current
market value analysis in determining fair value. The determination of future cash flows requires the estimation of
utilization, dayrates, operating margins, sustaining capital and remaining economic life. Such estimates can change
43
based on market conditions, technological advances in the industry or changes in regulations governing the industry.
The appraisals require estimation based on location, working status, asset condition and market conditions. Significant
and unanticipated changes to the assumptions could result in future impairments. A significantly prolonged period of
lower oil and natural gas prices could continue to adversely affect the demand for and prices of our services, which could
result in future impairment charges. As the determination of whether impairment charges should be recorded on our
long-lived assets is subject to significant management judgment, and an impairment of these assets could result in a
material charge on our consolidated statements of income (loss), management believes that accounting estimates related
to impairment of long-lived assets are critical.
n
Assumptions in the determination of future cash flows are made with the involvement of management
personnel at the operational level where the most specific knowledge of market conditions and other operating factors
exists. For 2020, 2019 and 2018, no significant changes have been made to the methodology utilized to determine future
cash flows.
For an asset classified as held for sale, we consider the asset impaired when its carrying amount exceeds fair
value less its cost to sell. Fair value is determined by calculating the expected sales price less any costs to sell.
Impairment of Goodwill and Intangible Assets. We review goodwill and intangible assets with indefinite
lives for impairment annually during the second quarter of each fiscal year or more frequently if events or changes in
circumstances indicate that the carrying amount of such goodwill and intangible assets may exceed their fair value. We
perform our impairment tests for goodwill for all our reporting units within our reportable segments. Our business
consists of U.S. Drilling, Canada Drilling, International Drilling, Drilling Solutions and Rig Technologies reportable
segments. Our Rig Technologies reportable segment includes our Canrig, RDS and 2TD reporting units. We initially
assess goodwill for impairment based on qualitative factors to determine whether the existence of events or
circumstances leads to a determination that it is more likely than not that the fair value of one of our reporting units is
greater than its carrying amount. If the carrying amount exceeds the fair value, an impairment charge will be recognized
in an amount equal to the excess; however, the loss recognized should not exceed the total amount of goodwill allocated
to that reporting unit.
d
rr
Due to industry conditions and the corresponding impact on future expectations of demand for our products and
services, including the effect on our stock price, we determined a triggering event had occurred and performed a
quantitative impairment assessment of our goodwill as of March 31, 2020. Based on the results of our goodwill test
performed in the first quarter of 2020, we recognized additional impairment charges to write off the remaining goodwill
balances attributable to our Drilling Solutions and Rig Technologies operating segments of $11.4 million and
$16.4 million, respectively in the quarter ended March 31, 2020.
We also reviewed our intangible assets for impairment in the first quarter of 2020. The fair value of our
intangible assets are determined using discounted cash flow models. Based on our updated projections of future cash
flows, the fair value of our intangible assets did not support the carrying value. As such, we recognized an impairment of
$83.6 million to write off all remaining intangible assets in the quarter ended March 31, 2020.
Our estimated fair values of our reporting units incorporate judgment and the use of estimates by management.
The fair values calculated in these impairment tests were determined using discounted cash flow models, which require
the use of significant unobservable inputs, representative of a Level 3 fair value measur
f
involve assumptions based on our utilization of rigs or other oil and gas service equipment, revenues and earnings from
affiliates, as well as direct costs, general and administrative costs, depreciation, applicable income taxes, capital
expenditures and working capital requirements. Our fair value estimates of these reporting units are sensitive to varying
dayrates, utilization and costs. A significantly prolonged period of lower oil and natural gas prices, other than those
assumed in developing our forecasts, or changes in laws and regulations could adversely affect the demand for and
prices of our services, which could in turn result in future goodwill and other intangible asset impairment charges for
these reporting units due to the potential impact on our estimate of our future operating results. Our discounted cash flow
projections for each reporting unit were based on financial forecasts. The future cash flows were discounted to present
value using discount rates determined to be appropriate for each reporting unit. Terminal values for each reporting unit
were calculated using a Gordon Growth methodology with a long-term growth rate of approximately 2%.
ement. Our cash flow models
Another factor in determining whether impairment has occurred is the relationship between our market
capitalization and our book value. As part of our annual review, we compared the sum of our reporting units’ estimated
fair value, which included the estimated fair value of non-operating assets and liabilities, less debt, to our market
44
capitalization and assessed the reasonableness of our estimated fair value. Any of the above-mentioned factors may
cause us to re-evaluate goodwill during any quarter throughout the year.
Income Taxes. We operate in a number of countries and our tax returns filed in those jurisdictions are subject
ontesting tax assessments in a
to review and examination by tax authorities within those jurisdictions. We are currently c
number of countries and may contest future assessments. We believe the ultimate resolution of the outstanding
assessments, for which we have not made any accrual, will not have a material adverse effect on our consolidated
financial statements. 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.
u
t
Audit claims of approximately $20.4 million attributable to income tax have been assessed against us. We have
contested, or intend to contest, these assessments, including through litigation if necessary, and we believe the ultimate
resolution, for which we have not made any accrual, will not have a material adverse effect on our consolidated financial
statements. Tax authorities may issue additional assessments or pursue legal actions as a result of tax audits and we
cannot predict or provide assurance as to the ultimate outcome of such assessments and legal actions.
f
r
Applicable income and withholding taxes have not been provided on undistributed earnings of our subsidiaries.
We do not intend to repatriate such undistributed earnings except for distributions upon which incremental income and
withholding taxes would not be material.
In certain jurisdictions we have recognized deferred tax assets and liabilities. Judgment and assumptions are
required in determining whether deferred tax assets will be fully or partially utilized. When we estimate that all or some
portion of certain deferred tax assets such as net operating loss carryforwards will not be utilized, we establish a
valuation allowance for the amount ascertained to be unrealizable. We continually evaluate strategies that could allow
for future utilization of our deferred assets. Any change in the ability to utilize such deferred assets will be accounted for
in the period of the event affecting the valuation allowance. If facts and circumstances cause us to change our
expectations regarding future tax consequences, the resulting adjustments could have a material effect on our financial
results or cash flow.
Litigation and Self-Insurance Reserves. Our operations are subject to many hazards inherent in the drilling
and drilling services industries, including blowouts, cratering, explosions, fires, loss of well control, loss of or damage to
the wellbore or underground reservoir, damaged or lost drilling equipment and damage or loss from inclement weather
or natural disasters. Any of these and other hazards could result in personal injury or death, damage
to or destruction of
equipment and facilities, suspension of operations, environmental and natural resources damage and damage to the
property of others. Our offshore operations are also subject to the hazards of marine operations including capsizing,
grounding, collision and other damage from hurricanes and heavy weather or sea conditions and unsound ocean bottom
conditions. Our operations are subject to risks of war or acts of terrorism, civil disturbances and other political events.
n
Accidents may occur, we may be unable to obtain desired contractual indemnities, and our insurance may prove
inadequate in certain cases. There is no assurance that our insurance or indemnification agreements will adequately
protect us against liability from all the consequences of the hazards described above. Moreover, our insurance coverage
generally provides that we assume a portion of the risk in the form of a deductible or self-insured retention.
Based on the risks discussed above, it is necessary for us to estimate the level of our liability related to
insurance and record reserves for these amounts in our consolidated financial statements. Reserves related to self-
insurance are based on the facts and circumstances specific to the claims and our past experience with similar claims.
The actual outcome of self-insured claims could differ significantly from estimated amount
s. We maintain actuarially
determined accruals in our consolidated balance sheets to cover self-insurance retentions for workers’ compensation,
employers’ liability, general liability and automobile
developed utilizing historical data to project future losses. Loss estimates in the calculation of these accruals are adjusted
based upon actual claim settlements and reported claims. These loss estimates and accruals recorded in our financial
statements for claims have historically been reasonable in light of the actual amount of claims paid.
liability claims. These accruals are based on certain assumptions
a
ff
Because the determination of our liability for self-insured claims is subject to significant management judgment
and in certain instances is based on actuarially estimated and calculated amounts, and because such liabilities could be
material in nature, management believes that accounting estimates related to self-insurance reserves are critical.
ff
45
During 2020, 2019 and 2018, no significant changes were made to the methodology used to estimate insurance
reserves. For purposes of earnings sensitivity analysis, if the December 31, 2020 reserves were adjusted by 10%, total
costs and other deductions would change by $12.3 million, or .44%.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES
We may be exposed to certain market risks arising from the use of financial instruments in the ordinary course
of business. This risk arises primarily as a result of potential changes in the fair market value of financial instruments
due to adverse fluctuations in foreign currency exchange rates, credit risk, interest rates, and marketable and non-
marketable security prices as discussed below.
Foreign Currency Risk. We operate in a number of international areas and are involved in transactions
denominated in currencies other than U.S. dollars, which exposes us to foreign exchange rate risk and foreign currency
devaluation risk. The most significant exposures arise in connection with our operations in Argentina, Russia and
Canada, which usually are substantially unhedged.
At various times, we utilize local currency borrowings (foreign currency denominated debt), the payment
structure of customer contracts and foreign exchange contracts to selectively hedge our exposure to exchange rate
fluctuations in connection with monetary assets, liabilities, cash flows and commitments denominated in certain foreign
currencies. A foreign exchange contract is a foreign currency transaction, defined as an agreement to exchange different
currencies at a given future date and at a specified rate. A hypothetical 10% increase in the value of all our foreign
currencies relative to the U.S. dollar as of December 31, 2020 would result in a $5.7 million increase in the fair value of
our net monetary liabilities denominated in currencies other than U.S. dollars.
uu
Credit Risk. Our financial instruments that potentially subject us to concentrations of credit risk consist
primarily of cash equivalents, short-term and long-term investments and accounts receivable. Cash equivalents such as
deposits and temporary cash investments are held by major banks or investment firms. Our short-term and long-term
investments are managed within established guidelines that limit the amounts that may be invested with any one issuer
and provide guidance as to issuer credit quality. We believe that the credit risk in our cash and investment portfolio is
minimized as a result of the mix of our investments. In addition, our trade receivables are with a variety of U.S.,
international and foreign-country national oil and gas companies. Management considers this credit risk to be limited
due to the financial resources of these companies. We perform ongoing credit evaluations of our customers, and we
generally do not require material collateral. We do occasionally require prepayment of amounts from customers whose
creditworthiness is in question prior to providing services to them. We maintain reserves for potential credit losses, and
these losses historically have been within management’s expectations.
Interest Rate and Marketable and Non-marketable Security Price Risk. Our financial instruments that are
potentially sensitive to changes in interest rates include our floating rate debt instruments (our 2018 Revolving Credit
Facility), our fixed rate debt securities comprised of our 4.625%, 5.50%, 5.10% and 5.75% senior notes, 0.75% senior
exchangeable notes, 7.25% and 7.50% senior guaranteed notes, 6.50% and 9.00% senior priority guaranteed notes, our
investments in debt securities (including corporate and mortgage-CMO debt securities) and our investments in overseas
funds that invest primarily in a variety of public and private U.S. and non-U.S. securities (including asset-backed and
mortgage-backed securities, global structured-asset securitizations, whole-loan mortgages and participations in whole
loans and whole-loan mortgages), which are classified as long-term investments.
We may utilize derivative financial instruments that are intended to manage our exposure to interest rate risks.
We account for derivative financial instruments under the Derivatives Topic of the ASC. The use of derivative financial
instruments could expose us to further credit risk and market risk. Credit risk in this context is the failure of a
counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is
positive, the counterparty would owe us, which can create credit risk for us. When the fair value of a derivative contract
is negative, we would owe the counterparty, and therefore, we would not be exposed to credit risk. We attempt to
minimize credit risk in derivative instruments by entering into transactions with major financial institutions that have a
significant asset base. Market risk related to derivatives is the adverse effect on the value of a financial instrument that
results from changes in interest rates. We try to manage market risk associated with interest-rate contracts by
establishing and monitoring parameters that limit the type and degree of market risk that we undertake.
46
Fair Value of Financial Instruments. The fair value of our fixed rate long-term debt and revolving credit
facilities is estimated based on quoted market prices or prices quoted from third-party financial institutions. The carrying
and fair values of these liabilities were as follows:
Effective
Interest
Rate
2020
Carrying
Value
As of December 31,
Fair
Value
Effective
Interest
Rate
(In thousands)
2019
Carrying
Value
Fair
Value
5.00% senior notes due
September 2020 . . . . . . . . . . . . . . . . . . — % $
—
—
— $
—
—
5.44 % $
282,046 $ 284,907
4.625% senior notes due
September 2021 . . . . . . . . . . . . . . . . . .
5.50% senior notes due January 2023 . .
5.10% senior notes due September 2023 .
0.75% senior exchangeable notes due
Januaryrr 2024 . . . . . . . . . . . . . . . . . . . . .
5.75% senior notes due February 2025 .
6.50% senior priority guaranteed notes
5.65 %
5.85 %
5.32 %
86,329
28,443
121,077
78,862
18,768
78,435
4.76 %
5.90 %
5.24 %
634,588
501,003
336,810
632,516
483,834
303,860
6.06 %
6.01 %
279,700
610,818
169,458
318,871
5.97 %
6.01 %
472,603
781,502
431,503
705,040
due Februaryrr 2025 . . . . . . . . . . . . . . . .
6.50 %
50,485
44,059
— % —
9.00% senior priority guaranteed notes
due Februaryrr 2025 . . . . . . . . . . . . . . . .
9.00 %
192,032
185,221
— % —
7.25% senior guaranteed notes due
Januaryrr 2026 . . . . . . . . . . . . . . . . . . . . .
7.51 %
559,978
396,106
— % —
—
—
—
—
—
—
7.50% senior guaranteed notes due
Januaryrr 2028 . . . . . . . . . . . . . . . . . . . . .
2012 revolving credit facility . . . . . . . . .
2018 revolving credit facility . . . . . . . . .
7.69 %
— % —
3.53 %
389,609
—
672,500
267,369
—
—
672,500
— % —
3.71 %
— % —
—
355,000
—
—
355,000
—
Less: deferred financing costs . . . . . . . .
2,990,971 $ 2,229,649
3,363,552 $ 3,196,660
22,270
$ 2,968,701
30,332
$ 3,333,220
The fair values of our cash equivalents, trade receivables and trade payables approximate their carrying values
due to the short-term nature of these instruments. Our short-term investments as of December 31, 2020 and 2019 were
carried at fair market value and totaled $9.5 million and $16.5 million, respectfully.
Our investments in debt securities and a portion of our long-term investments are sensitive to changes in
interest rates. Additionally, our investment portfolio of debt and equity securities, which are carried at fair value, exposes
us to price risk. A hypothetical 10% decrease in the market prices for all securities as of December 31, 2020 would
decrease the fair value of our marketable securities by $1.0 million.
47
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX
Report of Independent Registered Public Accounting Firm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Balance Sheets as of December 31, 2020 and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statements of Income (Loss) for the Years Ended December 31, 2020, 2019 and 2018 . . . . . . . . . . .
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2020, 2019 and
2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statements of Cash Flows for the Years Ended December 31, 2020, 2019 and 2018 . . . . . . . . . . . . . .
Consolidated Statements of Changes in Equity for the Years Ended December 31, 2020, 2019 and 2018 . . . . . . . .
Notes to Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
49
52
53
54
55
56
57
48
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of Nabors Industries Ltd.
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Nabors Industries Ltd. and its subsidiaries (the
“Company”) as of December 31, 2020 and 2019, and the related consolidated statements of income (loss), of
comprehensive income (loss), of changes in equity and of cash flows for each of the three years in the period ended
December 31, 2020, including the related notes and financial statement schedule listed in the index appearing under Item
15(a)(2) (collectively referred to as the “consolidated financial statements”). We also have audited the Company's
internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control -
Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission
(COSO).
d
k
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the
financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows
for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally
accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects,
effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal
k
Control - Integrated Framework (2013) issued by the COSO.
Change in Accounting Principle
As discussed in Note 21 to the consolidated financial statements, the Company has changed its method for accounting
for leases in 2019 due to the adoption of ASU No. 2016-02, Leases (Topic 842).
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 Report on Internal Control over Financial Reporting appearing under Item 9A. Our
responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal
control over financial reporting based on our audits. We are a public accounting firm registered with the Public
Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the
Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities
and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and
perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of
material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was
maintained in all material respects.
a
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.
49
Definition and Limitations of Internal Control over Financial Reporting
l
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.
uu
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.
aa
Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated
financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to
accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially
challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way
our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical
audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it
relates.
d
Impairment Assessments of Property, Plant and Equipment, Net within the U.S., International and Canada Drilling
Segments
As described in Note 3 and Note 8 to the consolidated financial statements, the Company had a consolidated property,
plant and equipment, net balance of $3,986 million as of December 31, 2020. During the year ended Decembe
the Company recorded consolidated impairment and other charges of $87 million within the US Drilling segment and
$117 million within the International Drilling segment, which primarily related to property, plant and equipment, net. As
disclosed by management, management reviews assets for impairment when events or changes in circumstances indicate
that their carrying amounts may not be recoverable. If the estimated undiscounted future cash flows are not sufficient to
support the asset’s recorded value, an impairment charge is recognized to the extent the carrying amount of the long-
lived asset exceeds its estimated fair value determined utilizing either discounted cash flows or a market approach
model. Management considers a number of factors such as estimated future cash flows from the assets, appraisals and
current market value analysis in determining fair value. The determination of future cash flows requires the estimation of
utilization, dayrates, operating margins, sustaining capital and remaining economic life. The appraisals require
estimation based on location, working status, asset condition and market conditions.
r 31, 2020,
ff
r
The principal considerations for our determination that performing procedures relating to the impairment assessments of
property, plant and equipment, net within the U.S., International, and Canada Drilling segments is a critical audit matter
are (i) the significant judgment by management when determining the estimated fair value for individual components
within asset groups, which in turn led to (ii) a high degree of auditor judgment, subjectivity and effort in performing
procedures and evaluating management’s significant assumptions related to asset condition and market conditions,
which vary by the individual components within asset groups for the related impairment assessments, and (iii) the audit
effort involved the use of professionals with specialized skill and knowledge.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our
overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls
relating to management’s impairment assessments of property, plant and equipment, net within the U.S., International
and Canada Drilling segments, including controls over the estimated fair value. These procedures also included, among
others, (i) testing management’s process for determining the fair value estimates; (ii) testing the completeness, accuracy,
and relevance of underlying data used in the models; and (iii) evaluating the reasonableness of significant assumptions
50
used by management related to asset condition and market conditions, which vary by individual components within asset
groups for the related impairment assessments. Evaluating management’s assumptions related to asset condition
involved evaluating whether the assumptions used by management were reasonable considering (i) the consistency with
operating and fixed asset records and (ii) whether these assumptions were consistent with evidence obtained in other
areas of the audit. Professionals with specialized skill and knowledge were used to assist in the evaluation of the
appropriateness of the fair value model and the reasonableness of market conditions for individual components within
asset groups in which appraisals were obtained.
/s/ PricewaterhouseCoopers LLP
Houston, Texas
February 24, 2021
We have served as the Company’s auditor since 1987.
51
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
December 31,
2019
2020
(In thousands, except per
share amounts)
Current assets:
ASSETS
t
t
Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Short-term investments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts receivable, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Inventoryrr , net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Assets held for sale . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other current assets. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property, plant and equipment, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Goodwill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
435,990
16,506
453,042
176,341
2,530
164,257
1,248,666
4,930,549
28,380
305,844
247,219
Total assets (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,503,428 $ 6,760,658
472,246 $
9,500
362,977
160,585
16,562
109,595
1,131,465
3,985,707
—
—
247,171
139,085
t
Current liabilities:
LIABILITIES AND EQUITY
Trade accounts payaa able . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income taxes payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Current lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term liabilities. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total liabilities (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
220,922 $
276,085
10,157
8,305
515,469
2,968,701
318,034
1,576
3,803,780
295,159
333,282
14,628
13,479
656,548
3,333,220
292,184
3,149
4,285,101
Commitments and contingencies (Note 8)
Redeemable noncontrolling interest in subsidiaryrr (Note 13) . . . . . . . . . . . . . . . . . . . . .
442,840
425,392
Shareholders’ equitytt :
Preferred shares, par value $0.001 per share:
Series A 6% Cumulative Mandatory Convertible; $50 per share liquidation
preference; outstanding 4,870 and 5,613, respectively . . . . . . . . . . . . . . . . . . . . . .
5
6
Common shares, par value $0.05 per share:
416
Authorized common shares 32,000; issued 8,383 and 8,324, respectively . . . . . . . . .
3,412,972
Capital in excess of par value . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(11,788)
Accumulated other comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Retained earnings (accumulated deficit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(104,775)
(1,314,020)
Less: treasuryrr shares, at cost, 1,090 and 1,056 common shares, respectively . . . . . . .
1,982,811
Total shareholders’ equitytt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
67,354
Noncontrolling interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2,050,165
Total equityt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total liabilities and equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,503,428 $ 6,760,658
419
3,423,935
(11,124)
(946,100)
(1,315,751)
1,151,384
105,424
1,256,808
t
_____________________________
(1) The consolidated balance sheets include assets and liabilities of consolidated joint ventures. See Note 13—Joint
Ventures for additional information.
The accompanying notes are an integral part of these consolidated financial statements.
52
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
Year Ended December 31,
2018
2019
2020
(In thousands, except per share amounts)
Revenues and other income:
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Earnings (losses) from unconsolidated affiliates . . . . . . . . . . . . . . . . . . . .
Investment income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total revenues and other income . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Costs and other deductions:
Direct costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
General and administrative expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Research and engineering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(Gain)/loss on debt buybacks and exchanges . . . . . . . . . . . . . . . . . . . . . . .
Impairments and other charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total costs and other deductions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income (loss) from continuing operations before income taxes . . . . . . . . . .
t
t
Income tax expense (benefit):
Current . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income (loss) from continuing operations, net of tax . . . . . . . . . . . . . . . . . . .
Income (loss) from discontinued operations, net of tax . . . . . . . . . . . . . . . . .
Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: Net (income) loss attributable to noncontrolling interest . . . . . . . . . . .
Net income (loss) attributable to Nabors . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: Preferred stock dividend . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net income (loss) attributable to Nabors common shareholders . . . . . . . . . .
Amounts attributable to Nabors common shareholders:
Net income (loss) from continuing operations . . . . . . . . . . . . . . . . . . . . . . . .
Net income (loss) from discontinued operations . . . . . . . . . . . . . . . . . . . . . . .
Net income (loss) attributable to Nabors common shareholders . . . . . . . . . .
$ 2,134,043 $ 3,043,383 $ 3,057,619
1
(9,499)
3,048,121
—
—
1,438
2,135,481
(5)
10,218
3,053,596
1,333,072
203,515
33,564
853,699
206,274
(228,274)
410,631
28,567
2,841,048
(705,567)
1,929,331
258,731
50,359
876,091
204,311
(11,468)
301,939
33,224
3,642,518
(588,922)
1,976,974
265,822
56,147
866,870
227,124
5,268
139,178
29,532
3,566,915
(518,794)
55,625
35,951
91,576
(680,498)
(12)
(680,510)
(22,375)
(7,430)
64,716
57,286
(762,853)
7
(762,846)
(42,795)
2,388
76,881
79,269
(598,063)
(14,663)
(612,726)
(28,222)
$ (805,641) $ (702,885) $ (640,948)
(12,305)
$ (820,252) $ (720,129) $ (653,253)
(14,611)
(17,244)
$ (820,259) $ (720,117) $ (638,590)
(14,663)
$ (820,252) $ (720,129) $ (653,253)
(12)
7
Earnings (losses) per share:
Basic from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Basic from discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted from discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average number of common shares outstanding:
Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
(118.69) $
—
$
$
(118.69) $
(118.69) $
—
$
(118.69) $
(105.39) $
—
—
(105.39) $
(105.39) $
—
—
(105.39) $
7,059
7,059
7,032
7,032
(97.42)
(2.19)
(99.61)
(97.42)
(2.19)
(99.61)
6,688
6,688
The accompanying notes are an integral part of these consolidated financial statements.
53
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Net income (loss) attributable to Nabors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other comprehensive income (loss), before tax:
Translation adjd ustment attributable to Nabors . . . . . . . . . . . . . . . . . . . . . . .
Pension liability amortization and adjd ustment . . . . . . . . . . . . . . . . . . . . . . .
Unrealized gains (losses) and amortization on cash flow hedges . . . . . . . .
Adoption of ASU No. 2016-01 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other comprehensive income (loss), before tax . . . . . . . . . . . . . . . . . . . . . . . .
Income tax expense (benefit) related to items of other comprehensive
income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other comprehensive income (loss), net of tax . . . . . . . . . . . . . . . . . . . . . . . . .
Comprehensive income (loss) attributable to Nabors . . . . . . . . . . . . . . . . . . . .
Net income (loss) attributable to noncontrolling interest . . . . . . . . . . . . . .
Translation adjd ustment attributable to noncontrolling interest . . . . . . . . . .
Comprehensive income (loss) attributable to noncontrolling interest . . . . . . .
Comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
t
2020
Year Ended December 31,
2019
(In thousands)
$ (805,641) $ (702,885) $ (640,948)
2018
435
210
160
—
805
16,943
217
567
—
—
17,727
(31,962)
216
567
(9,144)
(40,323)
141
664
(804,977)
42,795
—
—
42,795
187
(40,510)
(681,458)
28,222
(251)
27,971
$ (762,182) $ (662,918) $ (653,487)
190
17,537
(685,348)
22,375
55
22,430
The accompanying notes are an integral part of these consolidated financial statements.
54
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Cash flows from operating activities:
Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Adjustments to net income (loss):
Year Ended December 31,
2020
2019
2018
(In thousands)
(762,846)
$
(680,510)
$
(612,726)
k
Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Impairments and other charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Amortization of debt discount and deferred financing costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Losses (gains) on debt buyback . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Losses (gains) on long-lived assets, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Losses (gains) on investments, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Provision (recovery) of bad debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Share-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign currency transaction losses (gains), net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Noncontrolling interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Equity in (earnings) losses from unconsolidated affiliates, net of dividends . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
r
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Inventory . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Trade accounts payable and accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Income taxes payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net cash provided by (used for) operating activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows from investing activities:
Purchases of investments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Sales and maturities of investments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash paid for acquisition of businesses, net of cash acquired . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from sales of assets and insurance claims . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net cash (used for) provided by investing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash flows from financing activities:
853,697
64,717
318,582
31,238
(228,274)
64,365
4,286
18,194
24,638
13,133
(42,795)
—
—
(770)
67,502
6,188
38,672
20,830
(142,826)
(933)
2,163
349,761
(91)
2,760
—
—
(195,523)
27,397
(165,457)
876,103
35,894
213,404
30,931
(11,468)
40,346
(1,257)
20,626
24,660
20,876
(22,375)
5
667
276,685
(18,695)
5,157
13,106
(142,857)
(4,857)
8,117
684,558
(4,323)
18,849
(2,929)
(427,741)
60,288
(355,856)
r
Proceeds from issuance of long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Reduction in long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from revolving credit facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Reduction in revolving credit facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from (payment for) commercial paper . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from (payments for) short-term borrowings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from issuance of common shares, net of issuance costs . . . . . . . . . . . . . . . . . . . . . . . . .
Proceeds from issuance of preferred stock, net of issuance costs . . . . . . . . . . . . . . . . . . . . . . . . .
Repurchase of common and preferred shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Dividends to common and preferred shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Redeemable noncontrolling interest contribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Distributions to noncontrolling interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net cash (used for) provided by financing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Effect of exchange rate changes on cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net increase (decrease) in cash and cash equivalents and restricted cash . . . . . . . . . . . . . . . . . . . . . .
Cash and cash equivalents and restricted cash, beginning of period . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash and cash equivalents and restricted cash, end of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
1,000,000
(1,394,043)
(28,112)
1,552,500
(1,235,000)
—
—
—
—
—
(1,731)
(22,538)
—
(5,083)
(13,994)
(148,001)
(3,061)
33,242
442,038
475,280
r
RECONCILIATION OF CASH AND CASH EQUIVALENTS AND RESTRICTED CASH
Cash and cash equivalents, beginning of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Restricted cash, beginning of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash and cash equivalents and restricted cash, beginning of period . . . . . . . . . . . . . . . . . . . . . . . . . . $
435,990
6,048
442,038
Cash and cash equivalents, end of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Restricted cash, end of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash and cash equivalents and restricted cash, end of period . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
472,246
3,034
475,280
—
—
(455,360)
(1,767)
1,050,000
(865,000)
—
—
(561)
—
—
—
—
—
(49,583)
—
—
(4,552)
(4,750)
(331,573)
(6,171)
(9,042)
451,080
442,038
$
447,766
3,314
451,080
435,990
6,048
442,038
$
$
$
$
$
868,509
71,579
62,578
32,213
5,268
95,741
14,195
1,285
26,396
4,235
(28,222)
164
720
(66,486)
(13,981)
31,770
11,717
(76,561)
(41,939)
(60,682)
325,773
(676)
4,287
(20,859)
(458,938)
109,098
(367,088)
800,000
(878,278)
(21,277)
1,135,000
(1,475,000)
(40,000)
380
301,404
277,927
—
(87,098)
156,935
(5,452)
(8,912)
155,629
(5,263)
109,051
342,029
451,080
336,997
5,032
342,029
447,766
3,314
451,080
The accompanying notes are an integral part of these consolidated financial statements.
55
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T
Nabors Industries Ltd. and Subsidiaries
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 Nature of Operations
Unless the context requires otherwise, references in this annual report to “we,” “us,” “our,” “the Company,” or
“Nabors” mean Nabors Industries Ltd., together with our subsidiaries where the context re
annual report to “Nabors Delaware” mean Nabors Industries, Inc., a wholly owned subsidiary of Nabors.
quires. References in this
u
Our business is comprised of our global land-based and offshore drilling rig operations and other rig related
services and technologies. These services and technologies include tubular running services, wellbore placement
solutions, directional drilling, measurement-while-drilling (“MWD”), logging-while-drilling (“LWD”) systems and
services, equipment manufacturing, rig instrumentation and drilling optimization software.
The outbreak of the novel coronavirus (“COVID-19”), together with actions by large oil and natural gas
producing countries, led to decreases in commodity prices, specifically oil and natural gas prices, resulting from
oversupply and demand weakness. These price decreases caused significant disruptions and volatility in the global
marketplace during 2020. Lower prices and the resulting weakness in demand for our services, negatively affected our
results of operations and cash flows and uncertainty remains regarding the length and impact of COVID-19 on the
energy industry and the outlook for our business.
The consolidated financial statements and related footnotes are presented in accordance with U.S. GAAP.
Note 2 Summary of Significant Accounting Policies
Principles of Consolidation
Our consolidated financial statements include the accounts of Nabors, as well as all majority owned and
non-majority owned subsidiaries required to be consolidated under U.S. GAAP. All significant intercompany accounts
and transactions are eliminated in consolidation.
In addition to the consolidation of our majority owned subsidiaries, we also consolidate variable interest entities
(“VIE’s”) when we are determined to be the primary beneficiary of a VIE. Determination of the primary beneficiary of a
VIE is based on whether an entity has (1) the power to direct activities that most significantly impact the economic
performance of the VIE and (2) the obligation to absorb losses or the right to receive benefits of the VIE that could
potentially be significant to the VIE. Our determination of the primary beneficiary of a VIE considers all relationships
between us and the VIE. Our joint venture, SANAD, which is equally owned by Saudi Aramco and Nabors, has been
consolidated. As we have the power to direct activities that most significantly impact SANAD’s economic performance,
including operations, maintenance and certain sourcing and procurement, we have determined Nabors to be the primary
beneficiary. See Note 13—Joint Ventures.
f
Change in Presentation
Certain amounts within our consolidated statements of income (loss) have
d
been reclassified to conform to the
current period presentation.
Cash and Cash Equivalents
Cash and cash equivalents include demand deposits and various other short-term investments with original
maturities of three months or less.
Short-term Investments
Short-term investments consist primarily of equity securities which are stated at fair value with any changes in
fair value recognized in investment income (loss) in our consolidated statements of income (loss).
57
Inventory
Inventory is stated at the lower of cost or net realizable value. Cost is determined using the first-in, first-out or
weighted-average costs methods and includes the cost of materials, labor and manufacturing overhead. Inventory, which
is net of reserves of $23.5 million and $35.0 million as of December 31, 2020 and 2019, respectively, included the
following:
December 31,
2020
2019
(In thousands)
Raw materials . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 133,424 $ 130,414
5,498
Workrr -in-progress . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Finished goods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
40,429
$ 160,585 $ 176,341
3,452
23,709
Property, Plant and Equipment
Property, plant and equipment, including renewals and betterments, are stated at cost, while maintenance and
repairs are expensed currently. Interest costs applicable to the construction of qualifying assets are capitalized as a
component of the cost of such assets. We provide for the depreciation of our drilling rigs using the units-of-production
method. For each day a rig is operating, we depreciate it over an approximate 4,927-day period, with the exception of
our jackup rigs which are depreciated over an 8,030-day period, after provision for salvage value. For each day a rig
asset is not operating, it is depreciated over an assumed depreciable life of 20 years, with the exception of our jackup
rigs, where a 30-year depreciable life is used, after provision for salvage value.
Depreciation on our buildings, oilfield hauling and mobile equipment, and other machinery and equipment is
computed using the straight-line method over the estimated useful life of the asset after provision for salvage value
(buildings—10 to 30 years; oilfield hauling and mobile equipment and other machinery and equipment—3 to 10 years).
Amortization of capitalized leases is included in depreciation and amortization expense. Upon retirement or other
disposal of fixed assets, the cost and related accumulated depreciation are removed from the respective property, plant
and equipment accounts and any gains or losses are included in our consolidated statements of income (loss).
We review our assets for impairment when events or changes in circumstances indicate that their carrying
amounts may not be recoverable. If the estimated undiscounted future cash flows are not sufficient to support the asset’s
recorded value, an impairment charge is recognized to the extent the carrying amount of the long-lived asset exceeds its
estimated fair value. Management considers a number of factors such as estimated future cash flows from the assets,
appraisals and current market value analysis in determining fair value. The determination of future cash flows requires
the estimation of utilization, dayrates, operating margins, sustaining capital and remaining economic life. Such estimates
can change based on market conditions, technological advances in the industry or changes in regulations governing the
industry. Significant and unanticipated changes to the assumptions could result in future impairments. A significantly
prolonged period of lower oil and natural gas prices could adversely affect the demand for and prices of our services,
which could result in future impairment charges. As the determination of whether impairment charges should be
recorded on our long-lived assets is subject to significant management judgment, and an impairment of these assets
could result in a material charge on our consolidated statements of income (loss), management believes that accounting
estimates related to impairment of long-lived assets are critical.
f
For an asset classified as held for sale, we consider the asset impaired when its carrying amount exceeds fair
value less its cost to sell. Fair value is determined in the same manner as a long-lived asset that is held and used.
Goodwill
We have historically reviewed goodwill for impairment annually during the second quarter of each fiscal year
or more frequently if events or changes in circumstances indicate that the carrying amount of such goodwill and
intangible assets may exceed their fair value. We initially assess goodwill for impairment based on qualitative factors to
determine whether the existence of events or circumstances leads to a determination that it is more likely than not that
rrying amount exceeds the fair
the fair value of one of our reporting units is greater than its carrying amount. If the ca
n
58
value, an impairment charge will be recognized in an amount equal to the excess; however, the loss recognized should
not exceed the total amount of goodwill allocated to that reporting unit.
Our estimated fair values of our reporting units incorporate judgment and the use of estimates by management.
The fair values calculated in these impairment tests were determined using discounted cash flow models, which require
f
the use of significant unobservable inputs, representative of a Level 3 fair value measur
involve assumptions based on our utilization of rigs or other oil and gas service equipment, revenues and earnings from
affiliates, as well as direct costs, general and administrative costs, depreciation, applicable income taxes, capital
expenditures and working capital requirements. Our fair value estimates of these reporting units are sensitive to varying
dayrates, utilization and costs. Our discounted cash flow projections for each reporting unit were based on financial
forecasts. The future cash flows were discounted to present value using discount rates determined to be appropriate for
each reporting unit. Terminal values for each reporting unit were calculated using a Gordon Growth methodology with a
long-term growth rate of approximately 2%.
ement. Our cash flow models
Another factor in determining whether impairment has occurred is the relationship between our market
capitalization and our book value. As part of our annual review, we compared the sum of our reporting units’ estimated
fair value, which included the estimated fair value of non-operating assets and liabilities, less debt, to our market
capitalization and assessed the reasonableness of our estimated fair value. Any of the above-mentioned factors may
cause us to re-evaluate goodwill during any quarter throughout the year. Due to industry conditions that existed at
March 31, 2020 and the corresponding impact on future expectations of demand for our products and services, including
the effect on our stock price, we determined a triggering event had occurred and performed a quantitative impairment
assessment of our goodwill.
The change in the carrying amount of goodwill for our segments for the years ended December 31, 2020 and
2019 was as follows:
Acquisitions
and
Purchase
Price
Disposals
and
Adjustments Impairments
Balance at
December 31,
2018
Cumulative
Translation
Adjustment Adjustments
Other
Balance at
December 31,
2019
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . $
International Drilling . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . .
Rig Technologies . . . . . . . . . . . . . . . . . . .
50,149
75,634
11,436
46,695
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 183,914
$
$
(In thousands)
—
— $ (52,203)(1) $
—
—
(75,634)(1)
—
—
—
—
(28,136)(1)
—
— $ (155,973) $
and
—
— $
—
—
439
439 $
2,054 $
—
—
—
(2,054)
—
— $
—
—
11,436
16,944
28,380
Balance at
December 31,
2019
Purchase
Disposals
Price
and
Adjustments Impairments
Cumulative
Translation
Adjustment Adjustment
Other
Balance at
December 31,
2020
Drilling Solutions . . . . . . . . . . . . . . . . . $
Rig Technologies . . . . . . . . . . . . . . . . . .
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . $
11,436 $
16,944
28,380 $
— $ (11,436)(2) $
—
—
—
(16,362)(2)
—
— $ (27,798) $
—
(582)
(582) $
— $ —
—
— $ —
—
—
—
(In thousands)
(2)
We determined the carrying value of some of our reporting units exceeded their fair value in 2019. As such, we
recognized a goodwill impairment of $156.0 million. See Note 3—Impairments and Other Charges.
Due to industry conditions that existed at March 31, 2020, we performed a quantitative impairment assessment
of goodwill. Based on the results, we recognized a goodwill impairment of $27.8 million. See Note 3
—Impairments and Other Charges.
Litigation and Insurance Reserves
We estimate our reserves related to litigation and insurance based on the facts and circumstances specific to the
intain actuarially determined accruals
litigation and insurance claims and our past experience with similar claims. We ma
in our consolidated balance sheets to cover self-insurance retentions. See Note 15—Commitments and Contingencies
regarding self-insurance accruals. We estimate the range of our liability related to pending litigation when we believe the
t
59
amount and range of loss can reasonably be estimated. We record our best estimate of a loss when the loss is considered
probable. When a liability is probable and there is a range of estimated loss with no best estimate in the range, we record
the minimum estimated liability related to the lawsuits or claims. As additional information becomes available, we
assess the potential liability related to our pending litigation and claims and revise our estimates. Due to uncertainties
related to the resolution of lawsuits and claims, the ultimate outcome may differ from our estimates. For matters where
an unfavorable outcome is reasonably possible and significant, we disclose the nature of the matter and a range of
potential exposure, unless an estimate cannot be made at the time of disclosure.
Revenue Recognition
We recognize revenues and costs on daywork contracts daily as the work progresses over the contract term. For
certain contracts, we receive lump sum payments for the mobilization of rigs and other drilling equipment. We defer
revenue related to mobilization periods and recognize the revenue over the term of the related drilling contract.
Costs incurred related to a mobilization period for which a contract is secured are deferred and recognized over
the term of the related drilling contract. Costs incurred to relocate rigs and other drilling equipment to areas in which a
contract has not been secured are expensed as incurred. We defer recognition of revenue on amounts received from
customers for prepayment of services until those services are provided.
We recognize revenue for top drives and other capital equipment we manufacture upon transfer of control,
which generally occurs when the product has been shipped to the customer.
We recognize, as operating revenue, proceeds from business interruption insurance claims in the period that the
a
claim is realizable. Proceeds from casualty insurance settlements in excess of the carrying value of damaged assets are
recognized in other, net in our consolidated statement of income (loss) in the period that the applicable proof of loss
documentation is received. Proceeds from casualty insurance settlements that are expected to be less than the carrying
value of damaged assets are recognized at the time the loss is incurred and recorded in other, net in our consolidated
statement of income (loss).
We recognize reimbursements received for out of pocket expenses incurred as revenues and account for out of
pocket expenses as direct costs.
Research and Engineering
u
Research and engineering expenses are expensed as incurred and include costs associated with the research and
development of new products and services and costs associated with sustaining engineering of existing products and
services.
Income Taxes
We are a Bermuda exempted company and are not subject to income taxes in Bermuda. We have provided for
income taxes based on the tax laws and rates in effect in the countries where we operate and earn income. The income
taxes in these jurisdictions vary substantially. Our worldwide effective tax rate for financial statement purposes will
continue to fluctuate from year to year due to the change in the geographic mix of pre-tax earnings.
We recognize increases to our tax reserves for uncertain tax positions along with interest and penalties as an
increase to other long-term liabilities.
For U.S. and other jurisdictional income tax purposes, we have net operating loss carryforwards that we are
required to assess quarterly for potential valuation allowances. We consider the sufficiency of existing temporary
differences and expected future earnings levels in determining the amount, if any, of valuation allowance required
against such carryforwards and against deferred tax assets.
Foreign Currency Translation
For certain of our foreign subsidiaries, such as those in Canada, the local currency is the functional currency,
and therefore translation gains or losses associated with foreign-denominated monetary accounts are accumulated in a
separate section of the consolidated statements of changes in equity. For our other international subsidiaries, the U.S.
60
dollar is the functional currency, and therefore local currency transaction gains and losses, arising from remeasurement
of payables and receivables denominated in local currency, are included in our consolidated statements of income (loss).
Use of Estimates
The preparation of financial statements in conformity with U.S. GAAP requires management to make certain
ff
estimates and assumptions. These estimates and assumptions affect the reported amounts of assets and liabilities, the
disclosures of contingent assets and liabilities at the balance sheet date and the amounts of revenues and expenses
recognized during the reporting period. Actual results could differ from such estimates. Areas where critical accounting
estimates are made by management include:
•
•
•
•
•
•
depreciation of property, plant and equipment;
impairment of long-lived assets;
impairment of goodwill and intangible assets;
income taxes;
litigation and self-insurance reserves; and
fair value of assets acquired and liabilities assumed.
Recent Accounting Pronouncements Adopted
In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement
of Credit Losses on Financial Instruments, which changed accounting requirements for the recognition of credit losses
from an incurred or probable impairment methodology to a current expected credit losses (CECL) methodology. The
guidance is effective for interim and annual periods beginning after December 15, 2019. The guidance has been applied
using the modified retrospective method with a cumulative effect adjustment to beginning retained earnings. Trade
receivables (including the allowance for credit losses) are the only financial instrument in scope for ASU 2016-13
currently held by the Company. The adoption of this guidance as of the beginning of 2020 did not have a material impact
on our consolidated financial statements.
f
t
Note 3 Impairments and Other Charges
The components of impairments and other charges are provided below:
Impairments and Other Charges
t
Goodwill impairments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Intangible asset impairment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
US Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Rig Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Oil and gas related assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Severance and transaction related costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Year Ended December 31,
2019
2020
2018
$ 27,798
83,624
87,333
—
—
117,113
28,624
2,936
24,543
19,070
19,590
—
—
35,057
—
75,751
—
14,047
—
14,323
—
$ 410,631 $ 301,939 $ 139,178
155,973
47,731
—
—
17,818
17,927
—
7,823
—
11,447
43,220
We review our assets for impairment when events or changes in circumstances indicate that their carrying
amounts may not be recoverable. If the estimated undiscounted future cash flows are not sufficient to support the asset’s
recorded value, an impairment charge is recognized to the extent the carrying amount of the long-lived asset exceeds its
estimated
61
fair value. Management considers a number of factors such as estimated future cash flows from the assets, appraisals and
current market value analysis in determining fair value. The determination of future cash flows requires the estimation of
utilization, dayrates, operating margins, sustaining capital and remaining economic life. Such estimates can change
based on market conditions, technological advances in the industry or changes in regulations governing the industry. A
significantly prolonged period of lower oil and natural gas prices could continue to adversely affect the demand for and
prices of our services, which could result in future impairment charges.
For the year ended December 31, 2020
Goodwill impairments
We have historically performed our annual goodwill impairment test during the second quarter of each year. In
addition to our annual impairment test, we are required to regularly assess whether a triggering event has occurred which
tt
would require interim impairment testing. Due to industry conditions during the first quarter of 2020 and the
corresponding impact on future expectations of demand for our products and services, including the effect on our stock
price, we determined a triggering event had occurred and performed a quantitative impairment assessment of our
goodwill. Based on the results of our goodwill test performed, we recognized impairme
nt charges to write off the
rr
remaining goodwill balances attributable to our Drilling Solutions and Rig Technologies operating segments of
$11.4 million and $16.4 million, respectively.
Intangible asset impairments
We also reviewed our intangible assets for impairment in the first quarter of 2020 as a result of the industry
n
conditions. The fair value of our intangible assets are determined using discounted cash flow models. Based on our
updated projections of future cash flows, the fair value of our intangible assets did not support the carrying value. As
such, we recognized an impairment of $83.6 million to write off all remaining intangible assets attributable to our
Drilling Solutions and Rig Technologies operating segments.
US Drilling
Due to the sharp decline in activity in the US in the first part of the year, we recorded impairments of $33.3
million and functionally retired $54.0 million of our lower specification rigs in the Lower 48 and Alaska markets totaling
approximately $87.3 million. We determined that the assets were either functionally obsolete, would be no longer used,
or the carrying value was not fully recoverable and was in excess of its fair value.
International Drilling
We impaired $30.5 million and wrote down or retired $86.6 million totaling $117.1 million during 2020, which
represented most of our rig and drilling-related equipment in several international markets which have been impacted by
current market conditions and other factors, including Venezuela, Iraq, Algeria and certain offshore markets in the
eastern hemisphere. Due to our lack of work in these markets and limited visibility to any possibility of further work, we
have taken steps to exit or relocate these assets to other markets, or in some cases, to retire, sell or otherwise dispose of
these assets.
Drilling Solutions
We impaired or retired $28.6 million of fixed assets, equipment and inventory in our Drilling Solutions segment
as a result of the significant decline in utilization experienced over the first half of the year. We determined that the
assets were either functionally obsolete, would be no longer used, or the carrying value was not fully recoverable and
was in excess of its fair value.
Rig Technologies
As a result of our periodic analysis on inventories for our Rig Technologies segment, we recorded a $2.9
million provision for obsolescence.
62
Oil & gas related assets
During 2020, we recognized an impairment of $24.5 million to various assets related to our retained interest in
the oil and gas properties located on the North Slope of Alaska.
Severance and transaction related costs
During 2020, we recognized charges of $19.1 million due to severance and other related costs incurred to right-
size our cost structure.
Other assets
We wrote down or provided for $19.6 million of certain other assets including receivables related to our
operations. The charges were primarily attributable to markets which have been adversely impacted by foreign sanctions
or other political risk issues as well as bankruptcies or other financial problems.
For the year ended December 31, 2019
Goodwill impairments
As part of our annual goodwill impairment test performed during the second quarter of 2019, we determined the
carrying value of some of our reporting units exceeded their fair value. As such, we recognized impairments of $75.6
million for the remaining goodwill balance attributable to our International Drilling operating segment and $18.0 million
for a partial impairment to our goodwill balance attributable to the acquisition of 2TD reported within our Rig
Technologies operating segment. These non-cash pre-tax impairment charges were primarily the result of a sustained
decline in our market capitalization and lower future cash flow projections due to expectations for future commodity
t
prices below previous projections and the resulting impact on the lower demand projections for our products and
services within these reporting units.
During the fourth quarter of 2019, due to current industry conditions such as the drop in U.S. rig count as well
as the recent commodity prices and the corresponding impact on future expectations of demand for our products and
services, including the effect that these factors have had on our stock price, we performed a quantitative impairment
assessment of our goodwill as of December 31, 2019. Based on the results of our goodwill test, we recognized additional
impairment charges of $52.2 million for the remaining goodwill balance attributable to our U.S. Drilling operating
segment and $10.1 million for the remaining goodwill balance attributable to the acquisition of 2TD within our Rig
Technologies operating segment.
u
Intangible asset impairments
During the fourth quarter of 2019, we also determined the fair value of our rotary steerable tools in-process
research and development intangible asset associated with our acquisition of 2TD was less than the current book value.
As such, we recognized an impairment of $47.7 million to write off the intangible asset due to uncertainty in
commercialization and demand stemming from lower commodity prices and rig counts.
Canada
As a result of the extended period of reduced demand for some of our legacy asset classes, we retired some of
our rigs within the Canada drilling segment, which totaled approximately $17.8 million.
63
International Drilling
During 2019, we retired some of our rigs resulting in a loss of $15.4 million. In addition, we recorded
impairments totaling $2.5 million comprised of underutilized offshore platform rigs. These impairments resulted from
lack of future contractual opportunities on specific rigs as a result of current market conditions across certain geographic
regions.
ff
Rig Technologies
As a result of our periodic analysis on inventories for our Rig Technologies segment, we recorded a $7.8
million provision for obsolescence.
Severance and transaction related costs
During 2019, we recognized charges of $11.4 million due to severance and other related costs incurred to right-
size our cost structure.
Other assets
During 2019, we recorded provisions aggregating to $43.2 million for certain assets, including receivables
related to our international activities. The provisions were attributable to a number of foreign countries, which have been
adversely impacted by foreign sanctions or other political risk issues, bankruptcies or other financial problems.
For the year ended December 31, 2018
US Drilling
As a result of a decline in oil and gas prices in the fourth quarter and the extended period of reduced demand for
some of our legacy asset groups, we retired 13 of or remaining SCR rigs for a loss of $14.6 million. Additionally, we
recorded impairments of $20.5 million for underutilized rigs.
International Drilling
During 2018, we recognized a loss of $64.7 million on the sale of three offshore drilling rigs and eight
workover rigs. In addition, impairments of $11.1 million were deemed necessary due to lack of future contractual
opportunities on specific rigs as a result of a change in market conditions across certain geographic regions.
Rig Technologies
As a result of our periodic analysis on inventories for our Rig Technologies segment, we recorded a $14.0
million provision for obsolescence.
Severance and transaction related costs
During 2018, we incurred $14.3 million in transaction related costs, including professional fees
facility closure costs and other cost rationalization items, primarily in connection with the acquisition of Tesco.
, severances,
ff
Note 4 Accounts Receivable Sales Agreement
On September 13, 2019, we entered into a $250.0 million accounts receivable sales agreement (the “A/R
Agreement”) whereby certain U.S. operating subsidiaries of the Company (collectively, the “Originators”), sold or
contributed, and will on an ongoing basis continue to sell or contribute, certain of their domestic trade accounts
receivables to a wholly owned, bankruptcy-remote, special purpose entity (the “SPE” and “Seller”). The SPE would in
turn, sell, transfer, convey and assign to third-party financial institutions (the “Purchasers”), all the rights, title and
interest in and to its pool of eligible receivables. The sale of these receivables qualified for sale accounting treatment in
accordance with ASC 860. During the period of this program, cash receipts from the Purchasers at the time of the sale
were classified as operating activities in our consolidated statement of cash flows. Subsequent collections on the pledged
64
receivables, which were not sold, will be classified as operating cash flows in our consolidated statement of cash flows at
the time of collection.
Nabors Delaware and/or another subsidiary of Nabors acts as servicers of the sold receivables. The servicers
administer, collect and otherwise enforce these receivables and are compensated for doing so on terms that are generally
consistent with what would be charged by an unrelated servicer. The servicers initially receive payments made by
obligors on the receivables, then remit those payments in accordance with the Receivables Purchase Agreement. The
servicers and the Originators have contingent indemnification obligations to the SPE, and the SPE has contingent
indemnification obligations to the Purchasers, in each case customary for transactions of this type. These contingent
indemnification obligations are guaranteed by the Company pursuant to an Indemnification Guarantee in favor of the
Purchasers. The Purchasers have no recourse for receivables that are uncollectible as a result of the insolvency or
inability to pay of the account debtors.
The maximum purchase commitment of the Purchasers under the A/R Agreement is $250.0 million. The
m
amount available for sale to the Purchasers under the A/R Agreement fluctuates over time based on the total amount of
eligible receivables generated during the normal course of business after excluding excess concentrations and certain
other ineligible receivables. As of December 31, 2020, the total amoun
the Purchasers was $67.0 million, of which $54.0 million had been sold to the Purchasers. Trade accounts receivable
sold by the SPE to the Purchasers are derecognized from our condensed consolidated balance sheet. The fair value of the
sold receivables approximated book value due to the short-term nature of the receivables and, as a result, no gain or loss
on the sale of the receivables was recorded. Trade receivables pledged by the SPE as collateral to the Purchasers
a
(excluding receivables sold to the Purchasers) totaled $63.1 million as of December 31, 2020 and are included in
accounts receivable, net in our condensed consolidated balance sheet. The assets of the SPE cannot be used by the
Company for general corporate purposes. Additionally, creditors of the SPE do not have recourse to assets of the
Company (other than assets of the SPE).
t of eligible receivables available for purchase by
Note 5 Acquisitions
2018 Acquisitions
On October 3, 2018, we purchased PetroMar Technologies, a developer and operator of LWD downhole tools
focusing on high-value formation data to facilitate completion optimization particularly in unconventional reservoirs.
The tools complement our existing wellbore placement capabilities and is included in our Drilling Solutions operating
segment. Under the terms of the transaction, we paid an initial purchase price of $25.0 million. We may also be required
to make future payments that are contingent upon the future financial performance of this operation. As part of our
purchase price allocation, we recorded intangible assets of $36.2 million ($13.7 million of developed technology, $21.7
million of in process research and development and $0.8 million for tradename), goodwill of approximately $11.4
million and other liabilities of $22.6 million (net of other working capital items) primarily related to the estimate of
contingent payments on future financial performance as noted above. The pro forma effect on revenue and net income
(loss) have been determined to be immaterial to our financial statements. After further tests, the acquisition is not
significant and as such we have not included disclosures of the allocation of the purchase price or any pro forma
information.
f
Note 6 Fair Value Measurements
Fair value is the price that would be received upon sale of an asset or paid upon transfer of a liability in an
orderly transaction between market participants at the measurement date (exit price). We utilize market data or
assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the
risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market-corroborated, or
generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to
utilize the best information available. Accordingly, we employ valuation techniques that maximize the use of observable
inputs and minimize the use of unobservable inputs. The use of unobservable inputs is intended to allow for fair value
determinations in situations where there is little, if any, market activity for the asset or liability at the measurement date.
r
65
We are able to classify fair value balances utilizing a fair value hierarchy based on the observability of those inputs.
Under the fair value hierarchy:
•
•
•
Level 1 measurements include unadjusted quoted market prices for identical assets or liabilities in an active
market;
Level 2 measurements include quoted market prices for identical assets or liabilities in an active market
that have been adjusted for items such as effects of restrictions for transferability and those that are not
f
quoted but are observable through corroboration with observable market data, including quoted market
prices for similar assets; and
Level 3 measurements include those that are unobservable and of a subjective nature.
Our financial assets and liabilities that are accounted for at fair value on a recurring basis as of December 31,
2020 and 2019 consisted of short term investments in equity securities. During 2020, there were no transfers of our
financial assets between Level 1 and Level 2 measures. Our financial assets and liabilities are classified in their entirety
based on the lowest level of input that is significant to the fair value m
easurement. As of December 31, 2020 and 2019,
our short-term investments were carried at fair market value and totaled $9.5 million and $16.5 million, respectively, and
primarily consisted of Level 1 measurements. No material Level 2 or Level 3 measurements exist as of any of the
periods presented.
n
Nonrecurring Fair Value Measurements
We applied fair value measurements to our nonfinancial assets and liabilities measured on a nonrecurring basis,
which consist of measurements primarily to assets held-for-sale, goodwill, intangible assets and other long-lived assets
and assets acquired and liabilities assumed in a business combination. Based upon our review of the fair value hierarchy,
the inputs used in these fair value measurements were considered Level 3 inputs.
66
Fair Value of Financial Instruments
We estimate the fair value of our financial instruments in accordance with U.S. GAAP. The fair value of our
long-term debt and revolving credit facilities is estimated based on quoted market prices or prices quoted fromthird-party
financial institutions, thus a Level 2 measurement. The carrying and fair values of these liabilities were as follows:
rr
Effective
Interest
Rate
2020
Carrying
Value
As of December 31,
Fair
Value
Effective
Interest
Rate
(In thousands)
2019
Carrying
Value
Fair
Value
5.00% senior notes due
September 2020 . . . . . . . . . . . . . . . . . .
— % $—
—
— $
—
—
5.44 % $ 282,046 $ 284,907
4.625% senior notes due
September 2021 . . . . . . . . . . . . . . . . . .
5.50% senior notes due January 2023 . .
5.10% senior notes due
5.65 %
5.85 %
86,329
28,443
78,862
18,768
4.76 %
5.90 %
634,588
501,003
632,516
483,834
September 2023 . . . . . . . . . . . . . . . . . .
5.32 %
121,077
78,435
5.24 %
336,810
303,860
0.75% senior exchangeable notes due
Januaryrr 2024 . . . . . . . . . . . . . . . . . . . . .
5.75% senior notes due February 2025 .
6.50% senior priority guaranteed notes
6.06 %
6.01 %
279,700
610,818
169,458
318,871
5.97 %
6.01 %
472,603
781,502
431,503
705,040
due Februaryrr 2025 . . . . . . . . . . . . . . . .
6.50 %
50,485
44,059
— % —
9.00% senior priority guaranteed notes
due Februaryrr 2025 . . . . . . . . . . . . . . . .
9.00 %
192,032
185,221
— % —
7.25% senior guaranteed notes due
Januaryrr 2026 . . . . . . . . . . . . . . . . . . . . .
7.51 %
559,978
396,106
— % —
—
—
—
—
—
—
7.50% senior guaranteed notes due
Januaryrr 2028 . . . . . . . . . . . . . . . . . . . . .
2012 revolving credit facility . . . . . . . . .
2018 revolving credit facility . . . . . . . . .
Less: deferred financing costs . . . . . . . .
7.69 %
— % —
3.53 %
389,609
—
672,500
267,369
—
—
672,500
2,990,971 $ 2,229,649
— % —
3.71 %
— % —
—
355,000
—
—
355,000
—
3,363,552 $ 3,196,660
22,270
$ 2,968,701
30,332
$ 3,333,220
The fair values of our cash equivalents, trade receivables and trade payables approximate their carrying values
due to the short-term nature of these instruments.
Note 7 Share-Based Compensation
Total share-based compensation expense, which includes stock options and restricted shares, was $24.6 million,
$24.7 million and $26.4 million for 2020, 2019 and 2018, respectively. Compensation expense related to awards of
restricted shares totaled $23.6 million, $24.5 million and $26.0 million for 2020, 2019 and 2018, respectively, which is
included in direct costs and general and administrative expenses in our consolidated statements of income (loss). Share-
based compensation expense has been allocated to our various reportable segments. See Note 19—Segment Information.
In addition to the time-based restricted stock share-based awards, historically we have provided two types of
performance share awards: the first, based on our performance measured against pre-determined performance metrics
(“Performance Shares”) and the second, based on market conditions measured against a predetermined peer group
(“TSR Shares”). The performance period for the awards granted in 2020 commenced on January 1, 2019 and ended
December 31, 2019.
In 2020, under the Amended and Restated 2016 Stock Plan, the company introduced new Performance-Based
Restricted Stock Units (“PSUs”) awards to move away from Performance Shares. PSUs are granted at the beginning of
the one-year performance period and they are earned at the end of the same period, depending on performance.
At a special meeting of shareholders held April 20, 2020, the Board set the Reverse Stock Split ratio at 1-for-
50. All share and per share information included in this annual report has been retrospectively adjusted to reflect this
Reverse Stock Split.
67
Stock Option Plans
As of December 31, 2020, we had several stock plans under which options to purchase our common shares
could be granted to key officers, directors and managerial employees of Nabors and its subsidiaries. Options granted
under the plans have fair market value on the date of the grant. Options granted under the plans generally are exercisable
in varying cumulative periodic installments after one year. In the case of certain key executives and directors, options
granted may vest immediately on the grant date. Options granted under the plans cannot be exercised more than ten
years from the date of grant. Options to purchase 0.4 million and 0.2 million Nabors common shares remained available
for grant as of December 31, 2020 and 2019, respectively. Of the common shares available for grant as of December 31,
2020, approximately 0.4 million of these shares are also available for issuance in the form of restricted shares.
The fair value of each option award is estimated on the date of grant using the Black-Scholes option-pricing
model which uses assumptions for the risk-free interest rate, volatility, dividend yield and the expected term of the
options. The risk-free interest rate is based on the U.S. Treasury yield curve in effect at the time of grant for a period
equal to the expected term of the option. Expected volatilities are based on implied volatilities from traded options on
Nabors’ common shares, historical volatility of Nabors’ common shares, and other factors. We use historical data to
estimate the expected term of the options and employee terminations within the option-pricing model; separate groups of
employees that have similar historical exercise behavior are considered separately for valuation purposes. The expected
term of the options represents the period of time that the options granted are expected to be outstanding.
Stock option transactions under our various stock-based employee compensation plans are presented below:
Weighted-
Average
Exercise
Weighted-
Average
Remaining
Contractual
Aggregate
Intrinsic
Options
Shares Price
Term
Value
(In thousands, except exercise price)
Options outstanding as of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . .
Surrendered . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Options outstanding as of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . .
Options exercisable as of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . .
r
33 $ 638.63
964.17
(1)
(1)
718.53
31 $ 628.10
31 $ 628.10
3.40
years $ —
3.40 years $ —
During 2019 and 2018, respectively, we awarded options vesting over periods up to four years to purchase
2,759 and 3,422 of our common shares to certain of our directors. No options were awarded during 2020 nor were there
any unvested options during 2020.
The fair value of stock options granted during 2019 and 2018 was calculated using the Black-Scholes option
pricing model and the following weighted-average assumptions:
Weighted average fair value of options granted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Weighted average risk free interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Dividend yield . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Volatility (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expected life (in years) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
1.79%
1.65%
57.59%
4.0
2019
53.50 $
2018
87.50
2.59%
3.03%
57.11%
4.0
(1)
Expected volatilities are based on implied volatilities from publicly traded options to purchase Nabors' common
shares, historical volatility of Nabors' common shares and other factors.
There were no options exercised during 2020, 2019 or 2018. The total fair value of options that vested during
the years ended December 31, 2019 and 2018 was $0.2 million and $0.4 million, respectively.
68
Restricted Shares
Our stock plans allow grants of restricted shares. Restricted shares are issued on the grant date, but cannot be
sold or transferred. Restricted shares values are based on stock value at grant date. Restricted shares vest in varying
periodic installments ranging up to five years.
A summary of our restricted shares as of December 31, 2020, and the changes during the year then ended, is
presented below:
Restricted shares
Weighted-Average
Grant-Date Fair
Outstanding
Value
(In thousands, except fair value)
Unvested as of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Granted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Vested . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unvested as of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
98 $
4
(45)
(8)
49 $
270.27
35.27
298.17
262.06
226.06
During 2020, 2019 and 2018, we awarded 4,156, 65,299 and 47,850 restricted shares, respectively, to our
employees and directors. These awards had an aggregate value at their date of grant of $0.1 million, $10.6 million and
$16.6 million, respectively, and were scheduled to vest over a period of up to four years. The fair value of restricted
shares that vested during 2020, 2019 and 2018 was $2.6 million, $4.1 million and $8.7 million, respectively.
As of December 31, 2020, there was $6.8 million of total future compensation cost related to unvested
restricted share awards that are expected to vest. That cost is expected to be recognized over a weighted-average period
of approximately two years.
Restricted Shares Based on Performance Conditions
During the years ended December 31, 2020, 2019 and 2018, we awarded 59,490, 48,253 and 20,199 restricted
shares, respectively, vesting over a period of three years to some of our executives. The Performance Share awards
granted were based upon achievement of specific financial or operational objectives. The number of shares granted was
determined by the percentage of performance goals achieved during fiscal years 2019, 2018 and 2017, respectively.
These awards had an aggregate fair value at their date of grant of $8.8 million, $7.5 million and $7.0 million,
respectively.
The following table sets forth information regarding outstanding restricted shares based on performance
conditions as of December 31, 2020:
Performance based restricted shares
Outstanding as of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Granted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Vested . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outstanding as of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-Average
Grant-Date Fair
Outstanding
Value
(In thousands, except fair value)
$
65
59
(26)
98 $
223.39
148.00
276.85
163.74
Until shares are granted, our Performance Share awards are liability-classified awards. Our accrued liabilities
included $2.4 million for such awards at December 31, 2020 for the performance period beginning January 1, 2020
through December 31, 2020 and $2.4 million for such awards at December 31, 2019 for the performance period
beginning January 1, 2019 through December 31, 2019. The fair value of these awards that vested during the years
ended December 31, 2020, 2019 and 2018 was $3.0 million, $2.5 million and $4.8 million, respectively. The fair value
of these liability-classified awards are estimated at each reporting period, based on internal metrics and marked to
market.
During 2020, we granted PSU awards to certain of our executive officers covering a total of 31,204 shares of our
common stock. The number of earned shares that ultimately vest over three years, following conclusion of the
69
performance period, will be determined based upon on achievement of specific financial or operational goals. The
number of earned shares vesting can range from 30% of the PSU awards if minimum thresholds are achieved to a
maximum of 200%.
The following table sets forth information regarding outstanding PSUs based on performance conditions as of
December 31, 2020:
Restricted Stock Units
Outstanding as of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Granted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outstanding as of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Restricted Shares Based on Market Conditions
Weighted-Average
Grant-Date Fair
Outstanding
Value
(In thousands, except fair value)
—
148.00
148.00
$ —
—
31
31 $
During 2020, 2019 and 2018, we granted awards for 22,931, 52,191 and 21,163 TSR Shares, respectively,
which are equity classified awards and will vest on our performance compared to our peer group over a three-year
period. These awards had an aggregate fair value at their date of grant of $3.4 million, $3.7 million and $5.1 million,
respectively, after consideration of all assumptions.
The grant date fair value of these awards was based on a Monte Carlo model, using the following assumptions:
Year Ended December 31,
2019
2018
2020
2.02%
Risk free interest rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Expected volatility. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
57.00%
Closing stock price at grant date . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 148.00 $ 109.50 $ 343.50
Expected term (in years) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3.0
1.57%
74.00%
2.48%
70.00%
3.0
3.0
The following table sets forth information regarding outstanding restricted shares based on market conditions as
of December 31, 2020:
Market based restricted shares
Weighted-Average
Grant-Date Fair
Value
Outstanding
Outstanding as of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Granted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Vested . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Outstanding as of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
(In thousands, except fair value)
142.00
111.00
558.12
558.12
91.34
64
23
(3)
(5)
79 $
As of December 31, 2020, there was $2.9 million of total future compensation cost related to unvested TSR
Share awards. The TSR Shares will amortize over a weighted average remaining period of 1.58 years.
70
Note 8 Property, Plant and Equipment
The major components of our property, plant and equipment are as follows:
December 31,
2020
2019
(In thousands)
Land . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Buildings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling rigs and related equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Oilfield hauling and mobile equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other machinery and equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Oil and gas properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Construction-in-process (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
t
Less: accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
28,261 $
141,365
12,487,961
259,150
195,903
—
—
—
—
33,931
132,603
12,948,504
270,826
192,081
12,286
25,391
$ 13,112,640 $ 13,615,622
(8,685,073)
$ 3,985,707 $ 4,930,549
(9,126,933)
(1)
u
Relates primarily to amounts capitalized for new or substantially new drilling rigs and related equipment that
were under construction and had not yet been placed in service as of December 31, 2019.
Depreciation expense included in depreciation and amortization expense in our consolidated statements of
income (loss) totaled $851.8 million, $869.6 million and $860.6 million during 2020, 2019 and 2018, respectively.
rr
Repair and maintenance expense included in direct costs in our consolidated statements of income (loss) totaled
n
$154.2 million, $248.6 million and $265.6 million during 2020, 2019 and 2018, respectively.
Interest costs of $0.7 million, $1.5 million and $1.0 million were capitalized during 2020, 2019 and 2018,
respectively.
Note 9 Financial Instruments and Risk Concentration
We may be exposed to certain market risks arising from the use of financial instruments in the ordinary course
of business. These risks arise primarily as a result of potential changes in the fair market value of financial instruments
that would result from adverse fluctuations in foreign currency exchange rates, credit risk, interest rates, and marketable
and non-marketable security prices as discussed below.
Foreign Currency Risk
We operate in a number of international areas and are involved in transactions denominated in currencies other
than U.S. dollars, which exposes us to foreign exchange rate risk or foreign currency devaluation risk. The most
significant exposures arise in connection with our operations in Argentina, Russia and Canada, which usually are
substantially unhedged.
At various times, we utilize local currency borrowings (foreign-currency-denominated debt), the payment
structure of customer contracts and foreign exchange contracts to selectively hedge our exposure to exchange rate
fluctuations in connection with monetary assets, liabilities, cash flows and commitments denominated in certain foreign
currencies. A foreign exchange contract is a foreign currency transaction, defined as an agreement to exchange different
currencies at a given future date and at a specified rate.
uu
Credit Risk
Our financial instruments that potentially subject us to concentrations of credit risk consist primarily of cash
equivalents, short-term and long-term investments and accounts receivable. Cash equivalents such as deposits and
temporary cash investments are held by major banks or investment firms. Our short-term and long-term investments are
managed within established guidelines that limit the amounts that may be invested with any one issuer and provide
guidance as to issuer credit quality. We believe that the credit risk in our cash and investment portfolio is minimized as a
result of the mix of our investments. In addition, our trade receivables are with a variety of U.S., international and
71
foreign-country national oil and gas companies. As of December 31, 2020, approximately 25% and 21% of our net
accounts receivable balance was related to our operations in Saudi Arabia and Mexico, respectively. Management
considers this credit risk to be limited due to the financial resources of these companies. We perform ongoing credit
evaluations of our customers, and we generally do not require material collateral. We do occasionally require
prepayment of amounts from customers whose creditworthiness is in question prior to providing services to them. We
maintain reserves for potential credit losses, and these losses historically have been within management’s expectations.
Interest Rate and Marketable and Non-marketable Security Price Risk
Our financial instruments that are potentially sensitive to changes in interest rates include our floating rate debt
instruments comprised of our revolving credit facilities and our fixed rate debt securities comprised of our 4.625%,
5.50%, 5.10% and 5.75% senior notes, 0.75% senior exchangeable notes, 7.25% and 7.50% senior guaranteed notes and
6.50% and 9.00% senior priority guaranteed notes.
We may utilize derivative financial instruments that are intended to manage our exposure to interest rate risks.
The use of derivative financial instruments could expose us to further credit risk and market risk. Credit risk in this
context is the failure of a counterparty to perform under the terms of the derivative contract. When the fair value of a
derivative contract is positive, the counterparty would owe us, which can create credit risk for us. When the fair value of
a derivative contract is negative, we would owe the counterparty, and therefore, we would not be exposed to credit risk.
We attempt to minimize credit risk in derivative instruments by entering into transactions with major financial
institutions that have a significant asset base. Market risk related to derivatives is the adverse effect on the value of a
financial instrument that results from changes in interest rates. We try to manage market risk associated with interest-rate
contracts by establishing and monitoring parameters that limit the type and degree of market risk that we undertake.
k
t
Note 10 Debt
Debt consisted of the following:
As of December 31,
2019
2020
(In thousands)
—
— $
5.00% senior notes due September 2020 (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
4.625% senior notes due September 2021 (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.50% senior notes due January 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.10% senior notes due September 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
0.75% senior exchangeable notes due Januaryrr 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.75% senior notes due February 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
6.50% senior priority guaranteed notes due Februaryrr 2025 . . . . . . . . . . . . . . . . . . . . . . . .
9.00% senior priority guaranteed notes due Februaryrr 2025 . . . . . . . . . . . . . . . . . . . . . . . .
7.25% senior guaranteed notes due Januaryrr 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7.50% senior guaranteed notes due Januaryrr 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2012 revolving credit facility (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2018 revolving credit facility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
—
—
—
—
355,000
—
3,363,552
30,332
Less: deferred financing costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2,968,701 $ 3,333,220
86,329
28,443
121,077
279,700
610,818
50,485
192,032
559,978
389,609
—
—
672,500
2,990,971
22,270
282,046
634,588
501,003
336,810
472,603
781,502
(1) The 5.00% senior notes due September 2020 and 2012 Revolving Credit Facility were classified as long-term as of
December 31, 2019 because we had the ability and intent to repay these obligations utilizing our 2018 Revolving
Credit Facility.
(2) The 4.625% senior notes due September 2021 are classified as long-term because we have the ability and intent to
repay this obligation utilizing our 2018 Revolving Credit Facility.
72
As of December 31, 2020, the principal amount and maturities of our primary debt for each of the five years
after 2020 and thereafter are as follows:
ff
Paid at Maturity
(In thousands)
2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Thereafter. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
r
86,500 (1)
—
822,361 (2)
324,322 (3)
853,335 (4)
949,587 (5)
$
3,036,105
(1)
(2)
(3)
(4)
Represents our 4.625% senior notes due September 2021.
Represents our 5.50% senior notes due January 2023, 5.10% senior notes due September 2023 and our 2018
Revolving Credit Facility due October 2023.
Represents our 0.75% senior notes due January 2024.
Represents our 5.75% senior notes due February 2025, 6.5% senior priority guaranteed notes due February
2025 and our 9.0% senior priority guaranteed notes due February 2025.
(5)
Represents our 7.25% senior notes due January 2026 and our 7.50% senior notes due January 2028.
Nabors Delaware’s various fixed rate debt securities comprised of our 4.625%, 5.50%, 5.10%, and 5.75%
senior unsecured notes are fully and unconditionally guaranteed by us. The notes rank equal in right of payment to all
Nabors Delaware’s existing and future senior unsubordinated debt. The notes rank senior in right of payment to all
Nabors Delaware’s existing and future senior subordinated and subordinated debt. Our guarantee of the notes is
unsecured and ranks equal in right of payment to all our unsecured and unsubordinated indebtedness from time to time
outstanding. The notes are subject to redemption by Nabors Delaware, in whole or in part, at any time generally at a
redemption price equal to the greater of (i) 100% of the principal amount of the notes then outstanding to be redeemed;
or (ii) the sum of the present values of the remaining scheduled payments of principal and interest, determined in the
manner set forth in the applicable indenture. In the event of a change in control triggering event, as defined in the
indenture, the holders of notes may require Nabors Delaware to purchase all or any part of each note in cash equal to
101% of the principal amount plus accrued and unpaid interest, if any, to the date of purchase, except to the extent
Nabors Delaware has exercised its right to redeem the notes. The notes have customary covenants, including limitations
on the incurrence of liens and entering into sale and leaseback transactions as well as customary events of default.
f
During 2020, the proceeds from the 7.25% and 7.50% Senior Guaranteed Notes Due January 2026 and 2028
offering were primarily used to repurchase $952.9 million aggregate principal amount of certain of Nabors Delaware’s
senior notes that were tendered in the January 2020 Tender Offers pursuant to an offer to purchase and consent
solicitation. The aggregate principal amount repurchased included approximately (i)$407.7 million of our 5.50% senior
notes due 2023, (ii) $379.7 million of our 4.625% senior notes due 2021 and (iii) $165.5 million of our 5.10% senior
notes due 2023. In connection with the January 2020 Tender Offers, we recognized a net loss of $2.7 million.
During 2020, 2019 and 2018, we repurchased $372.0 million (excluding the January 2020 Tender Offers),
t
$468.3 million, and $873.0 million aggregate principal amount of our senior unsecured notes for approximately $300.9
million, $461.1 million and $906.5 million, respectively, in cash, reflecting principal, accrued and unpaid interest. In
connection with such repurchases, during 2020 and 2019, we recognized a net gain of approximately $69.2 million and
$11.5 million, respectively. During 2018, we recognized net losses of approximately $5.3 million, which represents the
premiums paid in connection with these repurchases or redemptions. In January 2021, we repurchased $23.0 million
aggregate principal amount of debt for approximately $15.1 million.
73
Exchange Transactions
During the fourth quarter of 2020, we entered into a series of public and private exchange transactions in which
Nabors Delaware exchanged newly issued 6.5% Senior Priority Guaranteed Notes due 2025 (the “6.5% Exchange
Notes”) and 9.0% Senior Priority Guaranteed Notes due 2025 (the “9.0% Exchange Notes,” and collectively, the
“Exchange Notes”) for various amounts of existing outstanding notes. Nabors Delaware did not receive any cash
proceeds from the issuance of the Exchange Notes.
Collectively from the series of exchanges, Nabors Industries, Inc. issued $50.5 million aggregate principal
amount of the 6.5% Exchange Notes and $192.0 million aggregate principal amount of new 9.0% Exchange Notes in
exchange for $526.8 million aggregate principal amount of various Nabors Delaware’s outstanding Notes.
We recorded a gain of $161.8 million in connection with the Exchange Transactions, which was accounted for
in accordance with ASC 470-60, Troubled Debt Restructuring by Debtors. Under ASC 470-60, a gain is recorded in an
amount equal to the sum of the future undiscounted payments (principal and interest) related to the new Exchange Notes
plus the costs incurred in connection with the transaction, less the carrying value of the notes that were exchanged. In
relation to the transactions, we recorded $71.6 million related to future contractual interest payments on the new
Exchange Notes, and have included this amount in accrued liabilities and other long-term liabilities.
The aggregate principal amounts and recognized gain for such transactions were as follows (in thousands):
Exchanged:
4.625% senior notes due September 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.50% senior notes due January 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.10% senior notes due September 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
0.75% senior exchangeable notes due Januaryrr 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.75% senior notes due February 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7.25% senior guaranteed notes due Januaryrr 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7.50% senior guaranteed notes due Januaryrr 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Aggregate principal amount exchanged . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Aggregate principal amount of debt issued in exchanges. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Aggregated net gain (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Per share amount of the aggregate gain . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
Year Ended
December 31,
2020
38,209
3,733
19,422
250,678
164,368
40,022
10,391
526,823
242,517
161,808
19.30
In January 2021, Nabors Delaware completed additional exchange transactions whereby (i) $35.0 million
aggregate principal amount of its 0.75% Exchangeable Notes and (ii) $5.0 million of its 5.75% Senior Notes were
exchanged for an additional issuance of $26.05 million of 9.0% Exchange Notes.
6.50% and 9.00% Senior Priority Guaranteed Notes due February 2025
In connection with the exchange transactions discussed above, in the fourth quarter of 2020, Nabors Delaware
issued $50.5 million aggregate principal amount of 6.5% Exchange Notes in a private exchange transaction in exchange
for $115.0 million aggregate principal amount of Nabors Delaware’s outstanding 0.75% Exchangeable Notes and $192.0
million aggregate principal amount of 9.0% Exchange Notes in a public exchange transaction in exchange for $411.8
million aggregate principal amount of various series of our and Nabors Delaware’s outstanding debt securites. The
Exchange Notes are guaranteed by (i) the Company, (ii) each of the subsidiaries of the Company that guarantee the
2026/2028 Notes and (iii) certain lower tier subsidiaries of the Company that guarantee Nabors Delaware’s 2018
Revolving Credit Facility. The guarantees of the Exchange Notes by the Lower Tier Guarantors are contractually
subordinate in right of payment to such subsidiaries’ guarantee of certain senior guaranteed debt, including obligations
under our 2018 Revolving Credit Facility.
Nabors Delaware did not receive any cash proceeds from the issuance of the Exchange Notes. The Exchange
Notes bear interest at an annual rate of 9.0% and will mature on February 1, 2025.
74
In January 2021, Nabors Delaware completed additional exchange transactions whereby $35 million aggregate
principal amount of its 0.75% Exchangeable Notes and $5 million of its 5.75% Senior Notes were exchanged for $26.05
million of the 9.0% Exchange Notes.
7.25% and 7.50% Senior Guaranteed Notes Due January 2026 and 2028
In January 2020, Nabors completed a private placement of $600.0 million aggregate principal amount of the 2026
Notes and $400.0 million aggregate principal amount of the 2028 Notes (collectively the “2026/2028 Notes”). The
2026/2028 Notes bear interest at an annual rate of 7.25% and 7.50%, respectively. The 2026/2028 Notes are fully and
unconditionally guaranteed by the 2026/2028 Notes Guarantors.
0.75% Senior Exchangeable Notes Due January 2024
In January 2017, Nabors Delaware issued $575.0 million in aggregate principal amount of 0.75% exchangeable
senior unsecured notes due 2024, which are fully and unconditionally guaranteed by Nabors. The notes bear interest at a
rate of 0.75% per year payable semiannually on January 15 and July 15 of each year, beginning on July 15, 2017. The
exchangeable notes are bifurcated for accounting purposes into debt and equity components of $411.2 million and
$163.8 million, respectively, based on the relative fair value at the issuance date.
The exchangeable notes are exchangeable, under certain conditions, at an initial exchange rate of .795 common
shares of Nabors per $1,000 principal amount of exchangeable notes (equivalent to an initial exchange price of
approximately $1,257.81 per common share). Upon any exchange, Nabors Delaware will settle its exchange obligation
in cash.
In connection with the Exchange Transactions, approximately $250.7 million of the aggregate principal amount
of the exchangeable notes were exchanged for new Exchange Notes, leaving approximately $324.3 million in aggregate
principal amount outstanding as of December 31, 2020.
2018 Revolving Credit Facility
In October 2018, Nabors Delaware and Nabors Drilling Canada Limited (“Nabors Canada” and together with
Nabors Delaware, the “Borrowers”) entered into a credit agreement dated October 11, 2018 by and among the
Borrowers, the Guarantors identified therein, HSBC Bank Canada, as the Canadian lender (the “Canadian Lender”) the
issuing banks and other lenders party thereto (the “US Lenders” and, together with the Canadian Lender, the “Lenders”)
and Citibank, N.A., as administrative agent solely for the U.S. Lenders (as may be amended, restated, supplemented or
otherwise modified from time to time, the “2018 Revolving Credit Facility”). The 2018 Revolving Credit Facility
originally had a borrowing capacity of $1.267 billion and is fully and unconditionally guaranteed by Nabors and certain
of its wholly owned subsidiaries. The 2018 Revolving Credit Facility matures at the earlier of (a) October 11, 2023 and
(b) July 19, 2022, if any of Nabors Delaware’s existing 5.50% senior notes due January 2023 remain outstanding as of
such date. The 2018 Revolving Credit Facility contains certain affirmative and negative covenants. Amendment No. 1
to the 2018 Revolving Credit Facility provided for additional currencies in which letters of credit could be issued. On
December 13, 2019, Amendment No. 2 was entered into which reduced the borrowing capacity to $1.0136 ($981.6
million for Nabors Delaware and $32.0 million for Nabors Canada), and replaced the net funded debt to capitalization
covenant with a covenant to maintain net funded indebtedness at no greater than 5.5 times EBITDA. Amendment No. 3
to the 2018 Revolving Credit Facility was entered into on March 3, 2020, in order to permit letters of credit from the
Canadian Lender on the portion of the facility dedicated to Canadian borrowings.
In September 2020, Amendment No. 4 was entered into in order to revise certain of the covenant and collateral
requirements under the 2018 Revolving Credit Facility. Amendment No. 4 provides the Lenders with a first lien security
interest in certain drilling rigs located in the U.S. and Canada and replaces the existing covenant to maintain net funded
debt at no greater than 5.5 times EBITDA with a new covenant to maintain minimum liquidity of no less than $160.0
million at any time. Minimum liquidity is defined to mean, generally, a consolidated cash balance consisting of (a) the
aggregate amount of unrestricted cash and cash equivalents maintained in a deposit account U.S. or Canadian branch of
a commercial bank, plus (b) the lesser of $75 million or an amount equal to 75% of the aggregate amount of unrestricted
cash and cash equivalents held in deposit account of a commercial bank outside of the U.S. or Canada, plus (c) available
commitments under the 2018 Revolving Credit Facility. Additionally, the “asset to debt coverage” ratio was revised
such that during any period in which Nabors Delaware fails to maintain an investment grade rating from at least two
75
ratings agencies, the guarantors under the facility and their respective subsidiaries will be required to maintain an asset to
debt coverage of at least 4.25:1, which was the case as of the date of this report. As of December 31, 2020, we had
$672.5 million outstanding under our 2018 Revolving Credit Facility and the net book value of the collateralized assets
under the 2018 Revolving Credit Facility was $1.3 billion. The weighted average interest rate on borrowings under the
2018 Revolving Credit Facility at December 31, 2020 was 3.53%. In order to make any future borrowings under the
2018 Revolving Credit Facility, Nabors and certain of its wholly owned subsidiaries are subject to compliance with the
conditions and covenants contained therein, including compliance with applicable financial ratios.
As of the date of this report, we were in compliance with all covenants under the 2018 Revolving Credit
Facility. We expect to remain in compliance with all covenants under the 2018 Revolving Credit Facility during the
twelve month period following the date of this report based on our current operational and financial projections.
However, we can make no assurance of continued compliance if our current projections or material underlying
assumptions prove to be incorrect. If we fail to comply with the covenants, the revolving credit commitment could be
terminated, and any outstanding borrowings under the facility could be declared immediately due and payable.
2012 Revolving Credit Facility
We repaid all outstanding amounts under the 2012 Revolving Facility in April 2020 and have terminated the
facility.
Short-Term Borrowings
We had 18 letter-of-credit facilities with various banks as of December 31, 2020. Availability and borrowings
under our letter-of-credit facilities are as follows:
Credit available . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: Letters of credit outstanding, inclusive of financial and performance guarantees . . . . . . . . . . . . . .
Remaining availabilitytt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Note 11 Income Taxes
Income (loss) from continuing operations before income taxes consisted of the following:
December 31,
2020
(In thousands)
630,552
$
114,984
515,569
$
United States and Other Jurisdictions
2020
Year Ended December 31,
2019
(In thousands)
2018
United States . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (182,706) $
Other jurisdictions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5,979 $ (119,419)
(399,375)
Income (loss) from continuing operations before income taxes . . . . . . . . . . $ (705,567) $ (588,922) $ (518,794)
(594,901)
(522,861)
76
Income tax expense (benefit) from continuing operations consisted of the following:
Year Ended December 31,
2019
2018
2020
(In thousands)
Current:
U.S. federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (39,268) $
Outside the U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
33,858
(2,020)
1,210 $ (32,351)
32,928
54,097
1,811
318
2,388
$ (7,430) $ 55,625 $
Deferred:
U.S. federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 67,909 $ 58,157 $ 37,476
Outside the U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
39,518
(113)
State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 64,716 $ 35,951 $ 76,881
Income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 57,286 $ 91,576 $ 79,269
(25,428)
3,222
(4,992)
1,799
A reconciliation of our statutory tax rate to our worldwide effective tax rate consists of the following:
2020
Year Ended December 31,
2019
(In thousands)
2018
Income tax provision at statutoryrr (Bermuda rate of 0%) . . . . . . . . . . . . . . . . . . . . $
Taxes (benefit) on U.S. and other international earnings (losses) at greater
— $—
— $ —
—
49,375
than the Bermuda rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
38,822
Increase (decrease) in valuation allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Tax reserves and interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(10,626)
State income taxes (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
1,698
Income tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 57,286 $ 91,576 $ 79,269
(15.3)%
Effective tax rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
62,751
(9,759)
861
3,433
54,060
32,869
1,107
3,540
(15.5)%
(8.1)%
t
The decrease in tax expense during 2020 compared to 2019 was primarily attributable to a decrease in operating
income in the jurisdictions in which we operate, as well as the change in our geographic mix of our pre-tax earnings
(losses). The decrease was partially offset by the gain related to our debt exchange transaction and the resulting
utilization of net operating losses.
77
The components of our net deferred taxes consisted of the following:
Deferred tax assets:
December 31,
2020
2019
(In thousands)
Net operating loss carryrr forwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 3,618,227 $ 2,834,851
Equity compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
6,577
Deferred revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
8,873
97,215
Tax credit and other attribute carryrr forwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Insurance loss reserves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2,248
172,120
Accrued interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
—
Depreciation and amortization for tax in excess of book expense . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
95,588
3,217,472
Subtotal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(2,813,567)
Valuation allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred tax assets: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
403,905
Deferred tax liabilities:
1,594
3,878
84,502
2,086
—
—
44,837
110,003
3,865,127
(3,602,144)
262,983 $
r
r
Depreciation and amortization for tax in excess of book expense . . . . . . . . . . . . . . . . . $
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Deferred tax liability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Net deferred tax assets (liabilities) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
—
— $
17,388
17,388 $
245,595 $
80,155
21,055
101,210
302,695
Balance Sheet Summaryrr :
Net noncurrent deferred tax asset . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Net noncurrent deferred tax liabilitytt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net deferred tax asset (liabilitytt ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
247,171 $
(1,576)
245,595 $
305,844
(3,149)
302,695
As of December 31, 2020, we had federal, state, and foreign net operating loss (“NOL”) carryforwards of
approximately $670.3 million, $1.2 billion and $13.8 billion, respectively. Of those amounts, $6.4 billion will expire
between 2021 and 2040 if not utilized. We provide a valuation allowance against NOL carryforwards in various tax
jurisdictions based on our consideration of existing temporary differences and expected future earning levels in those
jurisdictions. A valuation allowance of approximately $3.4 billion has been recognized related to certain NOL
carryforwards as we believe it is more likely than not that the benefit of these NOL carryforwards will not be realized.
ff
The following is a reconciliation of our uncertain tax positions:
2020
2019
2018
Balance as of Januaryrr 1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 25,770
—
Additions based on tax positions related to the current year . . . . . . . . . . . . . . . .
Additions for tax positions of prior years . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Reductions for tax positions for prior years . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
1,887
(953)
—
r
Balance as of December 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 26,704
r
(In thousands)
$ 25,711 $ 33,203
—
1,003
(860)
(84)
—
308
(7,800)
—
$ 25,770 $ 25,711
If the unrecognized tax benefits of $26.7 million are realized, this would favorably impact the worldwide
effective tax rate. As of December 31, 2020, 2019 and 2018, we had approximately $7.6 million, $7.7 million and $6.7
million, respectively, of interest and penalties related to uncertain tax positions. During 2020, 2019 and 2018, we
accrued and recognized estimated interest and penalties related to uncertain tax positions of approximately
($0.6) million, $0.8 million and $1.0 million, respectively. We include potential interest and penalties related to
uncertain tax positions within our global operations in the income tax expense (benefit) line item in our consolidated
statements of income (loss).
78
It is reasonably possible that our existing liabilities related to our reserve for uncertain tax positions may
increase or decrease in the next twelve 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 conduct business globally and, as a result, we file numerous income tax returns in the U.S. and non-U.S.
jurisdictions. In the normal course of business we are subject to examination by taxing authorities throughout the world,
including major jurisdictions such as Algeria, Canada, Mexico, Saudi Arabia and the United States. We are no longer
subject to U.S. Federal income tax examinations for years before 2017 and non-U.S. income tax examinations for years
before 2007.
Note 12 Shareholders’ Equity
Common shares
Our authorized share capital consists of 57.0 million shares of which 32.0 million are common shares, par value
$0.05 per share, and 25.0 million are preferred shares, par value $0.001 per share.
The preferred shares are issuable in
ff
one or more classes or series, full, limited or no voting rights, designations, preferences, special rights, qualifications,
limitations and restrictions, as may be determined by the Board.
During 2020, we repurchased 34 thousand of our common stock for an aggregate price of approximately $1.7
million, all of which are held by our subsidiaries, and which are accounted for as treasury stock.
During 2018, we issued 0.8 million of our common shares at a price to the public of $387.50 per share. Nabors
received aggregate net proceeds of approximately $301.4 million after deducting underwriting discounts, commissions
and offering expenses.
From time to time, treasury shares may be reissued subject to applicable securities law limitations. When shares
are reissued, we use the weighted-average-cost method for determining cost. The difference between the cost of the
shares and the issuance price is added to or deducted from our capital in excess of par value account. No shares have
been reissued during 2020, 2019 or 2018.
Convertible Preferred Shares
During 2018, we issued 5.75 million (including the underwriters option for .75 million) of our 6% Series A
Mandatory Convertible Preferred Shares (the “mandatory convertible preferred shares”), par value $.001 per share, with
a liquidation preference of $50 per share. Nabors received aggregate net proceeds of approximately $277.9 million after
deducting underwriting discounts, commissions and offering expenses. During 2019, we repurchased 136,772 of our
mandatory convertible preferred shares for approximately $2.9 million. In March 2020, our Board authorized a share
repurchase program under which we may repurchase, from time to time, up to $15.0 million of our mandatory
convertible preferred shares in the open market or in privately negotiated transactions. Through December 31, 2020, we
repurchased and canceled 0.9 million mandatory convertible preferred shares
approximately $15.0 million.
for an aggregate purchase price of
aa
aa
The dividends on the mandatory convertible preferred shares are payable on a cumulative basis at a rate of 6%
annually on the initial liquidation preference of $50 per share. Dividends accumulate and are paid quarterly to the extent
that we have available funds and our Board declares a dividend payable. We may elect to pay any accumulated and
unpaid dividends in cash or common shares or any combination thereof. At issuance, each mandatory convertible
preferred share was automatically convertible into between 0.1075 and 0.1290 of our common shares based on the
average share price over a period of twenty consecutive trading days ending prior to May 1, 2021, subject to anti-dilution
adjustments. As a result of the dividends paid on our common shares since the offering, the most recent publicly
announced conversion rate for each mandatory convertible preferred share is between 0.1144 and 0.1372 of our common
shares. Adjustments to the conversion ratio are required to be made and published when such adjustment would result in
an increase or decrease of one percent or more of the conversion rate. At any time prior to May 1, 2021, a holder of
mandatory convertible preferred shares may convert such mandatory convertible preferred shares into our common
shares at the minimum conversion rate, subject to adjustment. Otherwise, the mandatory convertible preferred shares
will automatically convert into common shares on May 1, 2021.
t
79
On February 23, 2021, the final cash dividend of $0.75 per mandatory convertible preferred share was declared
for shareholders and will be paid on May 3, 2021, to holders presenting the Preferred Shares for conversion.
Shareholder Rights Plan
On May 5, 2020, our Board adopted a shareholder rights plan and declared a dividend of one right (a “Right”)
for each outstanding common share to shareholders of record on May 15, 2020. Each Right entitles the holder to
purchase from Nabors one one-thousandth of a Series B Junior Participating Preferred Share, par value $0.001 per share
(the “Series B Preferred Shares”), of Nabors at a price of $58.08 per one one-thousandth of a Series B Preferred Share,
subject to adjustment. The description of the Rights are set forth in a Rights Agreement, dated May 5, 2020 (as amended
from time to time, the “Rights Agreement”), by and between Nabors and Computershare Trust Company, N.A., as
Rights Agent.
Initially, the Rights will not be exercisable and will trade with our common shares. Under the Rights
a
Agreement, the Rights will become exercisable only if a person or group or pers
ons acting together (each, an “acquiring
person”) acquires beneficial ownership of 4.9% or more of our outstanding common shares. The Rights Agreement was
amended on (i) May 27, 2020, to permit the shareholder identified therein, together with affiliates and associates, to
beneficially own up to 10% of our outstanding common shares before becoming an “acquiring person” (the “First
Amendment Identified Shareholder”), and on (ii) February 5, 2021, to permit the shareholder identified therein to
beneficially own up to 20% of our common shares or preferred shares before becoming an “acquiring person”, provided
that no fund of the shareholder other than one identified to Nabors (the “Second Amendment Identified Shareholder”)
shall be able to hold more 4.9% or more of the common shares or preferred shares, with the Second Amendment
Identified Shareholder being restricted from holding 7% or more of the common shares or preferred shares.
ff
If the Rights are triggered, each holder of a Right (other than the acquiring person, whose Rights will become
void) will be entitled to purchase additional shares of our common stock at a 50% discount. In addition, if we are
acquired in a merger or other business combination after someone has become an acquiring person, each holder of a
Right would then be entitled to purchase shares of the acquiring company’s stock at a 50% discount. Our Board, at its
option, may exchange each Right (other than Rights owned by the acquiring person that have become void), in whole or
in part, at an exchange ratio of one common share per outstanding Right, subject to adjustment. Except as provided in
the Rights Agreement, our Board is entitled to redeem the Rights at $0.01 per Right.
A person or group of persons that beneficially owns our common shares at or above the trigger threshold as of
the time of the public announcement of the Rights Agreement generally will not become an acquiring person until such
person or group of persons increases its ownership by 0.5% or more.
Note 13 Joint Ventures
During 2016, we entered into an agreement with Saudi Aramco, to form a new joint venture, SANAD, to own,
manage and operate onshore drilling rigs in the Kingdom of Saudi Arabia. SANAD, which is equally owned by Saudi
Aramco and Nabors, began operations during the fourth quarter of 2017.
During 2017, Nabors and Saudi Aramco each contributed $20 million in cash for the purpose of capitalizing the
joint venture upon formation. In addition, since inception Nabors and Saudi Aramco have each contributed a
each with a value of approximately
qq
combination of drilling rigs, drilling rig equipment and other assets, including cash,
$394 million to the joint venture. The contributions were received in exchange for redeemable ownership interests which
accrue interest annually, have a twenty-five year maturity and are required to be converted to authorized capital should
certain events occur, including the accumulation of specified losses. In the accompanying
d
Nabors has reported Saudi Aramco’s share of authorized capital as a component of noncontrolling interest in equity and
Saudi Aramco’s share of the redeemable ownership interests as redeemable noncontrolling interests in subsidiary,
classified as mezzanine equity. The accrued interest on the redeemable ownership interest is a non-cash financing
activity and is reported as an increase in the redeemable noncontrolling interest in subsidiary line in our condensed
consolidated balance sheet. In January 2021, SANAD settled approximately $100 million of the accrued interest from
inception to December 31, 2020, by making a cash payment to each partner for their respective amounts. The assets and
liabilities included in the condensed balance sheet below are (1) assets that can either be used to settle obligations of the
consolidated balance sheet
80
VIE or be made available in the future to the equity owners through dividends, distributions or in exchange of the
redeemable ownership interests (upon mutual agreement of the owners) or (2) liabilities for which creditors do not have
recourse to other assets of Nabors.
The condensed balance sheet of SANAD, as included in our consolidated balance sheet, is presented below.
December 31,
2020
2019
(In thousands)
Assets:
Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other current assets. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Property, plant and equipment, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
t
$ 368,981 $
79,711
17,148
428,331
2,590
$ 896,761 $
289,575
68,624
18,149
455,751
15,118
847,217
Liabilities:
Accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
$
61,808 $
18,791
80,599 $
64,365
17,929
82,294
Note 14 Related-Party Transactions
Nabors and certain current and former key employees, including Mr. Petrello, entered into split-dollar life
insurance agreements, pursuant to which we pay a portion of the premiums under life insurance policies with respect to
f
these individuals and, in some instances, members of their families. These agreements provide that we are reimbursed
for the premium payments upon the occurrence of specified events, including the death of an insured individual. Any
recovery of premiums paid by Nabors could be limited to the cash surrender value of the policies under certain
circumstances. As such, the values of these policies are recorded at their respective cash surrender values in our
consolidated balance sheets. We have made premium payments to date totaling $6.6 million related to these policies.
The cash surrender value of these policies of approximately $5.5 million is included in other long-term assets in our
consolidated balance sheets as of December 31, 2020 and 2019.
Under the Sarbanes-Oxley Act of 2002, the payment of premiums by Nabors under the agreements could be
deemed to be prohibited loans by us to these individuals. Consequently, we have paid no premiums related to our
agreements with these individuals since the adoption of the Sarbanes-Oxley Act.
In the ordinary course of business, we enter into various rig leases, rig transportation and related oilfield
services agreements with our unconsolidated affiliates at market prices. Historically, these transactions primarily related
to our former equity method investment in Nabors Arabia. During 2017, our joint venture with Saudi Aramco, SANAD,
began operations. As such, we have included transactions with Saudi Aramco effective as of the commencement of
operations of SANAD. See Note 13 — Joint Ventures. Revenues from business transactions with these affiliated entities
totaled $612.7 million, $672.9 million and $723.8 million for 2020, 2019 and 2018, respectively. Expenses from
business transactions with these affiliated entities totaled $0.2 million for 2018. Additionally, we had accounts
receivable from these affiliated entities of $90.4 million and $80.6 million as of December 31, 2020 and 2019.
In addition, Mr. Crane, one of our independent directors, is Chairman and Chief Executive Officer of Crane
Capital Group Inc. (“CCG”), an investment company that indirectly owns a majority interest in several operating
companies, some of which have provided services to us in the ordinary course of business, including international
logistics and electricity. During 2020, 2019 and 2018, we incurred costs for these services of $6.2 million, $20.0 million
and $17.1 million, respectively. We had accounts payable to these CCG-related companies of $0.8 million and
m
$2.4 million as of December 31, 2020 and 2019.
81
Note 15 Commitments and Contingencies
Commitments
Under the joint venture agreement with Saudi Aramco, the agreement requires us to backstop our share of the
joint venture’s obligations to purchase the first 25 drilling rigs in the event that there is insufficient cash in the joint
venture or third party financing available. Although we currently anticipate that the future rig purchase needs will be met
by cash flows from the joint venture and/or third party financing, no assurance can be given that the joint venture will
not require us to fund our backstop.
Leases
Nabors and its subsidiaries occupy various facilities and lease certain equipment under various lease
agreements. Rental expense relating to operating leases with terms greater than 30 days amounted to $12.4 million,
$15.9 million and $18.7 million for the years ended December 31, 2020, 2019 and 2018, respectively. See Note 21 —
Leases for more information on the minimum rental commitments under non-cancelable operating leases.
Contingencies
Income Tax Contingencies
We operate in a number of countries and our tax returns filed in those jurisdictions are subject to review and
examination by tax authorities within those jurisdictions. We do not recognize the benefit of income tax positions we
believe are more likely than not to be disallowed upon challenge by a tax authority. If any tax authority successfully
challenges our operational structure, intercompany pricing policies or the taxable presence of our 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 change substantially.
t
Litigation
Nabors and its subsidiaries are defendants or otherwise involved in a number of lawsuits in the ordinary course
of business. We estimate the range of our liability related to pending litigation when we believe the amount and range of
loss can be estimated. We record our best estimate of a loss when the loss is considered probable. When a liability is
probable and there is a range of estimated loss with no best estimate in the range, we record the minimum estimated
liability related to the lawsuits or claims. As additional information becomes available, we assess the potential liability
related to our pending litigation and claims and revise our estimates. Due to uncertainties related to the resolution of
lawsuits and claims, the ultimate outcome may differ from our estimates. For matters where an unfavorable outcome is
reasonably possible and significant, we disclose the nature of the matter and a range of potential exposure, unless an
estimate cannot be made at the time of disclosure. In the opinion of mana
provided, our ultimate exposure with respect to these pending lawsuits and claims is not expected to have a material
adverse effect on our consolidated financial position or cash flows, although they could have a material adverse effect on
our results of operations for a particular reporting period.
gement and based on liability accruals
f
In March 2011, the Court of Ouargla entered a judgment of approximately $21.4 million (at December 31, 2020
exchange rates) against us relating to alleged violations of Algeria’s foreign currency exchange controls, which require
that goods and services provided locally be invoiced and paid in local currency. The case relates to certain foreign
currency payments made to us by CEPSA, a Spanish operator, for wells drilled in 2006. Approximately $7.5 million of
the total contract amount was paid offshore in foreign currency, and approximately $3.2 million was paid in local
currency. The judgment includes fines and penalties of approximately four times the amount at issue. We have appealed
the ruling based on our understanding that the law in question applies only to resident entities incorporated under
Algerian law. An intermediate court of appeals upheld the lower court’s ruling, and we appealed the matter to the
Supreme Court. On September 25, 2014, the Supreme Court overturned the verdict against us, and the case was reheard
by the Ouargla Court of Appeals on March 22, 2015 in light of the Supreme Court’s opinion. On March 29, 2015, the
Ouargla Court of Appeals reinstated the initial judgment against us. We have appealed this decision again to the
Supreme Court. While our payments were consistent with our historical operations in the country, and, we believe, those
of other multinational corporations there, as well as interpretations of the law by the Central Bank of Algeria, the
ultimate resolution of this matter could result in a loss of up to $13.4 million in excess of amounts accrued.
82
On September 29, 2017, we were sued, along with Tesco Corporation and its Board of Directors, in a putative
shareholder class action filed in the United States District Court for the Southern District of Texas, Houston Division.
The plaintiff alleges that the September 18, 2017 Preliminary Proxy Statement filed by Tesco with the United States
Securities and Exchange Commission omitted material information with respect to the proposed transaction between
Tesco and Nabors announced on August 14, 2017. The plaintiff claims that the omissions rendered the Proxy Statement
false and misleading, constituting a violation of Sections 14(a) and 20(a) of the Securities Exchange Act of 1934. The
court consolidated several matters and entered a lead plaintiff appointment order. The plaintiff filed their amended
complaint, adding Nabors Industries Ltd. as a party to the consolidated action. Nabors filed its motion to dismiss, which
was granted by the court on March 29, 2019. The parties filed appellate briefs with the Fifth Circuit Court of Appeals,
and arguments were heard on March 4, 2020. On August 19, 2020, the Fifth Circuit Court upheld the lower court’s
decision dismissing the plaintiff’s claims. The plaintiff failed to file a petition for a writ of certiorari with the United
States Supreme Court within the deadline. Accordingly, all appeal avenues have been exhausted and this matter is now
closed.
Following a routine audit conducted in May and June of 2018 by the Atyrau Oblast Ecology Department (the
“AOED”), our joint venture in Kazakhstan, KMG Nabors Drilling Company (“KNDC”), was administratively fined for
not having emissions permits for KNDC owned or leased equipment. Prior to this audit, the AOED had always accepted
the operator’s permits for all their subcontractors. However, because of major personnel changes, AOED changed this
position and is now requiring that the owner/lessor of the equipment that emits the pollutants must have its own permits.
Administrative fines has been issued to KNDC and paid in the amount of $0.8 million for violations regarding the failure
to have proper permits. AOED had also assessed additional “environmental damages” in the amount of $3.4 million for
the period while KNDC did not hold its’ own emissions permit. However, KNDC appealed this fine and the AOED
Economic Court ruled in KNDC’s favor. AOED appealed this decision, which was reversed on February 21, 2020.
KNDC appealed to the Supreme Court but was unsuccessful in obtaining a reversal of the lower appeals court ruling.
Additional damages in the form of later year audits and taxes could become due as well exposing KNDC to possible
penalties and fines in an amount estimated to be up to approximately $4.0 million, of which we have fully accrued as a
liability. KNDC and the operator have executed an agreement formalizing the operator’s obligation to reimburse KNDC
for many of the financial expenses related to this case as well as penalties and expenses related to future audit periods.
KNDC now has its own permits, and the law has been amended to permit contractors to conduct work based on the
permit of its customer. Meanwhile, KNDC has received notice from government officials that certain of our employees
may be held personally responsible for any violations of the law by KNDC. We continue to be engaged and are
f
monitoring the situation.
Off-Balance Sheet Arrangements (Including Guarantees)
We are a party to some transactions, agreements or other contractual arrangements defined as “off-balance sheet
arrangements” that could have a material future effect on our financial position, results of operations, liquidity and
capital resources. The most significant of these off-balance sheet arrangements include the A/R Agreement (see Note
4—Accounts Receivable Sales Agreement) and certain agreements and obligations under which we provide financial or
performance assurance to third parties. Certain of these financial or performance assurances serve as guarantees,
including standby letters of credit issued on behalf of insurance carriers in conjunction with our workers’ compensation
insurance program and other financial surety instruments such as bonds. In addition, we have provided indemnifications,
which serve as guarantees, to some third parties. These guarantees include indemnification provided by Nabors to our
share transfer agent and our insurance carriers. We are not able to estimate the potential future maximum payments that
might be due under our indemnification guarantees.
Management believes the likelihood that we would be required to perform or otherwise incur any material
losses associated with any of these guarantees is remote. The following table summarizes the total maximum amount of
financial guarantees issued by Nabors:
Financial standby letters of credit and other financial surety
instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 184,675
—
— 112
1,140 $ 185,927
Maximum Amount
2021
2022
2023 Thereafter Total
(In thousands)
83
Note 16 Earnings (Losses) Per Share
ASC 260, Earnings per Share, requires companies to treat unvested share-based payment awards that have
nonforfeitable rights to dividends or dividend equivalents as a separate class of securities in calculating earnings (losses)
per share. We have granted and expect to continue to grant to employees restricted stock grants that contain
nonforfeitable rights to dividends. Such grants are considered participating securities under ASC 260. As such, we are
required to include these grants in the calculation of our basic earnings (losses) per share and calculate basic earnings
(losses) per share using the two-class method. The two-class method of computing earnings per share is an earnings
allocation formula that determines earnings per share for each class of comm
rr
according to dividends declared and participation rights in undistributed earnings. The participating security holders are
not contractually obligated to share in losses. Therefore, losses are not allocated to the participating security holders.
on stock and participating security
Basic earnings (losses) per share is computed utilizing the two-class method and is calculated based on the
weighted-average number of common shares outstanding during the periods presented.
Diluted earnings (losses) per share is computed using the weighted-average number of common and common
equivalent shares outstanding during the periods utilizing the two-class method for stock options and unvested restricted
stock. Shares issuable upon exchange of the 0.75% Exchangeable Notes are not included in the calculation of diluted
earnings (losses) per share unless the exchange value of the notes exceeds their principal amount at the end of the
relevant reporting period, in which case the notes will be accounted for as if the number of common shares that would be
necessary to settle the excess are issued. Such shares are only included in the calculation of the weighted-average
number of shares outstanding in our diluted earnings (losses) per share calculation, when the price of our shares exceeds
f
$1,257.81 on the last trading day of the quarter, which did not occur duri
ng the year ended December 31, 2020.
84
A reconciliation of the numerators and denominators of the basic and diluted earnings (losses) per share
computations is as follows:
Year Ended December 31,
2019
(In thousands, except per share amounts)
2018
2020
BASIC EPS:
Net income (loss) (numerator):
Income (loss) from continuing operations, net of tax . . . . . . . . . . . . . . . . . . . $ (762,853) $ (680,498) $ (598,063)
Less: net (income) loss attributable to noncontrolling interest . . . . . . . . . . . .
(28,222)
Less: preferred stock dividends . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(12,305)
Less: accrued distribution on redeemable noncontrolling interest in
(42,795)
(14,611)
(22,375)
(17,244)
subsidiaryrr . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(17,442)
(20,534)
(11,098)
Less: distributed and undistributed earnings allocated to unvested
shareholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(125)
(459)
(1,819)
Numerator for basic earnings per share:
Adjd usted income (loss) from continuing operations, net of tax - basic . . . . . $ (837,826) $ (741,110) $ (651,507)
(12) $ (14,663)
Income (loss) from discontinued operations, net of tax . . . . . . . . . . . . . . . . . . $
7 $
Weighted-average number of shares outstanding - basic . . . . . . . . . . . . . . . . . . .
Earnings (losses) per share:
7,059
7,032
6,688
Basic from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (118.69) $ (105.39) $
Basic from discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
—
—
—
Total Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (118.69) $ (105.39) $
DILUTED EPS:
Adjd usted income (loss) from continuing operations, net of tax - basic . . . . . . . . $ (837,826) $ (741,110) $ (651,507)
—
Add: effect of reallocating undistributed earnings of unvested shareholders .
—
—
(97.42)
(2.19)
(99.61)
Adjd usted income (loss) from continuing operations, net of tax - diluted . . . . . . $ (837,826) $ (741,110) $ (651,507)
(12) $ (14,663)
Income (loss) from discontinued operations, net of tax . . . . . . . . . . . . . . . . . . . . $
7 $
Weighted-average number of shares outstanding - basic . . . . . . . . . . . . . . . . . . .
Add: dilutive effect of potential common shares . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average number of shares outstanding - diluted . . . . . . . . . . . . . . . . .
Earnings (losses) per share:
7,059
—
7,059
7,032
—
7,032
Diluted from continuing operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (118.69) $ (105.39) $
Diluted from discontinued operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
—
—
—
Total Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (118.69) $ (105.39) $
6,688
—
6,688
(97.42)
(2.19)
(99.61)
All share and per share amounts have been adjusted for the 1-for-50 reverse split that became effective at 11:59
p.m. Eastern time on April 22, 2020.
For all periods presented, the computation of diluted earnings (losses) per share excludes outstanding stock
options with exercise prices greater than the average market price of Nabors’ common shares, because their inclusion
would be anti-dilutive and because they are not considered participating securities. In any period during which the
average market price of Nabors’ common shares exceeds the exercise prices of these stock options, such stock options
will be included in our diluted earnings (losses) per
Restricted stock is included in our basic and diluted earnings (losses) per share computation using the two-class method
of accounting in all periods because such stock is considered participating securities. For periods in which we experience
a net loss from continuing operations, all potential common shares have been excluded from the calculation of weighted-
average shares outstanding, because their inclusion would be anti-dilutive. The average number of shares from options
that were excluded from diluted earnings (losses) per share that would potentially dilute earnings per share in the future
were as follows:
share computation using the if-converted method of accounting.
r
Potentially dilutive securities excluded as anti-dilutive . . . . . . . . . . . . . . . . . . . . . . .
66
40
87
85
2020
Year Ended December 31,
2019
(In thousands)
2018
Additionally, we excluded 0.79 million common shares from the computation of diluted shares issuable upon
the conversion of mandatory convertible preferred shares, because their effect would be anti-dilutive under the if-
converted method.
t
Note 17 Supplemental Balance Sheet, Income Statement and Cash Flow Information
Accrued liabilities include the following:
December 31,
2020
December 31,
2019
(In thousands)
Accrued compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Deferred revenue and proceeds on insurance and asset sales . . . . . . . . . . . . . . . . . . . . . . . . .
Other taxes payaa able . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Workers’ compensation liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest payaa able . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Litigation reserves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Dividends declared and payaa able . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
82,462 $
61,473
28,602
7,788
62,935
13,976
3,653
15,196
97,003
89,051
31,472
30,214
51,316
14,736
7,832
11,658
$ 276,085 $ 333,282
Investment income (loss) includes the following:
2020
Year Ended December 31,
2019
(In thousands)
2018
Interest and dividend income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Gains (losses) on marketable securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
4,957
8,424 $
4,705 $
(14,456)
1,794
(3,267)
1,438 $ 10,218 $ (9,499)
Other, net includes the following:
Losses (gains) on sales, disposals and involuntary conversions of long-lived
2020
Year Ended December 31,
2019
(In thousands)
2018
assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 12,363 $
Litigation expenses and reserves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Foreign currency transaction losses (gains) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other losses (gains) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7,141 $ 11,789
9,939
5,226
4,156
20,929
3,648
(72)
$ 28,567 $ 33,224 $ 29,532
4,249
12,125
(170)
86
The changes in accumulated other comprehensive income (loss), by component, include the following:
Gains
(losses) on
cash flow
hedges
Defined
benefit
pension plan
items
Foreign
currency
items
(In thousands (1) )
Total
As of January 1, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Other comprehensive income (loss) before reclassifications . . . . . .
Amounts reclassified from accumulated other comprehensive
income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net other comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . .
As of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(1)
All amounts are net of tax.
(492) $ (3,945) $ (24,888) $ (29,325)
16,943
16,943
—
—
—
594
427
427
17,537
(65) $ (3,778) $ (7,945) $ (11,788)
—
—
16,943
167
167
Defined
benefit
Gains
(losses) on
cash flow pension plan
hedges
items
Foreign
currency
items
(In thousands (1) )
Total
As of January 1, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Other comprehensive income (loss) before reclassifications . . . . . . .
Amounts reclassified from accumulated other comprehensive
income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net other comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . .
As of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(1)
All amounts are net of tax.
(65) $ (3,778) $ (7,945) $ (11,788)
435
—
435
—
—
229
67
67
664
2 $ (3,616) $ (7,510) $ (11,124)
162
162
—
—
435
The line items that were reclassified to net income include the following:
Line item in consolidated statement of income (loss)
2020
Year Ended December 31,
2019
(In thousands)
2018
Interest expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
567
General and administrative expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
216
Total income (loss) from continuing operations before income tax . . . . . . . . . . . . . . . .
(783)
(187)
Tax expense (benefit) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Reclassification adjd ustment for (gains)/ losses included in net income (loss) . . . . . . . . $ (229) $ (594) $ (596)
160
210
(370)
(141)
567
217
(784)
(190)
87
Supplemental cash flow information includes the following:
2020
Year Ended December 31,
2019
(In thousands)
2018
Cash paid for income taxes (refunded), net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $(17,505) $ 6,553 $ 11,383
Cash paid for interest, net of capitalized interest . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 157,437 $ 174,357 $ 202,803
Net change in accounts payable related to capital expenditures . . . . . . . . . . . . . . . $ (1,188) $ (7,624) $ (8,556)
Non-cash increase in assets attributable to redeemable noncontrolling interest
t
in subsidiaryrr . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
—
— $
—
— $ 43,928
Acquisitions of businesses:
Fair value of assets acquired . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Goodwill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Liabilities assumed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Share issuance as consideration (non-cash financing activitytt ) . . . . . . . . . . . . . .
Cash paid for acquisitions of businesses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash and restricted cash acquired in acquisitions of businesses . . . . . . . . . . . . .
Cash (acquired in) paid for acquisitions of businesses, net . . . . . . . . . . . . . . . . . $
t
—
—
—
—
—
—
—
—
—
—
$ 2,929
—
—
—
—
—
2,929
—
—
$ 2,929
$ 48,053
11,436
(34,489)
—
25,000
(4,141)
$ 20,859
Note 18 Unaudited Quarterly Financial Information
Year Ended December 31, 2020
Quarter Ended
March 31,
June 30,
September 30, December 31,
(In thousands, except per share amounts)
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 718,364 $ 533,931 $ 438,352 $ 443,396
Income (loss) from continuing operations, net of tax . . . . . . . . . . $ (374,269) $ (137,968) $ (146,682) $ (103,934)
Income (loss) from discontinued operations, net of tax . . . . . . . .
55
(103,879)
Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
23
(137,945)
(93)
(374,362)
22
(146,660)
Less: Net (income) loss attributable to noncontrolling
interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(4,358)
Net income (loss) attributable to Nabors . . . . . . . . . . . . . . . . . . . . $ (391,827) $ (148,112) $ (157,465) $ (108,237)
(3,653)
Net income (loss) attributable to Nabors common shareholders . $ (395,479) $ (151,765) $ (161,118) $ (111,890)
Earnings (losses) per share: (1)
Less: Preferred stock dividend . . . . . . . . . . . . . . . . . . . . . . . . .
(10,167)
(10,805)
(17,465)
(3,653)
(3,652)
(3,653)
Basic from continuing operations . . . . . . . . . . . . . . . . . . . . . . . $ (56.72) $
Basic from discontinued operations . . . . . . . . . . . . . . . . . . . . .
Total Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (56.73) $
Diluted from continuing operations . . . . . . . . . . . . . . . . . . . . . $ (56.72) $
Diluted from discontinued operations . . . . . . . . . . . . . . . . . . . .
Total Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (56.73) $
(0.01)
(0.01)
(22.13) $
—
(22.13) $
(22.13) $
—
(22.13) $
(23.42) $
—
—
(23.42) $
(23.42) $
—
—
(23.42) $
(16.46)
0.01
(16.45)
(16.46)
0.01
(16.45)
88
Year Ended December 31, 2019
Quarter Ended
March 31,
June 30,
September 30, December 31,
(In thousands, except per share amounts)
Operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 799,640 $ 771,406 $ 758,076 $ 714,261
(99,788) $ (284,533)
Income (loss) from continuing operations, net of tax . . . . . . . . . . $ (103,376) $ (192,801) $
Income (loss) from discontinued operations, net of tax . . . . . . . .
22
(284,511)
Net income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(34)
(192,835)
(157)
(103,533)
157
(99,631)
Less: Net (income) loss attributable to noncontrolling
interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
21,827
Net income (loss) attributable to Nabors . . . . . . . . . . . . . . . . . . . . $ (117,709) $ (203,564) $ (118,928) $ (262,684)
(4,309)
Net income (loss) attributable to Nabors common shareholders . $ (122,022) $ (207,876) $ (123,238) $ (266,993)
Earnings (losses) per share: (1)
Less: Preferred stock dividend . . . . . . . . . . . . . . . . . . . . . . . . .
(19,297)
(10,729)
(14,176)
(4,312)
(4,310)
(4,313)
Basic from continuing operations . . . . . . . . . . . . . . . . . . . . . . . $
Basic from discontinued operations . . . . . . . . . . . . . . . . . . . . .
Total Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Diluted from continuing operations . . . . . . . . . . . . . . . . . . . . . $
Diluted from discontinued operations . . . . . . . . . . . . . . . . . . . .
Total Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
(18.11) $
(0.02)
(18.13) $
(18.11) $
(0.02)
(18.13) $
(30.31) $
—
—
(30.31) $
(30.31) $
—
—
(30.31) $
(18.27) $
0.02
(18.25) $
(18.27) $
0.02
(18.25) $
(38.66)
—
(38.66)
(38.66)
—
(38.66)
(1)
(2)
Earnings per share is computed independently for each of the quarters presented. Therefore, the sum of the
quarterly earnings per share may not equal the total computed for the year.
q
Note 19 Segment Information
Our business consists of five reportable segments: U.S. Drilling, Canada Drilling, International Drilling,
Drilling Solutions and Rig Technologies. The accounting policies of the segments are the same as those described in
Note 2—Summary of Significant Accounting Policies. Inter-segment sales are recorded at cost or cost plus a profit
margin. We evaluate the performance of our segments based on several criteria, including adjusted operating income
(loss).
The following table sets forth financial information with respect to our reportable operating segments:
2020
Year Ended December 31,
2019
(In thousands)
2018
Operating revenues:
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Rig Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other reconciling items (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
713,057 $ 1,240,936 $ 1,083,227
105,000
68,274
54,753
1,469,038
1,324,142
1,131,673
250,242
252,790
149,834
270,988
260,226
131,555
(120,876)
(102,985)
(46,829)
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 2,134,043 $ 3,043,383 $ 3,057,619
89
Adjd usted operating income (loss): (2)
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (96,176) $
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Rig Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(11,766)
(56,205)
6,167
(13,481)
Total segment adjd usted operating income (loss) . . . . . . . . . . . . . . . . . . . . . $ (171,461) $
64,313 $ (21,298)
(6,166)
(14,483)
74,221
(8,903)
37,626
59,465
(25,762)
(11,247)
58,621
89,145 $
2020
Year Ended December 31,
2019
(In thousands)
2018
Reconciliation of segment adjusted operating income (loss) to net income
2020
Year Ended December 31,
2019
(In thousands)
2018
(loss) from continuing operations before income taxes:
Total segment adjd usted operating income (loss) (2) . . . . . . . . . . . . . . . . . . . . $ (171,461) $
Other reconciling items (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Earnings (losses) from unconsolidated affiliates . . . . . . . . . . . . . . . . . . . . . .
Investment income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Gain/(loss) on debt buybacks and exchanges . . . . . . . . . . . . . . . . . . . . . . . . .
Impairments and other charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
58,621
(166,815)
1
(9,499)
(227,124)
(5,268)
(139,178)
(29,532)
Income (loss) from continuing operations before income taxes . . . . . . . . . . . $ (705,567) $ (588,922) $ (518,794)
(118,346)
—
—
1,438
(206,274)
228,274
(410,631)
(28,567)
(160,274)
(5)
10,218
(204,311)
11,468
(301,939)
(33,224)
89,145 $
t
Depreciation and amortization
2020
Year Ended December 31,
2019
(In thousands)
2018
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 398,326 $ 419,680 $ 394,586
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
37,172
383,227
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
31,037
Rig Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
16,387
4,461
Other reconciling items (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 853,699 $ 876,091 $ 866,870
24,784
377,599
40,074
15,299
(2,383)
29,766
372,883
32,289
12,715
8,758
2020
Year Ended December 31,
2019
(In thousands)
2018
Capital expenditures:
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Rig Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other reconciling items (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
44,606 $ 184,705 $ 222,338
2,018
12,981
5,020
172,565
209,728
127,888
30,709
23,598
12,306
12,250
6,592
2,637
2,592
(5,676)
251
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 189,706 $ 423,967 $ 453,435
90
Total assets:
U.S. Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,871,008 $ 2,369,200
202,706
Canada Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2,979,494
International Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Drilling Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
218,004
Rig Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
324,523
666,731
Other reconciling items (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5,503,428 $ 6,760,658
174,123
2,688,912
100,278
225,954
443,153
December 31,
2020
2019
(In thousands)
(1)
(2)
Represents the elimination of inter-segment transactions related to our Rig Technologies operating segment.
Adjusted operating income (loss) represents income (loss) from continuing operations before income taxes,
interest expense, earnings (losses) from unconsolidated affiliates, investment income (loss), (gain)/loss on debt
buybacks and exchanges, impairments and other charges and other, net. Management evaluates the performance
of our operating segments using adjusted operating income (loss), which is a segment performance measure,
because it believes that this financial measure reflects our ongoing profitability and performan
securities analysts and investors use this measure as one of the metrics on which they analyze our performance.
A reconciliation to income (loss) from continuing operations before income taxes is provided in the above table.
ce. In addition,
a
(3)
Represents the elimination of inter-segment transactions and unallocated corporate expenses, assets and capital
expenditures.
The following table sets forth financial information with respect to Nabors’ operations by geographic area
based on the location of service provided:
Operating revenues
2020
Year Ended December 31,
2019
(In thousands)
2018
U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Outside the U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
841,531 $ 1,554,442 $ 1,347,448
1,710,171
1,488,941
$ 2,134,043 $ 3,043,383 $ 3,057,619
1,292,512
Property, plant and equipment, net:
U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,917,203 $ 2,470,579 $ 2,892,910
Outside the U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2,574,960
$ 3,985,707 $ 4,930,549 $ 5,467,870
2,068,504
2,459,970
Goodwill:
U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Outside the U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$
—
— $
—
—
—
— $
13,430 $
14,950
28,380 $
65,633
118,281
183,914
During the years ended December 31, 2020, 2019 and 2018, $642.7 million, $696.4 million and $764.5 million
of our consolidated operating revenue was from Saudi Arabia. No other individual country outside of the U.S. was
material to our consolidated operating revenue during any of the three periods presented.
One customer accounted for approximately 29%, 22% and 24% of our consolidated operating revenues during
the years ended December 31, 2020, 2019 and 2018, respectively, and is included primarily in our International Drilling
reportable segment.
91
Note 20 Revenue Recognition
We recognize revenue when control of a good or service promised in a contract (i.e., performance obligation) is
transferred to a customer. Control is obtained when a customer has the ability to direct the use of and obtain substantially
all the remaining benefits from that good or service. Contract drilling revenues are recorded over time utilizing the input
method based on time elapsed. The measurement of progress considers the transfer of the service to the customer as we
provide daily drilling services. We receive payment after the services have been performed by billing customers
periodically (typically monthly). However, a portion of our revenues are recognized at a point-in-time as control is
transferred at a distinct point in time such as with the sale of our top drives and other capital equipment. Within our
drilling contracts, we have identified one performance obligation in which the transaction price is allocated.
Disaggregation of revenue
In the following table, revenue is disaggregated by geographical region. The table also includes a reconciliation
of the disaggregated revenue with the reportable segments:
U.S.
Drilling
Canada
Drilling
International
Drilling
Rig
Technologies Other Total
54,185 $
—
19
3,571
58,263
177
15,340
—
691,963
— $
135,601
—
39,221
—
59,461
—
827,501
—
235,685
—
191,440
—
(46,829)
(46,829)
131,555 $ (46,829) $ 2,134,043
Rig
Technologies Other
Total
172,559 $
— $ 1,365,077
170,262
—
67,899
—
78,875
—
865,889
—
373,065
—
225,301
—
(102,985)
(102,985)
260,226 $ (102,985) $ 3,043,383
—
986
8,852
56,455
2,318
19,056
—
Year Ended
December 31, 2020
Drilling
Solutions
(In thousands)
— $ 88,919 $
—
—
—
728,983
228,930
173,760
—
9,309
1,296
1,137
40,255
6,578
2,340
—
Lower 48 . . . . . . . . . . . . . . . . . . . . . . . . $ 548,859 $
U.S. Offshore Gulf of Mexico . . . . . . . .
Alaska . . . . . . . . . . . . . . . . . . . . . . . . . .
Canada . . . . . . . . . . . . . . . . . . . . . . . . .
Middle East & Asia . . . . . . . . . . . . . . . .
Latin America . . . . . . . . . . . . . . . . . . . .
Europe, Africa & CIS . . . . . . . . . . . . . .
Eliminations & other . . . . . . . . . . . . . . .
126,292
37,906
—
—
—
—
—
— $
—
—
54,753
—
—
—
—
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 713,057 $ 54,753 $
1,131,673 $ 149,834 $
U.S.
Drilling
Canada
Drilling
Lower 48 . . . . . . . . . . . . . . . . . . . . . . . . $ 1,021,879 $
U.S. Offshore Gulf of Mexico . . . . . . . .
Alaska . . . . . . . . . . . . . . . . . . . . . . . . . .
Canada . . . . . . . . . . . . . . . . . . . . . . . . .
Middle East & Asia . . . . . . . . . . . . . . . .
Latin America . . . . . . . . . . . . . . . . . . . .
Europe, Africa & CIS . . . . . . . . . . . . . .
Eliminations & other . . . . . . . . . . . . . . .
156,931
62,126
—
—
—
—
—
— $
—
—
68,274
—
—
—
—
International
Drilling
Year Ended
December 31, 2019
Drilling
Solutions
(In thousands)
— $ 170,639 $
—
—
—
765,493
355,189
203,460
—
13,331
4,787
1,749
43,941
15,558
2,785
—
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,240,936 $ 68,274 $
1,324,142 $ 252,790 $
92
U.S.
Drilling
Canada
Drilling
International
Drilling
Rig
Technologies
Other
Total
Year Ended
December 31, 2018
Drilling
Solutions
(In thousands)
Lower 48 . . . . . . . . . . . . . . . . . . . . . . $
U.S. Offshore Gulf of Mexico . . . . . .
Alaska . . . . . . . . . . . . . . . . . . . . . . . .
Canada . . . . . . . . . . . . . . . . . . . . . . .
Middle East & Asia . . . . . . . . . . . . . .
Latin America . . . . . . . . . . . . . . . . . .
Europe, Africa & CIS . . . . . . . . . . . .
Eliminations & other . . . . . . . . . . . . .
910,819 $
122,946
49,462
—
—
—
—
—
— $
—
—
105,000
—
—
—
—
— $ 173,219 $
—
—
—
888,500
360,385
220,153
—
13,776
3,670
5,849
35,486
15,350
2,892
—
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,083,227 $ 105,000 $
1,469,038 $ 250,242 $
Contract balances
188,550 $
— $ 1,272,588
136,722
—
53,909
—
140,531
—
950,222
—
384,249
—
240,274
—
(120,876)
(120,876)
270,988 $ (120,876) $ 3,057,619
—
777
29,682
26,236
8,514
17,229
—
We perform our obligations under a contract with a customer by transferring goods or services in exchange for
consideration from the customer. We recognize a contract asset or liability when we transfer goods or services to a
customer and bill an amount which differs from the revenue allocated to the related performance obligations.
The timing of revenue recognition may differ from the timing of invoicing to customers and these timing
differences result in receivables, contract assets, or contract liabilities (deferred revenue)
on our consolidated balance
sheet. In general, we receive payments from customers based on dayrates as stipulated in our contracts (i.e. operating
rate, standby rate). The invoices billed to the customer are based on the varying rates applicable to the operating status
on each rig. Accounts receivable are recorded when the right to consideration becomes unconditional.
tt
Dayrate contracts also may contain fees charged to the customer for up-front rig modifications, mobilization
and demobilization of equipment and personnel. These fees are associated with contract fulfillment activities, and the
cated to a single performance
a
related revenue (subject to any constraint on estimates of variable consideration) is allo
obligation and recognized ratably over the initial term of the contract. Mobilization fees are generally billable to the
customer in the initial phase of a contract and generate contract liabilities until they are recognized as revenue.
Demobilization fees are generally received at the end of the contract and generate contract assets when they are
recognized as revenue prior to becoming receivables from the customer.
We receive reimbursements from our customers for the purchase of supplies, equipment, personnel services and
other services provided at their request. Reimbursable revenues are variable and subject to uncertainty as the amounts
received and timing thereof are dependent on factors outside of our influence. Accordingly, these revenues are
constrained and not recognized until the uncertainty is resolved, which typically occurs when the related costs are
incurred on behalf of the customer. We are generally considered a principal in these transactions and record the
associated revenues at the gross amounts billed to the customer.
The opening and closing balances of our receivables, contract assets and current and long-term contract
liabilities are as follows:
Contract Contract
Assets
Contract Contract
Liabilities Liabilities
Contract
Assets
Receivables (Current) (Long-term) (Current) (Long-term)
As of December 31, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 507.0 $ 48.6 $
As of December 31, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 427.2 $ 23.5 $
24.9 $ 66.8 $
6.8 $ 42.8 $
70.5
44.2
(In millions)
93
Approximately 61% of the contract liability balance at the beginning of the period was recognized as revenue
during 2020 and 16% is expected to be recognized during 2021. The remaining 23% of the contract liability balance at
the beginning of the period is expected to be recognized as revenue during 2022 or thereafter.
Additionally, 64% of the contract asset balance at the beginning of the period was recognized as expense during
2020 and 22% is expected to be recognized during 2021. The remaining 14% of the contract asset balance at the
beginning of the period is expected to be recognized as expense during 2022 or thereafter. This disclosure does not
include variable consideration allocated entirely to a wholly unsatisfied performance obligation or promise to transfer a
distinct good or service that forms part of a single performance obligation.
Note 21 Leases
Prior to January 1, 2019, we accounted for leases under ASC 840 and did not record any right of use asset or
corresponding lease liability. We adopted ASC 842 using a modified retrospective approach with an effective date of
January 1, 2019. As such, financial information for prior periods has not been adjusted and continues to be reported
under ASC 840. Effective with the adoption of ASC 842, we have changed our accounting policy for leases as detailed
below.
We have evaluated the provisions of ASC 842, including certain practical expedients allowed. The significant
practical expedients we adopted include the following:
• We elected the practical expedient to apply the transition approach as of the beginning of the period of adoption
and not restate comparative periods;
• We elected to utilize the “package of three” expedients, as defined in ASC 842, whereby we did not reassess
whether contracts existing prior to the effective date contain leases, nor did we reassess lease classification
determinations nor whether initial direct costs qualify for capitalization;
• We elected the practical expedient to not capitalize any leases with initial terms of twelve months or less on our
condensed consolidated balance sheet;
•
For all underlying classes of leased assets, we elected the practical expedient to not separate lease and non-lease
components; and
• We elected the practical expedient to continue to account for land easements (also known as “rights of way”)
that were not previously accounted for as leases consistent with prior accounting until such contracts are
modified or replaced, at which time they would be assessed for lease classification under ASC 842.
As of the date of implementation on January 1, 2019, the impact of the adoption of ASC 842 resulted in the
recognition of a right of use asset and lease payable obligation on our condensed consolidated balance sheet of
approximately $42.8 million. As the right of use asset and the lease payable obligation were the same, there was no
cumulative effect impact on retained earnings.
Our leases primarily consist of office space and equipment used globally within our operations. We determine
whether a contract is or contains a lease at inception of the contract based on answers to a series of questions that address
whether an identified asset exists and whether we have the right to obtain substantially all the benefit of the assets and to
control its use over the full term of the agreement. When available, we use the rate implicit in the lease to discount lease
payments to present value; however, most of our leases do not pr
we must estimate our incremental borrowing rate using a credit notching approach to discount the lease payments based
on information available at lease commencement. Certain of our lease agreements include options to extend and options
to terminate the lease, which we do not include in our minimum lease terms unless management is reasonably certain to
exercise. We do not separate lease and nonlease components of contracts. There are no material residual value
guarantees nor any restrictions or covenants included in our lease agreements. Certain of our leases include provisions
for variable payments. These variable payments are typically determined based on a measure of throughput or actual
days or another measure of usage and are not included in the calculation of lease liabilities and right-of-use assets.
ovide a readily determinable implicit rate. Therefore,
a
t
94
Lease Position
The table below presents the lease related assets and liabilities recorded on our condensed consolidated balance
sheet:
Assets
Classification on the Balance Sheet
(In thousands)
Year Ended December 31,
2020
2019
Operating lease assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total lease assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term assets
$ 32,312 $ 46,647
$ 32,312 $ 46,647
Liabilities
Current liabilities:
Operating lease liabilities. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Current lease liabilities
$
8,305 $ 13,479
Noncurrent liabilities:
Operating lease liabilities. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term liabilities
$ 24,656 $ 33,396
$ 32,961 $ 46,875
Lease Costs
The table below presents certain information related to the lease costs for our operating leases:
t
Operating lease cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
Short-term lease cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Variable lease cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total lease cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
t
t
Year Ended
December 31,
2020
2019
(In thousands)
15,235 $
1,165
512
16,912 $
16,154
2,568
605
19,327
Other Information
The table below presents supplemental cash flow information related to leases:
Year Ended December 31,
2020
2019
(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
15,235 $
16,154
Right of use assets obtained in exchange for lease obligations:
Operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
— $
17,852
Lease Terms and Discount Rates
The table below presents certain information related to the weighted average remaining lease terms and
weighted average discount rates for our operating leases:
Weighted-average remaining lease term - operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . .
Weighted-average discount rate - operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7.91
6.07%
7.13
5.97%
Year Ended December 31,
2020
2019
95
Undiscounted Cash Flows
The table below reconciles the undiscounted cash flows for each of the first five years and the total remaining
years to the operating lease liabilities recorded on the condensed consolidated balance sheet:
December 31, 2020
(In thousands)
2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Thereafter. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total undiscounted lease liability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: amount of lease payments representing interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term lease obligations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
r
10,030
6,959
4,816
2,577
2,254
15,176
41,812
(8,851)
32,961
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
H
FINANCIAL DISCLOSURE
Not applicable.
ITEM 9A. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
We maintain a set of disclosure controls and procedures (as such term is defined in Rule 15d-15(e) under the
Exchange Act) designed to provide reasonable assurance that information required to be disclosed in our reports filed or
submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in
the SEC’s rules and forms, and that such information is accumulated and communicated to management as appropriate
to allow timely decisions regarding required disclosure. We have investments in certain unconsolidated entities that we
do not control or manage. Because we do not control or manage these entities, our disclosure controls and procedures
with respect to these entities are necessarily more limited than those we maintain with respect to our consolidated
subsidiaries.
The Company’s management, with the participation of the Chief Executive Officer and the Chief Financial
Officer, has evaluated the effectiveness of the Company’s disclosure controls and procedures as of the end of the period
covered by this annual report. Based on this evaluation, the Chief Executive Officer and the Chief Financial Officer have
concluded that, as of December 31, 2020, the Company’s disclosure controls and procedures were effective at the
reasonable assurance level.
Management’s Report on Internal Control over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting.
Our 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 U.S.
GAAP. Our 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 U.S. GAAP, 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.
96
Internal control over financial reporting cannot provide absolute assurance of achieving financial reporting
objectives because of its inherent limitations. Internal control over financial reporting is a process that involves human
diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal
control over financial reporting also can be circumvented by collusion or improper management override. Because of
these limitations, there is a risk that material misstatements may not be prevented or detected on a timely basis by
internal control over financial reporting. However, these inherent limitations are known features of the financial
reporting process. Therefore, it is possible to design into the process safeguards to reduce, though not eliminate, this risk.
Management conducted an evaluation of the effectiveness of the Company’s internal control over financial
reporting based on the criteria set forth in the Internal Control—Integrated Framework issued in 2013 by the Committee
of Sponsoring Organizations of the Treadway Commission (COSO). Based on this evaluation, management concluded
that the Company’s internal control over financial reporting was effective as of December 31, 2020.
k
PricewaterhouseCoopers LLP has issued a report on the effectiveness of the Company’s internal control over
financial reporting as of December 31, 2020, which is included in Part II, Item 8 of this annual report.
Changes in Internal Control over Financial Reporting
There have been no changes in internal control over financial reporting during the quarter ended December 31,
2020 that have materially affected, or are reasonably likely to materially affect, the Company’s inte
financial reporting.
ff
rnal control over
ITEM 9B. OTHER INFORMATION
Not applicable.
97
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
S
PART III
The information called for by this item will be contained in the definitive Proxy Statement to be distributed in
,” “Election of
connection with our 2021 annual general meeting of shareholders under the captions “Director Nominees
Directors”, “Other Executive Officers”, “Meetings of the Board and Committees” and “Section 16(a) Beneficial
Ownership Reporting Compliance” and is incorporated into this document by reference.
“
We have adopted a Code of Business Conduct (the “Code”) that applies to all directors, employees, including
our principal executive officer and principal financial and accounting officer. The Code satisfies the SEC’s definition of
a “Code of Ethics” and is posted on our website at www.nabors.com. We intend to disclose on our website any
amendments to the Code and any waivers of the Code that apply to our principal executive officer, principal financial
officer, or principal accounting officer.
On June 16, 2020, we filed with the New York Stock Exchange the Annual CEO Certification regarding our
compliance with the Exchange’s Corporate Governance listing standards as required by Section 303A-12(a) of the
Exchange’s Listed Company Manual.
ITEM 11. EXECUTIVE COMPENSATION
The information called for by this item will be contained in various sections of our definitive Proxy Statement
to be distributed in connection with our 2021 annual general meeting of shareholders, including under the captions
“Compensation Discussion and Analysis,” “2020 Summary Compensation Table,” 2020 Grants of Plan-Based
Awards,” “2020 Outstanding Equity Awards at Fiscal Year End,” “2020 Option Exercises and Shares Vested,” “2020
Non-Qualified Deferred Compensation,” “Required Pay-Ratio Disclosure,” “2020 Potential Payouts upon Termination
o
or Change in Control,” “Non-Employee Director Compensation,” “Risk A
Interlocks and Insider Participation,” and “Compensation Committee Report,
” and except as specified in the following
sentence, is incorporated into this document by reference. Information in our definitive Proxy Statement not deemed to
be “soliciting material” or “filed” with the SEC under its rules, including the Compensation Committee Report, is not
deemed to be incorporated by reference.
ssessment,” “Compensation Committee
d
ii
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND
RELATED SHAREHOLDER MATTERS
The information called for by this item will be contained in our definitive Proxy Statement to be distributed in
connection with our 2021 annual general meeting of shareholders, including under the captions “Share Ownership” and
“Securities Authorized for Issuance under Equity Compensation Plans” and is incorporated into this document by
reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
TT
The information called for by this item will be contained in our definitive Proxy Statement to be distributed in
connection with our 2021 annual general meeting of shareholders, including under the captions “Certain Relationships
and Related Transactions” and “Overview of Key Governance Topics – Director Independence,” is incorporated into
this document by reference.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
The information called for by this item will be contained in our definitive Proxy Statement to be distributed in
connection with our 2021 annual general meeting of shareholders, including under the caption “Independent Auditor
Fees” and is incorporated into this document by reference.
98
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
(a)
The following documents are filed as part of this annual report:
(1)
Financial Statements
Consolidated Balance Sheets as of December 31, 2020 and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statement of Income (Loss) for the Years Ended December 31, 2020, 2019 and 2018 . . . . . . .
Consolidated Statement of Comprehensive Income (Loss) for the Years Ended December 31, 2020, 2019
and 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statement of Cash Flows for the Years Ended December 31, 2020, 2019 and 2018 . . . . . . . . .
Consolidated Statement of Changes in Equity for the Years Ended December 31, 2020, 2019 and 2018 . . . .
Notes to Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
52
53
54
55
56
57
Page No.
(2)
Financial Statement Schedule
Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2020, 2019
and 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
100
Page No.
All other supplemental schedules are omitted because of the absence of the conditions under which they would
be required or because the required information is included in the financial statements or related notes.
(b)
Exhibit Index
See the Exhibit Index for a list of those exhibits filed herewith, which Exhibit Index also includes and identifies
management contracts or compensatory plans or arrangements required to be filed as exhibits to this Form 10-K by
Item 601 of Regulation S-K.
ITEM 16. FORM 10-K SUMMARY
None.
99
SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2020, 2019 and 2018
Balance at
Beginning
of Period
Charged to
Costs and
Other
Deductions Accounts
Charged to
Other
Balance at
End of
Period
Deductions
(In thousands)
18,929
5,082
—
— 836,879
(329) (10,575) $
—
— (16,653) $
69,807
23,477
—
— $ 3,616,880
17,529
11,808
(51)
—
—
—
— 862,611
61,782
3,097 $
(4,614) $
35,048
—
— $ 2,780,001
3,024
—
—
—
—
(226)
(5,967) $
14,688 (15,768) $
47,900
41,207
27,854
—
— $ 1,917,390
2020
61,782
Allowance for doubtful accounts . . . . . . . . . . . . . . . . . . . $
Inventoryrr reserve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
35,048
Valuation allowance on deferred tax assets . . . . . . . . . . . $ 2,780,001
2019
41,207
Allowance for doubtful accounts . . . . . . . . . . . . . . . . . . . $
Inventoryrr reserve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
27,854
Valuation allowance on deferred tax assets . . . . . . . . . . . $ 1,917,390
2018
44,376
Allowance for doubtful accounts . . . . . . . . . . . . . . . . . . . $
Inventoryrr reserve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $
28,934
Valuation allowance on deferred tax assets . . . . . . . . . . . $ 1,869,490
100
Exhibit No.
Description
Exhibit Index
3.1 Memorandum of Association of Nabors Industries Ltd. (incorporated by reference to Annex II to the
proxy statement/prospectus included in our Registration Statement on Form S-4 (File No. 333-76198)
filed with the SEC on May 10, 2002, as amended).
3.2 Certificate of Deposit of Memorandum of Increase of Share Capital (incorporated by reference to
Exhibit 3.1 to our Form 10-Q (File No. 001-32657) filed with the SEC on May 8, 2020).
3.3 Amended and Restated Bye-laws of Nabors Industries Ltd. (incorporated by reference to Exhibit 3.1 to
our Form 8-K (File No. 001-32657) filed with the SEC on April 22, 2020).
3.3(a) Certificate of Designations of the 6.00% Mandatory Convertible Preferred Shares, Series A of Nabors
Industries Ltd. (incorporated by reference to Exhibit 3.1 to our Form 8-K (File No. 001-32657) filed
with the SEC on May 14, 2018).
3.3(b) Certificate of Designation of Series B Junior Participating Preferred Shares of Nabors Industries Ltd.
(incorporated by reference to Exhibit 3.1 to our Form 8-K (File no 001-32657) filed with the SEC on
May 6, 2020).
4.1 Rights Agreement, dated May 5, 2020, between Nabors Industries Ltd. and Computershare Trust
Company, N.A., as Rights Agent, including the Certificate of Designation of Series B Junior
Participating Preferred Shares, the Form of Right Certificate, and the Summary of Rights to Purchase
Preferred Shares, respectively attached thereto as Exhibits A, B and C. (incorporated by reference to
Exhibit 4.1 to our Form 8-K (File No. 001-32657) filed with the SEC on May 6, 2020).
4.1(a) Amendment No. 1 to Rights Agreement, dated May 27, 2020 between Nabors Industries Ltd. and
Computershare Trust Company, N.A., as Rights Agent (incorporated by reference to Exhibit 10.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on June 2, 2020).
4.1(b) Amendment No. 2 to Rights Agreement, dated February 5, 2021 between Nabors Industries Ltd. and
Computershare Trust Company, N.A., as Rights Agent. (incorporated by reference to Exhibit 4.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on February 5, 2021).
4.2 Description of Share Capital.*
4.3
Indenture, dated as of September 14, 2010, among Nabors Industries, Inc., Nabors Industries Ltd.,
Wilmington Trust Company, as trustee, and Citibank, N.A. as securities administrator, with respect to
Nabors Industries, Inc.’s 5.0% Senior Notes due 2020 (including form of 5.0% Senior Note due 2020)
(incorporated by reference to Exhibit 4.2 to our Form 8-K (File No. 001-32657) filed with the SEC on
September 15, 2010).
Indenture, dated as of August 23, 2011, among Nabors Industries, Inc., Nabors Industries Ltd.,
Wilmington Trust, National Association, as trustee and Citibank, N.A. as securities administrator, with
respect to Nabors Industries, Inc.’s 4.625% Senior Notes due 2021 (including form of 4.625% Senior
Note due 2021) (incorporated by reference to Exhibit 4.1 to our Form 8-K (File No. 001-32657) filed
with the SEC on August 24, 2011).
Indenture related to the 2.35% Senior Notes due 2016 and 5.10% Senior Notes due 2023, dated as of
September 12, 2013, among Nabors Industries, Inc. as Issuer, Nabors Industries Ltd. as Guarantor,
Wilmington Trust, National Association as Trustee and Citibank, N.A. as Securities Administrator
(including form of 2.35% Senior Note due 2016 and form of 5.10% Senior Note due 2023)
(incorporated by reference to Exhibit 4.1 to Nabors Industries Ltd. Form 8-K (File No. 001-32657) filed
with the SEC on September 13, 2013).
Indenture, dated as of December 9, 2016 by and among Nabors Industries, Inc., as issuer, Nabors
Industries Ltd., as guarantor, Citibank, N.A., as securities administrator and Wilmington Trust, National
Association, as trustee with respect to Nabors Industries, Inc.’s 5.50% Senior Notes due 2023
(incorporated by reference to Exhibit 4.1 to our Form 8-K (File No. 001-32657) filed with the SEC on
December 9, 2016).
4.4
4.5
4.6
101
Exhibit No.
Description
4.6(a) First Supplemental Indenture to the Indenture, dated January 22, 2020, among Nabors Industries, Inc.,
4.7
as issuer, Nabors Industries Ltd., as guarantor, Wilmington Trust, National Associate, as trustee, and
Citibank, N.A., as securities administrator with respect to Nabors Industries, Inc.’s 5.50% Senior Notes
due 2023 (incorporated by reference to Exhibit 10.1 to our Form 8-K (File No. 001-32657) filed with
the SEC on January 22, 2020).
Indenture, dated as of January 13, 2017, by and among Nabors Industries, Inc., as issuer, Nabors
Industries Ltd., as guarantor, Citibank, N.A., as securities administrator and Wilmington Trust, National
Association, as trustee with respect to Nabors Industries, Inc.’s 0.75% Exchangeable Senior Notes due
2024 (incorporated by reference to Exhibit 4.1 to our Form 8-K (File No. 001-32657) filed with the
SEC on January 13, 2017).
t
4.8
4.9
75% Exchangeable Senior
4.7(a) Supplemental Indenture, dated as of October 29, 2020 by and among Nabors Industries Inc., as Issuer,
rr
Nabors Industries, Ltd., as Guarantor, Wilmington Trust, National Association., as trustee and Citibank,
N.A., as securities administrator with respect to Nabors Industries, Inc.’s 0.
a
Notes due 2024 (incorporated by reference to Exhibit 4.2 to our Current Report on Form 8-K (File
No. 001-32657) filed with the SEC on November 3, 2020).
Indenture, dated as of January 23, 2018, by and among Nabors Industries, Inc., Nabors Industries Ltd.,
as Guarantor, Citibank, N.A., as securities administrator and Wilmington Trust National Association, as
trustee with respect to Nabors Industries, Inc.’s 5.75% Senior Notes due 2025 (incorporated by
reference to Exhibit 4.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 23, 2018).
Indenture, dated as of January 10, 2020 by and among Nabors Industries Ltd., as Issuer, Nabors
Industries, Inc., as Guarantor, Nabors International Finance Inc., as Guarantor, Nabors Lux Finance 1,
as Guarantor, Nabors Global Holdings Limited, as Guarantor, Nabors Drilling Holdings Inc., as
Guarantor, Nabors Holdings Ltd., as Guarantor, and Wells Fargo Bank, N.A., as trustee, with respect to
Nabors’ Industries Ltd.’s 7.25 Senior Guaranteed Notes due 2026 and 7.50% Guaranteed Notes due
2028, including as exhibits thereto the form of Notes (incorporated by reference to Exhibit 4.1 to our
form 8-K (File No. 00132657) filed with the SEC on January 14, 2020).
Indenture, dated as of October 29, 2020 by and among Nabors Industries Inc., as Issuer, the guarantors
party thereto, and Wilmington Trust, National Association., as trustee with respect to Nabors Industries,
Inc.’s 6.5% Senior Priority Guaranteed Notes due 2025 (incorporated by reference to Exhibit 4.1 to our
Current Report on Form 8-K (File No. 001-32657) filed with the SEC on November 3, 2020).
Indenture, dated as of December 1, 2020 by and among Nabors Industries, Inc., as Issuer, the guarantors
party thereto, and Wilmington Trust, National Association, as trustee with respect to Nabors Industries,
Inc.’s 9.00% Senior Priority Guaranteed Notes due 2025 (incorporated by reference to Exhibit 4.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on December 4, 2020).
4.11
4.10
10.1 Call Option Transaction Confirmation, dated as of January 9, 2017, between Nabors Industries Ltd.,
Nabors Industries, Inc. and Citigroup Global Markets Inc. (incorporated by reference to Exhibit 10.2 to
our Form 8-K (File No. 001-32657) filed with the SEC on January 11, 2017).
10.2 Call Option Transaction Confirmation, dated as of January 9, 2017, between Nabors Industries Ltd.,
f
Nabors Industries, Inc. and Goldman, Sachs & Co. (incorporated by reference to Exhibit 10.3 to our
Form 8-K (File No. 001-32657) filed with the SEC on January 11, 2017).
10.3 Additional Call Option Transaction Confirmation, dated as of January 10, 2017, between Nabors
Industries Ltd., Nabors Industries, Inc. and Citigroup Global Markets Inc. (incorporated by reference to
Exhibit 10.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 13, 2017).
10.4 Additional Call Option Transaction Confirmation, dated as of January 10, 2017, between Nabors
Industries Ltd., Nabors Industries, Inc. and Goldman, Sachs & Co. (incorporated by reference to Exhibit
10.2 to our Form 8-K (File No. 001-32657) filed with the SEC on January 13, 2017).
10.5 Shareholders’ Agreement, dated October 31, 2016, between Saudi Aramco Development Company and
Nabors International Netherlands B.V. (incorporated by reference to Exhibit 10.20 to our Form 10-K
(File No. 001-32657) filed with the SEC on February 28, 2017).
102
Exhibit No.
Description
10.6 Credit Agreement, dated as of November 29, 2012, among Nabors Industries, Inc. as US borrower,
Nabors Canada as Canadian borrower, Nabors Industries Ltd. as guarantor, HSBC Bank Canada as
Canadian lender, the other lenders party thereto, Mizuho Corporate Bank, Ltd. and HSBC Bank USA,
N.A. as documentation agents, HSBC Bank USA, N.A. as syndication agent and Citibank, N.A. as
administrative agent for the US lenders (incorporated by reference to Exhibit 10.1 to our Form 8-K (File
No. 001-32657) filed with the SEC on November 30, 2012).
10.6(a) Amendment No. 1, dated as of July 14, 2015, to Credit Agreement, dated as of November 29, 2012,
among Nabors Industries, Inc. as US Borrower, Nabors Canada as Canadian Borrower, Nabors
Industries Ltd. as Guarantor, HSBC Bank Canada as Canadian Lender, the other lenders party thereto,
Mizuho Corporate Bank, Ltd. and HSBC Bank USA, N.A. as Documentation Agents, HSBC Bank
USA, N.A. as Syndication Agent and Citibank, N.A. as Administrative Agent for the US Lenders
(incorporated by reference to Exhibit 10.1 to our Form 8-K (File No. 001-32657) filed with the SEC on
July 15, 2015).
10.6(b) Amendment No. 2, dated as of March 23, 2016, to Credit Agreement, dated as of March 23, 2016,
among Nabors Industries, Inc. as US Borrower, Nabors Canada as Canadian Borrower, Nabors
Industries Ltd. as Guarantor, HSBC Bank Canada as Canadian Lender, the other lenders party thereto,
Mizuho Corporate Bank, Ltd. and HSBC Bank USA, N.A. as Documentation Agents, HSBC Bank
USA, N.A. as Syndication Agent and Citibank, N.A. as Administrative Agent for the US Lenders
(incorporated by reference to Exhibit 10.7(b) to our Form 10-K (File No. 001-32657) filed with the SEC
on February 28, 2019).
10.6(c) Amendment No. 3 to Credit Agreement, dated as of October 11, 2018, among Nabors Industries, Inc.,
Nabors Drilling Canada Limited, Nabors Industries Ltd., HSBC Bank Canada, the other lenders party
thereto, Citibank, N.A., and Wilmington Trust, National Association, as successor administrative agent
(incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-32657) filed with the SEC on
October 12, 2018).
10.7 Credit Agreement, dated as of October 11, 2018, among Nabors Industries, Inc., as US Borrower,
Nabors Drilling Canada Limited, as Canadian Borrower, Nabors Industries Ltd., as Holdings, the other
Guarantors from time to time party thereto, HSBC Bank Canada, as Canadian Lender, the Issuing Banks
and other Lenders party thereto and Citibank, N.A., as Administrative Agent solely for the US Lenders
and not for the Canadian Lender (incorporated by reference to Exhibit 10.1 to our Form 8-K (File No.
001-32657) filed with the SEC on October 12, 2018).
10.7(a) First Amendment to 2018 Credit Agreement, dated as of October 25, 2019, among Nabors Industries,
Inc., as US Borrower, Nabors Drilling Canada Limited, as Canadian Borrower, Nabors Industries Ltd.,
as Holdings, the other Guarantors from time to time party thereto, HSBC Bank Canada, as Canadian
Lender, the Issuing Banks and other Lenders party thereto and Citibank, N.A., as Administrative Agent
solely for the US Lenders and not for the Canadian Lender (incorporated by reference to Exhibit 10.4 to
our form 10-Q 9File No. 001-32657) filed with the SEC on November 1, 2019).
10.7(b) Second Amendment to 2018 Credit Agreement, dated as of October 13, 2019, by and among Nabors
Industries, Inc., as US Borrower, Nabors Drilling Canada Limited, as Canadian Borrower, Nabors
Industries Ltd., as Holdings, the other Guarantors from time to time party thereto, HSBC Bank Canada,
as Canadian Lender, the Issuing Banks and other Lenders party thereto and Citibank, N.A., as
Administrative Agent solely for the US Lenders (incorporated by reference to Exhibit 10.1 to our Form
8-K (File No. 001-32657) filed with the SEC on December 16, 2019).
r
10.7(c) Third Amendment to 2018 Credit Agreement, dated as of March 3, 2020, by and among Nabors
Industries, Inc., as US Borrower, Nabors Drilling Canada Limited, as Canadian Borrower Nabors
Industries Ltd., as Holdings, the other Guarantors from time to time party thereto, HSBC Bank Canada,
as Canadian Lender, the Issuing Banks and other Lenders party thereto and Citibank, N.A., as
Administrative Agent solely for the US Lenders and not for the Canadian Lender (incorporated by
reference to Exhibit 10.1 to our Form 10-Q (File No. 001-32657) filed with the SEC on May 8, 2020).
103
Exhibit No.
Description
10.7(d) Fourth Amendment to Credit Agreement, dated as of September 24, 2020, by and among Nabors
Industries, Inc., as U.S. Borrower, Nabors Drilling Canada Limited, as Canadian Borrower, Nabors
Industries Ltd., as Holdings, the other Guarantors from time to time party thereto, HSBC Bank Canada,
as Canadian Lender, the Issuing Banks, the U.S. Lenders party thereto and Citibank, N.A., as
Administrative Agent solely for the U.S. Lenders (incorporated by reference to Exhibit 10.1 to our
Current Report on Form 8-K (File No, 001-32657) filed with the SEC on September 24, 2020). [A
portion of this exhibit has been redacted].
10.8 Receivables Purchase Agreement dated as of September 13, 2019, by and among Nabors A.R.F., LLC,
certain operating subsidiaries of Nabors Industries Ltd., and Nabors Industries, Inc., (incorporated by
reference to Exhibit 10.1 to our Form 8-K (File No. 001-32657) filed with the SEC on
September 18, 2019).
10.8(a) Receivables Sale Agreement dated as of September 13, 2019, by and among Nabors A.R.F., LLC, ,
Nabors Industries, Inc., the purchasers party thereto, and Wells Fargo Bank, N.A., as Administrative
Agent (incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-32657) filed with the
SEC on September 18, 2019).
Indemnification Agreement, dated as of September 13, 2019, between Nabors Industries Ltd. and Wells
Fargo Bank, N.A. (incorporated by reference to Exhibit 10.3 to our Form 8-K (File No. 001-32657)
filed with the SEC on September 18, 2019).
10.8(b)
10.12(+) Executive Employment Agreement by and among Nabors Industries Ltd., Nabors Industries, Inc. and
Anthony G. Petrello, effective as of January 1, 2013 (incorporated by reference to Exhibit 99.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on March 11, 2013).
10.12(a)(+) First Amendment to Executive Employment Agreement, dated December 19, 2014, among Nabors
m
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to
Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on December 19, 2014).
10.12(b)(+) Second Amendment to Executive Employment Agreement, dated as of June 5, 2015, among Nabors
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to
Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on June 8, 2015).
10.12(c)(+) Third Amendment to Executive Employment Agreement, dated as of December 31, 2015, among
Nabors Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to
Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 5, 2016).
10.12(d)(+) Fourth Amendment to Executive Employment Agreement, dated June 10, 2016, among Nabors
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit
99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on June 13, 2016).
10.12(e)(+) Fifth Amendment to Executive Employment Agreement, dated October 15, 2018, among Nabors
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit
10.3 to our Form 10-Q (File No. 001-32657) filed with the SEC on November 7, 2018).
10.12(f)(+) Sixth Amendment to Executive Employment Agreement, dated December 31, 2018, among Nabors
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit
10.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 4, 2019).
10.12(g)(+) Seventh Amendment to Executive Employment Agreement, dated January 2, 2020, among Nabors
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit
10.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 8, 2020).
10.12(h)(+) Eighth Amendment to Executive Employment Agreement, dated April 6, 2020, among Nabors
Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit 10
Exhibit 10.1 to our Form 8-K (File No. 00132657) filed with the SEC on April 9, 2020).
10.13(+) Amended and Restated Executive Employment Agreement, dated January 2, 2020, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo. (incorporated by reference to Exhibit 10.2
to our Form 8-K (File No. 001-32657) filed with the SEC on January 8, 2020).
104
Exhibit No.
Description
10.13(a)(+) First Amendment to Amended and Restated Employment Agreement, dated April 6, 2020, among
Nabors Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to
Exhibit 10.2 to our Form 8-K (File No. 00132657) filed with the SEC on April 9, 2020).
10.14(+) Form of Indemnification Agreement entered into between Nabors Industries Ltd. and the directors and
executive officers (incorporated by reference to Exhibit 10.28 to our Form 10-K (File No. 000-49887)
filed with the SEC on March 31, 2003).
10.15(+) Form of Director Cash Award Agreement (incorporated by reference to Exhibit 10.13 to our Form 10-Q
(File No. 001-32657) filed with the SEC on August 4, 2020).
10.16(+) Amended and Restated 1999 Stock Option Plan for Non-Employee Directors (amended on May 2,
2003) (incorporated by reference to Exhibit 10.29 to our Form 10-Q (File No. 000-49887) filed with the
SEC on May 12, 2003).
10.16(a)(+) Form of Stock Option Agreement to the Amended and Restated 1999 Stock Option Plan for Non-
Employee Directors (incorporated by reference to Exhibit 10.2 to our Form 10-Q (File No. 001-32657)
filed with the SEC on April 28, 2017).
10.17(+) Nabors Industries Ltd. Amended and Restated 2003 Employee Stock Plan (incorporated by reference to
Exhibit A of our Proxy Statement (File No. 001-32657) filed with the SEC on May 4, 2006).
10.17(a)(+) Form of Stock Option Agreement—Petrello/Isenberg (incorporated by reference to Exhibit 10.03 to our
Form 8-K (File No. 000-49887) filed with the SEC on March 2, 2005).
10.17(b) Form of Stock Option Agreement—Others (incorporated by reference to Exhibit 10.04 to our Form 8-K
(File No. 000-49887) filed with the SEC on March 2, 2005).
10.18(+) Amended and Restated Nabors Industries Ltd. 2016 Stock Plan (incorporated by reference to Annex B
to Nabors Industries Ltd.’s Definitive Proxy Statement (File No. 001-32657) filed with the SEC on
April 23, 2020).
10.18(a)(+) Form of Nabors Industries Ltd. TSR Stock Agreement – Anthony G. Petrello (2020), pursuant to the
Amended and Restated 2016 Stock Plan (incorporated by reference to Exhibit 10.7 to our Form 10-Q
(File No. 001-32657) filed with the SEC on August 4, 2020).
10.18(b)(+) Form of Nabors Corporate Services, Inc. TSR Stock Agreement – Anthony G. Petrello (2020), pursuant
to the Amended and Restated 2016 Stock Plan (incorporated by reference to Exhibit 10.8 to our Form
10-Q (File No. 001-32657) filed with the SEC on August 4, 2020).
10.18(c)(+) Form of Nabors Industries Ltd. TSR Stock Agreement – William Restrepo (2020), pursuant to the
Amended and Restated 2016 Stock Plan (incorporated by reference to Exhibit 10.9 to our Form 10-Q
(File no. 001-32657) filed with the SEC on August 4, 2020).
10.18(d)(+) Form of Nabors Corporate Services, Inc. TSR Stock Agreement – William Restrepo (2020), pursuant to
the Amended and Restated 2016 Stock Plan (incorporated by reference to Exhibit 10.10 to our Form 10-
Q (File no. 001-32657) filed with the SEC on August 4, 2020).
10.18(e)(+) Form of Nabors Industries Ltd. Performance-Based Restricted Stock Unit Agreement (2020) – Anthony
G. Petrello, pursuant to the Amended and Restated 2016 Stock Plan (incorporated by reference to
Exhibit 10.3 to our Form 10-Q (File No. 001-32657) filed with the SEC on August 4, 2020).
10.18(f)(+) Form of Nabors Corporate Services, Inc. Performance-Based Restricted Stoc
k Unit Agreement (2020) –
Anthony G. Petrello, pursuant to the Amended and Restated 2016 Stock Plan (incorporated by reference
to Exhibit 10.4 to our Form 10-Q (File No. 001-32657) filed with the SEC on August 4, 2020).
a
10.18(g)(+) Form of Nabors Industries Ltd. Performance-Based Restricted Stock Unit Agreement (2020) – William
Restrepo, pursuant to the Amended and Restated 2016 Stock Plan (incorporated by reference to Exhibit
10.5 to our Form 10-Q (File No. 001-32657) filed with the SEC on August 4, 2020).
10.18(h)(+) Form of Nabors Corporate Services, Inc. Performance-Based Restricted Stoc
k Unit Agreement (2020) –
William Restrepo, pursuant to the Amended and Restated 2016 Stock Plan (incorporated by reference to
Exhibit 10.6 to our Form 10-Q (File No. 001-32657) filed with the SEC on August 4, 2020).
d
a
105
Exhibit No.
Description
10.18(i)(+) Form of CEO Performance-Based Restricted Stock Unit Agreement (2021), pursuant to the Amended
and Restated 2016 Stock Plan (incorporated by reference to Exhibit 10.1 to our Form 8-K (File No. 001-
32657) filed with the SEC on January 8, 2021).
10.18(j)(+) Form of CFO Performance-Based Restricted Stock Unit Agreement (2021), pursuant to the Amended
and Restated 2016 Stock Plan (incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-
32657) filed with the SEC on January 8, 2021).
10.18(k)(+) Form of Restricted Stock Agreement – Directors, pursuant to the Amended and Restated Nabors
Industries Ltd. 2016 Stock Plan (incorporated by reference to Exhibit 10.2 to our Registration Statement
on Form S-8 (File No. 333-239325) filed with the SEC on June 19, 2020).
10.18(l)(+) Form of Restricted Stock Agreement – Others, pursuant to the Amended and Restated Nabors Industries
Ltd. 2016 Stock Plan (incorporated by reference to Exhibit 10.3 to our Registration Statement on Form
S-8 (File No. 333-239325) filed with the SEC on June 19, 2020).
10.18(m)(+) Form of Stock Option Agreement – Others, pursuant to the 2016 Stock Plan (incorporated by reference
to Exhibit 10.1(b) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.18(n)(+) Form of Nabors Industries Ltd. TSR Stock Grant Agreement – Anthony G. Petrello, pursuant to the
2016 Stock Plan (incorporated by reference to Exhibit 10.1(d) to our Form 10-Q (File No. 001-32657)
filed with the SEC on April 28, 2017).
10.18(o)(+) Form of Nabors Corporate Services, Inc. TSR Stock Grant Agreement – Anthony G. Petrello, pursuant
to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(e) to our Form 10-Q (File No. 001-
32657) filed with the SEC on April 28, 2017).
10.18(p)(+) Form of Nabors Industries Ltd. TSR Stock Grant Agreement – William Restrepo, pursuant to the 2016
Stock Plan (incorporated by reference to Exhibit 10.1(f) to our Form 10-Q (File No. 001-32657) filed
with the SEC on April 28, 2017).
10.18(q)(+) Form of Nabors Corporate Services, Inc. TSR Grant Agreement – William Restrepo, pursuant to the
2016 Stock Plan (incorporated by reference to Exhibit 10.1(g) to our Form 10-Q (File No. 001-32657)
filed with the SEC on April 28, 2017).
10.18(r)(+) Form of Nabors Industries Ltd. Restricted Stock Agreement – Anthony G. Petrello, pursuant to the 2016
Stock Plan (incorporated by reference to Exhibit 10.1(h) to our Form 10-Q (File No. 001-32657) filed
with the SEC on April 28, 2017).
10.18(s)(+) Form of Nabors Corporate Services, Inc. Restricted Stock Agreement – Anthony G. Petrello, pursuant
to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(i) to our Form 10-Q (File No. 001-
32657) filed with the SEC on April 28, 2017).
10.18(t)(+) Form of Nabors Industries Ltd. Restricted Stock Agreement – William Restrepo, pursuant to the 2016
Stock Plan (incorporated by reference to Exhibit 10.1(j) to our Form 10-Q (File No. 001-32657) filed
with the SEC on April 28, 2017).
10.18(u)(+) Form of Nabors Corporate Services, Inc. Restricted Stock Agreement – William Restrepo, pursuant to
the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(k) to our Form 10-Q (File No. 001-
32657) filed with the SEC on April 28, 2017).
10.18(v)(+) Form of Nabors Industries Ltd. TSR Grant Agreement – Executive, pursuant to the 2016 Stock Plan and
the 2013 Stock Plan (incorporated by reference to Exhibit 10.15(n) to our Form 10-K (File No. 001-
32657) filed with the SEC on February 28, 2019).
10.18(w)(+) Form of Nabors Corporate Services, Inc. TSR Grant Agreement – Executive, pursuant to the 2016 Stock
Plan and the 2013 Stock Plan (incorporated by reference to Exhibit 10.15(o) to our Form 10-K (File
No. 001-32657) filed with the SEC on February 28, 2019).
10.18(x)(+) Form of Nabors Industries Ltd. TSR Stock Grant Agreement – Anthony G. Petrello (2020)
(incorporated by reference to Exhibit 10.3 to our form 8-K (File No. 001-32657) filed with the SEC on
January 8, 2020).
106
Exhibit No.
Description
10.18(y)(+) Form of Nabors Corporate Services, Inc. TSR Stock Grant Agreement – Anthony G. Petrello (2020)
(incorporated by reference to Exhibit 10.4 to our form 8-K (File No. 001-32657) filed with the SEC on
January 8, 2020).
10.18(z)(+) Form of CEO Performance Based Stock Restricted Unit Agreement (2020) (incorporated by reference
to Exhibit 10.5 to our form 8-K (File No. 001-32657) filed with the SEC on January 8, 2020).
10.18(aa)(+) Form of CFO Performance Based Stock Restricted Unit Agreement (2020) (incorporated by reference
to Exhibit 10.6 to our form 8-K (File No. 001-32657) filed with the SEC on January 8, 2020).
10.19(+) Nabors Industries, Inc. Executive Deferred Compensation Plan (as Amended and Restated Effective as
of April 1, 2017) (incorporated by reference to Exhibit 10.3(a) to our Form 10-Q (File No. 001-32657)
filed with the SEC on April 28, 2017).
10.19(a)(+) Amendment No. 1 to Nabors Industries, Inc. Executive Deferred Compensation Plan (incorporated by
reference to Exhibit 10.5 to our form 10-Q (File No. 001-32657) filed with the SEC on
November 1, 2019).
10.19(b)(+) Form of Deferred Bonus Agreement under the Nabors Industries, Inc. Executive Deferred
Compensation Plan (incorporated by reference to Exhibit 10.3(b) to our Form 10-Q (File No. 001-
32657) filed with the SEC on April 28, 2017).
10.20(+) Nabors Industries, Inc. Deferred Compensation Plan (as Amended and Restated Effective as of
January 1, 2017) (incorporated by reference to Exhibit 10.4 to our Form 10-Q (File No. 001-32657)
filed with the SEC on April 28, 2017).
10.20(a)(+) Amendment No. 1 to Nabors Industries, Inc. Deferred Compensation Plan (incorporated by reference to
d
Exhibit 10.6 to our form 10-Q (File No. 001-32657) filed with the SEC on November 1, 2019).
10.20(b)(+) Amendment No. 2 to Nabors Industries, Inc. Deferred Compensation Plan (incorporated by reference to
d
Exhibit 10.7 to our form 10-Q (File No. 001-32657) filed with the SEC on November 1, 2019).
21 Significant Subsidiaries.*
22
Issuer of Registered Guaranteed Debt Securities.*
23.1 Consent of Independent Registered Public Accounting Firm—PricewaterhouseCoopers LLP.*
31.1 Rule 13a-14(a)/15d-14(a) Certification of Anthony G. Petrello, Chairman, President and Chief
Executive Officer.*
31.2 Rule 13a-14(a)/15d-14(a) Certification of William Restrepo, Chief Financial Officer.*
32.1 Certifications required by Rule 13a-14(b) or Rule 15d-14(b) and Section 1350 of Chapter 63 of Title 18
of the United States Code (18 U.S.C. 1350), executed by Anthony G. Petrello, Chairman, President and
Chief Executive Officer and William Restrepo, Chief Financial Officer.*
Inline XBRL Instance Document*
Inline XBRL Schema Document*
Inline XBRL Calculation Linkbase Document*
Inline XBRL Label Linkbase Document*
Inline XBRL Presentation Linkbase Document*
Inline XBRL Definition Linkbase Document*
101.INS
101.SCH
101.CAL
101.LAB
101.PRE
101.DEF
104 Cover Page Interactive Data File (the cover page XBRL tags are embedded in the Inline XBRL
document)
* Filed herewith.
(+) Management contract or compensatory plan or arrangement.
107
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has
duly caused this annual report to be signed on its behalf by the undersigned, thereunto duly authorized.
SIGNATURES
NABORS INDUSTRIES LTD.
By:
/s/ ANTHONY G. PETRELLO
Anthony G. Petrello
Chairman, President and
Chief Executive Officer
(Principal Executive Officer)
By:
/s/ WILLIAM RESTREPO
William Restrepo
Chief Financial Officer
(Principal Financial Officer and Accounting Officer)
Date:
February 24, 2021
Pursuant to the requirements of the Securities Exchange Act of 1934, this annual report has been signed below
by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
Signature
Title
Date
/s/ ANTHONY G. PETRELLO
Chairman, President and Chief Executive
February 24, 2021
Officer
Anthony G. Petrello
/s/ WILLIAM RESTREPO
William Restrepo
Chief Financial Officer
February 24, 2021
/s/ TANYA S. BEDER
Tanya S. Beder
Director
/s/ ANTHONY R. CHASE
Anthony R. Chase
Director
/s/ JAMES R. CRANE
James R. Crane
Director
/s/ MICHAEL C. LINN
Michael C. Linn
Director
/s/ JOHN P. KOTTS
John P. Kotts
Director
/s/ JOHN YEARWOOD
John Yearwood
Director
108
February 24, 2021
February 24, 2021
February 24, 2021
February 24, 2021
February 24, 2021
February 24, 2021
BOARD OF DIRECTORS
LEADERSHIP TEAM
Anthony G. Petrello
Nabors Chairman of the Board, President & Chief
Executive Officer
Tanya S. Beder
Chairman & CEO of SBCC Group, Inc.
Anthony R. Chase
Chairman & CEO of ChaseSource, L.P.
James R. Crane
Chairman & CEO of Crane Capital Group, Inc.
John P. Kotts
Private investor and entrepreneur
Michael C. Linn
President & CEO of MCL Ventures, LLC
John Yearwood
Lead Director, Retired President,
CEO & COO of Smith International, Inc.
Anthony G. Petrello
Chairman, President & Chief Executive Officer
William Restrepo
Chief Financial Officer
Mark D. Andrews
Corporate Secretary
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Siggi Meissner
President, Global Drilling & Engineering
Subodh Saxena
Senior Vice President, Nabors Drilling Solutions
Don Prejean
Senior Vice President, Canrig
Travis Purvis
Senior Vice President,
Global Operations
Michael Rasmuson
Senior Vice President, General Counsel
& Chief Compliance Officer
Jade Strong
Senior Vice President & Chief Administrative
Officer
Yehya Altameimi
Chief Executive Officer
Saudi Aramco Nabors Drilling (SANAD)
SHAREHOLDER INFORMATION
Corporate Address
Crown House
Second Floor
4 Par-la-Ville Road Hamilton,
Bermuda HM 08 Telephone:
(441) 292-1510
FAX: (441) 292-1334
Mailing Address
P.O. Box HM3349
Hamilton, HMPX
Bermuda
Form 10-K
Our Form 10-K is available on our website at www.nabors.com within the
“Investor Relations” section. Copies may be obtained at no charge by writing
to our Corporate Secretary at Nabors’ corporate office.
Transfer Agent
Computershare Trust Company, N.A.
www.computershare.com/investor
Shareholder correspondence should be mailed to:
Computershare
P.O. Box 505000
Louisville, KY
40233-5000
United States
Overnight correspondence should be sent to:
Computershare
462 South 4th Street, Suite 1600
Louisville, KY
40202
United States
Shareholder online inquiries:
https://www-us.computershare.com/investor/Contact
Investor Relations Contact:
William C. Conroy
Vice President of Corporate Development & Investor Relations
William.Conroy@Nabors.com
Independent Registered Public Accounting Firm
PricewaterhouseCoopers LLP Houston, Texas
On April 5, 2021, the closing price of our common shares as reported on the
New York Stock Exchange (“NYSE”) was $90.60, and there were
approximately 1,744 shareholders of record of our common shares. The
common shares are listed on the NYSEunder the symbol “NBR.”
For additional information regarding corporate governance, historical
financial data, investor presentations and global rig fleet, please visit
www.nabors.com.
This annual report includes forward-looking statements within the meaning
of the Securities Act of 1933 and the Securities Exchange Act of 1934. Such
forward-looking statements are subject to a number of risks and
uncertainties, as disclosed by Nabors from time to time in its filings with the
Securities and Exchange Commission. As a result of these factors, Nabors’
actual results may differ materially from those indicated or implied by such
forward-looking statements. The forward-looking statements contained in
this annual report reflect management’s estimates and beliefs as of the date
this annual report is first made available to shareholders. Nabors does not
undertake to update these forward-looking statements.
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WWW.NABORS.COM
2020 ANNUAL REPORT