REDEFINING
THE WAY WELLS
ARE DRILLED
2 0 1 7 A N N U A L R E P O R T
New technology is changing how
we drill wells, with automated
equipment and downhole tools
that drill more accurately in
record time.
These technologies increase safety, boost wellbore productivity
and improve efficiency more than ever before.
With an integrated product portfolio of innovative drilling rigs,
downhole tools, surface equipment and performance software,
Nabors is redefining the industry. We know what it takes to
continually improve the drilling process. Using innovative
software and advanced wellbore placement tools, we are
leveraging the rig as a platform for remote monitoring and the
integration of services to expand the possibilities of drilling
automation and analytics.
The new era of drilling is here – today.
2017 ACCOMPLISHMENTS
Successfully completed the acquisition of Tesco
Corporation in an all-stock transaction valued at
approximately $180 million
Commenced operations of SANAD, our onshore drilling
joint venture with Saudi Aramco in Saudi Arabia
Acquired Robotic Drilling Systems AS, a provider of
automated tubular and tool handling equipment for the
onshore and offshore drilling markets
Experienced a 63% increase in the average number of
rigs working in the U.S. Drilling segment during 2017, as
compared to 2016, as average daily margins increased
from $4,484 in the first quarter of 2017 to $6,444 during
the fourth quarter of 2017
Achieved $50 million annual run-rate target for Nabors
Drilling Solutions (NDS), increasing NDS’ adjusted
EBITDA* to approximately $12.6 million during the fourth
quarter of 2017, as compared to $2.27 million in the
fourth quarter of 2016
* Adjusted EBITDA is computed by subtracting the sum of direct costs, general and administrative expenses and research and engineering expenses from operating revenues. Adjusted
EBITDA is a non-GAAP financial measure and should not be used in isolation or as a substitute for the amounts reported in accordance with GAAP. In addition, adjusted EBITDA
excludes certain cash expenses that the Company is obligated to make. However, management evaluates the performance of its operating segments and the consolidated Company
based on several criteria, including adjusted EBITDA and adjusted operating income (loss), because it believes that these financial measures accurately reflect the Company’s ongoing
profitability and performance. Securities analysts and investors use this measure as one of the metrics on which they analyze the Company’s performance. Other companies in this
industry may compute these measures differently. A reconciliation of this non-GAAP measure to income (loss) from continuing operations before income taxes, which is the most
closely comparable GAAP measure, is provided on the last page of this publication in a table titled, “Reconciliation of Non-GAAP Measures”.
CEO LETTER TO SHAREHOLDERS
ANTHONY G. PETRELLO
CH AIRMAN , P RE SIDEN T & CE O
be 50 newbuild rigs, manufactured in Saudi
Arabia. These new rigs, working under longer
duration contracts, will further solidify SANAD
as the region’s premier onshore drilling
contractor and also strengthen our financial
position for the foreseeable future.
automated directional drilling software and
RigCloud® analytics offering. Furthermore,
these technological advancements should
position Nabors as a leading provider of
drilling automation systems for onshore and
offshore markets.
The recovery in global oil prices is expected
to propel our financial performance in the
U.S. Lower 48 market, where moderately
expansive operator budgets led to the
increased demand for rigs during 2017 and
early 2018. Margins have expanded and
our Nabors SmartRig™ units continue to
operate at full utilization, further confirming
our technology integration strategies and
initiatives. Our rig enhancement program, for
example, enabled us to meet the growing
demand for Nabors SmartRig™ units with
little capital investment, and also share in the
value creation for customers. As we anticipate
these positive trends to continue throughout
2018, we have renewed our organizational
focus on the U.S. market with a relentless
pursuit for further cost reductions that will
enhance our overall financial results.
Also confirming our recent technology
initiatives, we achieved our $50 million
annualized adjusted EBITDA target for the
Nabors Drilling Solutions (NDS) business
in 2017. During the fourth quarter, adjusted
EBITDA for NDS was $12.6 million. The
momentum in this business has led us
to double the adjusted EBITDA target for
2018. Given the size of NDS and its growing
contribution to the Company, we also revised
our financial reporting segments to include
a new reporting segment called Drilling
Solutions. Tesco’s tubular services business
will benefit this segment’s financial results as
we further expand the scale of casing running
and other NDS services.
While NDS has primarily focused on the
U.S. Lower 48 market since its creation in
2015, international expansion and growth is
gaining traction. For example, Saudi Arabia
is expected to be an emerging market for
directional drilling and managed pressure
drilling (MPD) services. We have commenced
two directional drilling jobs in the Kingdom,
and now have a strong tubular services
business for serving the entire Middle East
region.
During 2018, we expect the rotary steerable
and robotics efforts to transition from research
and development to commercialization.
We also plan to commercialize our new
performance tools such as the Navigator™
I am proud of our accomplishments, all of
which were made possible by our highly
capable and talented team of approximately
15,000 employees, and the support of
their families. Their hard work, dedication
and commitment to the Company, and to
each other, was particularly evident during
the tragic aftermath of Hurricane Harvey in
2017. Around the globe, our team pulled
together and demonstrated an outpouring
of generosity and support for Texas flood
victims. For the first time ever, Houstonia
Magazine recognized Nabors as one of
Houston’s top employers because of the
Company’s support provided to employees
and the community in such a time of great
need.
We extended our community outreach efforts
beyond the United States as hundreds of
employees volunteered for service projects in
seven countries as part of our first-ever Good
Nabors Day.
Through technological innovation,
environmental impact planning, corporate
safety initiatives and community relations
activities, we realize that how we conduct
business is one of the primary drivers of our
company.
As market conditions improve, I believe
Nabors is well positioned for a highly
profitable, successful and sustainable
future. In summary, the strengthened macro
commodity price environment, near-
term commercialization of our additional
technology projects, progress toward our
automation efforts and recognition of our rig
performance indicates an improved outlook
for 2018. Based on current market trends
that reveal a tightening supply and demand
for oil throughout the year, I believe we can
look forward to an even more meaningful and
promising outlook in 2019.
Sincerely,
Anthony G. Petrello
Chairman, President & CEO
Nabors Industries Ltd.
Dear Shareholders:
As we enter a new era characterized
by greater drilling efficiency, increased
automation and more precise wellbore
placement, Nabors strengthened its
capabilities and competitive position during
2017 to redefine the way wells are drilled.
Among our most notable accomplishments
was the successful acquisition of Tesco
Corporation, a top-tier global tubular services
provider and rig equipment manufacturer. This
transaction supports our ongoing strategy to
integrate rig services into our rig operating
system and provide more value to customers
by leveraging the drilling rig as the delivery
platform for rig services. As a result of the
Tesco acquisition, Nabors doubled its patent
count and installed top-drive base. I believe
the transaction will accelerate our automated
tubular services offering while yielding
significant global synergies. We have already
made substantial progress toward achieving
our synergy targets, and we anticipate
capturing approximately $25 million of cost
synergies in 2018.
With operations now in 28 countries, Nabors
enhanced the value of our international
infrastructure as we further strengthened our
ability to serve key oil and gas markets around
the world. In late 2017, we commenced
operations with SANAD, our onshore drilling
joint venture with Saudi Aramco in the
Kingdom of Saudi Arabia. This partnership
between the world’s largest oil producer
and one of the largest drilling contractors
represents an opportunity to achieve
significantly higher operating efficiencies and
well productivity over time. At the end of the
first quarter of 2018, we had 45 working rigs
in Saudi Arabia. In 2020, SANAD should begin
taking initial deliveries on what will ultimately
2017 OPERATING
REVENUES
INCREASED 15%,
COMPARED TO 2016
OPERATING REVENUE (BILLIONS, USD)
2.7
2.6
2.5
2.4
2.3
2.2
2.1
2.0
2016
2017
AS A RESULT OF THE TESCO
ACQUISITION IN DEC. 2017,
Doubled patent count to more than 450 patents for innovative
drilling equipment and technologies
Doubled top drive footprint to more than 2,600 top drives sold
around the world
Expanded global operations to five new countries, with an
active presence in 28 countries
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
(cid:95)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
(cid:134)
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2017
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)
980363970
(I.R.S. Employer
Identification No.)
N/A
(Zip Code)
(441) 292-1510
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:
Title of each class
Common shares, $.001 par value per share
Name of each exchange on which registered
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:95) NO (cid:134)
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:134) NO (cid:95)
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:95) NO (cid:134)
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to
be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to file such
reports). YES (cid:95) NO (cid:134)
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:95)
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:95)
Accelerated Filer (cid:134)
Non-accelerated Filer (cid:134)
(Do not check if a
smaller reporting company)
Smaller Reporting Company (cid:134)
Emerging Growth Company (cid:134)
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or
revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. (cid:134)
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES (cid:134) NO (cid:95)
The aggregate market value of the 189,149,782 common shares held by non-affiliates of the registrant outstanding as of the last business day of our most
recently completed second fiscal quarter, June 30, 2017, based on the closing price of our common shares as of such date of $8.14 per share as reported on the New
York Stock Exchange, was $1,539,679,225. Common shares held by each officer and director and by each person who owns 5% or more of the outstanding common
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.
The number of common shares outstanding as of February 22, 2018 was 315,538,146, excluding 52,800,203 common shares held by our subsidiaries, or
368,338,349 in the aggregate.
DOCUMENTS INCORPORATED BY REFERENCE
Specified portions of the definitive Proxy
Statement to be distributed in connection with our 2018 Annual General Meeting of Shareholders (Part III).
NABORS INDUSTRIES LTD.
Form 10-K Annual Report
For the Year Ended December 31, 2017
Table of Contents
PART I
Business ................................................................................................................................................
Item 1.
Item 1A. Risk Factors ..........................................................................................................................................
Item 1B. Unresolved Staff Comments .................................................................................................................
Item 2.
Properties ..............................................................................................................................................
Item 3.
Legal Proceedings .................................................................................................................................
Item 4.
Mine Safety Disclosures .......................................................................................................................
Item 5.
PART II
Market Price of and Dividends on the Registrant’s Common Equity, Related Shareholder Matters
and Issuer Purchases of Equity Securities .............................................................................................
Item 6.
Selected Financial Data ........................................................................................................................
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 .....................................................................................
Item 9.
Changes in and Disagreements With Accountants on Accounting and Financial Disclosure ..............
Item 9A. Controls and Procedures .......................................................................................................................
Item 9B. Other Information .................................................................................................................................
PART III
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
Directors, Executive Officers and Corporate Governance ....................................................................
Executive Compensation ......................................................................................................................
Security Ownership of Certain Beneficial Owners and Management and Related Shareholder
Matters ..................................................................................................................................................
Certain Relationships and Related Transactions and Director Independence .......................................
Principal Accounting Fees and Services ...............................................................................................
PART IV
Item 15.
Item 16.
Exhibits, Financial Statement Schedules ..............................................................................................
Form 10-K Summary ............................................................................................................................
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20
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21
21
24
26
41
44
105
105
106
107
107
107
107
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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 public may read and
copy any material that we file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC
20549 and may obtain information on the operation of the Public Reference Room by calling the SEC at
1-800-SEC-0330. 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.
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:
•
•
•
•
•
•
•
•
•
•
•
•
•
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
industry;
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 downgrade in our credit rating, availability
under our unsecured 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, including our joint
venture in Saudi Arabia and recent acquisition of Tesco Corporation;
the recent changes in U.S. tax laws and the possibility of changes in other tax laws and other laws and
regulations;
3
•
•
the possibility of political or economic instability, civil disturbance, war or acts of terrorism in and of the
countries in which we do business; and
general economic conditions, including the capital and credit markets.
Our businesses depend, 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 decrease in the price of oil or natural gas, that
has a material impact on exploration, development and production activities, could also materially affect our financial
position, results of operations and cash flows.
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
Part I, Item 1A.—Risk Factors.
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.
PART I
ITEM 1. BUSINESS
Overview
Since its founding in 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 numerous international markets. Nabors also provides
directional drilling services, performance tools, and innovative technologies for its own rig fleet and those of 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, consisting of equipment manufacturing, rig instrumentation and optimization software. We
also specialize in wellbore placement solutions and are a leading provider of directional drilling and measurement while
drilling (“MWD”) systems and services.
On December 1, 2017, Nabors announced the commencement of operations of Saudi Aramco Nabors Drilling
Company (“SANAD”), a 50/50 joint venture between Saudi Arabian Oil Company (“Saudi Aramco”) and Nabors.
SANAD owns, manages and operates onshore drilling rigs in the Kingdom of Saudi Arabia.
On December 15, 2017, Nabors completed the acquisition of Tesco Corporation (“Tesco”). Tesco’s tubular
services business will benefit our new Drilling Solutions segment (see below) as we expand globally into key regions.
The acquisition had the additional benefit of combining Tesco’s rig equipment manufacturing, rental and aftermarket
service business with our Rig Technologies segment, creating a leading rig equipment and drilling automation provider.
Under the terms of the acquisition, Nabors acquired all common shares of Tesco in an all-stock transaction, with Tesco
shareholders receiving 0.68 common shares of Nabors for each Tesco share owned, or approximately 32.1 million
Nabors common shares.
During the fourth quarter of 2017, we effected a change in the reporting of our segments to better reflect our
product offerings and the growing significance of our Nabors’ Drilling Solutions business. The expansion of our tubular
services offering attributable to the acquisition of Tesco during the fourth quarter, along with management’s increasing
focus on the strategic aspect of this business and expectation of future growth, culminated in the decision to break this
operation out into its own segment called Drilling Solutions. This operation was historically included within our Rig
Services segment, which we have renamed Rig Technologies and now primarily reflects the oilfield equipment
manufacturing, rental and aftermarket service business of Canrig Drilling Technology (“Canrig”). Our segment
4
information has been revised to conform to the new reportable segments. Our business now consists of five reportable
segments: U.S., Canada, International, Drilling Solutions and Rig Technologies.
As a global provider of drilling and drilling-related services for land-based and offshore oil and natural gas
wells, our fleet of rigs and drilling-related equipment as of December 31, 2017 includes:
•
•
407 actively marketed rigs for land-based drilling operations in the United States, Canada and
approximately 20 other countries throughout the world; and
38 actively marketed rigs for offshore drilling operations in the United States and multiple international
markets.
The following table presents our average rigs working (a measure of activity and utilization over the year) and
average utilization for the years ended December 31, 2017, 2016 and 2015:
2017
Year Ended December 31,
2016
2015
U.S. .............................................................
Canada ........................................................
International ...............................................
Average
Average
Average
Average
Average
Rigs Working Utilization Rigs Working Utilization Rigs Working Utilization
41%
25%
79%
50%
120.0
16.7
124.0
260.7
100.8
15.4
91.1
207.3
62.0
9.7
100.2
171.9
42%
30%
57%
46%
24%
14%
62%
35%
Average
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. International
average rigs working includes our equivalent percentage ownership of rigs owned by unconsolidated affiliates.
Additional information regarding the geographic markets in which we operate and our business segments can
be found in Note 21—Segment Information in Part II, Item 8.—Financial Statements and Supplementary Data.
U.S. Drilling
Our U.S. Drilling operations include land drilling activities in the lower 48 states and Alaska as well as offshore
operations in the Gulf of Mexico. We operate one of the largest land-based drilling rig fleets in the United States,
consisting of 192 AC rigs and 33 SCR rigs which were actively marketed as of December 31, 2017.
Nabors’ first AC land rig was built during 2002. Since then, the AC rig technology has significantly evolved as
more than 900 AC rigs have been added to the U.S. land market. As the industry shifted to multi well pad drilling,
operators demanded greater efficiencies and adaptability through batch drilling. We believe our latest generation of
PACE® drilling rigs are ideal for batch drilling, with pad optimal features, such as our proprietary side saddle design,
and advanced walking capabilities.
In 2013, we introduced our PACE®-X800 rig with an advanced walking system that enables the rig to move
quickly over existing wells, along the X and Y axes. Most of the ancillary equipment moves with the rig, enabling it to
move easily between adjacent rows of wells. Through December 31, 2017, we have placed a total of 47 PACE®-X800
rigs into service within the lower 48 market, including three rigs during fiscal year 2017.
During the second half of 2016, we introduced our new 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. Through December 31,
2017, we have placed eight PACE®-M800 rigs into service, including four rigs during fiscal year 2017.
In addition to land drilling operations throughout the lower 48 states and Alaska, we also actively marketed 14
platform rigs in the U.S. Gulf of Mexico as of December 31, 2017.
5
Our U.S. drilling operations contributed approximately 31% of our consolidated operating revenues for the year
ended December 31, 2017, compared with approximately 25% of our consolidated operating revenues for the year ended
December 31, 2016.
Canada Drilling
Our rig fleet consisted of 42 land-based drilling rigs in Canada as of December 31, 2017. Our Canada drilling
operations contributed approximately 3% of our consolidated operating revenues for the year ended December 31, 2017,
compared with approximately 2% of our consolidated operating revenues for the year ended December 31, 2016.
International Drilling
We maintain a footprint in nearly every major oil and gas market across the globe, most notably in Saudi
Arabia, Algeria, Argentina, Colombia, Kazakhstan and Venezuela. Many of our rigs in our international drilling markets
were designed to address the challenges inherent in specific drilling locations such as those required in the desert and
remote or environmentally sensitive locations, as well as the various shale plays. As of December 31, 2017, our
international fleet consisted of 139 land-based drilling rigs in approximately 20 countries. We also actively marketed
17 platforms and seven jackup rigs in the international offshore drilling markets as of the same date. We continue to
upgrade and deploy high-specification desert rigs specifically for gas drilling in the Middle East. We have been able to
extend the utilization of the PACE®-X800 rigs in international markets by deploying six such rigs in Latin America.
During 2016, we entered into an agreement with Saudi Aramco, to form a new joint venture to own, manage
and operate onshore drilling rigs in the Kingdom of Saudi Arabia. The joint venture, which is equally owned by Saudi
Aramco and Nabors, commenced operations in the fourth quarter of 2017. The joint venture leverages our established
business in Saudi Arabia to begin operations, with a focus on Saudi Arabia's existing and future onshore oil and gas
fields.
Our International drilling operations contributed approximately 58% of our consolidated operating revenues for
the year ended December 31, 2017, compared with approximately 68% of our consolidated operating revenues for the
year ended December 31, 2016.
Drilling Solutions
Through Nabors Drilling Solutions, we offer specialized drilling technologies, such as patented steering
systems and rig instrumentation software systems that enhance drilling performance and wellbore placement. These
products include:
• ROCKit® directional drilling system, which is used to provide data collection services to oil and gas
exploration and service companies;
• REVit® control system, which is a real-time stick slip mitigation system that extends bit life, reduces tool
failures and increases penetration rates, resulting in significant savings in drilling time and costs;
• RigWatch® software, which is computerized software and equipment that monitors a rig’s real-time
performance and provides daily reporting for drilling operations, making this data available through the
internet; and
• DrillSmart® software, which allows the drilling system to adapt to operating parameters and drilling
conditions while optimizing performance.
Nabors specializes in wellbore placement solutions and is a leading provider of directional drilling and MWD
systems and services. Our MWD product line is a proprietary family of advanced systems, representing the latest
technology developed specifically for the unique requirements of land-based drilling applications. Our tools are ideal for
applications where high reliability, precise wellbore placement and drilling efficiency are crucial. Nabors’ patented
directional drilling tools enable a higher level of precision and cost effectiveness. These products include:
6
• AccuMP® mud pulse MWD system, which is designed to address many of the current MWD reliability
issues present in the market today;
• AccuWave® collar mounted Electromagnetic MWD system that addresses the needs of the land market
through the latest technology and design techniques; and
• Nabors’ AccuSteer® Measurement While Drilling (M/LWD) Suite which is a premier dynamics evaluation
MWD system for performance drilling with integrated advanced geosteering measurements. The
AccuSteer® system is a collar based M/LWD designed specifically for the unconventional market.
In addition, the acquisition of Tesco in December 2017 compliments our investment in Nabors Drilling
Solutions and augments our drilling technology offering through enhanced tubular services.
Our Drilling Solutions operations contributed approximately 6% of our consolidated operating revenues for the
year ended December 31, 2017, compared with approximately 3% of our consolidated operating revenues for the year
ended December 31, 2016.
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.
Our Rig Technologies operations contributed approximately 2% of our consolidated operating revenues, net of
intercompany sales, for the year ended December 31, 2017, compared with approximately 2% of our consolidated
operating revenues for the year ended December 31, 2016.
Our Business Strategy
Our business strategy is to build shareholder value and enhance our competitive position by:
•
•
•
•
•
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 returns above our cost of capital.
During 2017 we achieved several milestones in our drive to automate and integrate the well construction
process. As the industry continues its recovery from the severe downturn that began in 2014, we believe the investments
we have made in our rigs and related technology and equipment are all paying off. We are focused on drilling the most
productive, efficient and safe wells to our clients’ specifications, engineered for highly complex and demanding geology.
Our global fleet of 444 rigs is the fundamental platform for our business. We entered 2018 having nearly
completed our goal of 100 Nabors SmartRig™ units for the U.S. Lower 48. Our new PACE®-M1000 rig was introduced
in the second half of 2017, building on the PACE®-M800’s capabilities to deliver optimal well construction for ultra-
long laterals with minimal time spent mobilizing between well pads. Additionally, our enhanced PACE®-X Quad design
began operations for two different major customers in 2017. This innovative mast structure handles four stands of drill
pipe instead of three, decreasing the number of connections and saving time for the customer. Finally, the retrofitting of
much of our non-PACE®-X, 1500 HP AC fleet to bolster capabilities for faster drilling, improved mobility and extended
reach has boosted the number of super spec rigs in our fleet at a fraction of the cost of newbuilds.
During 2017, we also made significant progress in expanding our drilling technology portfolio. We believe
these actions position us well to address the changing market dynamic both in the United States and internationally. Our
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technological development efforts drive toward a seamless integration of the rig’s operations with downhole sensing. In
addition, we are adding complementary services to our traditional rig offering and in many cases replacing third-party
providers of these complementary services as a single service provider. We successfully built scale across wellbore
placement, performance drilling tools, managed pressure drilling services, and other services in the Lower 48, and are
now bringing these services to certain international markets. These efforts support our strategy to differentiate our
drilling services, and ultimately reduce our customers’ unit costs through advanced drilling technology and value added
enhancements.
The acquisition of Tesco augmented both our drilling technology offering through enhanced tubular services, as
well as our rig equipment portfolio. We believe the addition of the many skilled operating and manufacturing personnel
to our team combined with our global rig platform will bolster our capabilities in 2018. We also took a major step
forward toward our vision of a fully automated rig with the acquisition of Robotic Drilling Systems in September 2017.
This exciting modular technology is applicable both in onshore and offshore markets, and provides additional
opportunities to further develop Canrig’s global scale and customer base.
As oil prices improved in the second half of 2017, a healthier exploration and production industry has expanded
its activity. We are well positioned to offer greater value than ever before. With our significantly enhanced global fleet,
growing penetration of Nabors Drilling Solutions products and services, and development of next-generation rig
equipment, we have positioned Nabors not just for the rig of the future, but for the future of well construction.
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).
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
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 national and independent oil and gas companies. One customer, Saudi Aramco,
accounted for approximately 29%, 33% and 12% of our consolidated operating revenues during the years ended
December 31, 2017, 2016 and 2015, respectively, which operating revenues are included in the results of our
International drilling reportable segment. The increase in 2016 compared to 2015 was primarily as a result of our
acquisition of the remaining interest in Nabors Arabia Company Limited (“Nabors Arabia”), our prior joint venture in
Saudi Arabia, in May 2015 and our consolidation of Nabors Arabia’s results of operations. Nabors Arabia was
historically a joint venture in the Kingdom, but now is wholly-owned by Nabors. Our contracts with Saudi Aramco are
on a per rig basis. As noted above, we have entered into a new joint venture with this customer.
Our Employees
As of December 31, 2017, we employed approximately 15,000 people in approximately 20 countries. Our
number of employees fluctuates depending on the current and expected demand for our services. Some rig-based
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employees in Alaska, Argentina, Mexico and Venezuela are represented by collective bargaining units. We believe our
relationship with our employees is generally good.
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.
Research and Engineering
Research and engineering continues to be an important part of our overall business. During 2017, we spent
approximately $51.1 million on research and engineering activities compared to $33.6 million during 2016. The
effective use of technology is critical to maintaining our competitive position within the drilling industry. We expect to
continue developing technology internally and/or acquiring technology through strategic acquisitions.
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. For
example, oil prices were as high as $107 per barrel during 2014 and were as low as $26 per barrel in 2016. Oil prices
began to stabilize during 2017 to moderate levels at an average of approximately $54 per barrel, still well below the peak
we experienced three years ago and the average price over the last decade. As experienced in 2015 and 2016, 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 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 Item 7.— Management’s Discussion and Analysis of Financial Condition
and Results of Operations.
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 readily 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 readily moved from one region to another in response to changes in levels of
activity and many of the total available contracts are currently awarded on a bid basis, competition has increased based
on the supply of existing and new rigs across all of 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—We operate in a highly competitive industry with excess drilling
capacity, which may adversely affect our results of operations.
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Certain competitors are present in more than one of the markets in which we operate, although no one
competitor operates in all such markets. We compete with (1) Helmerich & Payne, Inc., Patterson-UTI Energy, Inc. and
several other competitors with national, regional or local rig operations in the United States, (2) Saipem S.p.A, KCA
Deutag, and Weatherford International Ltd. and various contractors in our international markets and (3) Precision
Drilling, Ensign Energy Services, and others in Canada.
Acquisitions and Divestitures
We have grown from a land drilling business centered in the U.S. lower 48 states, 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. At the
beginning of 1990, our fleet consisted of 44 actively marketed land drilling rigs in Canada, Alaska and in various
international markets. Today, our worldwide fleet of actively marketed rigs consists of 407 land drilling rigs, 31 offshore
platform rigs and seven jackup units. 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.
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.
On March 24, 2015, we completed the merger of our Completion & Production Services business with C&J
Energy Services, Inc. (“C&J Energy”). In the merger and related transactions, our wholly-owned interest in our
Completion & Production Services business was exchanged for cash and an equity interest in the combined entity, C&J
Energy Services Ltd. (“CJES”). Prior to the merger, our Completion & Production Services business conducted our
operations involved in the completion, life-of-well maintenance and plugging and abandonment of wells in the United
States and Canada. On July 20, 2016, CJES and certain of its subsidiaries commenced voluntarily cases under chapter 11
of the U.S. Bankruptcy Code, and as a result, we no longer hold a meaningful stake in CJES. For more information on
the accounting for our investment in CJES, see Note 9—Investments in Unconsolidated Affiliates in Part II, Item 8.—
Financial Statements and Supplementary Data.
In addition, we undertook the following strategic transactions over the last three years.
In May 2015, we paid $106.0 million in cash to acquire the remaining 49% equity interest in Nabors Arabia,
our prior joint venture in Saudi Arabia, making it a wholly owned subsidiary. Previously, we held a 51% equity interest
with a carrying value of $44.7 million, and we had accounted for the joint venture as an equity method investment. The
acquisition of the remaining interest allows us to strategically align our future growth in this market by providing
additional flexibility to invest capital and pursue future investment opportunities. As a result, we consolidated the assets
and liabilities of Nabors Arabia on the acquisition date based on their respective fair values. We have also consolidated
the operating results of Nabors Arabia since the acquisition date and reported those results in our International drilling
segment.
During 2016, we entered into an agreement with Saudi Aramco, to form a new joint venture to own, manage
and operate onshore drilling rigs in the Kingdom of Saudi Arabia. The joint venture, which is equally owned by Saudi
Aramco and Nabors, commenced operations in the fourth quarter of 2017. The joint venture leverages our established
business in Saudi Arabia to begin operations, with a focus on Saudi Arabia's existing and future onshore oil and gas
fields.
In September 2017 we paid an initial amount of approximately $50.7 million in cash, subject to customary
closing adjustments, to acquire Robotic Drilling Systems AS (“RDS”), a provider of automated tubular and tool handling
equipment for the onshore and offshore drilling markets based in Stavanger, Norway. This transaction will allow us to
integrate RDS’s highly capable team and product offering with the technology portfolio of Canrig, and strengthens the
development of Canrig’s drilling automation solutions.
In December 2017, we acquired all of the outstanding common shares of Tesco in an all-stock transaction.
Tesco shareholders received 0.68 common shares of Nabors for each Tesco share owned, or approximately 32.1 million
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Nabors common shares. The combination of Tesco with Nabors’ current product offerings strengthens our ability to
accelerate and scale deployment in drilling automation and analytics.
Environmental Compliance
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 2018. 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
governmental 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
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.
Our business, financial condition or results of operations could be materially adversely affected by any of these
risks.
Fluctuations in oil and natural gas prices could adversely affect drilling activity and our revenues, cash flows and
profitability.
Our operations 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, can be highly volatile. For
example, oil prices were as high as $107 per barrel during 2014 and were as low as $26 per barrel in February 2016.
During 2017, oil prices began to stabilize to moderate levels at an average of approximately $54 per barrel, still well
below the peak we experienced three years ago and the average price over the last decade. The decrease in oil prices was
caused by, among other things, an oversupply of crude oil and stagnant demand. Worldwide military, political and
economic events, including initiatives by the Organization of Petroleum Exporting Countries, 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 economic conditions, 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.
As a result of the low oil price environment that began at the end of 2014, drilling, exploration and production
activity declined in 2015 and remained low throughout 2016, resulting in a corresponding decline in the demand for our
drilling services and/or a reduction in our dayrates and rig utilization. Although oil prices rebounded somewhat in 2017,
they remain relatively low when compared to prices earlier in the decade and the level of drilling, exploration and
production activities remains lower than prior to 2014. The continuation of relatively lower oil and natural gas prices, or
a decline in such prices, could have an adverse effect on our revenues, cash flows, liquidity and profitability.
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. Additionally, these circumstances could indicate that the carrying amount of our
goodwill and intangible assets may exceed their fair value, which could result in a future goodwill impairment. 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.
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Our customers and thereby our business and profitability could be adversely affected by turmoil in the global
economy.
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
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
certain of our customers experiencing an inability to pay vendors, including us. In addition, we may experience
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 world wide economy, undercapacity, 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. 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, in recent years, the ability to deliver rigs with new technology and features has
become an important factor in determining job awards. Our customers increasingly demand the services of newer, higher
specification drilling rigs, which requires continued technological developments and increased capital expenditures. Our
ability to continually provide technologically competitive drilling-related equipment and services can impact our ability
to defend, maintain or increase prices, maintain market share, and negotiate acceptable contract terms with our
customers. Our competitors may be able to respond more quickly to new or emerging technologies and services and
changes in customer requirements for equipment. New technologies, services or standards could render some of our
services, drilling rigs or equipment obsolete, which could adversely impact our ability to compete. Another key factor in
job award determinations 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 that could adversely affect our results of operations.
Our operations are subject to many hazards inherent in the drilling and workover 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 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. Global climate change could lengthen
these periods of reduced activity, but we cannot currently estimate to what degree. Our offshore operations involve the
additional hazards of marine operations including capsizing, grounding, collision, damage from hurricanes and heavy
weather or sea conditions and unsound ocean bottom conditions. Our operations are also subject to risks of war, civil
disturbances or other political events.
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Accidents may occur, we may be unable to obtain desired contractual indemnities, and our insurance may prove
inadequate in certain cases. The occurrence of an event for which we are not fully 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 of these risks. 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.
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
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
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.
We may record additional losses or impairment charges related to sold or idle rigs.
In 2017 and 2016, we recognized impairment charges of $6.9 million and $245.2 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 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.
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 2017 and 2016, we received approximately 45% and 46%, 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% and 33% 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
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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.
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.
We derive a significant portion of our business from global markets, including major operations in the Middle
East, Canada, South America, Algeria, the Far East, North Africa and Russia. These operations are subject to various
risks, including war, civil disturbances, labor strikes, political or economic instability, 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. 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. To the extent that any of these risks arising from our operations in global markets are realized, it could have a
material adverse effect on our business, financial condition and results of operations.
Our financial and operating flexibility could be affected by our long-term debt and other financial commitments.
As of December 31, 2017, we had approximately $4.0 billion in outstanding debt and the ability to borrow up to
$1.7 billion under our revolving credit facility and commercial paper program, subject to compliance with the conditions
and covenants of that facility including the facility’s requirement that our net debt to capital ratio not exceed 0.60:1. As
of December 31, 2017, our net debt to capital ratio was 0.56:1. On January 16, 2018, we consummated an offering of
$800 million in aggregate principal amount of Nabors Delaware’s 5.75% senior notes due 2025. The proceeds from this
offering were used to repay indebtedness of Nabors and its subsidiaries, including all of Nabors Delaware’s outstanding
6.15% senior notes due February 2018. After giving effect to this offering, our total outstanding debt was approximately
$4.0 billion. We also have various financial commitments, such as leases, firm transportation and processing, 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 facility 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.
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.
However, our ability to access capital markets could be limited by, among other things, oil and gas prices, our existing
capital structure, our credit ratings, and the health 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, such as the liquidity of the overall capital
markets and the state of the economy and oil and gas industry, are outside of our control. 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, liquidity 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 the 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 others also are
considered by the rating agencies. The major U.S. credit rating agencies have downgraded our senior unsecured debt
rating to non-investment grade. These and 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 flows.
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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. Furthermore, the Organization for
Economic Co-Operation and Development (‘‘OECD’’) published a Base Erosion and Profit Shifting Action Plan in
July 2013, seeking to reform the taxation of multinational companies. The recommendations made by the OECD may
result in unilateral, uncoordinated changes in tax laws in the countries in which we operate or are organized, which may
result in double taxation or otherwise increase our tax liabilities which in turn could have a material adverse effect on
our financial condition and results of operations.
The recently enacted Tax Cuts and Jobs Act of 2017 (H.R. 1), 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 new law imposes more
stringent limitations on the deductibility of interest expense, the deductibility of 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. 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 corporate
restructuring transactions.
Changes to or noncompliance with governmental 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, storage, 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 substances, oilfield waste
and other waste materials and the use of underground storage tanks.
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 but, in June 2017, the EPA published a
proposed rule that would stay certain portions of the June 2016 standards for two years and reconsider the entirety of the
June 2016 standards. On August 10, 2017, the D.C. Circuit rejected a request by the American Petroleum Institute, an
intervenor in the case, to reconsider the court’s July 3, 2017 decision to vacate the 90-day stay.
15
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,
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, following the filing of a lawsuit in the U.S. District Court for the District of Columbia in May 2016 by several
non-governmental environmental groups against the EPA for the agency’s failure to timely assess its RCRA Subtitle D
criteria regulations for oil and gas wastes, The EPA and the environmental groups entered into an agreement that was
finalized in a Consent Decree issued by the District Court on December 28, 2016. Under the Consent Decree, the EPA is
required to propose no later than March 15, 2019, a rulemaking for revision of certain Subtitle D criteria regulations
pertaining to oil and gas wastes or sign a determination that revision of the regulations is not necessary. If the EPA
proposes a rulemaking for revised oil and gas waste regulations, the Consent Decree requires that the EPA take final
action following notice and comment rulemaking no later than July 15, 2021. Any reclassification of such wastes as
RCRA hazardous wastes could result in more stringent and costly handling, disposal and clean-up requirements.
Legislators and regulators in the United States and other jurisdictions where we operate also focus increasingly
on restricting the emission of carbon dioxide, methane and other greenhouse gases that may contribute to warming of the
Earth’s atmosphere, and other climate changes. 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. Some international initiatives have been or may be adopted,
which could result in increased costs of operations in covered jurisdictions. In December 2015, the United States joined
the international community in the 21st Conference of the Parties of the United Nations Framework Convention on
Climate Change in Paris, France that prepared an agreement requiring member countries to review and ‘‘represent a
progression’’ in their intended nationally determined contributions, which set greenhouse gas emission reduction goals
every five years beginning in 2020. Although this international agreement, referred to as the “Paris Agreement’, does not
create any binding obligations for nations to limit their greenhouse gas emissions, it does include pledges to voluntarily
limit or make future emissions. The Paris Agreement was signed by the United States in 2016 but, in August 2017, the
U.S. State Department officially informed the United Nations of the intent of the United States to withdraw from the
Paris Agreement. In addition, the EPA has published findings that emissions of greenhouse gases present an
endangerment to public health and the environment, which may lead to further regulations of greenhouse gas emissions
under existing provisions of the Clean Air Act. The EPA has already issued rules requiring monitoring and reporting of
greenhouse gas emissions from the oil and natural gas sector, including onshore and offshore production activities.
Furthermore, in November 2016, the Bureau of Land Management (‘‘BLM’’) published a final rule requiring reductions
in methane emissions from venting, flaring, and leaking activities on public lands, but the BLM has since published a
proposed rulemaking in October 2017 that would temporarily suspend certain requirements contained in the November
2016 final rule until January 17, 2019. 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.
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 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.
Additionally, our suppliers, manufacturers, and service providers could be negatively impacted by changes in
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
16
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.
Any violation of the Foreign Corrupt Practices Act or any other similar anti-corruption laws could have a negative
impact on us.
A significant portion of our revenue is derived from operations outside the United States, which exposes us to
complex foreign and U.S. regulations inherent in doing cross-border business and in each of the countries in which we
transact business. We are subject to compliance with the United States Foreign Corrupt Practices Act (‘‘FCPA’’) and
other similar anti-corruption laws, 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 meant to ensure compliance, we cannot be sure that our internal policies, procedures and
programs will always protect us from violations of these laws. Violations of these laws may result in severe criminal and
civil sanctions as well as other penalties. The occurrence or allegation of these types of risks may adversely affect our
business, financial condition and results of operations.
Provisions in our organizational documents may be insufficient to thwart a coercive hostile takeover attempt;
conversely, they may deter a change of control transaction and decrease the likelihood of a shareholder receiving a
change of control premium.
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;
• 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.
At the request of shareholders, in June 2012 we adopted an amendment to our bye-laws to declassify the Board.
In addition, our shareholder rights plan expired in July 2016, and in 2017 we amended our policy regarding nomination
and proxy access for director candidates recommended by shareholders. Each of these changes may make it easier for
another party to acquire control of the Company. The remaining provisions designed to avoid a coercive takeover may
not be fully effective so that a party may still be able to acquire the Company without paying what the Board considers
to be fair value, including a control premium.
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,
including claims related to our acquisition of Tesco. 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.
17
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, or 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 or confidential
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;
exposure to litigation;
loss or damage to our worksite data delivery systems; and
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
result of such cyber attacks. Any cyber incident could have a material adverse effect on our business, financial condition
and results of operations.
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.
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 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 related equipment, and our
ability to maintain an effective, working relationship with our joint venture partner.
We also completed the acquisition of Tesco in December 2017. Potential issues and difficulties that may be
encountered with the Tesco acquisition include the following:
•
•
•
the inability to successfully integrate the respective businesses of Tesco and Nabors in a manner that
permits the combined company to achieve the cost savings and operating synergies anticipated to result
from the combination, which could result in the anticipated benefits of the combination not being realized
partly or wholly in the time frame currently anticipated or at all;
lost sales and customers as a result of certain customers of either or both of the two companies deciding not
to do business with the combined company, or deciding to decrease their amount of business in order to
reduce their reliance on a single company;
integrating personnel from the two companies while maintaining focus on providing consistent, high
quality products and customer service;
18
•
•
•
certain regulatory approvals related to the transaction that we are still in the process of obtaining;
potential unknown liabilities and unforeseen increased expenses, delays or regulatory conditions associated
with the Tesco transaction; and
performance shortfalls as a result of the diversion of management’s attention caused by completing the
transaction and integrating the companies’ operations.
The anticipated benefits of the Saudi joint venture, the Tesco acquisition, and other strategic transactions may
not be 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 and significant transactional expenses,
which may have an 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.
The successful execution of our business strategies will depend, 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 with us. 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.
In addition, Nabors’ performance could be adversely affected if the company does not identify or retain key
employees and skilled workers of Tesco. It is possible that these employees may not remain with the combined
company. The loss of the services of one or more of such key employees and skilled workers could adversely affect
Nabors’ future operating results because of their experience and knowledge of Tesco’s business. In addition, current and
prospective employees may experience uncertainty about their future roles with the company as the integration of
Tesco’s operations with Nabors’ continues. This may adversely affect the ability of Nabors to attract and retain key
personnel, which could adversely affect Nabors’ performance.
Significant issuances of common shares or exercises of stock options could adversely affect the market price of our
common shares.
As of February 22, 2018, we had 800,000,000 authorized common shares, of which 368,338,349 shares were
outstanding and entitled to vote, of which 52,800,203 million were held by our subsidiaries. In addition, 10,629,634
common shares were reserved for issuance pursuant to stock option and employee benefit plans, and 31,997,773
common shares were reserved for issuance upon exchange of outstanding Exchangeable Notes. 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 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.
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
19
applicable subsidiaries’ jurisdiction of organization and other laws and regulations. If subsidiaries are unable to
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.
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; and Dhahran, Saudi Arabia.
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
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 and the province of British Columbia, Canada.
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 management and based on liability accruals
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.
In March 2011, the Court of Ouargla entered a judgment of approximately $24.6 million (at December 31, 2017
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 $16.6 million in excess of amounts accrued.
On September 29, 2017, Nabors and Nabors Maple Acquisition Ltd. 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
20
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, and alleges liability by Nabors as a control person of Tesco. Defendants have
consolidated this case, captioned The Vladimir Gusinsky Rev. Trust et al. v. Tesco Corporation et al., No. 4:17-cv-02918
(S.D. Tex.) (Miller, J.) with two other matters recently filed making the same or similar legal claims against Nabors
and/or Tesco, captioned Panella v. Tesco Corporation et al., No. 4:17-cv-02904 (S.D. Tex.) (Bennett, J.) and Norman
Heinze v. Tesco Corporation et al., No. 4:17-cv-03029 (S.D. Tex).
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
PART II
ITEM 5. MARKET PRICE OF AND DIVIDENDS ON THE REGISTRANT’S COMMON EQUITY, RELATED
SHAREHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information.
Our common shares, par value $0.001 per share, are publicly traded on the New York Stock Exchange (the
“NYSE”) under the symbol “NBR”.
The following table sets forth the reported high and low sales prices of our common shares as reported on the
NYSE for the periods indicated.
Calendar Year
2016 ................................................................................. First Quarter
Share Price
High Low
$ 9.84 $ 4.93
7.61
8.46
11.01
11.21
12.33
17.68
Second Quarter
Third Quarter
Fourth Quarter
2017 ................................................................................. First Quarter
Second Quarter
Third Quarter
Fourth Quarter
$ 18.40 $ 11.89
7.16
6.18
5.32
14.28
8.70
8.04
On February 22, 2018, the closing price of our common shares as reported on the NYSE was $6.68.
Holders.
At February 22, 2018, there were approximately 1,916 shareholders of record of our common shares.
Dividends.
On February 23, 2018, our Board declared a cash dividend of $0.06 per common share, which will be paid on
April 3, 2018 to shareholders of record at the close of business on March 13, 2018.
Our quarterly cash dividends on our total outstanding common shares during the past two fiscal years are shown
in the table below. The declaration and payment of future dividends will be at the discretion of the Board and will
21
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.
Paid per Share
2017 2016 2017
(in thousands, except per share amounts)
Total Payment
2016
Quarter
First ................................................................... $ 0.06 $ 0.06 $ 17,154
17,149
Second ..............................................................
17,153
Third .................................................................
17,148 (1) 17,039 (2)
Fourth ................................................................
$ 16,923
17,003
17,001
0.06
0.06
0.06
0.06
0.06
0.06
(1)
(2)
This quarterly cash dividend was paid on January 3, 2018 to shareholders of record on December 13, 2017.
This quarterly cash dividend was paid on January 4, 2017 to shareholders of record on December 14, 2016.
See Part I—Item 1.A. Risk Factors—As a holding company, we depend on our operating subsidiaries to meet
our financial obligations.
Recent Sales of Unregistered Securities.
On December 15, 2017, we reported in a current report on Form 8-K that we had issued approximately
32,034,232 shares of our common stock in connection with the acquisition of Tesco Corporation. The shares were issued
in reliance on an exemption from registration under federal securities laws provided by Section 3(a)(10) of the Securities
Act of 1933, as amended (the “3(a)(10) Exception”), for the issuance and exchange of securities approved after a public
hearing on the fairness of the terms and conditions of the exchange by a court of competent jurisdiction in front of whom
the securities will be issued had the right to appear. We were later informed by our transfer agent that approximately
43,445 additional common shares were issued at closing to certain Tesco employee shareholders for stock awards that
had vested, and therefore were included in the number of Tesco shares outstanding at closing, but had not yet been
processed by Tesco prior to closing. These shares were also issued under the 3(a)(10) Exception. As a result, in
connection with the acquisition of Tesco Corporation we issued a total of approximately 32.1 million Nabors common
shares.
Issuer Purchases of Equity Securities.
The following table provides information relating to our repurchase of common shares during the three months
ended December 31, 2017:
of Shares
Approximated
Total Number Dollar Value of
Shares that May
Yet Be
Purchased
Under the
Program (2)
Part of Publicly
Program
Average Purchased as
Price
Paid per Announced
Total
Number of
Shares
Period
(In thousands, except per share amounts)
October 1 - October 31 . . . . . . . . . . . . . . . . . . .
November 1 - November 30 . . . . . . . . . . . . . .
December 1 - December 31 . . . . . . . . . . . . . . .
Repurchased Share (1)
6.96
<1 $
5.85
6 $
6.39
48 $
—
—
3,128
298,716
298,716
280,645
(1)
Shares were withheld from employees and directors to satisfy certain tax withholding obligations due in
connection with grants of shares under our 2003 Employee Stock Plan, the 2013 Stock Plan and the 2016 Stock
Plan. Each of the 2016 Stock Plan, the 2013 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.
(2)
In August 2015, our Board authorized a share repurchase program under which we may repurchase up to
$400 million of our common shares in the open market or in privately negotiated transactions. During the year
22
ended December 31, 2017, we repurchased 3.1 million of our common shares for an aggregate purchase price of
approximately $18.1 million under this program. As of December 31, 2017, we had approximately
$280.6 million that remained authorized under the program that may be used to repurchase shares. The
repurchased shares are held by our 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, 2017, our subsidiaries held 52.8 million of our common shares.
Performance Graph
The following graph illustrates comparisons of five-year cumulative total returns among Nabors, the
S&P 500 Index, Dow Jones Oil Equipment and Services Index, S&P MidCap 400 Index and Russell 3000 Index. We are
included in the S&P MidCap 400 Index and Russell 3000 Index and therefore, are presenting these indices below. Total
return assumes $100 invested on December 31, 2012 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
2012
2013
2014
2015
2016
2017
Nabors Industries Ltd.
S&P 500 Index
Dow Jones Oil Equipment and Services Index
S&P MidCap 400 Index
Russell 3000 Index
2012 2013 2014 2015 2016 2017
Nabors Industries Ltd. ........................................ 100 119
52
S&P 500 Index ....................................................... 100 132 151 153 171 208
Dow Jones Oil Equipment and Services Index ...... 100 128 106
87
S&P MidCap 400 Index ......................................... 100 134 147 143 173 201
134 150 151 170 206
Russell 3000 Index ................................................ 100
61 121
82 105
92
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.
23
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.
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.
2017
Year Ended December 31,
2015
(In thousands, except per share amounts and ratio data)
2014
2016
2013
Operating Data (1)(2)
Operating revenues ............................................ $ 2,564,285 $ 2,227,839 $ 3,864,437 $ 6,152,015 $ 6,843,051
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 ............
(135)
(1,029,742)
(18,363)
(1,029,607)
(42,797)
(372,294)
(43,519)
(540,633)
(381)
(372,675)
(11,179)
147,162
(7,180)
139,982
(6,178)
(546,811)
(621)
164,827
(67,526)
165,448
(1,011,244)
(497,114)
(329,497)
158,341
232,974
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:
(1.75) $
(0.15)
(1.90) $
(1.75) $
(0.15)
(1.90) $
(3.58) $
(0.06)
(3.64) $
(3.58) $
(0.06)
(3.64) $
(1.14) $
(0.15)
(1.29) $
(1.14) $
(0.15)
(1.29) $
0.51 $
(0.04)
0.47 $
0.51 $
(0.04)
0.47 $
0.80
(0.23)
0.57
0.79
(0.23)
0.56
Basic ..............................................................
Diluted ...........................................................
280,653
280,653
276,475
276,475
282,982
282,982
294,182
296,592
289,965
292,323
Capital expenditures and acquisitions of
businesses (3) ..................................................... $ 600,909 $ 414,379 $ 923,236 $ 1,365,994 $ 1,433,586
7.4:1
2.4:1
Interest coverage ratio (4) ..................................
6.2:1
9.8:1
3.4:1
24
Balance Sheet Data (1)(2)
Cash, cash equivalents and short-term
investments ............................................ $
Working capital ......................................
Property, plant and equipment, net ........
Total assets .............................................
Long-term debt .......................................
Shareholders’ equity ..............................
Debt to capital ratio:
2017
As of December 31,
2016
2014
2015
(In thousands, except ratio data)
2013
536,169 $
507,133 $
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
1,174,399
8,599,125
11,862,923
4,331,840
4,908,619
1,442,406
8,597,813
12,137,749
3,882,055
5,969,086
778,204
2,000,475
8,712,088
12,631,867
4,355,181
5,944,929
Gross (5) ............................................
Net (6) ...............................................
0.58:1
0.56:1
0.52:1
0.50:1
0.47:1
0.43:1
0.39:1
0.36:1
0.42:1
0.38:1
(1)
(2)
(3)
(4)
(5)
(6)
All periods present the operating activities of most of our wholly owned oil and gas businesses, our previously
held equity interests in oil and gas joint ventures in Canada and Colombia, aircraft logistics operations and
construction services as discontinued operations.
Our acquisitions’ results of operations and financial position have been included beginning on the respective
dates of acquisition and include RDS (September 2017), Tesco (December 2017), Nabors Arabia (May 2015),
2TD (October 2014), KVS (October 2013) and Navigate Energy Services, Inc. (January 2013). 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.
Represents capital expenditures and the total purchase price of acquisitions.
The interest coverage ratio is a trailing 12-month quotient of the sum of (x) operating revenues, direct costs,
general and administrative expenses and research and engineering expenses divided by (y) interest expense. The
interest coverage ratio is not a measure of operating performance or liquidity defined by generally accepted
accounting principles in the United States of America (“U.S. GAAP”) and may not be comparable to similarly
titled measures presented by other companies.
The gross debt to capital ratio is calculated by dividing total debt by total capitalization (total debt plus
shareholders’ equity). The gross debt to capital ratio is not a measure of operating performance or liquidity
defined by U.S. GAAP and may not be comparable to similarly titled measures presented by other companies.
The net debt to capital ratio is calculated by dividing net debt by net capitalization. Net debt is defined as total
debt minus the sum of cash and cash equivalents and short-term investments. Net capitalization is defined as net
debt plus shareholders’ equity. The net debt to capital ratio is not a measure of operating performance or
liquidity defined by U.S. GAAP and may not be comparable to similarly titled measures presented by other
companies.
25
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 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 are a provider of 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, consisting of equipment manufacturing,
rig instrumentation and optimization software. We also specialize in wellbore placement solutions and are a leading
provider of directional drilling and MWD systems and services.
During 2016, we entered into an agreement with Saudi Aramco, to form a new joint venture to own, manage
and operate onshore drilling rigs in the Kingdom of Saudi Arabia. The joint venture, which is equally owned by Saudi
Aramco and Nabors, commenced operations in the fourth quarter of 2017. The joint venture leverages our established
business in Saudi Arabia to begin operations, with a focus on Saudi Arabia's existing and future onshore oil and gas
fields.
On December 15, 2017, Nabors completed the acquisition of Tesco. Tesco’s tubular services business will
benefit our Drilling Solutions segment as we expand globally into key regions. The acquisition had the additional benefit
of combining Tesco’s rig equipment manufacturing, rental and aftermarket service business with our Rig Technologies
segment, creating a leading rig equipment and drilling automation provider. Under the terms of the acquisition, Nabors
acquired all common shares of Tesco in an all-stock transaction, with Tesco shareholders receiving 0.68 common shares
of Nabors for each Tesco share owned, or approximately 32.1 million Nabors common shares.
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. The oil and natural gas markets have traditionally been volatile and tend
to be highly sensitive to supply and demand cycles.
The worldwide supply and demand for oil has improved over the past couple of years, while OPEC has
successfully curtailed supply growth. The increase in the price of oil has spurred rig count growth in the U.S. and
increased expression of interest for additional rigs internationally, which historically is less cyclical than the U.S. In the
U.S., our average rigs working during 2017 experienced a 63% increase compared to 2016. Internationally, our average
rigs working during 2017 experienced a decrease of 9% compared to 2016. Due to the large number of idle rigs in the
market at the beginning of the year, the increase in the demand for rigs resulted in the increase in average rigs working
without considerable upward pressure on prices, or dayrates. However, as we entered new contracts or renewed existing
ones throughout 2017, most notably during the latter half of the year, we experienced favorable dayrate increases. This
trend has continued into 2018.
Recent Developments
On December 22, 2017, the United States enacted the Tax Cuts and Jobs Act of 2017 (“Tax Reform Act”).
Among a number of significant changes to the current U.S. federal income tax rules, the Tax Reform Act reduces the
marginal U.S. corporate income tax rate from 35 percent to 21 percent, limits the current deduction for net interest
expense, limits the use of net operating losses to offset future taxable income, and imposes a type of minimum tax
designed to reduce the benefits derived from intercompany transactions and payments that result in base erosion. As a
result of the Tax Reform Act, we were required to revalue deferred tax assets and liabilities from 35 percent to 21
percent. This revaluation has resulted in recognition of an expense of approximately $138.6 million, which is included as
26
a component of income tax expense in continuing operations. We believe the other provisions of the Tax Reform Act
should not have a material impact on our consolidated financial statements. On December 22, 2017, Staff Accounting
Bulletin No. 118 ("SAB 118") was issued to address the application of U.S. GAAP in situations when a registrant does
not have the necessary information available, prepared, or analyzed (including computations) in reasonable detail to
complete the accounting for certain income tax effects of the Tax Reform Act. In accordance with SAB 118, we have
calculated our best estimate of the impact of the Tax Reform Act in our year end income tax provision in accordance
with our understanding of the Tax Reform Act and guidance available as of the date of this filing. However, we are
continuing to assess the impact that it will have on us and our preliminary assessment is subject to the finalization of
management’s analysis related to certain matters.
In January 2018, Nabors Delaware completed an offering of $800 million aggregate principal amount of 5.75%
senior unsecured notes due February 1, 2025, which are fully and unconditionally guaranteed by us. The proceeds from
this offering were used to repay indebtedness of Nabors and its subsidiaries, including all of Nabors Delaware’s
outstanding 6.15% senior notes due February 2018.
At December 31, 2017, we had $550.0 million outstanding under our $2.25 billion revolving credit facility and
commercial paper program. Availability under the revolving credit facility is subject to a covenant not to exceed a net
debt to capital ratio of 0.60:1. As of December 31, 2017, our net debt to capital ratio was 0.56:1. See Item 6. “Selected
Financial Data”. The net debt to capital ratio as of December 31, 2017 does not give effect to the issuance of the senior
notes in January 2018 discussed above.
Financial Results
Comparison of the years ended December 31, 2017 and 2016
Operating revenues in 2017 totaled $2.6 billion, representing an increase of $336.4 million, or 15%, from 2016.
We have seen a significant increase in the number of rigs working in the U.S. compared to the same period last year,
which has led to higher revenues in our U.S. Drilling, Drilling Solutions and Rig Technologies reportable segments.
Internationally, we experienced a decline in the number of rigs working of approximately 9%, which has partially offset
the increases realized in the U.S. Drilling segment.
Net loss from continuing operations attributable to Nabors totaled $503.3 million for 2017 ($1.75 per diluted
share) compared to a net loss from continuing operations attributable to Nabors of $1.0 billion ($3.58 per diluted share)
in 2016. This equated to a decrease in loss from continuing operations attributable to Nabors of $508.1 million. In
combination with the increase in revenue noted above, our net loss from continuing operations attributable to Nabors
was positively impacted by the absence of an equity method investment in CJES, which accounted for $442.0 million of
our net loss for the year ended December 31, 2016 related to our share of the net loss of CJES as well as impairment
charges associated with the investment. Our results for 2017 include a benefit for a release of reserves due to favorable
tax audit outcomes during the year of $167.0 million. This was offset by $138.6 million in income tax expense recorded
in connection with the Tax Reform Act.
General and administrative expenses in 2017 totaled $251.2 million, representing an increase of $23.5 million,
or 10% from 2016. This is primarily reflective of an increase in headcount and compensation in response to the increase
in drilling activity.
Research and engineering expenses in 2017 totaled $51.1 million, representing an increase of $17.5 million, or
52%, from 2016. The increase is a result of increased efforts towards a number of strategic research and engineering
projects, including the acquisition of RDS during 2017.
Depreciation and amortization expense in 2017 was $842.9 million, representing a decrease of $28.7 million, or
3%, from 2016. The decrease was primarily due to the impact from retirements and impairments of various rigs and rig
equipment in late 2016 partially offset by incremental depreciation associated with capital expenditures as we upgrade
our existing rig fleet.
27
Segment Results of Operations
Our business is comprised of our global land-based and offshore drilling rig operations and other rig related
services and technologies, consisting of equipment manufacturing, rig instrumentation and optimization software. We
also specialize in wellbore placement solutions and are a leading provider of directional drilling and MWD systems and
services.
During the fourth quarter of 2017, we effected a change in the reporting of our segments to better reflect our
product offerings and growing significance of our Nabors Drilling Solutions business. The expansion of our tubular
services offering attributable to the acquisition of Tesco during the fourth quarter, along with management’s increasing
focus on the strategic aspect of this business and expectation of future growth, culminated in the decision to break this
operation out into its own segment called Drilling Solutions. This operation was historically included within our Rig
Services segment, which we have renamed Rig Technologies and now primarily reflects the oilfield equipment
manufacturing, rental and aftermarket service business of Canrig. Our segment information has been revised to conform
to the new reportable segments. Our business now consists of five reportable segments: U.S., Canada, International,
Drilling Solutions and Rig Technologies. See Note 21—Segment Information for additional information on the change
in reporting segments.
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) is computed by subtracting the sum of direct
costs, general and administrative expenses, research and engineering expenses and depreciation and amortization from
operating revenues. A reconciliation of adjusted operating income to net income (loss) from continuing operations
before income taxes can be found in Note 21—Segment Information.
The following tables set forth certain information with respect to our reportable segments and rig activity:
Year Ended December 31,
2017
2016
Increase/(Decrease)
2017 to 2016
(In thousands, except percentages and rig activity)
U.S.
Operating revenues ............................................................................................................ $
Adjusted operating income (loss) ...................................................................................... $
Average rigs working (1)...................................................................................................
805,223 $
(213,877) $
100.8
554,072 $
(197,710) $
62.0
251,151
(16,167)
38.8
Canada
Operating revenues ............................................................................................................ $
Adjusted operating income (loss) ...................................................................................... $
Average rigs working (1)...................................................................................................
82,929 $
(22,262) $
15.4
51,472 $
(36,818) $
9.7
31,457
14,556
5.7
45 %
(8)%
63 %
61 %
40 %
59 %
International
Operating revenues ............................................................................................................ $ 1,474,060 $ 1,508,890 $
164,677 $
Adjusted operating income (loss) ...................................................................................... $
100.2
Average rigs working (1)...................................................................................................
108,428 $
91.1
(34,830)
(56,249)
(9.1)
(2)%
(34)%
(9)%
Drilling Solutions
Operating revenues ............................................................................................................ $
Adjusted operating income (loss) ...................................................................................... $
140,701 $
16,738 $
63,759 $
(16,503) $
76,942
33,241
121 %
201 %
Rig Technologies
Operating revenues ............................................................................................................ $
Adjusted operating income (loss) ...................................................................................... $
234,542 $
(30,964) $
151,951 $
(31,981) $
82,591
1,017
54 %
3 %
(1)
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. International average rigs
working includes our equivalent percentage ownership of rigs owned by unconsolidated affiliates.
U.S.
Operating results decreased in 2017 compared to 2016. We experienced a 63% increase in the average number
of rigs working during 2017 compared to 2016, which was the primary contributor to the $251.2 million, or 45%,
28
increase in operating revenues. However, dayrates were lower on average, mitigating the impact of increased activity on
our average daily margins and adjusted operating income. Additionally, positive results were partially offset by a
decrease in operating revenue and adjusted operating income in our offshore operations. Our results for 2016 included a
favorable resolution of negotiations for one of our rigs in the Gulf of Mexico, which resulted in partial recovery of
standby revenues for past quarters of approximately $20.9 million. The absence of this incremental revenue in
combination with a decline in the number of rigs working in the Gulf of Mexico contributed to the overall decline in
operating results.
Canada
Operating results increased in 2017 compared to 2016 due to an increase in drilling rig activity, as evidenced by
the increase in average number of rigs working during 2017 compared to 2016.
International
Operating results decreased in 2017 compared to 2016 primarily due to the loss of revenue and increased costs
related to downtime incurred to perform structural work on many of our rigs in our largest international market during
the first half of 2017. Additionally, results were negatively impacted by a 9% reduction in average number of rigs
working during 2017 compared to 2016. Partially offsetting these declines were increased drilling activity in Colombia,
Kazakhstan and Kuwait.
Drilling Solutions
Operating results increased in 2017 compared to 2016 primarily due to a substantial increase in the performance
tools revenue days. Although prices on average have been lower in the U.S., we have experienced increased pricing
throughout 2017, most notably during the fourth quarter as contracts are renegotiated. Additionally, we have experienced
growth across all product lines as a result of the significant increase in drilling activity in the U.S. during 2017 compared
to 2016.
Rig Technologies
Operating results increased in 2017 compared to 2016 due to the significant increase in drilling activity in the
U.S. for the period and in the demand for our products and services. The revenue increase in the segment is driven by an
increase in capital equipment deliveries from Canrig.
Other Financial Information
Earnings (losses) from unconsolidated affiliates
Earnings (losses) from unconsolidated affiliates represents our share of the net income (loss), as adjusted for
our basis differences, of our equity method investments. We previously accounted for our investment in CJES under the
equity method on a one-quarter lag through June 30, 2016. On July 20, 2016, CJES voluntarily filed for protection under
Chapter 11 of the Bankruptcy Code. As a result, beginning with the third quarter of 2016, we ceased accounting for our
investment under the equity method of accounting. Earnings (losses) from unconsolidated affiliates for the year ended
December 31, 2016 includes our share of the net income (loss) of CJES from October 1, 2015 through March 31, 2016,
resulting in a loss of $221.9 million, inclusive of charges of $138.5 million representing our share of CJES’s fixed asset
impairment charges for the period.
Interest expense
Interest expense for 2017 was $222.9 million, representing an increase of $37.5 million, or 20%, compared to
2016. The increase was primarily due to the additional interest expense related to the issuance of $600 million in
aggregate principal amount of 5.5% senior notes due 2023 during December 2016 as well as the issuance of
$575 million in aggregate principal amount of 0.75% senior exchangeable notes due 2024 during January 2017. This
increase was partially offset by a reduction in interest expense due to the repayment of the term loan facility with
proceeds of these offerings and with the repurchase or redemption of approximately $367.9 million in aggregate
principal amount of 6.15% senior notes due 2018 since December 31, 2016.
29
Impairments and other charges
Impairments and other charges for 2017 was $44.5 million, which included $21.6 million in transaction related
costs, $16.0 million loss recognized on the early extinguishment of debt resulting from debt repurchases and
impairments of long-lived assets of $6.9 million comprised of underutilized rigs in our International drilling segment.
Other, net
Other, net for 2017 was $14.9 million of expense, which included net losses on sales and disposals of assets of
approximately $19.0 million and foreign currency exchange losses of $1.6 million.
Other, net for 2016 was $44.2 million of expense, which was primarily comprised of net losses on sales and
disposals of assets of approximately $14.8 million, legal and professional fees primarily of $12.9 million incurred in
connection with preserving our interests in CJES, foreign currency exchange losses of $5.7 million and increases to
litigation reserves of $3.9 million.
Income tax rate
Our worldwide effective tax rate during 2017 was 14.3% compared to 15.6% during 2016. The effective tax
rate for 2017 includes a benefit for the release of reserves due to favorable audit outcomes during the year of
$167.0 million. This was partially offset by a non-cash write-down of net deferred tax assets of $138.6 million
attributable to the Tax Reform Act passed during the fourth quarter of 2017.
Discontinued operations
Our discontinued operations during 2017 and 2016 consisted of our historical wholly owned oil and gas
businesses. Income (loss) from discontinued operations during 2017 was a loss of $43.9 million compared to a loss of
$18.4 million during 2016. During 2017 and 2016, we recognized impairment charges of $35.3 million and $15.4
million, respectively, due to the deterioration of economic conditions in the dry gas market in western Canada.
Additionally, our net loss for 2017 included a $16.5 million charge related to the settlement of litigation associated with
our previously owned Ramshorn International properties.
Additional discussion of our policy pertaining to the calculations of our annual impairment tests, including any
impairment of goodwill, is set forth in Critical Accounting Estimates below in this section and in Note 2—Summary of
Significant Accounting Policies in Part II, Item 8.—Financial Statements and Supplementary Data. Additional
information relating to discontinued operations is provided in Note 4—Assets Held for Sale and Discontinued
Operations in Part II, Item 8.—Financial Statements and Supplementary Data.
Comparison of the years ended December 31, 2016 and 2015
Operating revenues in 2016 totaled $2.2 billion, representing a decrease of $1.6 billion, or 42%, from 2015. The
decrease in revenues was due to the significant decline in the number of rigs working as evidenced by a 34% reduction
in average rigs working during 2016 compared to 2015. Also contributing to the decline in revenue were lower dayrates
as existing contracts expired and were repriced at the lower prevailing market dayrates for many rigs, while other rigs
commenced standby rates, terminations or price concessions granted to certain customers. The remainder of the decrease
in operating revenue was due to ceasing to consolidate the revenues associated with our Completion & Production
Services business, which accounted for $0.4 billion, or 22%, of the overall decrease.
Net loss from continuing operations attributable to Nabors totaled $1.0 billion for 2016 ($3.58 per diluted
share) compared to a net loss from continuing operations attributable to Nabors of $329.9 million ($1.14 per diluted
share) in 2015. This equated to an increase in loss from continuing operations attributable to Nabors of $681.5 million.
Approximately $435.2 million of the increase in loss was attributable to our segment adjusted operating income (loss),
which is our primary measure of operating performance. See Segment Results of Operations for further information on
the changes to segment adjusted operating income (loss). The remainder of the increase in loss was attributable to higher
losses from unconsolidated affiliates and an increase in the magnitude of impairments and other charges. We recorded a
$221.9 million loss in 2016 compared to an $81.3 million loss in 2015 for our share of the net income (loss) of CJES,
which represents our portion (53%) of their net income (loss). Our impairments and other charges were $505.2 million
30
in 2016 compared to $369.0 million in 2015, for a $136.2 million increase in losses. These charges were primarily
comprised of $285.4 million related to impairments and retirements of tangible assets and equipment as a result of the
sustained decline in oil prices and the continued realization of lower demand for and obsolescence of legacy asset classes
and $219.7 million related to other-than-temporary impairments on our equity method investments. Similarly, during
2015 we recognized approximately $369.0 million in impairments and other charges. These charges resulted from the
impact of the industry downturn on our business activity and future outlook as the continuation of depressed oil prices
led to considerable reductions in capital spending by some of our customers and diminished demand for our drilling
services. These charges were primarily comprised of $140.1 million related to impairments and retirements of tangible
assets and equipment, $180.6 million related to an other-than-temporary impairment on our equity method investment in
CJES and $48.3 million for a provision for International operations. Additional information relating to impairments and
other charges is provided in Note 3—Impairments and Other Charges in Part II, Item 8.—Financial Statements and
Supplementary Data.
General and administrative expenses in 2016 totaled $227.6 million, representing a decrease of $96.7 million,
or 30% from 2015. The decrease was partially attributable to the fact that we ceased consolidating the expenses from our
former Completion & Production Services business as a result of the CJES merger, which accounted for approximately
$26.0 million of the decrease. Also contributing to the decrease was a reduction in average headcount of approximately
22% as a result of our efforts to right size our back office functions to the level of operations. The remainder of the
decrease is attributed to our continued cost-reduction efforts across our remaining operating units and our corporate
offices.
Research and engineering expenses in 2016 totaled $33.6 million, representing a decrease of $7.7 million, or
19%, over 2015. The decrease was primarily attributable to a reduction in workforce and general cost-reduction efforts
across the various operating units. Also contributing to the decrease was the reduction in drilling related projects as a
result of the decline in overall activity.
Depreciation and amortization expense in 2016 was $871.6 million, representing a decrease of $98.8 million, or
10%, over 2015. The decrease was due largely to the fact that we ceased consolidating the expenses from our former
Completion & Production Services business as a result of the CJES merger, which accounted for $51.1 million of the
decrease. The remainder of the decrease primarily relates to an increased number of rigs that were not working during
the period, which results in a lower inactive depreciation rate and the impact from various retirements of legacy fleet rigs
in late 2015.
31
Segment Results of Operations
The following tables set forth certain information with respect to our reportable segments and rig activity:
Year Ended December 31,
2016
2015
Increase/(Decrease)
2016 to 2015
U.S.
Operating revenues ..............................................................................................................
Adjusted operating income (loss) ........................................................................................
Average rigs working (1).....................................................................................................
$
$ (197,710) $
554,072 $ 1,256,989 $ (702,917)
87,051 $ (284,761)
(58.0)
120.0
62.0
(56)%
(327)%
(48)%
Canada
Operating revenues ..............................................................................................................
Adjusted operating income (loss) ........................................................................................
Average rigs working (1).....................................................................................................
$
$
51,472 $
(36,818) $
9.7
137,494 $ (86,022)
(7,029) $ (29,789)
(7.0)
16.7
(63)%
n/m (2)
(42)%
International
Operating revenues ..............................................................................................................
Adjusted operating income (loss) ........................................................................................
Average rigs working (1).....................................................................................................
$ 1,508,890 $ 1,862,393 $ (353,503)
308,262 $ (143,585)
$
(23.8)
164,677 $
100.2
124.0
(19)%
(47)%
(19)%
Drilling Solutions
Operating revenues ..............................................................................................................
Adjusted operating income (loss) ........................................................................................
$
$
63,759 $
(16,503) $
69,828 $
(10,879) $
(6,069)
(5,624)
(9)%
(36)%
Rig Technologies
Operating revenues ..............................................................................................................
Adjusted operating income (loss) ........................................................................................
$
$
151,951 $
(31,981) $
321,238 $ (169,287)
(1,762) $ (30,219)
(53)%
n/m (2)
(1)
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. International average rigs
working includes our equivalent percentage ownership of rigs owned by unconsolidated affiliates.
(2)
The number is so large that it is not meaningful.
U.S.
Operating results decreased in 2016 compared to 2015 primarily due to the continued decline in drilling activity
in the lower 48 states, reflected by a 48% reduction in the average number of rigs working during 2016 compared to the
prior period. The decline in drilling activity is the result of lower customer demand for drilling rigs due to the depressed
oil price environment. This lower demand also resulted in lower dayrates for rigs, both of which contributed to the
decrease in revenue as well as adjusted operating income (loss). Partially offsetting the decrease in drilling activity
during 2016 was a favorable resolution of negotiations for one of our rigs in the Gulf of Mexico, which resulted in
partial recovery of standby revenues for past quarters of approximately $20.9 million. While activity levels were lower
on average throughout 2016, we believe that activity levels bottomed in the earlier half of the year and we have seen a
marked improvement over the second half of the year, reflected by an increase in our average rigs working of 50% from
the lowest point early in the second quarter to the end of the year.
Canada
Operating results decreased in 2016 compared to 2015 due to a decline in both drilling rig activity and dayrates.
These declines were the direct result of lower industry activity and pricing pressure from customers resulting from the
decline in oil and gas prices. The lower activity was evidenced by a 42% reduction in average rigs working during 2016
compared to the prior period. The seasonal decline in the second quarter of 2016 was minimalized by the historically low
first quarter rig counts, which averaged 4 rigs. However, we experienced an increase over the course of the second half
of 2016. We exited 2016 and entered 2017 with a marked increase in rigs working to 25 rigs at the end of January 2017.
International
Operating results decreased in 2016 compared to 2015 primarily due to a decline in drilling activity, reflected
by a 19% reduction in average rigs working during 2016 compared to the prior period. The decrease in our operating
results was also adversely affected by pricing pressure and diminished demand as customers released rigs in response to
32
the significant drop in oil prices. Partially offsetting the decrease in activity for the year ended December 31, 2016 was
approximately $45.7 million in revenue related to early termination and demobilization payments, recovery of certain
contractual disputes and a business interruption insurance claim.
Drilling Solutions
Operating results decreased in 2016 compared to 2015 primarily due to a broad-based decline in revenue-
producing activities as well as the continued decline in our directional drilling businesses due to generally lower drilling
activity and intense competition driven by the low prices of oil and gas.
Rig Technologies
Operating results decreased in 2016 compared to 2015 primarily due to fewer top drive and catwalk unit sales,
which is driven by the low prices of oil and gas.
Other Financial Information
Earnings (losses) from unconsolidated affiliates
Earnings (losses) from unconsolidated affiliates represents our share of the net income (loss), as adjusted for
our basis differences, of our equity method investments, primarily composed of our investment in CJES. We accounted
for our investment in CJES on a one-quarter lag through June 30, 2016. On July 20, 2016, CJES voluntarily filed for
protection under chapter 11 of the Bankruptcy Code. As a result, beginning in the third quarter of 2016, we ceased
accounting for our investment in CJES under the equity method of accounting. The year ended December 31, 2016
includes our share of the net income (loss) of CJES from October 1, 2015 through March 31, 2016, resulting in a loss of
$221.9 million, inclusive of charges of $138.5 million representing our share of CJES’s fixed asset impairment charges
for the period. As we wrote off the remaining carrying value of our investment in CJES during the second quarter of
2016, we did not record our share of the earnings (losses) of CJES for the three months ended June 30, 2016 as we are
not contractually responsible for losses beyond our investment. The operating losses of CJES for the period noted above
are primarily due to reduced activity levels resulting from the extended downturn in oil prices.
Interest expense
Interest expense for 2016 was $185.4 million, representing a marginal increase of $3.4 million, or 2%,
compared to 2015. During 2016, we curtailed spending on major projects, which resulted in a reduction in the amount of
capitalized interest recognized during the period of approximately $13.8 million. The reduction in capitalized interest for
the year was partially offset by the benefit of lower interest expense incurred on our 6.15% and 9.25% senior notes of
approximately $9.1 million. The average amounts outstanding under these senior notes were lower throughout 2016 due
to the repurchases made in 2015 and early 2016 of approximately $10.8 million and $131.0 million, respectively.
Other, net
Other, net for 2016 was $44.2 million of expense, which was primarily comprised of net losses on sales and
disposals of assets of approximately $14.8 million, legal and professional fees primarily incurred in connection with
preserving our interests in CJES of $12.9 million, foreign currency exchange losses of $5.7 million and increases to
litigation reserves of $3.9 million.
Other, net for 2015 was $39.2 million of income, which was primarily comprised of a net gain of $47.1 million
related to the CJES merger, inclusive of a $102.2 million gross gain offset by transaction costs and post-closing
adjustment, and net gains on sales and disposals of assets of approximately $2.3 million. These gains were partially
offset by increases to litigation reserves of $8.2 million and foreign currency exchange losses of $0.4 million.
Income tax rate
Our worldwide effective tax rate during 2016 was 15.6% compared to 22.9% during 2015. The change was
attributable to the effect of the geographic mix of pre-tax earnings (losses), including greater losses in high-tax
jurisdictions. The tax effect of impairments and our share of the net loss of CJES also contributed to the change.
33
Discontinued operations
Our discontinued operations during 2016 and 2015 consisted of our historical wholly owned oil and gas
businesses. Income (loss) from discontinued operations during 2016 was a loss of $18.4 million compared to a loss of
$42.8 during 2015. Our net loss during 2016 was primarily due to a $15.4 million impairment charge due to the
deterioration of economic conditions in the dry gas market in western Canada. Similarly, during 2015 we recognized
impairment charges of $51.0 million on our oil and gas properties in western Canada as well as a $3.1 million
impairment charge for a note receivable remaining from the sale of one of our former Canada subsidiaries that provided
logistics services.
Additional discussion of our policy pertaining to the calculations of our annual impairment tests, including any
impairment of goodwill, is set forth in Critical Accounting Estimates below in this section and in Note 2—Summary of
Significant Accounting Policies in Part II, Item 8.—Financial Statements and Supplementary Data. Additional
information relating to discontinued operations is provided in Note 4—Assets Held for Sale and Discontinued
Operations in Part II, Item 8.—Financial Statements and Supplementary Data.
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, our
commercial paper program and cash generated from operations. As of December 31, 2017, we had cash and short-term
investments of $365.4 million and working capital of $527.9 million. As of December 31, 2016, we had cash and short-
term investments of $295.2 million and working capital of $333.9 million. At December 31, 2017, we had $550.0
million of borrowings outstanding under our $2.25 billion revolving credit facility and commercial paper program.
In January 2017, Nabors Delaware issued $575 million in aggregate principal amount of its 0.75%
exchangeable senior unsecured notes due 2024, which are fully and unconditionally guaranteed by Nabors. The
exchangeable notes are exchangeable, under certain conditions, at an initial exchange rate of 39.75 common shares of
the Company per $1,000 principal amount of notes (equivalent to an initial exchange price of approximately $25.16 per
common share). Upon any exchange, Nabors Delaware will settle its exchange obligation in cash, common shares of the
Company, or a combination of cash and common shares, at our election. In connection with the pricing of the notes, we
entered into privately negotiated capped call transactions which are expected to reduce potential dilution to common
shares and/or offset potential cash payments required to be made in excess of the principal amount upon any exchange of
notes. Such reduction and/or offset is subject to a cap representing a price per share of $31.45, an approximately 75.0%
premium over our share price of $17.97 as of the date of the transaction. The net proceeds from the offering of the
exchangeable notes were used to prepay the remaining balance of our unsecured term loan originally scheduled to
mature in 2020, as well as to pay approximately $40.3 million for the cost of the capped call transactions. Any remaining
net proceeds from the offering were allocated for general corporate purposes, including to repurchase or repay other
indebtedness.
In January 2018, Nabors Delaware completed an offering of $800 million aggregate principal amount of 5.75%
senior unsecured notes due February 1, 2025, which are fully and unconditionally guaranteed by Nabors. The proceeds
from this offering were used to repay indebtedness of Nabors and its subsidiaries, including all of Nabors Delaware’s
outstanding 6.15% senior notes due February 2018.
We had 15 letter-of-credit facilities with various banks outstanding as of December 31, 2017. Availability under
these facilities as of December 31, 2016 was as follows:
Credit available .........................................................................................................................................
Less: Letters of credit outstanding, inclusive of financial and performance guarantees ...........................
Remaining availability ..............................................................................................................................
December 31,
2017
(In thousands)
759,421
$
153,489
605,932
$
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
34
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 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 downgraded our senior unsecured debt rating
to non-investment grade. These and 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 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.
Our gross debt to capital ratio was 0.58:1 as of December 31, 2017 and 0.52:1 as of December 31, 2016,
respectively. Our net debt to capital ratio was 0.56:1 as December 31, 2017 and 0.50:1 as of December 31, 2016. The
gross debt to capital ratio is calculated by dividing total debt by total capitalization (total debt plus shareholders’ equity).
The net debt to capital ratio is calculated by dividing net debt by net capitalization. Net debt is defined as total debt
minus the sum of cash and cash equivalents and short-term investments. Net capitalization is defined as net debt plus
shareholders’ equity. Availability under the revolving credit facility is subject to a covenant not to exceed a net debt to
capital ratio of 0.60:1. Neither the gross debt to capital ratio nor the net debt to capital ratio is a measure of operating
performance or liquidity defined by U.S. GAAP and may not be comparable to similarly titled measures presented by
other companies.
Our interest coverage ratio was 2.4:1 as of December 31, 2017 and 3.4:1 as of December 31, 2016. The interest
coverage ratio is a trailing 12-month quotient of the sum of operating revenues, direct costs, general administrative
expenses and research and engineering expenses divided by interest expense. The interest coverage ratio is not a measure
of operating performance or liquidity defined by U.S. GAAP and may not be comparable to similarly titled measures
presented by other companies. None of the above ratios give effect to the issuance of the senior notes in January 2018
discussed above.
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.
Our current cash and investments, projected cash flows from operations and our 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.
Future Cash Requirements
We expect capital expenditures over the next 12 months to be approximately $0.5 billion. Purchase
commitments outstanding at December 31, 2017 totaled approximately $196.0 million, primarily for rig-related
enhancements, new construction and equipment, as well as sustaining capital expenditures, other operating expenses and
purchases of inventory. We can reduce planned expenditures if necessary or increase them if market conditions and new
business opportunities warrant 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 believe these programs will result in the enhancement of a significant number of rigs in our existing Lower 48 fleet.
When the programs are completed, we expect to have a larger fleet of high-specification land rigs deployed in the Lower
48. We believe the capabilities of these high-specification rigs will meet or exceed requirements from customers.
We have historically completed a number of acquisitions and will continue to evaluate opportunities to acquire
assets or businesses to enhance our operations. Several of our previous acquisitions were funded through issuances of
debt or our common shares, such as our acquisition of Tesco in December 2017. Future acquisitions may be funded
using existing cash or by issuing debt or additional shares of our stock. Such capital expenditures and acquisitions will
depend on our view of market conditions and other factors.
35
On August 25, 2015, our Board authorized a share repurchase program (the “program”) under which we may
repurchase, from time to time, up to $400 million of our common shares by various means, including in the open market
or in privately negotiated transactions. This authorization does not have an expiration date and does not obligate us to
repurchase any of our common shares. During 2017 and 2016, we repurchased 3.1 million and 0.3 million, respectively,
of our common shares for an aggregate purchase price of approximately $18.1 million and $1.7 million, respectively,
under this program. As of December 31, 2017, the remaining amount authorized under the program that may be used to
purchase shares was $280.6 million. The repurchased shares, which are held by our subsidiaries, are registered and
tradable subject to applicable securities law limitations and have the same voting and other rights as other outstanding
shares. As of December 31, 2017, our subsidiaries held 52.8 million of our common shares.
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.
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, 2017:
Total
< 1 Year 1-3 Years
3-5 Years Thereafter
Payments due by Period
(In thousands)
Contractual cash obligations:
Long-term debt: (1)
Principal ........................................... $ 4,203,301 $ 460,837 (2) $ 1,524,164 (3) $ 696,000 (4) $ 1,522,300 (5)
177,664
Interest .............................................
11,342
Operating leases (6) ............................
213,873
Purchase commitments (7) .................
4,252
Employment contracts (6) ..................
Transportation and processing
contracts (6)(8) ...................................
142,425
4,141
—
—
638,311
31,855
215,540
4,552
277,541
8,264
1,667
300
40,681
8,108
—
—
11,249
2,652
8,597
—
—
The table above excludes liabilities for uncertain tax positions totaling $35.0 million as of December 31, 2017 because
we are unable to make reasonably reliable estimates of the timing of cash settlements with the respective taxing
authorities. Further details on the uncertain tax positions can be found in Note 12—Income Taxes in Part II, Item 8.—
Financial Statements and Supplementary Data.
(1)
(2)
(3)
(4)
(5)
(6)
See Note 11—Debt in Part II, Item 8.—Financial Statements and Supplementary Data
Represents the aggregate principal amount of Nabors Delaware’s 6.15% senior notes due February 2018. We
used the proceeds from our January 2018 senior notes offering to repay these notes.
Represents the aggregate principal amount of Nabors Delaware’s 9.25% senior notes due January 2019, 5.0%
senior notes due September 2020, and amounts outstanding under our commercial paper program and revolving
credit facility due July 2020.
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, 5.10%
senior notes due September 2023 and 0.75% senior exchangeable notes due January 2024.
See Note 17—Commitments and Contingencies in Part II, Item 8.—Financial Statements and Supplementary
Data.
36
(7)
(8)
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.
We have contracts with pipeline companies to pay specified fees based on committed volumes for gas transport
and processing, as calculated on a monthly basis. See Notes 4—Assets Held for Sale and Discontinued
Operations and 17—Commitments and Contingencies in Part II, Item 8.—Financial Statements and
Supplementary Data.
During the three months ended December 31, 2017, our Board declared a cash dividend of $0.06 per common
share. This quarterly cash dividend was paid on January 3, 2018 to shareholders of record on December 13, 2017.
During the year ended December 31, 2017, we paid cash dividends totaling $68.5 million. See Item 5.—Market Price of
and Dividends on the Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity—
Dividends.
During 2016, we entered into an agreement with Saudi Aramco, to form a new joint venture to own, manage
and operate onshore drilling rigs in the Kingdom of Saudi Arabia. The joint venture, which is equally owned by Saudi
Aramco and Nabors, commenced operations in the fourth quarter of 2017. The joint venture leverages our established
business in Saudi Arabia to begin operations, with a focus on Saudi Arabia's existing and future onshore oil and gas
fields. During 2017, Nabors and Saudi Aramco each contributed $20 million in cash as the initial contribution upon
formation of the joint venture. In addition, during 2017 Nabors and Saudi Aramco each contributed approximately $204
million in a combination of drilling rigs, drilling rig equipment or other assets, including cash, to the joint venture in
proportion to the respective party’s ownership interest. We have also agreed to contribute an additional five drilling rigs
and related assets to the joint venture in January 2019. Additionally, the agreement requires each partner to backstop its
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.
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 2017 and 2016 cash flows below.
Operating Activities. Net cash provided by operating activities totaled $62.8 million during 2017, compared to
$531.9 million during 2016. Operating cash flows are our primary source of capital and liquidity. The decrease in our
operating cash flows was primarily due to a substantial turnaround in cash required for working capital as business
conditions improved during 2017. 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 $384.9 million in cash flows during 2017 and provided $92.1 million in cash
flows during 2016.
Investing Activities. Net cash used for investing activities totaled $502.0 million during 2017 compared to net
cash used of $382.1 million in 2016. 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 2017 and
2016, we used cash for capital expenditures totaling $574.5 million and $395.5 million, respectively.
We received $57.9 million in proceeds from sales of assets and insurance claims during 2017 compared to
$34.8 million in 2016.
Financing Activities. Net cash provided by financing activities totaled $512.2 million during 2017. During
2017, we received net proceeds of $519.9 million in connection with the issuance of our exchangeable senior unsecured
notes and $550.0 million in amounts borrowed under our commercial paper program and revolving credit facility. This
37
was partially offset by the repayment of the remaining balance of our unsecured term loan of $162.5 million and the
repurchase or redemption of $381.8 million, reflecting principal and premiums incurred in connection with these
repurchases of senior notes due February 2018. Additionally, we paid dividends of $68.5 million and received proceeds
of $8.3 million due to stock options exercised and $80.1 million in contributions from our joint venture partner in
SANAD.
Net cash used for financing activities totaled $138.2 million during 2016. This was primarily due to the
$348.0 million payoff of notes that matured in September 2016 coupled with the $145.6 million pay down of notes that
mature in 2018 and beyond. In 2016, we received proceeds of $600.0 million from our 5.50% senior notes which was
used to prepay the $162.5 million portion due under our term loan and repay amounts outstanding under our revolving
credit facility and commercial paper program. During 2016, the net amounts paid under our revolving credit facility and
commercial paper program was $8.0 million. Additionally, we paid cash dividends of $50.9 million.
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 involve agreements and obligations under
which we provide financial or performance assurance to third parties. Certain of these agreements 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 .................................................................... $ 81,131 184,848 367
39 $ 266,385
Maximum Amount
2017
2018
2019 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.
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.
38
For a summary of all of 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, workover and well-servicing industries are
very capital intensive. Property, plant and equipment represented 69% of our total assets as of December 31, 2017, and
depreciation and amortization constituted 27% of our total costs and other deductions in 2017.
Depreciation for our primary operating assets, drilling and workover 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, well-servicing rigs, oilfield hauling and mobile equipment, marine transportation
and supply vessels, aircraft 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; well-servicing
rigs—3 to 15 years; marine transportation and supply vessels—10 to 25 years; aircraft equipment—5 to 20 years; oilfield
hauling and mobile equipment and other machinery and equipment—3 to 10 years).
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.
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,
2017, 2016 and 2015, 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,
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
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, workover and well-servicing industry is
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 reduce the carrying amount of the long-lived asset to
its estimated 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. 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.
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 2017, 2016 and 2015, 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 in the same manner as a long-lived asset that is held and used.
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
39
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 of our reporting units within our reportable segments. Our business
consists of U.S., Canada, International, Drilling Solutions and Rig Technologies reportable segments. Our Rig
Technologies reportable segment includes our Canrig operations. The impairment test involves comparing the estimated
fair value of the reporting unit to 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.
The fair values calculated in these impairment tests are determined using discounted cash flow models
involving 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 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 that are 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 3%. We believe the fair value estimated for purposes of these tests
represent a Level 3 fair value measurement.
A significantly prolonged period of lower oil and natural gas prices or changes in laws and regulations could
continue to adversely affect the demand for and prices of our services, which could result in future goodwill impairment
charges for other reporting units due to the potential impact on our estimate of our future operating results.
Income Taxes. We operate in a number of countries throughout the world and our tax returns filed in those
jurisdictions are subject to review and examination by tax authorities within those jurisdictions. We are currently
contesting tax assessments throughout the world 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.
Audit claims of approximately $163.5 million attributable to income, customs and other business taxes 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.
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,
workover and well-servicing 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 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.
40
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 of 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 amounts. We maintain actuarially
determined accruals in our consolidated balance sheets to cover self-insurance retentions for workers’ compensation,
employers’ liability, general liability and automobile liability claims. These accruals are based on certain assumptions
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.
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.
During 2017, 2016 and 2015, no significant changes were made to the methodology used to estimate insurance
reserves. For purposes of earnings sensitivity analysis, if the December 31, 2017 reserves were adjusted by 10%, total
costs and other deductions would change by $15.1 million, or .48%.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
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 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, 2017 would result in a $6.4 million increase in the fair value of
our net monetary liabilities denominated in currencies other than U.S. dollars.
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 revolving credit facility
and the Nabors Delaware term loan which was repaid in part in December 2016 with the remainder repaid in January
41
2017), our fixed rate debt securities comprised of our 6.15%, 9.25%, 5.0%, 4.625%, 5.50% and 5.10% senior notes, our
0.75% senior exchangeable 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.
Fair Value of Financial Instruments. The fair value of our fixed rate long-term debt, revolving credit facility
and commercial paper 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:
As of December 31,
2017
2016
Effective
Interest
Rate
Carrying
Value
Fair
Value
(In thousands)
Effective
Interest
Rate
Carrying
Value
Fair
Value
(In thousands)
670,757
303,489
669,846
6.15% senior notes due February 2018 ........... 6.27 % $ 460,762 $ 462,674
9.25% senior notes due January 2019 ............. 9.77 %
321,028
5.00% senior notes due September
2020 ................................................................ 5.43 %
4.625% senior notes due September
2021 ................................................................ 4.76 %
5.50% senior notes due January 2023 ............. 5.85 %
5.10% senior notes due September
2023 ................................................................ 5.28 %
0.75% senior exchangeable notes due
January 2024 ................................................... 5.90 %
Term loan facility ............................................ — %
Revolving credit facility .................................. 2.73 %
Commercial paper ........................................... 1.87 %
Other ............................................................... — %
443,940
—
510,000
40,000
181
4,055,944 $ 4,024,277
429,982
—
510,000
40,000
181
695,108
600,000
665,003
584,850
346,576
325,844
6.40 % $ 827,539 $ 865,300
337,443
303,489
9.33 %
5.21 %
669,540
689,211
4.75 %
5.85 %
694,868
600,000
708,765
627,000
5.26 %
346,448
348,613
— %
1.76 %
1.86 %
1.16 %
— %
—
162,500
—
—
297
—
162,500
—
—
297
3,604,681 $ 3,739,129
Less: deferred financing costs .........................
27,997
$ 4,027,947
26,049
$ 3,578,632
42
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 cash, cash equivalents, short-term and long-term investments and
other receivables as of December 31, 2017 and 2016 are included in the table below:
December 31,
2017
2016
Weighted-
Average
Fair
Value
Interest
Rates
Life
(Years)
Fair
Value
Interest
Rates
(In thousands, except rates)
Weighted-
Average
Life
(Years)
Cash and cash equivalents .................... $ 336,997 0.49 - 1.50 %
Short-term investments:
— $ 264,093 0.24 - 0.69 %
—
Available-for-sale equity
securities ..........................................
Available-for-sale debt securities:
28,359
—
—
31,097
—
—
10 3.41 - 3.83 %
7.5
12 2.90 - 3.15 %
7.3
Mortgage-CMO debt securities .....
Total available-for-sale securities ........
Total short-term investments ................
Long-term investments ........................
Total cash, cash equivalents, short-
term and long-term investments ........... $ 373,201
28,369
28,369
7,835
N/A
31,109
31,109
4,023
$ 299,225
N/A
Our investments in debt securities listed in the above table 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, 2017 would decrease the fair value of our available-for-sale securities by $2.8 million.
43
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX
Report of Independent Registered Public Accounting Firm .......................................................................................
Consolidated Balance Sheets as of December 31, 2017 and 2016 ..............................................................................
Consolidated Statements of Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015 ......................
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2017, 2016 and
2015 ............................................................................................................................................................................
Consolidated Statements of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015...........................
Consolidated Statements of Changes in Equity for the Years Ended December 31, 2017, 2016 and 2015 ................
Notes to Consolidated Financial Statements ...............................................................................................................
45
47
48
49
50
51
52
44
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 as of
December 31, 2017 and 2016, and the related consolidated statements of income (loss), comprehensive income (loss),
changes in equity and cash flows for each of the three years in the period ended December 31, 2017, 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, 2017, based on criteria established in Internal Control - Integrated Framework (2013)
issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the
financial position of the Company as of December 31, 2017 and 2016 and the results of their operations and their cash
flows for each of the three years in the period ended December 31, 2017 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, 2017, based on criteria established in
Internal Control - Integrated Framework (2013) issued by the COSO.
Basis for Opinions
The Company's management is responsible for these consolidated financial statements, for maintaining effective internal
control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting,
included in Management's Report on Internal Control over Financial Reporting appearing under Item 9A. Our
responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal
control over financial reporting based on our audits. We are a public accounting firm registered with the Public
Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to
the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the
Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and
perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of
material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was
maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material
misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that
respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and
disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used
and significant estimates made by management, as well as evaluating the overall presentation of the consolidated
financial statements. Our audit of internal control over financial reporting included obtaining an understanding of
internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the
design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing
such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable
basis for our opinions.
45
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding
the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with
generally accepted accounting principles. A company’s internal control over financial reporting includes those policies
and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the
transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are
recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting
principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of
management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely
detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the
financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.
Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become
inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may
deteriorate.
/s/ PricewaterhouseCoopers LLP
Houston, Texas
March 1, 2018
We have served as the Company’s auditor since 1987.
46
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
December 31,
2017
2016
(In thousands, except per
share amounts)
Current assets:
Cash and cash equivalents ................................................................................................ $
Short-term investments ....................................................................................................
Accounts receivable, net ..................................................................................................
Inventory, net ...................................................................................................................
Assets held for sale ..........................................................................................................
Other current assets ..........................................................................................................
Total current assets ......................................................................................................
Property, plant and equipment, net ..................................................................................
Goodwill ..........................................................................................................................
Deferred income taxes .....................................................................................................
Other long-term assets .....................................................................................................
264,093
31,109
508,355
103,595
76,668
172,019
1,155,839
6,267,583
166,917
366,586
230,090
Total assets (1) ............................................................................................................. $ 8,401,984 $ 8,187,015
336,997 $
28,369
698,477
166,307
37,052
180,134
1,447,336
6,109,565
173,226
419,003
252,854
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt ..................................................................................................... $
Trade accounts payable ....................................................................................................
Accrued liabilities ............................................................................................................
Income taxes payable .......................................................................................................
Total current liabilities .................................................................................................
Long-term debt .................................................................................................................
Other long-term liabilities ................................................................................................
Deferred income taxes .....................................................................................................
Total liabilities (1) .......................................................................................................
363,416
533,044
22,835
919,476
4,027,766
301,633
10,338
5,259,213
181 $
297
264,578
543,248
13,811
821,934
3,578,335
522,456
9,495
4,932,220
Commitments and contingencies (Note 17)
Redeemable noncontrolling interest in subsidiary (Note 14) ...........................................
Equity:
Shareholders’ equity:
Common shares, par value $0.001 per share:
203,998
—
334
Authorized common shares 800,000; issued 367,510 and 333,598, respectively ......
2,521,332
Capital in excess of par value ......................................................................................
(12,119)
Accumulated other comprehensive income (loss) .......................................................
2,033,427
Retained earnings .........................................................................................................
(1,295,949)
Less: treasury shares, at cost, 52,800 and 49,673 common shares, respectively .........
3,247,025
Total shareholders’ equity ...........................................................................................
7,770
Noncontrolling interest ................................................................................................
Total equity ..................................................................................................................
3,254,795
Total liabilities and equity ........................................................................................... $ 8,401,984 $ 8,187,015
368
2,791,129
11,185
1,423,154
(1,314,020)
2,911,816
26,957
2,938,773
_____________________________
(1)
The consolidated balance sheet as of December 31, 2017 includes assets and liabilities of consolidated joint
ventures. See Note 14—Joint Ventures for additional information.
The accompanying notes are an integral part of these consolidated financial statements.
47
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
Year Ended December 31,
2016
(In thousands, except per share amounts)
2015
2017
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 ...................................................................................
Impairments and other charges ............................................................
Other, net .............................................................................................
Total costs and other deductions .................................................
Income (loss) from continuing operations before income taxes ...............
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 ..................................................
Amounts attributable to Nabors:
Net income (loss) from continuing operations .........................................
Net income (loss) from discontinued operations ......................................
Net income (loss) attributable to Nabors ..................................................
$ 2,564,285 $ 2,227,839 $ 3,864,437
(75,081)
2,308
3,791,664
7
1,194
2,565,486
(221,914)
1,183
2,007,108
1,718,069
251,184
51,069
842,943
222,889
44,536
14,880
3,145,570
(580,084)
1,344,298
227,639
33,582
871,631
185,360
498,499
44,174
3,205,183
(1,198,075)
2,371,436
324,328
41,253
970,459
181,928
368,967
(39,172)
4,219,199
(427,535)
(102,080)
19,110
(82,970)
(497,114)
(43,519)
(540,633)
(6,178)
89,865
(187,903)
(98,038)
(329,497)
(42,797)
(372,294)
(381)
$ (546,811) $ (1,029,742) $ (372,675)
14,780
(201,611)
(186,831)
(1,011,244)
(18,363)
(1,029,607)
(135)
$ (503,292) $ (1,011,379) $ (329,878)
(42,797)
$ (546,811) $ (1,029,742) $ (372,675)
(18,363)
(43,519)
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:
$
$
$
$
(1.75) $
(0.15)
(1.90) $
(1.75) $
(0.15)
(1.90) $
(3.58) $
(0.06)
(3.64) $
(3.58) $
(0.06)
(3.64) $
(1.14)
(0.15)
(1.29)
(1.14)
(0.15)
(1.29)
Basic ....................................................................................................
Diluted .................................................................................................
280,653
280,653
276,475
276,475
282,982
282,982
Dividends declared per common share ....................................................
$
0.24 $
0.24 $
0.24
The accompanying notes are an integral part of these consolidated financial statements.
48
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Net income (loss) attributable to Nabors ........................................................
Other comprehensive income (loss), before tax:
Translation adjustment attributable to Nabors ...........................................
Unrealized gains (losses) on marketable securities:
Unrealized gains (losses) on marketable securities .................................
Less: reclassification adjustment for (gains) losses included in net
income (loss) ...........................................................................................
Unrealized gains (losses) on marketable securities ...................................
Pension liability amortization and adjustment...........................................
Pension buyout ..........................................................................................
Unrealized gains (losses) and amortization on cash flow hedges ..............
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 adjustment attributable to noncontrolling interest ..................
Comprehensive income (loss) attributable to noncontrolling interest ............
Comprehensive income (loss) ........................................................................
2017
Year Ended December 31,
2016
(In thousands)
$ (546,811) $ (1,029,742) $ (372,675)
2015
28,372
17,743
(110,874)
(6,061)
11,054
(15,310)
970
(5,091)
(275)
—
613
23,619
3,495
14,549
1,061
3,059
613
37,025
—
(15,310)
1,104
—
613
(124,467)
315
23,304
(523,507)
6,178
282
6,460
$ (517,047) $
1,551
35,474
(994,268)
135
251
386
648
(125,115)
(497,790)
381
(1,461)
(1,080)
(993,882) $ (498,870)
The accompanying notes are an integral part of these consolidated financial statements.
49
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
2017
Year Ended December 31,
2016
(In thousands)
2015
Cash flows from operating activities:
Net income (loss) ................................................................................................................................... $ (540,633) $ (1,029,607) $ (372,294)
Adjustments to net income (loss):
Depreciation and amortization ........................................................................................................
Deferred income tax expense (benefit) ...........................................................................................
Impairments and other charges........................................................................................................
Deferred financing costs amortization ............................................................................................
Discount amortization on long-term debt .......................................................................................
Losses (gains) on debt buyback.......................................................................................................
Losses (gains) on long-lived assets, net ..........................................................................................
Losses (gains) on investments, net ..................................................................................................
Impairments on equity method holdings .........................................................................................
Losses (gains) on merger and acquisitions ......................................................................................
Share-based compensation ..............................................................................................................
Foreign currency transaction losses (gains), net .............................................................................
Pension buyout ................................................................................................................................
Equity in (earnings) losses of unconsolidated affiliates, net of dividends .....................................
Other ................................................................................................................................................
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 (used for) provided by 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 ........................................................
Investment in unconsolidated affiliates ...........................................................................................
Capital expenditures ........................................................................................................................
Proceeds from sales of assets and insurance claims .......................................................................
Proceeds from merger transaction ...................................................................................................
Other ................................................................................................................................................
Net cash (used for) provided by investing activities .............................................................................
Cash flows from financing activities:
845,439
9,096
42,188
7,088
20,495
16,005
19,064
972
—
—
31,896
1,604
—
(7)
(5,542)
(165,353)
(17,444)
16,518
28,772
79,204
14,811
(341,417)
62,756
(6,722)
13,069
9,040
—
(574,467)
57,933
—
(856)
(502,003)
874,296
(206,670)
236,745
4,381
2,074
(6,665)
85,064
—
216,242
—
32,000
5,669
3,059
221,914
1,333
250,400
40,647
37,904
98
(180,200)
(46,576)
(10,203)
531,905
(24)
739
(22,278)
—
(395,455)
34,831
—
64
(382,123)
973,318
(203,145)
129,341
5,290
1,969
—
63,338
—
180,591
(49,382)
47,313
9,881
—
84,275
627
529,151
23,852
34,390
(27,461)
(566,042)
(1,680)
(6,776)
856,556
(9)
961
(80,187)
(445)
(867,106)
68,206
650,050
1,081
(227,449)
Increase (decrease) in cash overdrafts .............................................................................................
Proceeds from issuance of long-term debt ......................................................................................
Debt issuance costs ..........................................................................................................................
Proceeds from revolving credit facilities ........................................................................................
Reduction in revolving credit facilities ...........................................................................................
Proceeds from (payments for) issuance of common shares ............................................................
Repurchase of common shares ........................................................................................................
Distributions to noncontrolling interest ..........................................................................................
Noncontrolling interest contribution ...............................................................................................
Reduction in long-term debt ............................................................................................................
Dividends to shareholders ...............................................................................................................
Proceeds from (payment for) commercial paper, net ......................................................................
Cash proceeds from equity component of exchangeable debt ........................................................
Proceeds from term loan ..................................................................................................................
Payments on term loan ....................................................................................................................
Redeemable noncontrolling interest contribution ...........................................................................
Proceeds from (payments for) short-term borrowings ....................................................................
Purchase of capped call hedge transactions ....................................................................................
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 ...........................................................................
Cash and cash equivalents, beginning of period ...................................................................................
Cash and cash equivalents, end of period ............................................................................................. $
(188)
411,200
(11,043)
725,000
(215,000)
8,300
(18,071)
(7,272)
20,000
(381,814)
(68,503)
40,000
159,952
—
(162,500)
61,123
(543)
(40,250)
(8,211)
512,180
(29)
72,904
264,093
336,997 $
3
600,000
(11,520)
611,500
(611,500)
967
(1,687)
—
—
(493,612)
(50,924)
(8,000)
—
—
(162,500)
—
(6,211)
—
(4,732)
(138,216)
(2,003)
9,563
254,530
264,093 $
645
—
(1,847)
—
(450,000)
1,296
(99,598)
—
3,972
(27,478)
(69,363)
(525,119)
—
625,000
(300,000)
—
318
—
(7,767)
(849,941)
(25,785)
(246,619)
501,149
254,530
The accompanying notes are an integral part of these consolidated financial statements.
50
NABORS INDUSTRIES LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
Common Shares
Capital
in Excess
Accumulated
Other
Non-
Par
of Par
Value Value
Comprehensive Retained Treasury controlling Total
Equity
Earnings
Interest
Income
Shares
141
—
—
2,189
Shares
— —
— —
—
—
—
1,296
47,863
(8,320)
—
— —
3
— —
— —
— —
— —
— —
— —
328 2,452,261
—
—
—
(In thousands)
As of December 31, 2014 ......................... 328,196
Net income (loss) ......................................
Dividends to shareholders ........................
Repurchase of treasury shares ..................
Other comprehensive income (loss),
net of tax ...................................................
Issuance of common shares for stock
options exercised, net of surrender of
unexercised stock options .........................
Share-based compensation .......................
Other .........................................................
As of December 31, 2015 ......................... 330,526 $ 331 $2,493,100 $
Net income (loss) ......................................
Dividends to shareholders ........................
Repurchase of treasury shares ..................
Other comprehensive income (loss),
net of tax ...................................................
Issuance of common shares for stock
options exercised, net of surrender of
unexercised stock options .........................
Share-based compensation .......................
Other .........................................................
As of December 31, 2016 ......................... 333,598 $ 334 $2,521,332 $
Net income (loss) ......................................
Dividends to shareholders ........................
Repurchase of treasury shares ..................
Other comprehensive income (loss),
net of tax ...................................................
Issuance of common shares for stock
options exercised, net of surrender of
unexercised stock options .........................
Equity component of exchangeable
debt ............................................................
Capped call transaction .............................
Adoption of ASU No. 2016-09 ................
Share-based compensation .......................
Issuance of common shares to Tesco
shareholders .............................................. 32,078
Noncontrolling interest contributions
(distributions), net .....................................
Other .........................................................
As of December 31, 2017 ......................... 367,510 $ 368 $2,791,129 $
—
— —
3
116,195
(40,250)
1,943
31,896
—
—
—
—
967
32,000
(4,735)
—
—
—
—
1
—
—
—
—
—
(8,212)
—
—
—
—
—
—
—
992
178,961
(10,736)
—
2,970
842
102
—
32
—
1
77,522 3,573,172 (1,194,664)
(372,675)
(69,363)
—
—
—
(99,598)
—
—
—
10,170 4,918,789
(372,294)
(69,363)
(99,598)
381
—
—
(125,115)
—
—
(1,461)
(126,576)
—
—
—
—
—
—
—
—
—
1,296
47,863
(6,249)
(47,593) $ 3,131,134 $(1,294,262) $ 11,158 $ 4,293,868
(1,029,607)
(67,965)
(1,687)
(1,029,742)
(67,965)
—
—
—
(1,687)
—
—
2,068
—
—
—
135
—
—
35,474
—
—
251
35,725
—
—
—
—
—
—
—
—
—
(12,119) $ 2,033,427 $(1,295,949) $
—
—
—
(546,811)
(68,612)
—
—
—
(18,071)
967
—
32,000
—
(3,774)
(8,506)
7,770 $ 3,254,795
6,178
(540,633)
—
(68,612)
—
(18,071)
23,304
—
—
282
23,586
—
—
—
—
—
—
—
—
—
5,150
—
—
—
—
—
—
—
—
—
—
—
—
—
—
(10,735)
116,195
(40,250)
7,093
31,896
178,993
—
—
13,018
(8,502)
11,185 $ 1,423,154 $(1,314,020) $ 26,957 $ 2,938,773
13,018
(291)
—
—
—
—
The accompanying notes are an integral part of these consolidated financial statements.
51
Nabors Industries Ltd. and Subsidiaries
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 Nature of Operations
We own and operate one of the world’s largest land-based drilling rig fleets and are a leading provider of
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, consisting of equipment
manufacturing, rig instrumentation and optimization software. We also specialize in wellbore placement solutions and
are a leading provider of directional drilling and MWD systems and services.
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. 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. 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 and accordingly consolidate
the joint venture. See Note 14—Joint Ventures.
Investments in operating entities where we have the ability to exert significant influence, but where we do not
control operating and financial policies, are accounted for using the equity method. Our share of the net income (loss) of
these entities is recorded as earnings (losses) from unconsolidated affiliates in our consolidated statements of income
(loss). The investments in these entities are included in investment in unconsolidated affiliates in our consolidated
balance sheets. During the third quarter of 2016, CJES filed for bankruptcy, at which time we ceased accounting for our
investment in CJES as an equity method investment. Prior to the bankruptcy filing, we historically recorded our share of
the net income (loss) of our equity method investment in CJES on a one-quarter lag, as we were not able to obtain the
financial information of CJES on a timely basis. See Note 9—Investments in Unconsolidated Affiliates.
Change in Presentation
Certain amounts within our consolidated statements of income (loss) have been reclassified to conform to the
current period presentation.
During the fourth quarter of 2017, we determined that we had incorrectly accounted for the deferred tax assets
related to certain share based compensation that had expired in prior years, resulting in an overstatement of our deferred
tax asset balance. The correction of this error resulted in a reduction to both deferred tax assets and capital in excess of
par of approximately $19.0 million. There was no impact to our consolidated statement of income (loss) for any periods
presented.
52
Change in Segments
During the fourth quarter of 2017, the Company revised its reporting segments to reflect a change in how
management reviews financial information and makes operating decisions. The Company has reclassified prior-period
amounts to conform to the current period’s presentation. See Note 21—Segment Information for additional information
on the change in reportable segments.
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.
Investments
Short-term investments
Short-term investments consist primarily of equity securities. Securities classified as available-for-sale are
stated at fair value. Unrealized holding gains and temporary losses for available-for-sale securities are excluded from
earnings and, until realized, are presented in the statement of comprehensive income (loss). Unrealized holding losses
are included in earnings during the period for which the loss is determined to be other-than-temporary.
In computing realized gains and losses on the sale of equity securities, the specific-identification method is
used. In accordance with this method, the cost of the equity securities sold is determined using the specific cost of the
security when originally purchased.
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 $28.9 million, included the following:
December 31,
2017
2016
(In thousands)
Raw materials .......................................................................................................................... $ 124,635 $
Work-in-progress ....................................................................................................................
Finished goods ........................................................................................................................
19,113
22,559
84,431
1,204
17,960
$ 166,307 $ 103,595
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 and workover 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, well-servicing rigs, oilfield hauling and mobile equipment, marine transportation
and supply vessels, 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; well-servicing rigs—3 to 15 years;
marine transportation and supply vessels—10 to 25 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).
53
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. In December
2017, we signed a Purchase and Sale Agreement (“PSA”) to sell certain of our jackups for a combination of cash and
equity. The PSA included several conditions to closing that must be reached before the deal proceeds to close. We are
uncertain at this time whether or when these conditions may be achieved, as well as what the ultimate consideration
value may be at closing. However, if the conditions are met and the deal proceeds to close, we could record a loss on the
sale in the range of up to $50 million - $70 million. 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.
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 review 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 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.
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 involving
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 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 3%.
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.
54
The change in the carrying amount of goodwill for our reporting units for the years ended December 31, 2017
and 2016 was as follows:
Acquisitions
and
Purchase
Price
Balance at
December 31,
2015
Disposals
Cumulative Balance at
Translation December 31,
and
Adjustments Impairments Adjustment
(In thousands)
2016
Drilling & Rig Technologies:
U.S. ................................................. $
International ...................................
Rig Technologies............................
Total ................................................... $
50,149
75,634
40,876
166,659
$
$
— $
—
—
— $
— $
—
—
— $
— $
—
258
258 $
50,149
75,634
41,134
166,917
Acquisitions
and
Balance at
December 31,
2016
Purchase
Disposals
Price
and
Adjustments Impairments Adjustment
(In thousands)
Cumulative Balance at
Translation December 31,
2017
Drilling & Rig Technologies:
U.S. ................................................. $
International ...................................
Rig Technologies ............................
Total ................................................... $
50,149
75,634
41,134
166,917
$
$
— $
—
5,690 (1)
5,690 $
— $
—
—
— $
— $
—
619
619 $
50,149
75,634
47,443
173,226
(1)
Represents the goodwill recorded in connection with our acquisition of RDS. See Note 5—Acquisitions for
additional discussion.
Goodwill for the consolidated company, totaling approximately $10.2 million, is expected to be deductible for
tax purposes.
Litigation and Insurance Reserves
We estimate our reserves related to litigation and insurance based on the facts and circumstances specific to the
litigation and insurance claims and our past experience with similar claims. We maintain actuarially determined accruals
in our consolidated balance sheets to cover self-insurance retentions. See Note 17—Commitments and Contingencies
regarding self-insurance accruals. We estimate the range of our liability related to pending litigation when we believe the
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. 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. At December 31, 2017 and
2016, our deferred revenues classified as other long-term liabilities were $135.0 million and $321.0 million,
respectively. At December 31, 2017 and 2016, our deferred revenues classified as accrued liabilities were $218.4 million
and $255.6 million, respectively.
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
55
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. At December 31, 2017 and 2016, our deferred
expenses classified as other current assets were $61.2 million and $63.4 million, respectively. At December 31, 2017 and
2016, our deferred expenses classified as other long-term assets were $32.6 million and $69.5 million, respectively.
We recognize revenue for top drives and other capital equipment we manufacture when the earnings process is
complete. This generally occurs when products have been shipped, title and risk of loss have been transferred,
collectability is probable, and pricing is fixed or determinable.
We recognize, as operating revenue, proceeds from business interruption insurance claims in the period that the
applicable proof of loss documentation is received. 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
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. As a result of our acquisition of 2TD during 2014, we recorded intangible assets related to in process research
and development of $47.7 million. As these products are developed, we will transfer the balances to completed
technology and begin amortizing the intangible assets over the estimated useful life. No transfers occurred during the
years ended December 31, 2017, 2016 or 2015. We have made progress in the development of our rotary steerable
drilling technology tools, including successful tests in 2015, October of 2016 and most recently November of 2017. The
tools are currently being modified to another phase of verification testing before shipping the tools to the U.S. for further
field tests.
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.
On December 22, 2017, the United States enacted the Tax Reform Act. Among a number of significant changes
to the current U.S. federal income tax rules, the Tax Reform Act reduces the marginal U.S. corporate income tax rate
from 35 percent down to 21 percent, limits the current deduction for net interest expense, limits the use of net operating
losses to offset future taxable income, and imposes a type of minimum tax designed to reduce the benefits derived from
intercompany transactions and payments that result in base erosion. As a result of the Tax Reform Act, we were required
to revalue deferred tax assets and liabilities from 35 percent to 21 percent. This revaluation has resulted in recognition of
an expense of approximately $138.6 million, which is included as a component of income tax expense in continuing
operations. We believe the other provisions of the Tax Reform Act should not have a material impact on our
consolidated financial statements. On December 22, 2017, Staff Accounting Bulletin No. 118 ("SAB 118") was issued to
address the application of U.S. GAAP in situations when a registrant does not have the necessary information available,
prepared, or analyzed (including computations) in reasonable detail to complete the accounting for certain income tax
effects of the Tax Reform Act. In accordance with SAB 118, we have calculated our best estimate of the impact of the
Tax Reform Act in our year end income tax provision in accordance with our understanding of the Tax Reform Act and
guidance available as of the date of this filing. However, we are continuing to assess the impact that it will have on us
and our preliminary assessment is subject to the finalization of management’s analysis related to certain matters.
We recognize increases to our tax reserves for uncertain tax positions along with interest and penalties as an
increase to other long-term liabilities.
56
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.
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
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;
impairment of short-term and equity method investments;
income taxes;
litigation and self-insurance reserves; and
fair value of assets acquired and liabilities assumed.
Recent Accounting Pronouncements Adopted
In March 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-07, Investments—
Equity Method and Joint Ventures, to simplify the transition to the equity method of accounting. This standard
eliminates the requirement to retroactively adopt the equity method of accounting as a result of an increase in the level of
ownership interest or degree of influence. Instead, the equity method investor should add the cost of acquiring the
additional interest in the investee to the current basis of the investor’s previously held interest and adopt the equity
method of accounting as of the date the investment qualifies for the equity method of accounting. This guidance is
effective for public companies for fiscal years beginning after December 15, 2016. The adoption of this guidance did not
have an impact on our consolidated financial statements.
In March 2016, the FASB issued ASU No. 2016-09, Compensation—Stock Compensation, to simplify the
accounting for share-based payment transactions, including the income tax consequences, classification of awards as
either equity or liabilities and classification on the statement of cash flows. This guidance is effective for public
companies for fiscal years beginning after December 15, 2016. We adopted this guidance on a prospective basis
effective January 1, 2017. The impact of adoption was a decrease in deferred tax liabilities of $7.1 million and an
increase in retained earnings of $7.1 million related to excess tax benefits on prior awards. Additionally, we elected to
account for forfeitures as they occur. The impact of this election resulted in an increase in capital in excess of par and a
corresponding decrease in retained earnings of $1.9 million.
In January 2017, the FASB issued ASU No. 2017-04, Intangibles—Goodwill and Other, which simplifies the
subsequent measurement of goodwill by eliminating Step 2 of the goodwill impairment test. In computing the implied
57
fair value of goodwill under Step 2, an entity had to perform procedures to determine the fair value at the impairment
testing date of its assets and liabilities (including unrecognized assets and liabilities) following the procedure that would
be required in determining the fair value of assets acquired and liabilities assumed in a business combination. Under this
new standard, an entity should perform its goodwill impairment test by comparing the fair value of a reporting unit with
its carrying amount and then recognize an impairment charge, as necessary, for the amount by which the carrying
amount exceeds the reporting unit’s fair value, not to exceed the total amount of goodwill allocated to that reporting unit.
This guidance is effective for fiscal years beginning after December 15, 2019. We have elected to early adopt this
guidance on a prospective basis for our annual goodwill impairment test performed subsequent to January 1, 2017. The
adoption of this standard did not have an impact on our consolidated financial statements.
Recent Accounting Pronouncements Not Yet Adopted
In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, relating to the
revenue recognition from contracts with customers that creates a common revenue standard for U.S. GAAP and IFRS.
The core principle will require recognition of revenue to represent the transfer of promised goods or services to
customers in an amount that reflects the consideration, including costs incurred, to which the entity expects to be entitled
in exchange for those goods or services. The standard will also require significantly expanded disclosures containing
qualitative and quantitative information regarding the nature, amount, timing and uncertainty of revenue and cash flows
arising from contracts with customers. In July 2015, the FASB approved a one year deferral of this standard, with a new
effective date for fiscal years beginning after December 15, 2017. Throughout 2017 we, along with our third party
consultants, identified and reviewed our revenue streams, identified a subset of contracts to represent these revenue
streams and performed a detailed analysis of such contracts. We adopted this guidance under the modified retrospective
approach as of January 1, 2018. The adoption of this standard did not have a material impact on our consolidated
financial statements.
In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments—Overall, relating to the
recognition and measurement of financial assets and liabilities. This standard enhances the reporting model for financial
instruments, which includes amendments to address aspects of recognition, measurement, presentation and disclosure.
This new standard became effective for us on January 1, 2018. Upon adoption, we recorded an adjustment to retained
earnings of $9.1 million to eliminate the net unrealized gain balance in accumulated other comprehensive income (loss)
related to the equity instruments. If we do have a material amount of investments in equity securities in the future, we
expect that the impact to our consolidated statements of income (loss) and other comprehensive income (loss) from this
update could be material. Furthermore, depending on trends in the stock market, we may see increased volatility in our
consolidated statements of income (loss) and other comprehensive income (loss).
In February 2016, the FASB issued ASU No. 2016-02, Leases, relating to leases to increase transparency and
comparability among companies. This standard requires that all leases with an initial term greater than one year be
recorded on the balance sheet as an asset and a lease liability. Additionally, this standard will require disclosures
designed to give financial statement users information on the amount, timing, and uncertainty of cash flows arising from
leases. This guidance is effective for public companies for fiscal years beginning after December 15, 2018. Early
application is permitted. This standard requires an entity to separate lease components from nonlease components within
a contract. While the lease components would be accounted for under ASU No. 2016-02, nonlease components would be
accounted for under ASU No. 2014-09. We have determined that under the new standard, our drilling contracts contain a
lease component and therefore we will be required to separately recognize revenues associated with the lease and
services components. Therefore, we are evaluating ASU No. 2016-02 concurrently with the provisions of ASU No.
2014-09 and the impact this will have on our consolidated financial statements. We expect to adopt this guidance
beginning January 1, 2019.
In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows, to reduce the diversity in
practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows. This
guidance is effective for public companies for fiscal years beginning after December 15, 2017. We do not expect the
adoption of this guidance to have an impact on our consolidated financial statements.
In October 2016, the FASB issued ASU No. 2016-16, Income Taxes, which simplifies the accounting for the
income tax consequences of intra-entity transfers of assets other than inventory. We will adopt this standard during the
first quarter of 2018 using the modified retrospective method, through a cumulative-effect adjustment directly to retained
earnings. We are still evaluating the impact this will have on our consolidated financial statements.
58
In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows: Restricted Cash, to provide
guidance on the classification of restricted cash in the statement of cash flows. This guidance is effective for public
companies for fiscal years beginning after December 15, 2017. The amendments in the ASU should be adopted on a
retrospective basis. We do not expect the adoption of this guidance to have an impact on our consolidated financial
statements.
In January 2017, the FASB issued ASU 2017-01, Clarifying the Definition of a Business, which clarifies the
definition of a business and provides further guidance for evaluating whether a transaction will be accounted for as an
acquisition of an asset or a business. The standard provides a test to determine whether a set of assets and activities
acquired is a business. When substantially all of the fair value of the gross assets acquired is concentrated in a single
identifiable asset or group of similar identifiable assets, the set is not a business. Under the updated guidance, an
acquisition of a single property will likely be treated as an asset acquisition as opposed to a business combination and
associated transaction costs will be capitalized rather than expensed as incurred. Additionally, assets acquired, liabilities
assumed, and any noncontrolling interest will be measured at their relative fair values. We do not expect the adoption of
this standard to have an impact on our consolidated financial statements.
In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation, to reduce diversity in
practice and provide clarity regarding existing guidance in ASC 718, “Stock Compensation”. The standard provides
guidance on the types of changes to the terms or conditions of share-based payment awards to which an entity would be
required to apply modification accounting under ASC 718. Specifically, an entity would not apply modification
accounting if the fair value, vesting conditions and classification of the awards are the same immediately before and after
the modification. This guidance is effective for public companies for fiscal years beginning after December 15, 2017.
We do not expect the adoption of this standard to have an impact on our consolidated financial statements.
Note 3 Impairments and Other Charges
The components of impairments and other charges are provided below:
2017
Year Ended December 31,
2016
(In thousands)
2015
Tangible Assets & Equipment:
Provision for retirement of assets .......................................................................... $
Impairment of long-lived assets .............................................................................
Subtotal ...............................................................................................................
Other Charges:
— $ 69,072 $ 65,633
74,464
140,097
216,355
285,427
6,895
6,895
Other-than-temporary impairment .........................................................................
Provision for International operations ...................................................................
Transaction related costs ........................................................................................
Loss (gain) on early extinguishment of debt ..........................................................
180,591
48,279
—
—
Total .................................................................................................................... $ 44,536 $ 498,499 $ 368,967
219,737
—
—
(6,665)
—
—
21,628
16,013
For the year ended December 31, 2017
Tangible Assets and Equipment
In 2017, we recorded impairments totaling $6.9 million primarily comprised of underutilized rigs in our
International drilling reportable segment. These impairments were deemed necessary due to the lack of future
contractual opportunities because the rigs were smaller and lower horsepower than our newer rigs and also rigs
competing in an overcrowded offshore market.
Transaction related costs
During 2017, we incurred $21.6 million in transaction related costs, including professional fees, severances,
facility closure costs and other cost rationalization items, primarily in connection with the acquisition of Tesco.
59
Loss (gain) on early extinguishment of debt
During 2017, we repurchased $367.9 million aggregate principal amount of our senior notes. We paid the
holders an aggregate of approximately $381.7 million in cash, reflecting principal and accrued and unpaid interest and
prepayment premium and recognized a loss of $16.0 million as part of the debt extinguishment. See Note 11—Debt for
additional discussion.
For the year ended December 31, 2016
Throughout the first half of 2016, we experienced decreased demand for our services as well as increased
pricing pressure. Although there was a slight uptick in activity over the latter half of 2016, management evaluated our
existing rig fleet and identified asset classes that may not fully participate in the next drilling cycle given the current
requirements of many drilling programs and other factors. This resulted in both the provision for retirement of assets and
tangible asset impairments. The majority of the remaining charges are attributable to our previous investment in CJES,
which experienced severe financial and operational difficulties in their business, and ultimately commenced voluntarily
cases under chapter 11 of the U.S. Bankruptcy code in July 2016. These charges are outlined below.
Tangible Assets and Equipment
The following table summarizes the 2016 retirement and impairment charges for tangible assets and equipment
by reportable operating segment:
Drilling & Rig Technologies:
Provision for Tangible Asset
Impairments
Retirements
Total
U.S. ................................................................................................................... $
Canada ..............................................................................................................
International ......................................................................................................
Drilling Solutions .............................................................................................
Rig Technologies ..............................................................................................
Other .................................................................................................................
Total ............................................................................................................... $
25,365 $
19,573
23,275
859
—
—
69,072 $
163,182 $ 188,547
20,698
1,125
35,996
12,721
859
—
15,343
15,343
23,984
23,984
216,355 $ 285,427
During 2016, we retired certain classes of rigs and rig components in our U.S., Canada and International
drilling reportable segments and reduced their carrying value to their estimated salvage value. As a result of the
sustained decline in oil and gas prices and the extended period of reduced demand for some of our legacy asset classes,
we retired 24 of our remaining SCR rigs within the U.S. drilling reportable segment. We utilized some of the parts on
these retired rigs to enhance and upgrade other existing rigs in our fleet. Additionally, we retired 7 older rigs in our
Canada Drilling reportable segment. Within our International drilling reportable segment, we also retired various older,
smaller and in some cases functionally obsolete rigs and yard assets.
In 2016, we also recorded impairments totaling $216.4 million primarily comprised of $163.2 million for
underutilized rigs in our U.S. Drilling reportable segment as well as $12.7 million in our International drilling reportable
segment. These impairments were deemed necessary due to the lack of future contractual opportunities because the rigs
were smaller and lower horsepower than our newer rigs, which limits the rigs functional capabilities of drilling many of
the more complex wells in the current environment. Included in the other amount was an impairment of $22.4 million
that we recognized related to our retained interest in the oil and gas properties located on the North Slope of Alaska to
reduce the carrying value to fair value, as a result of the sustained decline in oil prices. The balance of the impairment
charge primarily relates to obsolete inventory and various rig-related equipment within our Rig Technologies reportable
segment.
Other-than-temporary impairment
During 2016, we recognized impairment charges associated with our CJES holdings in the amount of
$216.2 million resulting from declines in the fair value of our investment including other than temporary impairment
charges of $192.4 million. Additionally, we recorded a charge related to a reserve of certain other amounts associated
with our CJES holdings, including affiliate receivables of $23.8 million.
60
The balance of the charge was related to an impairment of an equity security during the third quarter of 2016.
As the trading price of the security remained below our cost basis for an extended period, we determined the investment
was other than temporarily impaired and it was appropriate to write down the investment’s carrying value to its current
estimated fair value. See Note 9—Investments in Unconsolidated Affiliates.
Loss (gain) on early extinguishment of debt
During 2016, we repurchased $152.7 million aggregate principal amount of our senior notes. We paid the
holders an aggregate of approximately $157.5 million in cash, reflecting principal and accrued and unpaid interest and
prepayment premium and recognized a gain as part of the debt extinguishment. See Note 11—Debt for additional
discussion.
For the year ended December 31, 2015
Throughout 2015, our industry continued to experience depressed oil prices, which led to considerable
reductions in capital spending by some of our customers and diminished demand for our drilling services. The impact of
the industry downturn on our business activity and future outlook resulted in impairments and retirement provisions of
approximately $140.1 million, an other-than-temporary impairment on our investment in CJES of $180.6 million, and
the provision for International operations of $48.3 million during 2015 as discussed below.
Tangible Assets and Equipment
The following table summarizes the 2015 retirement and impairment charges for tangible assets and equipment
by reportable operating segment:
Provision for Tangible Asset
Retirements Impairments
Total
Drilling & Rig Technologies:
U.S. ...................................................................................................................... $ 47,247 $
Canada .................................................................................................................
International .........................................................................................................
Rig Technologies .................................................................................................
Other ....................................................................................................................
Total ..................................................................................................................... $ 65,633 $
7,547
10,839
—
—
— $ 47,247
7,547
—
63,318
52,479
3,879
3,879
18,106
18,106
74,464 $ 140,097
During 2015, we retired some rigs and rig components in our U.S., Canada and International drilling reportable
segments and reduced their carrying value to their estimated salvage value. Due to market conditions and resulting
competitive drilling market, we experienced a decline in utilization of our remaining legacy rigs. Accordingly, we retired
roughly half of our fleet of SCR rigs within the U.S. Drilling reportable segment, continuing to market the remaining 47
of our most competitive assets within this group. Additionally, we retired various yard assets within our International
reportable segment as well as rig-related equipment in our Canada reportable segment.
In 2015, we also recorded impairments totaling $74.5 million primarily comprised of $52.5 million for an
inactive jackup rig in our International reportable segment. We recognized an impairment of $15.1 million to our
retained interest in the oil and gas properties located on the North Slope of Alaska to reduce the carrying value to fair
value, as a result of the sustained decline in oil prices. The balance of the impairment charge primarily relates to obsolete
inventory within our Rig Technologies reportable segment.
Other-than-temporary impairment
During the third quarter of 2015, we determined the carrying value of our investment in CJES was other than
temporarily impaired which resulted in an impairment charge of $180.6 million. The charge directly resulted from
reduced activity levels driven by lower customer demand stemming from lower oil prices coupled with the further
pricing concessions required by the highly competitive environment. See Note 9—Investments in Unconsolidated
Affiliates.
61
Provision for International operations
During 2015, we recognized $25.4 million related to assets and receivables impacted by the degradation of the
overall country economy and financial situation in Venezuela, which has been adversely affected by the downturn in oil
prices, primarily comprised of a loss of $10.0 million related to the remeasurement of our net monetary assets
denominated in local currency from the official exchange rate of 6.3 Bolivares per US dollar to the SIMADI exchange
rate which was 199 Bolivares per US dollar as of September 30, 2015 and $15.4 million related to the write-off of a
receivable balance. The balance of this provision represents an obligation associated with the decision to exit a non-core
business line in another country within the region of $22.9 million.
Note 4 Assets Held for Sale and Discontinued Operations
Assets Held for Sale
Assets held for sale as of December 31, 2017 and 2016 was $37.1 million and $76.7 million, respectively.
These assets consisted primarily of our oil and gas holdings which are mainly in the Horn River basin in western Canada
of $25.9 million and $65.0 million, respectively, as of the periods noted above and the operating results have been
reflected in discontinued operations. The remainder represents assets that meet the criteria to be classified as assets held
for sale, but do not represent a disposal of a component of an entity or a group of components of an entity representing a
strategic shift that has or will have a major effect on the entity's operations and financial results.
The carrying value of our assets held for sale represents the lower of carrying value or fair value less costs to
sell. We continue to market these properties at prices that are reasonable compared to current fair value.
We have contracts with pipeline companies to pay specified fees based on committed volumes for gas transport
and processing associated with these properties held for sale. At December 31, 2017, our undiscounted contractual
commitments for these contracts approximated $11.2 million, and we had total liabilities of $8.5 million, $6.1 million of
which were classified as current and are included in accrued liabilities. At December 31, 2016, our undiscounted
contractual commitments for these contracts approximated $17.2 million, and we had total liabilities of $12.5 million,
$5.5 million of which were classified as current and are included in accrued liabilities.
The amounts at each balance sheet date represented our best estimate of the fair value of the excess capacity of
the pipeline commitments calculated using a discounted cash flow model, when considering our disposal plan, current
production levels, natural gas prices and expected utilization of the pipeline over the remaining contractual term.
Decreases in actual production or natural gas prices could result in future charges related to excess pipeline
commitments.
62
Discontinued Operations
The operating results from the assets discussed above for all periods presented are presented and accounted for
as discontinued operations in the accompanying consolidated statements of income (loss) and the respective
accompanying notes to the consolidated financial statements. Our condensed statements of income (loss) from
discontinued operations for each reportable segment were as follows:
Year Ended December 31,
2017
2015
2016
(In thousands, except percentages)
Operating revenues (1) ......................................................................................... $ 6,169 $ 2,859 $
Income (loss) from Oil & Gas discontinued operations:
3,212
Income (loss) from discontinued operations ...................................................... $ (2,506) $ (3,978) $ (5,003)
Less: Impairment charges or other (gains) and losses on sale of wholly
owned assets (2) ................................................................................................. $ 51,028 $ 19,445 $ 49,890
Less: Income tax expense (benefit) .................................................................... $ (10,015) $ (5,060) $ (14,455)
Income (loss) from Oil and Gas discontinued operations, net of tax ................ $ (43,519) $ (18,363) $ (40,438)
Income (loss) from Rig Technologies discontinued operations:
Income (loss) from discontinued operations ...................................................... $
Less: Impairment charges or other (gains) and losses on sale of wholly
3,146 (3)
— $
owned assets ....................................................................................................... $
(787)
— $
Less: Income tax expense (benefit) .................................................................... $
— $ (2,359)
Income (loss) from Rig Technologies discontinued operations, net of tax ....... $
Income (loss) from discontinued operations, net of tax ..................................... $ (43,519) $ (18,363) $ (42,797)
— $
— $
— $
— $
— $
—
Oil and Gas
(1)
(2)
Reflects operating revenues of our historical oil and gas reportable segment.
Includes impairment charges of $35.3 million, $15.4 million and $51.0 million in 2017, 2016 and 2015,
respectively, due to the deterioration of economic conditions in the natural gas market in western Canada,
partially offset by a gain related to our restructure of our future pipeline obligations. Additionally, this line item
includes a charge of $16.5 million related to the settlement of litigation during 2017 associated with our
previously owned Ramshorn International properties.
Rig Technologies
(3)
Reflects an impairment charge for a note receivable of $3.1 million remaining from the sale of one of our
former Canada subsidiaries that provided logistics services.
Additional discussion of our policy pertaining to the calculations of our annual impairment tests, including any
impairment to goodwill, is set forth in Note 2—Summary of Significant Accounting Policies. A further protraction of
lower commodity prices or an inability to sell these assets in a timely manner could result in recognition of future
impairment charges.
63
Note 5 Acquisitions
2017 Acquisitions
Robotic Drilling Systems
On September 5, 2017 we paid approximately $50.7 million in cash, subject to customary closing adjustments,
to acquire Robotic Drilling Systems AS (“RDS”), a provider of automated tubular and tool handling equipment for the
onshore and offshore drilling markets based in Stavanger, Norway. This transaction will allow us to integrate RDS’s
highly capable team and product offering with the technology portfolio of Canrig and strengthens the development of
Canrig’s drilling automation solutions. As part of our purchase price allocation, we have recorded intangible assets of
$53.3 million ($20.8 million of developed technology and $32.5 million of in process research and development),
goodwill of approximately $5.7 million and other liabilities of $7.3 million (net of other working capital items). The
intangible assets related to developed technology are being amortized using the straight-line method over the estimated
useful life of 10 years. We have consolidated the operating results of RDS since the acquisition date and reported those
results in our Rig Technologies segment. The pro forma effect on revenue and net income (loss) have been determined to
be immaterial to our financial statements. Further, tests of significance for this acquisition do not result in a significant
acquisition and as such we have not included disclosures of the allocation of the purchase price or any pro forma
information.
Tesco Corporation
On December 15, 2017, Nabors completed the acquisition of Tesco Corporation (“Tesco”). Tesco’s tubular
services business will benefit our Drilling Solutions segment as we expand into numerous key regions globally.
Additionally, the acquisition combined Tesco’s rig equipment manufacturing, rental and aftermarket service business
into our Rig Technologies segment, creating a leading rig equipment and drilling automation provider. Under the terms
of the acquisition, Nabors acquired all common shares of Tesco in an all-stock transaction, with Tesco shareholders
receiving 0.68 common shares of Nabors for each Tesco share owned, or approximately 32.1 million Nabors common
shares. The fair value of common shares issued was $179.0 million based on the closing price of Nabors common shares
as of the last trading day prior to the issuance as stipulated in the acquisition agreement.
The following table provides the preliminary allocation of the purchase price as of the acquisition date.
(In thousands)
Assets:
Fair Value
at Acquisition
Cash and cash equivalents .....................................................................................................................
Accounts receivable ...............................................................................................................................
Inventory ................................................................................................................................................
Other current assets ...............................................................................................................................
Property, plant and equipment ...............................................................................................................
Other long-term assets ...........................................................................................................................
Total assets ............................................................................................................................................
$
Liabilities:
Accounts payable ...................................................................................................................................
Accrued liabilities ..................................................................................................................................
Other long-term liabilities ......................................................................................................................
Total liabilities .......................................................................................................................................
Net assets acquired ...................................................................................................................................
$
$
59,804
41,565
44,525
13,889
61,650
3,647
225,080
14,111
29,542
2,436
46,089
178,991
We expect to finalize the allocation of the purchase price during the first half of 2018 when we are able to
perform reviews of all book versus tax variances by jurisdiction.
We have consolidated the operating results of Tesco since the acquisition date and reported those results in our
Drilling Solutions and Rig Technologies segments. We included an additional $7.7 million in operating revenues and
$0.1 million in earnings from the acquisition date through December 31, 2017 in our consolidated statements of income
(loss) as a result of this acquisition.
64
The following unaudited supplemental pro forma results present consolidated information as if the acquisition
had been completed as of January 1, 2016. The unaudited supplemental pro forma results should not be considered
indicative of the results that would have occurred if the acquisition had been consummated as of January 1, 2016; nor are
they indicative of future results.
Year Ended
December 31,
(In thousands, except per share amounts)
Operating revenues .............................................................................................................. $ 2,717,933 $ 2,362,576
(1,129,172)
Income (loss) from continuing operations, net of tax ..........................................................
(3.59)
Income (loss) from continuing operations per share - basic ................................................. $
(3.59)
Income (loss) from continuing operations per share - diluted .............................................. $
(1.75) $
(1.75) $
(554,235)
2016
2017
2015 Acquisitions
On May 24, 2015, we paid $106.0 million in cash to acquire the remaining 49% equity interest in Nabors
Arabia, our joint venture in Saudi Arabia, making it a wholly owned subsidiary. Previously, we held a 51% equity
interest with a carrying value of $44.7 million and we had accounted for the joint venture as an equity method
investment. The acquisition of the remaining interest allows us to strategically align our future growth in this market by
providing additional flexibility to invest capital and pursue future investment opportunities. As a result, we consolidated
the assets and liabilities of Nabors Arabia on May 24, 2015 based on their respective fair values. We have also
consolidated the operating results of Nabors Arabia since the acquisition date and reported those results in our
International drilling segment. The excess of the estimated fair value of the assets and liabilities over the net carrying
value of our previously held equity interest resulted in a gain of $2.3 million and was reflected in other, net in the
consolidated statement of income (loss) for the year ended December 31, 2015.
The following table provides the allocation of the purchase price as of the acquisition date. The purchase price
was allocated to the net tangible and intangible assets acquired and liabilities assumed based on fair value. The excess of
the purchase price over such fair values was recorded as goodwill.
(In thousands)
Assets:
Fair Value
at Acquisition
Cash ....................................................................................................................................................... $
Accounts receivable ...............................................................................................................................
Other current assets ...............................................................................................................................
Property, plant and equipment, net ........................................................................................................
Intangible assets .....................................................................................................................................
Goodwill ................................................................................................................................................
Other long-term assets ...........................................................................................................................
Total assets ............................................................................................................................................
Liabilities:
Accounts payable ................................................................................................................................... $
Accrued liabilities ..................................................................................................................................
Intangible liability ..................................................................................................................................
Deferred tax liability ..............................................................................................................................
Other long-term liabilities ......................................................................................................................
Total liabilities .......................................................................................................................................
Net assets acquired ................................................................................................................................... $
48,058
153,819
58,021
89,643
28,784
75,634
7,709
461,668
206,599
74,393
13,472
4,823
9,400
308,687
152,981
The goodwill recognized as a result of the acquisition of $75.6 million is primarily attributable to the workforce
of the acquired business, strategic market access, ability to provide other services and products, a strategic customer with
a long history of business and the expected synergies from combining the operations. This goodwill is not expected to be
deductible for tax purposes. The identifiable intangible asset of $28.8 million and liability of $13.5 million consist of the
fair value of the acquired favorable and unfavorable contracts, respectively, with a weighted-average amortization period
of 2 years.
65
We included an additional $248.9 million in operating revenues and $6.0 million in earnings from the
acquisition date through December 31, 2015 in our consolidated statements of income (loss) as a result of this
acquisition.
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.
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
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.
The following table sets forth, by level within the fair value hierarchy, our financial assets and liabilities that are
accounted for at fair value on a recurring basis as of December 31, 2017. During 2017, 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 measurement.
Fair Value as of December 31, 2017
Level 3
Level 2
Level 1
Assets:
Short-term investments:
Available-for-sale equity securities .................................................................... $ 22,909 $
Mortgage-CMO debt securities ..........................................................................
—
Total short-term investments ................................................................................... $ 22,909 $
5,450 $
10
5,460 $
—
—
—
(In thousands)
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,
assets acquired and liabilities assumed in a business combination and our pipeline contractual commitment.
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, revolving credit facility and commercial paper is estimated based on quoted market prices or prices
66
quoted from third-party financial institutions, thus a level 2 measurement. The carrying and fair values of these liabilities
were as follows:
Effective
Interest
Rate
2017
Carrying
Value
As of December 31,
Fair
Value
Effective
Interest
Rate
2016
Carrying
Value
Fair
Value
(In thousands)
(In thousands)
6.27 % $ 460,762 $
9.77 %
303,489
462,674
321,028
6.40 % $ 827,539 $ 865,300
337,443
9.33 %
303,489
5.43 %
6.15% senior notes due February 2018 ...
9.25% senior notes due January 2019 .....
5.00% senior notes due September
2020 ........................................................
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
5.90 %
January 2024 ...........................................
Term loan facility .................................... — %
2.73 %
Revolving credit facility ..........................
Commercial paper ...................................
1.87 %
Other ....................................................... — %
4.76 %
5.85 %
5.28 %
669,846
670,757
5.21 %
669,540
689,211
695,108
600,000
665,003
584,850
4.75 %
5.85 %
694,868
600,000
708,765
627,000
346,576
325,844
5.26 %
346,448
348,613
429,982
—
510,000
40,000
181
443,940
—
510,000
40,000
181
4,055,944 $ 4,024,277
— %
1.76 %
1.86 %
1.16 %
— %
—
162,500
—
—
297
—
162,500
—
—
297
3,604,681 $ 3,739,129
Less: deferred financing costs .................
27,997
$ 4,027,947
26,049
$ 3,578,632
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.
As of December 31, 2017, our short-term investments were carried at fair market value and included
$28.4 million in securities classified as available-for-sale. As of December 31, 2016, our short-term investments were
carried at fair market value and included $31.1 million in securities classified as available-for-sale.
Note 7 Share-Based Compensation
Total share-based compensation expense, which includes stock options and restricted shares, totaled
$31.9 million, $32.0 million and $47.3 million for 2017, 2016 and 2015, respectively. Compensation expense related to
awards of restricted shares totaled $31.4 million, $31.3 million and $37.0 million for 2017, 2016 and 2015, respectively,
which is included in direct costs and general and administrative expenses in our consolidated statements of income
(loss). Additionally, we recognized $8.7 million of expense related to awards of restricted shares granted in connection
with the closing of the CJES merger during 2015 which is included in other, net in our consolidated statement of income
(loss) for the year ended December 31, 2015. Share-based compensation expense has been allocated to our various
reportable segments. See Note 21—Segment Information.
In addition to the time-based restricted stock share-based awards, we provide two types of performance share
awards: the first, based on our performance measured against pre-determined performance metrics and the second, based
on market conditions measured against a predetermined peer group. The performance period for the awards granted in
2017 commenced on January 1, 2016 and ended December 31, 2016.
Stock Option Plans
As of December 31, 2017, 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 generally are at prices equal to the fair market value of the shares 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
67
the plans cannot be exercised more than ten years from the date of grant. Options to purchase 6.8 million and 8.0 million
Nabors common shares remained available for grant as of December 31, 2017 and 2016, respectively. Of the common
shares available for grant as of December 31, 2017, approximately 5.7 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:
Options
Shares Price
Weighted-
Average
Exercise
Weighted-
Average
Remaining
Contractual
Term
Aggregate
Intrinsic
Value
Options outstanding as of December 31, 2016 ....................
Granted ............................................................................
Exercised .........................................................................
Forfeited ..........................................................................
Options outstanding as of December 31, 2017 ....................
Options exercisable as of December 31, 2017 .....................
5,217 $
124
(842)
(105)
4,394 $
4,360 $
12.56
8.59
9.85
9.43
13.04
13.03
2.81 years $
2.77 years $
—
—
(In thousands, except exercise price)
During 2017, 2016 and 2015, respectively, we awarded options vesting over periods up to four years to
purchase 124,271, 99,711 and 158,219 of our common shares to our employees, executive officers and directors.
The fair value of stock options granted during 2017, 2016 and 2015 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) .....................................................................................
1.85%
2.94%
50.82%
4.0
1.09%
2.21%
45.69%
4.0
Year Ended December 31,
2016
2017
2.86 $
3.52 $
2015
4.40
1.29%
2.05%
50.01%
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.
68
A summary of our unvested stock options as of December 31, 2017, and the changes during the year then ended
is presented below:
Unvested Stock Options
Unvested as of December 31, 2016 ..........................................................................
Granted ................................................................................................................
Vested ..................................................................................................................
Forfeited ..............................................................................................................
Unvested as of December 31, 2017 ..........................................................................
Weighted-Average
Grant-Date Fair
Value
Outstanding
(In thousands, except fair value)
5.34
2.86
3.27
—
5.21
57 $
124
(147)
—
34 $
The total intrinsic value of options exercised during 2017, 2016 and 2015 was $5.1 million, $0.3 million and
$0.8 million, respectively. The total fair value of options that vested during the years ended December 31, 2017, 2016
and 2015 was $0.5 million, $1.9 million and $1.9 million, respectively.
As of December 31, 2017, there was $0.1 million of total future compensation cost related to unvested options
that are expected to vest. That cost is expected to be recognized over a weighted-average period of approximately one
year.
Restricted Stock
Our stock plans allow grants of restricted shares. Restricted shares are issued on the grant date, but cannot be
sold or transferred. Restricted shares vest in varying periodic installments ranging up to five years.
A summary of our restricted shares as of December 31, 2017, and the changes during the year then ended, is
presented below:
Restricted shares
Unvested as of December 31, 2016 ..........................................................................
Granted ................................................................................................................
Vested ..................................................................................................................
Forfeited ..............................................................................................................
Unvested as of December 31, 2017 ..........................................................................
Weighted-Average
Grant-Date Fair
Value
Outstanding
(In thousands, except fair value)
13.41
12.84
14.65
12.33
12.67
3,885 $
1,130
(1,567)
(150)
3,298 $
During 2017, 2016 and 2015, we awarded 1,130,304, 1,885,440 and 2,546,801 restricted shares, respectively, to
our employees and directors. These awards had an aggregate value at their date of grant of $14.5 million, $20.5 million
and $34.8 million, respectively, and were scheduled to vest over a period of up to four years. The fair value of restricted
shares that vested during 2017, 2016 and 2015 was $19.2 million, $13.5 million and $18.3 million, respectively.
As of December 31, 2017, there was $27.6 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, 2017, 2016 and 2015, we awarded 461,919, 1,284,829 and 438,307
restricted shares, respectively, vesting over a period of three years to some of our executives. The performance 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 2017, 2016 and 2015, respectively.
These awards had an aggregate fair value at their date of grant of $7.1 million, $13.9 million and $5.9 million,
respectively.
69
The following table sets forth information regarding outstanding restricted shares based on performance
conditions as of December 31, 2017:
Performance based restricted shares
Outstanding as of December 31, 2016 ......................................................................
Granted .................................................................................................................
Vested ...................................................................................................................
Outstanding as of December 31, 2017 ......................................................................
Weighted-Average
Grant-Date Fair
Value
1,595
Outstanding
(In thousands, except fair value)
12.01
$
15.31
462
13.33
(644)
12.49
1,413 $
Until shares are granted, our awards that are earned based on performance conditions are liability-classified
awards. Our accrued liabilities included $2.2 million for such awards at December 31, 2017 for the performance period
beginning January 1, 2017 through December 31, 2017 and $2.5 million for such awards at December 31, 2016 for the
performance period beginning January 1, 2016 through December 31, 2016. The fair value of these awards that vested
during the years ended December 31, 2017, 2016 and 2015 was $7.1 million, $1.5 million and $6.8 million, respectively.
The fair value of these liability-classified awards are estimated at each reporting period, based on internal metrics and
marked to market.
Restricted Shares Based on Market Conditions
During 2017, 2016 and 2015, we granted 397,692, 749,427 and 544,925 restricted 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 $4.4 million, $4.2 million and $4.7 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,
2015
2017
2016
Risk free interest rate .................................................................................................
Expected volatility .....................................................................................................
Closing stock price at grant date ................................................................................ $ 16.81 $
Expected term (in years) ............................................................................................
1.62%
55.00%
3.0
1.41%
52.00%
1.18%
50.00%
8.64 $ 12.98
3.00
3.0
The following table sets forth information regarding outstanding restricted shares based on market conditions as
of December 31, 2017:
Market based restricted shares
Outstanding as of December 31, 2016 .....................................................................
Granted ................................................................................................................
Vested ..................................................................................................................
Forfeited ..............................................................................................................
Outstanding as of December 31, 2017 .....................................................................
Weighted-Average
Grant-Date Fair
Value
$
1,690
Outstanding
(In thousands, except fair value)
7.94
11.16
11.40
11.40
7.89
398
(237)
(159)
1,692 $
As of December 31, 2017, there was $4.4 million of total future compensation cost related to unvested
performance share awards that are expected to vest.
70
Note 8 Property, Plant and Equipment
The major components of our property, plant and equipment are as follows:
Land ....................................................................................................................... $
Buildings ................................................................................................................
Drilling, workover and well-servicing rigs, and related equipment .......................
Marine transportation and supply vessels ..............................................................
Oilfield hauling and mobile equipment ..................................................................
Other machinery and equipment ............................................................................
Oil and gas properties ............................................................................................
Construction-in-process (1) ....................................................................................
Less: accumulated depreciation and amortization ..................................................
$
$
December 31,
2017
2016
(In thousands)
52,000 $
134,318
12,997,470
4,377
272,384
172,674
12,286
284,348
13,929,857 $
(7,820,292)
6,109,565 $
46,319
115,502
12,638,749
—
274,137
181,069
12,286
288,673
13,556,735
(7,289,152)
6,267,583
(1)
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, 2017 or 2016.
Depreciation expense included in depreciation and amortization expense in our consolidated statements of
income (loss) totaled $835.9 million, $885.4 million and $951.4 million during 2017, 2016 and 2015, respectively.
Repair and maintenance expense included in direct costs in our consolidated statements of income (loss) totaled
$241.4 million, $151.4 million and $304.7 million during 2017, 2016 and 2015, respectively.
Interest costs of $2.5 million, $6.7 million and $20.4 million were capitalized during 2017, 2016 and 2015,
respectively.
Note 9 Investments in Unconsolidated Affiliates
On March 24, 2015, we completed the merger of our Completion & Production Services business with C&J
Energy. We received total consideration comprised of approximately $693.5 million in cash ($650.0 million after
settlement of working capital requirements) and approximately 62.5 million common shares in the combined company,
CJES, representing approximately 53% of the outstanding and issued common shares of CJES as of the closing date.
On July 20, 2016, CJES and certain of its subsidiaries commenced voluntarily cases under chapter 11 of the
U.S. Bankruptcy code. Prior to the bankruptcy reorganization, we had significant influence over CJES, but not a
controlling financial interest, and accounted for our investment in CJES under the equity method of accounting. As a
result of the chapter 11 filing, beginning in the third quarter of 2016, we ceased accounting for our investment in CJES
as an equity method investment and began to report this investment at our estimated fair value as we did not expect to
have a meaningful continuing interest in CJES. We wrote off the remaining carrying value of our investment in CJES
during the second quarter of 2016, and as such, there was no impact to our consolidated financial statements as a result
of the change in accounting.
Historical Treatment of the Completion & Production Services business and our investment in CJES
Prior to the merger, we consolidated the results of our Completion & Production Services business into our
operating results. As a result of the merger, CJES became an unconsolidated affiliate and we ceased consolidating the
operating results of our Completion & Production Services business. Therefore, subsequent to the closing date of the
merger, our share of the net income (loss), as adjusted for our basis difference, of our equity method investment in CJES
was recorded as earnings (losses) from unconsolidated affiliates in our consolidated statements of income (loss) through
June 30, 2016. Our policy was to record our share of the net income (loss) of CJES on a one-quarter lag as were not able
to obtain the financial information of CJES on a timely basis. The equity in earnings from CJES, which is reflected in
71
earnings (losses) from unconsolidated affiliates in our consolidated statement of income (loss) was as follows for the
periods noted below:
Years Ended December 31,
2016
2015
(In thousands)
Nabors' share of equity method earnings (losses) ............................................................... $
(221,933) $
(81,260)
During the first quarter of 2015, we recognized an estimated gross gain of $102.2 million in connection with the
merger based on the difference between the consideration received and the carrying value of the assets and liabilities of
our Completion & Production Services business. This gain was partially offset by $49.6 million in transaction costs
related to the merger. During 2015, we recorded a post-closing adjustment of $5.5 million attributable to the settlement
of certain working capital requirements at the completion of the transition period.
We recorded our investment in the equity of CJES in the investment in unconsolidated affiliates line in our
consolidated balance sheet. Our policy is to review our equity method investments for impairment whenever certain
impairment indicators exist including the absence of an ability to recover the carrying amount of the investment or
inability of the investee to sustain an earnings capacity which would justify the carrying amount of the investment. A
loss in value of an investment that is other than a temporary decline should be recognized. As a result of this review,
during the first quarter of 2016, we determined the carrying value of our investment was other than temporarily
impaired, which resulted in an impairment charge of $153.4 million to reduce our carrying value to its estimated fair
value of $93.8 million, determined principally based on the average share price over a specified period. Additionally, we
recognized a $23.8 million charge to reserve certain other amounts associated with our CJES holdings including affiliate
receivables. Similarly, during 2015, we recorded an other than temporary impairment charge of $180.6 million. These
other-than-temporary impairments are reflected in impairments and other charges in our consolidated statements of
income (loss) for the years ended December 31, 2016 and 2015. See Note 3—Impairments and Other Charges.
As a result of CJES’s Chapter 11 filing on July 20, 2016, we determined our investment was other than
temporarily impaired as of June 30, 2016 and recorded a charge of $39.0 million to write off substantially all of the
remaining net book value of our investment. These charges are reflected in impairments and other charges in our
consolidated statement of income (loss) for the year ended December 31, 2016. We also recognized an additional
$9.1 million in professional fees incurred in connection with our efforts to preserve the value of our CJES holdings in
anticipation of the bankruptcy filing. These charges are reflected in other, net in our consolidated statement of income
(loss) for the year ended December 31, 2016. Pursuant to a mediated settlement agreement we entered into with various
other parties in the CJES bankruptcy proceedings, we agreed to support the debtors' chapter 11 plan of reorganization in
exchange for: (i) two allowed unsecured claims for which we will receive distributions of up to $4.85 million; (ii) an
amendment to the tax matters agreement providing that CJES pay up to $11.5 million of obligations for which we would
have otherwise been responsible; (iii) cancellation of various other obligations we had to the debtors; (iv) our pro rata
share of warrants to acquire 2% of the common equity in the reorganized debtors at a strike price of $1.55 billion; and
(v) a mutual release of claims. The bankruptcy court approved the terms of the Settlement Agreement and confirmed the
debtors' plan and, on January 6, 2017, CJES announced it had emerged from bankruptcy.
The tables below present summarized financial information for our investments in unconsolidated affiliates. As
we wrote off the remaining carrying value of our investment in CJES during the second quarter of 2016, we did not
record our share of the earnings (losses) of CJES for the three months ended June 30, 2016 in our consolidated statement
of income (loss) during the year ended December 31, 2016 as we are not contractually responsible for losses beyond our
investment.
September 30,
2016
(In thousands)
Current assets ............................................................................................................................................ $
383,750
Long-term assets ....................................................................................................................................... $ 1,138,092
147,699
Current liabilities ...................................................................................................................................... $
41,613
Long-term liabilities .................................................................................................................................. $
72
Nine Months Ended
September 30,
2016
Year Ended
December 31,
2015
Gross revenues ............................................................................................................. $
Gross margin ................................................................................................................ $
Net income (loss) ......................................................................................................... $
Nabors' share of equity method earnings (losses) ........................................................ $
727,320 $
18,943 $
(825,921) $
(221,933) $
1,748,889
225,773
(872,542)
(81,260)
Note 10 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 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.
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 revolving credit facility and Nabors Delaware term loan which was repaid in part in December 2016
with the remainder repaid in January 2017) and our fixed rate debt securities comprised of our 2.35%, 6.15%, 9.25%,
5.0%, 4.625%, 5.50% and 5.10% senior 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
73
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.
Note 11 Debt
Debt consisted of the following:
As of December 31,
2016
2017
(In thousands)
6.15% senior notes due February 2018 (1) ........................................................................... $ 460,762 $ 827,539
303,489
9.25% senior notes due January 2019 ...................................................................................
669,540
5.00% senior notes due September 2020 ..............................................................................
694,868
4.625% senior notes due September 2021 ............................................................................
600,000
5.50% senior notes due January 2023 ...................................................................................
346,448
5.10% senior notes due September 2023 ..............................................................................
0.75% senior exchangeable notes due January 2024 ............................................................
—
162,500
Term loan facility ..................................................................................................................
—
Revolving credit facility ........................................................................................................
—
Commercial paper .................................................................................................................
297
Other .....................................................................................................................................
3,604,681
297
26,049
$ 4,027,766 $ 3,578,335
303,489
669,846
695,108
600,000
346,576
429,982
—
510,000
40,000
181
4,055,944
181
27,997
Less: current portion .............................................................................................................
Less: deferred financing costs ...............................................................................................
(1)
The 6.15% senior notes due February 2018 have been classified as long-term because we have the ability and
intent to repay this obligation utilizing our revolving credit facility. We used the proceeds from our
January 2018 senior notes offering to repay these notes
As of December 31, 2017, the principal amount and maturities of our primary debt for each of the five years
after 2017 and thereafter are as follows:
2018 ................................................................................................................................................. $
2019 .................................................................................................................................................
2020 .................................................................................................................................................
2021 .................................................................................................................................................
2022 .................................................................................................................................................
Thereafter .........................................................................................................................................
$
460,837 (1)
303,489 (2)
1,220,675 (3)
696,000 (4)
—
1,522,300 (5)
4,203,301
Paid at Maturity
(In thousands)
(1)
(2)
(3)
(4)
(5)
Represents our 6.15% senior notes due February 2018.
Represents our 9.25% senior notes due January 2019.
Represents our 5.0% senior notes due September 2020 and amounts outstanding under our commercial paper
program and revolving credit facility due July 2020.
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 0.75%
senior exchangeable notes due January 2024.
Nabors Delaware’s various fixed rate debt securities comprised of our 6.15%, 9.25%, 5.00%, 4.625, 5.50% and
5.10%, senior unsecured notes are fully and unconditionally guaranteed by us. The notes rank equal in right of payment
74
to all of Nabors Delaware’s existing and future senior unsubordinated debt. The notes rank senior in right of payment to
all of our existing and future senior subordinated and subordinated debt. Our guarantee of the notes is unsecured and
ranks equal in right of payment to all of 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.
During 2017, 2016 and 2015, we repurchased $367.9 million, $152.7 million, and $27.5 million aggregate
principal amount of our senior unsecured notes for approximately $381.7 million, $157.5 million and $27.5 million,
respectively, in cash, reflecting principal, accrued and unpaid interest.
0.75% Senior Exchangeable Notes Due January 2024
In January 2017, Nabors Industries, Inc. issued $575 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. Debt issuance costs
of $9.6 million and equity issuance costs of $3.9 million were capitalized in connection with the issuance of these notes
in long-term debt and netted against the proceeds allocated to the equity component, respectively, in our consolidated
balance sheet. The debt issuance costs are being amortized through January 2024.
The exchangeable notes are exchangeable, under certain conditions, at an initial exchange rate of 39.75
common shares of Nabors per $1,000 principal amount of exchangeable notes (equivalent to an initial exchange price of
approximately $25.16 per common share). Upon any exchange, Nabors Delaware will settle its exchange obligation in
cash, common shares of Nabors, or a combination of cash and common shares, at our election.
In connection with the pricing of the notes, we entered into privately negotiated capped call transactions which
are expected to reduce potential dilution to common shares and/or offset potential cash payments required to be made in
excess of the principal amount upon any exchange of notes. Such reduction and/or offset is subject to a cap representing
a price per share of $31.45, an approximately 75.0% premium over our share price of $17.97 as of the date of the
transaction. The capped call meets the definition of a derivative under ASC 815, Derivatives and Hedging, as it has an
underlying (the Company’s share price), a notional amount (the number of underlying shares to be purchased per
option), an initial net investment less (by more than a nominal amount) than the amount that would have to be paid to
own the underlying and provides for a default net share settlement (but could also be settled in cash at the election of the
Company). However, the capped call meets the derivative scope exception under ASC 815 for instruments indexed to
the Company’s own stock and classified in shareholders’ equity and therefore was initially recorded in equity. Until such
time as the Company elects a settlement method for the exchangeable notes, the capped call transaction will continue to
be accounted for as equity. At conversion, if the Company elects to partially settle the notes in cash in excess of the
principal amount, or fully in cash, the capped call will be subject to mark to market through earnings as a derivative until
such settlement is paid.
The net proceeds from the offering of the exchangeable notes were used to prepay the remaining balance of our
unsecured term loan originally scheduled to mature in 2020, as well as to pay the cost of the capped call transactions.
The remaining net proceeds from the offering were allocated for general corporate purposes, including to repurchase or
repay other indebtedness.
Commercial Paper Program
In April 2013, Nabors Delaware established a commercial paper program. This program, as amended, currently
allows for the issuance from time to time of up to an aggregate amount of $2.25 billion in commercial paper with a
maturity of no more than 397 days. Our commercial paper borrowings are classified as long-term debt because the
borrowings are fully supported by availability under our revolving credit facility, which matures as currently structured
75
in July 2020, more than one year from now. The weighted average interest rate on borrowings during the year ended
December 31, 2017 was 1.87%. As of December 31, 2017, we had $40.0 million in borrowings outstanding under this
program. The commercial paper program can be used for short-term needs that arise and can be repaid with cash flows
from operations.
Revolving Credit Facility
In July 2015, we entered into an amendment to our existing committed, unsecured revolving credit facility to
increase the borrowing capacity to $2.2 billion, extend the maturity date to July 2020 and increase the size of the
accordion option to $500.0 million. We subsequently exercised $50.0 million of the accordion option to bring the total
availability to $2.25 billion. The weighted average interest rate on borrowings during the year ended December 31, 2017
was 2.73%. As of December 31, 2017, we had $510.0 million in borrowings outstanding under this facility. The
revolving credit facility contains various covenants and restrictive provisions that limit our ability to incur additional
indebtedness, make investments or loans and create liens and require us to maintain a net funded indebtedness to total
capitalization ratio of no greater than 0.60:1, as defined in the agreement. We were in compliance with all covenants
under the agreement at December 31, 2017. If we fail to perform our obligations under the covenants, the revolving
credit commitment could be terminated, and any outstanding borrowings under the facility could be declared
immediately due and payable.
Term Loan Facility
On September 29, 2015, Nabors Delaware entered into a new five-year unsecured term loan facility for $325.0
million, which was fully and unconditionally guaranteed by us. The term loan facility contained a mandatory
prepayment of $162.5 million due in September 2018, which was repaid in December 2016 utilizing a portion of the
proceeds received in connection with the 5.50% senior notes offering. In January 2017, we repaid the remaining $162.5
million term loan utilizing the proceeds received in connection with the 0.75% senior exchangeable notes and the facility
was terminated.
Short-Term Borrowings
We had 15 letter-of-credit facilities with various banks as of December 31, 2017. 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 availability ............................................................................................................................. $
December 31,
2017
(In thousands)
759,421
153,489
605,932
Note 12 Income Taxes
Income (loss) from continuing operations before income taxes consisted of the following:
United States and Other Jurisdictions
2017
Year Ended December 31,
2016
(In thousands)
2015
United States ................................................................................................... $ (369,162) $
Other jurisdictions ...........................................................................................
(728,589) $ (264,919)
(162,616)
(469,486)
Income (loss) from continuing operations before income taxes ................ $ (580,084) $ (1,198,075) $ (427,535)
(210,922)
76
Income tax expense (benefit) from continuing operations consisted of the following:
2017
Year Ended December 31,
2016
(In thousands)
2015
Current:
U.S. federal .................................................................................................... $ (160,761) $ (19,937) $
Outside the U.S. ............................................................................................
State ...............................................................................................................
59,491
(810)
5,088
76,550
8,227
$ (102,080) $ 14,780 $ 89,865
31,846
2,871
Deferred:
U.S. federal .................................................................................................... $ 49,020 $ (164,297) $ (182,518)
(14,641)
1,757
Outside the U.S. ............................................................................................
(7,142)
(22,673)
State ...............................................................................................................
$ 19,110 $ (201,611) $ (187,903)
Income tax expense (benefit) ............................................................................. $ (82,970) $ (186,831) $ (98,038)
(26,684)
(3,226)
A reconciliation of our statutory tax rate to our worldwide effective tax rate consists of the following:
2017
Year Ended December 31,
2016
(In thousands)
2015
Income tax provision at statutory (Bermuda rate of 0%) ..................................... $
Taxes (benefit) on U.S. and other international earnings (losses) at
(109,101)
greater than the Bermuda rate ..............................................................................
22,655
Increase (decrease) in valuation allowance ..........................................................
—
Impact of Tax Reform Act ...................................................................................
(12,679)
Tax reserves and interest ......................................................................................
State income taxes (benefit) .................................................................................
1,087
Income tax expense (benefit) ............................................................................... $ (82,970) $ (186,831) $ (98,038)
22.9 %
Effective tax rate ..................................................................................................
(98,119)
29,165
138,635
(148,615)
(4,036)
(181,426)
17,865
—
(3,468)
(19,802)
15.6%
14.3%
— $
— $
—
The decrease attributable to tax reserves during 2017 was primarily due to the release of reserves due to
favorable audit outcomes during the year of $167.0 million. As a result of the Tax Reform Act, we were required to
revalue deferred tax assets and liabilities from 35 percent to 21 percent which resulted in a provision of $138.6 million to
income tax expense. We believe the other provisions of the Tax Reform Act did not have a material impact on our
consolidated financial statements.
Our preliminary estimate of the Tax Reform Act and the remeasurement of our deferred tax assets and liabilities
is subject to the finalization of management’s analysis related to certain matters, such as developing interpretations of
the provisions of the Tax Reform Act, changes to certain estimates and the filing of our tax returns. U.S. Treasury
regulations, administrative interpretations or court decisions interpreting the Tax Reform Act may require further
adjustments and changes in our estimates. The final determination of the Tax Reform Act and the remeasurement of our
deferred assets and liabilities will be completed as additional information becomes available, but no later than one year
from the enactment of the Tax Reform Act in accordance with SAB 118.
77
The components of our net deferred taxes consisted of the following:
Deferred tax assets:
December 31,
2017
2016
(In thousands)
Net operating loss carryforwards .................................................................................. $ 1,974,658 $ 1,826,656
36,972
Equity compensation .....................................................................................................
31,082
Deferred revenue ...........................................................................................................
91,680
Tax credit and other attribute carryforwards .................................................................
Insurance loss reserves ..................................................................................................
5,118
357,285
Accrued interest.............................................................................................................
115,909
Other ..............................................................................................................................
2,464,702
Subtotal .........................................................................................................................
(1,807,728)
Valuation allowance ......................................................................................................
Deferred tax assets: ............................................................................................................ $
656,974
Deferred tax liabilities:
10,281
14,005
131,640
6,626
234,033
80,492
2,451,735
(1,869,490)
582,245 $
Depreciation and amortization for tax in excess of book expense ................................ $
Variable interest investments ........................................................................................
Other ..............................................................................................................................
Deferred tax liability ..................................................................................................... $
Net deferred tax assets (liabilities) ................................................................................ $
146,448 $
—
27,132
173,580 $
408,665 $
288,088
641
11,154
299,883
357,091
Balance Sheet Summary:
Net noncurrent deferred tax asset (1) ............................................................................ $
Net noncurrent deferred tax liability .............................................................................
Net deferred tax asset (liability) .................................................................................... $
419,003 $
(10,338)
408,665 $
366,586
(9,495)
357,091
(1)
This amount is included in other long-term assets.
For U.S. federal income tax purposes, we have net operating loss (“NOL”) carryforwards of approximately
$398.0 million that, if not utilized, will expire between 2031 and 2036. The NOL carryforwards for alternative minimum
tax purposes are approximately $383.0 million. Additionally, we have NOL carryforwards in other jurisdictions of
approximately $7.1 billion of which $550.0 million, if not utilized, will expire at various times from 2018 to 2037. 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. We have recorded a deferred tax
asset of approximately $1.71 billion as of December 31, 2017 relating to NOL carryforwards that have an indefinite life
in several non-U.S. jurisdictions. A valuation allowance of approximately $1.70 billion has been recognized because we
believe it is more likely than not that substantially all of the deferred tax asset will not be realized.
In addition, for state income tax purposes, we have NOL carryforwards of approximately $744.0 million that, if
not utilized, will expire at various times from 2018 to 2037.
The following is a reconciliation of our uncertain tax positions:
Balance as of January 1 .......................................................... $
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 ........................................................................
Balance as of December 31 .................................................... $
Year Ended December 31,
2016
(In thousands)
188,376
$
$
2017
179,255
—
25,119 (1)
(171,171)(2)
—
3,873
(11,547)(3)
—
33,203
(1,447)
179,255
$
2015
201,338
384
—
(9,234)(4)
(4,112)(5)
$
188,376
(1)
Includes $12.0 million reduction in Norway, $9.0 million in the U.S. and $2.0 million in Egypt.
78
(2)
(3)
(4)
Includes $167.0 million related to internal restructuring.
Includes $7.2 million related to the expiration of statute of limitations in Australia, Algeria and Mexico, a $2.0
million reduction to Trinidad and $2.1 million related to foreign currency translation.
Includes a $6.0 million reduction in Canada, Trinidad and the U.S., $2.0 million related to foreign currency
translation and $1.1 million due to the expiration of statute of limitations.
(5)
Includes $5.0 million related to settlements in Colombia, Ecuador, U.S. and Canada.
If the reserves of $33.2 million are not realized, this would favorably impact the worldwide effective tax rate.
As of December 31, 2017, 2016 and 2015, we had approximately $9.7 million, $9.2 million and $7.4 million,
respectively, of interest and penalties related to uncertain tax positions. During 2017, 2016 and 2015, we accrued and
recognized estimated interest and penalties related to uncertain tax positions of approximately $0.5 million, $0.6 million
and $1.4 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).
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 2015 and non-U.S. income tax examinations for years
before 2007.
Note 13 Common Shares
During 2017 and 2016, with approval of the Board, we repurchased 3.1 million and 0.3 million, respectively, of
our common shares in the open market for $18.1 million and $1.7 million, respectively, all of which are held by our
subsidiaries, and which are accounted for as treasury shares.
Our authorized share capital consists of 825,000,000 shares of which 800,000,000 are common shares, par
value $0.001 per share, and 25,000,000 are preferred shares, par value $0.001 per share. No preferred shares were issued
or outstanding as of December 31, 2017. The preferred shares are issuable in 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.
From time to time, treasury shares may be reissued. 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 2017, 2016
or 2015.
In 2017, 2016 and 2015, the Compensation Committee of our Board granted restricted share awards to some of
our executive officers, other key employees, and independent directors. We awarded 1,989,915, 3,919,696, and
3,530,033 restricted shares at an average market price of $13.08, $9.85 and $10.09 to these individuals for 2017, 2016
and 2015, respectively. See Note 7—Share-Based Compensation for a summary of our restricted stock and option
awards as of December 31, 2017.
In 2016 and 2017, our Board declared quarterly cash dividends of $0.06 per outstanding common share. The
aggregate amount paid in 2016 for dividends was $50.9 million. The aggregate amount paid in 2017 for dividends was
$68.5 million. The fourth quarter 2017 dividend was paid on January 3, 2018 in the amount of $17.1 million.
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Shareholder Rights Plan
On July 16, 2012, the Board declared the issuance of one preferred share purchase right (a “Right”) for each
Common Share issued and outstanding on July 27, 2012 (the “Record Date”) to the shareholders of record on that date.
On July 16, 2016, the Rights expired.
Note 14 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, during 2017 Nabors and Saudi Aramco each contributed a combination of
drilling rigs, drilling rig equipment and other assets, including cash, each with a value of approximately $204 million to
the joint venture 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 consolidated balance sheet 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 condensed balance sheet of SANAD, as included in our consolidated balance sheet, is presented below.
(In thousands)
Assets:
December 31,
2017
Cash and cash equivalents .......................................................................................................................
Accounts receivable .................................................................................................................................
Other current assets .................................................................................................................................
Property, plant and equipment, net ..........................................................................................................
Other long-term assets .............................................................................................................................
Total assets ..............................................................................................................................................
Liabilities:
Accounts payable .....................................................................................................................................
Accrued liabilities ....................................................................................................................................
Total liabilities .........................................................................................................................................
$
$
$
$
94,496
10,580
10,834
130,218
23,091
269,219
7,236
2,592
9,828
The assets of SANAD cannot be used by Nabors for general corporate purposes. Additionally, creditors of
SANAD do not have recourse to other assets of Nabors.
Note 15 Pension, Postretirement and Postemployment Benefits
Pension Plans
In conjunction with our acquisition of Pool Energy Services Co. (“Pool”) in November 1999, we acquired the
assets and liabilities of a defined benefit pension plan, the Pool Company Retirement Income Plan (the “Pool Pension
Plan”). Benefits under the Pool Pension Plan are frozen and participants were fully vested in their accrued retirement
benefit on December 31, 1998. The unfunded liability was $6.7 million and $7.3 million as of December 31, 2017 and
2016, respectively, and our net periodic benefit expense was $1.2 million, $1.1 million and $1.0 million for the years
ended December 31, 2017, 2016 and 2015, respectively.
During 2016, we launched a voluntary, one-time opportunity to buyout active employees and retirees who were
eligible participants of the Pool Pension Plan. The total amount of payments to those who elected to take the buyout was
approximately $10.3 million and such payments were made from pension plan assets. Additionally, we recognized a
charge related to the buyout of approximately $3.0 million, which is reflected in other, net in our consolidated statement
of income (loss) for the year ended December 31, 2016. Due to the immateriality of the costs and liabilities of this plan,
no further disclosure is presented.
80
Note 16 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
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 $6.0 million is included in other long-term assets in our
consolidated balance sheets as of December 31, 2017 and 2016.
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. See Note 5 — Acquisitions. 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 14 — Joint Ventures. During 2015, we entered into a
Transition Services Agreement with CJES, which expired on December 31, 2015. Revenues from business transactions
with these affiliated entities totaled $65.7 million and $142.2 million for 2017 and 2015, respectively. Expenses from
business transactions with these affiliated entities totaled $0.1 million for 2017 and 2016. Additionally, we had accounts
receivable from these affiliated entities of $54.2 million as of December 31, 2017, and $0.1 million as of December 31,
2016. We had accounts payable to these affiliated entities of $0.1 million as of December 31, 2016 and long-term
payables with these affiliated entities of $0.8 million as of December 31, 2017 and 2016, which are included in other
long-term liabilities.
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 2017, 2016 and 2015, we made payments for these services of $14.6 million,
$23.5 million and $33.7 million, respectively. We had accounts payable to these CCG-related companies of $0.8 million
and $1.0 million as of December 31, 2017 and 2016, respectively.
81
Note 17 Commitments and Contingencies
Commitments
During 2016, we entered into an agreement with Saudi Aramco, to form a new joint venture to own, manage
and operate onshore drilling rigs in the Kingdom of Saudi Arabia. The joint venture, which is equally owned by Saudi
Aramco and Nabors, commenced operations in the fourth quarter of 2017. The joint venture leverages our established
business in Saudi Arabia to begin operations, with a focus on Saudi Arabia's existing and future onshore oil and gas
fields. During 2017, Nabors and Saudi Aramco each contributed $20 million in cash as the initial contribution upon
formation of the joint venture. In addition, during 2017 Nabors and Saudi Aramco have each contributed approximately
$204 million in a combination of drilling rigs, drilling rig equipment or other assets, including cash, to the joint venture
in proportion to the respective party’s ownership interest. We have also agreed to contribute an additional five drilling
rigs and related assets to the joint venture in January 2019. Additionally, 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.
The minimum rental commitments under non-cancelable operating leases, with lease terms in excess of one
year subsequent to December 31, 2017, were as follows:
2018 ......................................................................................................................................................... $
2019 .........................................................................................................................................................
2020 .........................................................................................................................................................
2021 .........................................................................................................................................................
2022 .........................................................................................................................................................
Thereafter .................................................................................................................................................
(In thousands)
11,342
4,864
3,400
2,265
1,876
8,108
31,855
$
The above amounts do not include property taxes, insurance or normal maintenance that the lessees are required
to pay. Rental expense relating to operating leases with terms greater than 30 days amounted to $15.0 million,
$15.7 million and $24.6 million for the years ended December 31, 2017, 2016 and 2015, respectively.
Minimum Volume Commitment
We have contracts with pipeline companies to pay specified fees based on committed volumes for gas transport
and processing. Our pipeline contractual commitments as of December 31, 2017 were as follows:
2018 ......................................................................................................................................................... $
2019 .........................................................................................................................................................
2020 .........................................................................................................................................................
2021 .........................................................................................................................................................
2022 .........................................................................................................................................................
Thereafter (1) ...........................................................................................................................................
(In thousands)
8,597
2,652
—
—
—
—
11,249
$
(1)
Final commitment period is for the period ending May 2019. See Note 4—Assets Held for Sale and
Discontinued Operations for additional discussion.
82
Employment Contracts
We have entered into employment contracts with certain of our employees. Our minimum salary and bonus
obligations under these contracts as of December 31, 2017 were as follows:
2018 ......................................................................................................................................................... $
2019 .........................................................................................................................................................
2020 .........................................................................................................................................................
2021 .........................................................................................................................................................
2022 .........................................................................................................................................................
Thereafter .................................................................................................................................................
(In thousands)
4,252
300
—
—
—
—
4,552
$
Other Obligations. In addition to salary and bonus, Mr. Petrello receives group life insurance at an amount at
least equal to three times his base salary, various split-dollar life insurance policies, reimbursement of expenses, various
perquisites and a personal umbrella insurance policy in the amount of $5 million. Premiums payable under the
split-dollar life insurance policies were suspended as a result of the adoption of the Sarbanes-Oxley Act of 2002.
Contingencies
Income Tax Contingencies
We operate in a number of countries throughout the world and our tax returns filed in those jurisdictions are
subject to review and examination by tax authorities within those jurisdictions. We recognize the tax benefit from an
uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the
taxing authorities, based on the technical merits of the tax position. 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.
We have received an assessment from a tax authority in Latin America in connection with a 2007 income tax
return. The assessment relates to the denial of depreciation expense deductions related to drilling rigs. Similar deductions
were taken for tax year 2009. Although Nabors and its tax advisors believe these deductions are appropriate and intend
to continue to defend our position, we have recorded a partial reserve to account for this contingency. If we ultimately do
not prevail, we estimate that we would be required to recognize additional tax expense in the range of $3 million to $8
million.
Self-Insurance
We estimate the level of our liability related to insurance and record reserves for these amounts in our
consolidated financial statements. Our estimates are based on the facts and circumstances specific to existing claims and
our past experience with similar 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 and are actuarially supported. Although we
believe our insurance coverage and reserve estimates are reasonable, a significant accident or other event that is not fully
covered by insurance or contractual indemnity could occur and could materially affect our financial position and results
of operations for a particular period.
We self-insure for certain losses relating to workers’ compensation, employers’ liability, general liability,
automobile liability and property damage. Some of our workers’ compensation claims, employers’ liability and marine
employers’ liability claims are subject to a $3.0 million per-occurrence deductible; additionally, some of our automobile
liability claims are subject to a $2.5 million deductible. General liability claims remain subject to a $5.0 million
per-occurrence deductible. Our policies were renewed effective April 1, 2017 and remain subject to these same
deductibles.
83
In addition, we are subject to a $5.0 million deductible for land rigs and for offshore rigs. This applies to all
kinds of risks of physical damage except for named windstorms in the U.S. Gulf of Mexico for which we are
self-insured.
Political risk insurance is procured for select operations in South America, Africa, the Middle East and Asia.
Losses are subject to a $0.25 million deductible, except for Colombia, which is subject to a $0.5 million deductible.
There is no assurance that such coverage will adequately protect Nabors against liability from all potential consequences.
As of December 31, 2017 and 2016, our self-insurance accruals totaled $150.9 million and $157.4 million,
respectively, and our related insurance recoveries/receivables were $29.0 million as of December 31, 2017 and 2016.
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 management and based on liability accruals
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.
In March 2011, the Court of Ouargla entered a judgment of approximately $24.6 million (at December 31, 2017
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 $16.6 million in excess of amounts accrued.
On September 29, 2017, Nabors and Nabors Maple Acquisition Ltd. 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, and alleges liability by Nabors as a control person of Tesco. Defendants have
consolidated this case, captioned The Vladimir Gusinsky Rev. Trust et al. v. Tesco Corporation et al., No. 4:17-cv-02918
(S.D. Tex.) (Miller, J.) with two other matters recently filed making the same or similar legal claims against Nabors
and/or Tesco, captioned Panella v. Tesco Corporation et al., No. 4:17-cv-02904 (S.D. Tex.) (Bennett, J.) and Norman
Heinze v. Tesco Corporation et al., No. 4:17-cv-03029 (S.D. Tex).
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 involve agreements and obligations under
84
which we provide financial or performance assurance to third parties. Certain of these agreements 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:
Maximum Amount
2017
2018
2019 Thereafter
Total
(In thousands)
Financial standby letters of credit and other financial
surety instruments ......................................................... $
81,131
184,848 367
39 $
266,385
Note 18 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 common stock and participating security
according to dividends declared and participation rights in undistributed earnings.
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 $575 million 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 $25.16 on the last trading day of the quarter, which did not occur during the year ended December 31, 2017.
85
A reconciliation of the numerators and denominators of the basic and diluted earnings (losses) per share
computations is as follows:
Year Ended December 31,
2016
2017
2015
(In thousands, except per share amounts)
BASIC EPS:
Net income (loss) (numerator):
Income (loss) from continuing operations, net of tax .............................. $
Less: net (income) loss attributable to noncontrolling interest ................
Less: (earnings) losses allocated to unvested shareholders .....................
Numerator for basic earnings per share:
Adjusted income (loss) from continuing operations, net of
tax - basic ................................................................................................ $
Income (loss) from discontinued operations, net of tax .......................... $
Weighted-average number of shares outstanding - basic .............................
Earnings (losses) per share:
Basic from continuing operations ............................................................ $
Basic from discontinued operations ........................................................
Total Basic ................................................................................................... $
DILUTED EPS:
Adjusted income (loss) from continuing operations, net of tax - basic ........ $
Add: effect of reallocating undistributed earnings of unvested
shareholders .............................................................................................
Adjusted income (loss) from continuing operations, net of tax - diluted ..... $
Income (loss) from discontinued operations, net of tax ............................... $
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:
Diluted from continuing operations......................................................... $
Diluted from discontinued operations .....................................................
Total Diluted ................................................................................................ $
(497,114) $ (1,011,244) $ (329,497)
(381)
7,820
(6,178)
13,210
(135)
22,730
(490,082) $
(43,519) $
280,653
(988,649) $ (322,058)
(18,363) $ (42,797)
282,982
276,475
(1.75) $
(0.15)
(1.90) $
(3.58) $
(0.06)
(3.64) $
(1.14)
(0.15)
(1.29)
(490,082) $
(988,649) $ (322,058)
—
(490,082) $
(43,519) $
280,653
—
280,653
—
—
(988,649) $ (322,058)
(18,363) $ (42,797)
282,982
276,475
—
—
282,982
276,475
(1.75) $
(0.15)
(1.90) $
(3.58) $
(0.06)
(3.64) $
(1.14)
(0.15)
(1.29)
For all periods presented, the computation of diluted earnings (losses) per Nabors’ 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. 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 options
that were excluded from diluted earnings (losses) per share that would potentially dilute earnings per share in the future
were as follows:
2017
Year Ended December 31,
2016
(In thousands)
2015
Potentially dilutive securities excluded as anti-dilutive .............................................
4,534
5,372
9,459
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 share computation using the
if-converted method of accounting. 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.
86
Note 19 Supplemental Balance Sheet, Income Statement and Cash Flow Information
Accrued liabilities include the following:
December 31,
2017
2016
(In thousands)
Accrued compensation ......................................................................................................... $ 130,970 $ 116,775
255,626
Deferred revenue ..................................................................................................................
16,419
Other taxes payable ..............................................................................................................
18,255
Workers’ compensation liabilities ........................................................................................
57,233
Interest payable ....................................................................................................................
24,896
Litigation reserves ................................................................................................................
5,462
Current liability to discontinued operations .........................................................................
17,039
Dividends declared and payable ...........................................................................................
31,543
Other accrued liabilities .......................................................................................................
$ 533,044 $ 543,248
218,370
32,095
13,987
65,642
18,830
6,074
17,148
29,928
Other, net includes the following:
2017
Year Ended December 31,
2016
(In thousands)
2015
Losses (gains) on sales, disposals and involuntary conversions of long-lived assets .... $ 19,026 $ 14,830 $ (2,293)
(96,719)
Gain on Merger transaction ...........................................................................................
—
49,645
Charges related to our CJES holdings (1) .....................................................................
12,879
8,194
Litigation expenses and reserves ...................................................................................
3,936
392
Foreign currency transaction losses (gains) ..................................................................
5,669
—
(Gain) loss on debt buyback ..........................................................................................
—
1,609
Other losses (gains) .......................................................................................................
6,860
$ 14,880 $ 44,174 $ (39,172)
—
—
1,273
1,603
—
(7,022)
(1)
Includes legal and professional fees incurred primarily in connection with preserving our interests in CJES and
transaction costs associated with the merger. See Note 9 — Investments in Unconsolidated Affiliates.
87
The changes in accumulated other comprehensive income (loss), by component, include the following:
Gains
Unrealized
gains (losses)
(losses) on on available-
cash flow
for-sale
securities
hedges
Defined
benefit
pension plan
items
Foreign
currency
items
Total
As of January 1, 2016 .............. $
(1,670) $
(314) $
(In thousands (1) )
(6,568) $
(39,041) $
(47,593)
Other comprehensive
income (loss) before
reclassifications ....................
Amounts reclassified from
accumulated other
comprehensive income
(loss) .....................................
Net other comprehensive
income (loss) ........................
As of December 31, 2016 ........ $
(1)
All amounts are net of tax.
—
11,054
—
17,743
28,797
374
3,495
2,808
—
6,677
374
(1,296) $
14,549
14,235 $
2,808
(3,760) $
17,743
(21,298) $
35,474
(12,119)
Gains
(losses) on
cash flow
hedges
Unrealized
gains (losses)
on available-
Defined
benefit
for-sale
securities
pension plan
items
14,235 $
(In thousands (1) )
(3,760) $
Foreign
currency
items
Total
(21,298) $
(12,119)
As of January 1, 2017 .............. $
(1,296) $
Other comprehensive
income (loss) before
reclassifications ....................
Amounts reclassified from
accumulated other
comprehensive income
(loss) .....................................
Net other comprehensive
income (loss) ........................
As of December 31, 2017 ........ $
(1)
All amounts are net of tax.
—
(6,061)
—
28,372
22,311
374
970
(351)
—
993
374
(922) $
(5,091)
9,144 $
(351)
(4,111) $
28,372
7,074 $
23,304
11,185
88
The line items that were reclassified to net income include the following:
Line item in consolidated statement of income (loss)
Investment income (loss) ......................................................................................
Impairments and other charges .............................................................................
Interest expense .....................................................................................................
General and administrative expenses ....................................................................
Other expense (income), net .................................................................................
Total income (loss) from continuing operations before income tax ......................
Tax expense (benefit) ............................................................................................
Reclassification adjustment for (gains)/ losses included in net income (loss) ......
Supplemental cash flow information includes the following:
Year Ended December 31,
2015
2017
2016
(In thousands)
— $
$
— $
—
—
3,495
613
613
1,104
1,061
5,365
3,059
(7,082)
(8,228)
(648)
(1,551)
$ (1,468) $ (6,677) $ (6,434)
970
613
200
—
(1,783)
(315)
2017
Year Ended December 31,
2016
(In thousands)
2015
Cash paid for income taxes ................................................................................. $ 20,581 $ 34,479 $ 66,910
Cash paid for interest, net of capitalized interest ................................................ $ 191,986 $ 184,445 $ 168,979
Net change in accounts payable related to capital expenditures ......................... $ (35,227) $ 22,920 $ (59,565)
Non-cash increase in assets attributable to redeemable noncontrolling
interest in subsidiary ........................................................................................... $ 142,875 $
Acquisitions of businesses:
— $
—
Fair value of assets acquired .......................................................................... $ 280,709
Goodwill .........................................................................................................
5,690
Liabilities assumed ......................................................................................... (55,742)
—
Gain on acquisition.........................................................................................
(178,993)
Share issuance as consideration (non-cash financing activity) .......................
Payments on future consideration ..................................................................
—
51,664
Cash paid for acquisitions of businesses ........................................................
Cash acquired in acquisitions of businesses ...................................................
(60,704)
Cash (acquired in) paid for acquisitions of businesses, net ............................ $ (9,040)
$
—
—
—
—
—
22,278
22,278
—
$ 22,278
$ 327,857
86,502
(306,084)
(2,308)
—
22,278
128,245
(48,058)
$ 80,187
Note 20 Unaudited Quarterly Financial Information
Year Ended December 31, 2017
Quarter Ended
March 31, June 30, September 30, December 31,
(In thousands, except per share amounts)
Operating revenues ........................................................... $ 562,550 $ 631,355 $
Income (loss) from continuing operations, net of tax ........ $ (147,628) $ (115,476) $
Income (loss) from discontinued operations, net of tax .....
Net income (loss) ...............................................................
(439)
(148,067)
(15,504)
(130,980)
Less: Net (income) loss attributable to
noncontrolling interest ...................................................
(917)
(1,971)
Net income (loss) attributable to Nabors ............................ $ (148,984) $ (132,951) $
Earnings (losses) per share: (1)
Basic from continuing operations .................................. $
Basic from discontinued operations ..............................
Total Basic .................................................................... $
Diluted from continuing operations............................... $
Diluted from discontinued operations ...........................
Total Diluted ................................................................. $
(0.52) $
—
(0.52) $
(0.52) $
—
(0.52) $
(0.41) $
(0.05)
(0.46) $
(0.41) $
(0.05)
(0.46) $
89
662,103 $
(119,285) $
(27,134)
(146,419)
708,277
(114,725)
(442)
(115,167)
(2,113)
(148,532) $
(1,177)
(116,344)
(0.42) $
(0.10)
(0.52) $
(0.42) $
(0.10)
(0.52) $
(0.40)
—
(0.40)
(0.40)
—
(0.40)
Year Ended December 31, 2016
Quarter Ended
March 31, June 30, September 30, December 31,
(In thousands, except per share amounts)
Operating revenues ........................................................... $ 597,571 $ 571,591 $
Income (loss) from continuing operations, net of tax ........ $ (396,644) $ (186,565) $
Income (loss) from discontinued operations, net of tax .....
Net income (loss) ...............................................................
(926)
(397,570)
(984)
(187,549)
Less: Net (income) loss attributable to
noncontrolling interest ...................................................
(724)
2,899
Net income (loss) attributable to Nabors ............................ $ (398,294) $ (184,650) $
Earnings (losses) per share: (1)
Basic from continuing operations .................................. $
Basic from discontinued operations ..............................
Total Basic .................................................................... $
Diluted from continuing operations............................... $
Diluted from discontinued operations ...........................
Total Diluted ................................................................. $
(1.41) $
—
(1.41) $
(1.41) $
—
(1.41) $
(0.65) $
—
(0.65) $
(0.65) $
—
(0.65) $
519,729 $
(97,839) $
(12,187)
(110,026)
538,948
(330,196)
(4,266)
(334,462)
(1,185)
(111,211) $
(1,125)
(335,587)
(0.35) $
(0.04)
(0.39) $
(0.35) $
(0.04)
(0.39) $
(1.17)
(0.01)
(1.18)
(1.17)
(0.01)
(1.18)
(1)
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.
Note 21 Segment Information
During the fourth quarter of 2017, we effected a change in the reporting of our segments to better reflect our
product offerings and growing significance of our Nabors Drilling Solutions business. The expansion of our tubular
services offering attributable to the acquisition of Tesco during the fourth quarter, along with management’s increasing
focus on the strategic aspect of this business and expectation of future growth, culminated in the decision to break this
operation out into its own segment called Drilling Solutions. This operation was historically included within our Rig
Services segment, which we have renamed Rig Technologies and now primarily reflects the oilfield equipment
manufacturing, rental and aftermarket service business of Canrig. Our segment information has been revised to conform
to the new reportable segments. Our business now consists of five reportable segments: U.S., Canada, International,
Drilling Solutions and Rig Technologies. The reportable segments within the Completion & Production Services
business reflect historical operating information through the closing date of the merger with CJES.
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).
90
The following table sets forth financial information with respect to our reportable operating segments:
2017
Year Ended December 31,
2016
(In thousands)
2015
Operating revenues:
Drilling & Rig Technologies:
U.S. .........................................................................................................
Canada ....................................................................................................
International ...........................................................................................
Drilling Solutions ...................................................................................
Rig Technologies....................................................................................
Subtotal Drilling & Rig Technologies .................................................
$
805,223 $
82,929
1,474,060
140,701
234,542
2,737,455
554,072 $ 1,256,989
137,494
1,862,393
69,828
321,238
3,647,942
51,472
1,508,890
63,759
151,951
2,330,144
Completion & Production Services:
Completion Services ..............................................................................
Production Services ................................................................................
Subtotal Completion & Production Services ..........................................
—
—
—
—
—
—
207,860
158,512
366,372
Other reconciling items (1) .........................................................................
Total .......................................................................................................
(173,170)
(149,877)
(102,305)
$ 2,564,285 $ 2,227,839 $ 3,864,437
2017
Year Ended December 31,
2016
(In thousands)
2015
Adjusted operating income (loss): (2)
Drilling & Rig Technologies:
U.S. ..........................................................................................................
Canada .....................................................................................................
International ............................................................................................
Drilling Solutions ....................................................................................
Rig Technologies.....................................................................................
Subtotal Drilling & Rig Technologies ..................................................
$ (213,877) $ (197,710) $
(22,262)
108,428
16,738
(30,964)
(141,937)
(36,818)
164,677
(16,503)
(31,981)
(118,335)
87,051
(7,029)
308,262
(10,879)
(1,762)
375,643
Completion & Production Services:
Completion Services ...............................................................................
Production Services .................................................................................
Subtotal Completion & Production Services .......................................
—
—
—
—
—
—
(55,243)
(3,559)
(58,802)
Total segment adjusted operating income (loss) .....................................
$ (141,937) $ (118,335) $ 316,841
2017
Year Ended December 31,
2016
(In thousands)
2015
Reconciliation of segment adjusted operating income (loss) to
net income (loss) from continuing operations before income taxes:
Total segment adjusted operating income (loss) (2) .................................. $ (141,937) $
Other reconciling items (3) ........................................................................
Earnings (losses) from unconsolidated affiliates .......................................
Investment income (loss) ...........................................................................
Interest expense .........................................................................................
Impairments and other charges ..................................................................
Other, net ...................................................................................................
(118,335) $ 316,841
(159,880)
(130,976)
(75,081)
(221,914)
2,308
1,183
(181,928)
(185,360)
(368,967)
(498,499)
39,172
(44,174)
Income (loss) from continuing operations before income taxes ................... $ (580,084) $ (1,198,075) $ (427,535)
(157,043)
7
1,194
(222,889)
(44,536)
(14,880)
91
Depreciation and amortization
Drilling & Rig Technologies:
2017
Year Ended December 31,
2015
2016
(In thousands)
U.S. ................................................................................................................... $ 375,171 $ 388,367 $ 425,952
Canada ..............................................................................................................
46,786
411,004
International .....................................................................................................
11,221
Drilling Solutions .............................................................................................
22,398
Rig Technologies..............................................................................................
917,361
Subtotal Drilling & Rig Technologies ...........................................................
39,597
400,753
16,188
11,530
843,239
42,143
411,372
18,598
14,552
875,032
Completion & Production Services:
Completion Services ........................................................................................
Production Services ..........................................................................................
Subtotal Completion & Production Services .................................................
Other reconciling items (3) ...................................................................................
27,133
26,602
53,735
(637)
Total ................................................................................................................ $ 842,943 $ 871,631 $ 970,459
—
—
—
(3,401)
—
—
—
(296)
Capital expenditures and acquisitions of businesses:
Drilling & Rig Technologies:
2017
Year Ended December 31,
2015
2016
(In thousands)
U.S. ................................................................................................................... $ 330,875 $ 183,146 $ 224,819
Canada ..............................................................................................................
24,167
578,896
International .....................................................................................................
5,506
Drilling Solutions .............................................................................................
Rig Technologies..............................................................................................
7,285
840,673
Subtotal Drilling & Rig Technologies ...........................................................
45,691
Completion & Production Services .......................................................................
36,872
Other reconciling items (3) ...................................................................................
Total ................................................................................................................ $ 600,909 $ 414,379 $ 923,236
17,197
159,817
58,925
42,368
609,182
—
(8,273)
4,546
169,640
21,606
2,003
380,941
—
33,438
December 31,
2017
2016
(In thousands)
Total assets:
Drilling & Rig Technologies:
U.S. .................................................................................................................................. $ 3,203,560 $ 3,172,767
329,620
Canada .............................................................................................................................
3,600,057
International ....................................................................................................................
Drilling Solutions ............................................................................................................
81,490
277,945
Rig Technologies.............................................................................................................
7,461,879
Subtotal Drilling & Rig Technologies ..........................................................................
725,136
Other reconciling items (3) ..................................................................................................
Total ............................................................................................................................... $ 8,401,984 $ 8,187,015
347,773
3,540,829
182,162
459,665
7,733,989
667,995
(1)
(2)
Represents the elimination of inter-segment transactions.
Adjusted operating income (loss) is computed by subtracting the sum of direct costs, general and administrative
expenses, research and engineering expenses and depreciation and amortization from operating revenues.
Management evaluates the performance of our reportable segments using adjusted operating income (loss),
which is a 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. A reconciliation to income (loss) from continuing operations
before income taxes is provided in the above table.
92
(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:
2017
Year Ended December 31,
2016
(In thousands)
2015
Operating revenues
U.S. ........................................................................................................... $
Outside the U.S. .......................................................................................
973,464 $
642,835 $ 1,823,906
2,040,531
1,585,004
$ 2,564,285 $ 2,227,839 $ 3,864,437
1,590,821
Property, plant and equipment, net:
U.S. ........................................................................................................... $ 3,163,425 $ 3,048,749 $ 3,703,533
3,324,269
Outside the U.S. .......................................................................................
3,218,834
$ 6,109,565 $ 6,267,583 $ 7,027,802
2,946,140
Goodwill:
U.S. ........................................................................................................... $
Outside the U.S. .......................................................................................
$
54,198 $
119,028
173,226 $
54,199 $
112,718
166,917 $
54,198
112,461
166,659
During the years ended December 31, 2017, 2016 and 2015, $727.7 million, $731.4 million and $604.5 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%, 33% and 12% of our consolidated operating revenues during
the years ended December 31, 2017, 2016 and 2015, respectively, and is included in our International drilling reportable
segment.
Note 22 Condensed Consolidating Financial Information
Nabors has fully and unconditionally guaranteed all of the issued public debt securities of Nabors Delaware, its
wholly-owned subsidiary. The following condensed consolidating financial information is included so that separate
financial statements of Nabors Delaware is 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.
The following condensed consolidating financial information presents condensed consolidating balance sheets
as of December 31, 2017 and 2016, and statements of income (loss), statements of comprehensive income (loss) and the
statements of cash flows for the years ended December 31, 2017, 2016 and 2015 of (a) Nabors, parent/guarantor,
(b) Nabors Delaware, issuer of public debt securities guaranteed by Nabors, (c) the non-guarantor subsidiaries,
(d) consolidating adjustments necessary to consolidate Nabors and its subsidiaries and (e) Nabors on a consolidated
basis.
93
Condensed Consolidating Balance Sheets
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer)
December 31, 2017
Other
Subsidiaries
(Non-
Consolidating
Guarantors) Adjustments
Total
(In thousands)
ASSETS
Current assets:
Cash and cash equivalents ....................... $
Short-term investments ...........................
Accounts receivable, net .........................
Inventory, net ..........................................
Assets held for sale .................................
Other current assets .................................
Total current assets .............................
Property, plant and equipment, net .........
Goodwill .................................................
Intercompany receivables .......................
Investment in consolidated affiliates .......
Deferred income taxes ............................
Other long-term assets ............................
336,997
28,369
698,477
166,307
37,052
180,134
1,447,336
6,109,565
173,226
—
—
419,003
252,854
Total assets ......................................... $ 2,934,063 $ 6,346,418 $ 12,272,741 $ (13,151,238) $ 8,401,984
— $
—
—
—
—
—
—
—
—
(614,694)
(12,131,052)
(333,349)
(72,143)
44 $
—
—
—
—
56
100
—
—
481,092
5,531,799
333,349
78
1,091 $
—
—
—
—
50
1,141
—
—
133,602
2,799,320
—
—
335,862 $
28,369
698,477
166,307
37,052
180,028
1,446,095
6,109,565
173,226
—
3,799,933
419,003
324,919
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt ............................ $
Trade accounts payable ...........................
Accrued liabilities ...................................
Income taxes payable ..............................
Total current liabilities .......................
Long-term debt ........................................
Other long-term liabilities .......................
Deferred income taxes ............................
Intercompany payable .............................
Total liabilities ...................................
— $
— $
181 $
147
21,100
—
21,247
—
—
—
1,000
22,247
124
67,760
—
67,884
4,099,909
16,284
—
—
4,184,077
363,145
444,184
22,835
830,345
—
285,349
343,687
613,694
2,073,075
— $
—
—
—
—
(72,143)
—
(333,349)
(614,694)
(1,020,186)
181
363,416
533,044
22,835
919,476
4,027,766
301,633
10,338
—
5,259,213
Redeemable noncontrolling interest in
203,998
subsidiary ................................................
2,911,816
Shareholders’ equity ...............................
26,957
Noncontrolling interest ...........................
Total equity ........................................
2,938,773
Total liabilities and equity .................. $ 2,934,063 $ 6,346,418 $ 12,272,741 $ (13,151,238) $ 8,401,984
—
(12,131,052)
—
(12,131,052)
—
2,911,816
—
2,911,816
—
2,162,341
—
2,162,341
203,998
9,968,711
26,957
9,995,668
94
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer)
December 31, 2016
Other
Subsidiaries
(Non-
Consolidating
Guarantors) Adjustments
Total
(In thousands)
ASSETS
Current assets:
Cash and cash equivalents ....................... $
Short-term investments ...........................
Accounts receivable, net .........................
Inventory, net ..........................................
Assets held for sale .................................
Other current assets .................................
Total current assets .............................
Property, plant and equipment, net .........
Goodwill .................................................
Intercompany receivables .......................
Investment in consolidated affiliates .......
Deferred tax assets ..................................
Other long-term assets ............................
264,093
31,109
508,355
103,595
76,668
172,019
1,155,839
6,267,583
166,917
—
—
366,586
230,090
Total assets ......................................... $ 3,313,900 $ 5,306,351 $ 10,798,193 $ (11,231,429) $ 8,187,015
10,177 $
—
—
—
—
22,209
32,386
—
—
—
4,830,572
443,049
344
— $
—
—
—
—
—
—
—
—
(1,485,390)
(9,084,774)
(443,049)
(218,216)
252,768 $
31,109
508,355
103,595
76,668
149,760
1,122,255
6,267,583
166,917
1,342,942
1,083,948
366,586
447,962
1,148 $
—
—
—
—
50
1,198
—
—
142,448
3,170,254
—
—
LIABILITIES AND EQUITY
— $
297 $
Current liabilities:
297
Current portion of debt ............................ $
264,578
Trade accounts payable ...........................
543,248
Accrued liabilities ...................................
13,811
Income taxes payable ..............................
821,934
Total current liabilities .......................
3,578,335
Long-term debt ........................................
522,456
Other long-term liabilities .......................
9,495
Deferred income taxes ............................
—
Intercompany payable .............................
4,932,220
Total liabilities ...................................
3,247,025
Shareholders’ equity ...............................
7,770
Noncontrolling interest ...........................
Total equity ........................................
3,254,795
Total liabilities and equity .................. $ 3,313,900 $ 5,306,351 $ 10,798,193 $ (11,231,429) $ 8,187,015
— $
8
65,246
—
65,254
3,796,550
22,659
—
1,439,390
5,323,853
(17,502)
—
(17,502)
— $
—
—
—
—
(218,215)
—
(443,049)
(1,485,390)
(2,146,654)
(9,084,775)
—
(9,084,775)
205
20,669
—
20,874
—
—
—
46,000
66,874
3,247,026
—
3,247,026
264,365
457,333
13,811
735,806
—
499,797
452,544
—
1,688,147
9,102,276
7,770
9,110,046
95
Condensed Consolidating Statements of Income (Loss)
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer/
Guarantor)
Year Ended December 31, 2017
Other
Subsidiaries
(Non-
Guarantors)
(In thousands)
Consolidating
Adjustments
Total
Revenues and other income:
Operating revenues ............................................. $
Earnings (losses) from unconsolidated
—
affiliates ..............................................................
Earnings (losses) from consolidated affiliates .... (528,180)
17
Investment income (loss) ...................................
Total revenues and other income ..................... (528,163)
— $
Costs and other deductions:
— $ 2,564,285 $
— $ 2,564,285
—
18,380
63
18,443
7
(343,233)
13,031
2,234,090
—
853,033
(11,917)
841,116
7
—
1,194
2,565,486
Direct costs .........................................................
General and administrative expenses .................
Research and engineering ...................................
Depreciation and amortization ...........................
Interest expense ..................................................
Impairments and other charges ...........................
Other, net ............................................................
Intercompany interest expense ...........................
Total costs and other deductions ......................
—
10,995
—
—
—
—
7,662
(9)
18,648
—
715
—
125
232,103
—
19,033
—
251,976
1,718,069
240,139
51,069
842,818
(9,214)
44,536
(12,480)
9
2,874,946
—
(665)
—
—
—
—
665
—
—
1,718,069
251,184
51,069
842,943
222,889
44,536
14,880
—
3,145,570
Income (loss) from continuing operations
before income taxes ................................................ (546,811)
—
Income tax expense (benefit) .............................
Income (loss) from continuing operations,
net of tax ................................................................. (546,811)
Income (loss) from discontinued operations,
—
net of tax .................................................................
Net income (loss) ................................................... (546,811)
(233,533)
109,700
(640,856)
(192,670)
841,116
—
(580,084)
(82,970)
(343,233)
(448,186)
841,116
(497,114)
—
(343,233)
(43,519)
(491,705)
—
841,116
(43,519)
(540,633)
Less: Net (income) loss attributable to
noncontrolling interest ........................................
(6,178)
Net income (loss) attributable to Nabors ................. $ (546,811) $ (343,233) $ (497,883) $ 841,116 $ (546,811)
(6,178)
—
—
—
96
Nabors
(Parent/
Guarantor)
Revenues and other income:
Year Ended December 31, 2016
Other
Nabors
Delaware
(Issuer/
Guarantor)
Subsidiaries
(Non-
Guarantors)
(In thousands)
Consolidating
Adjustments
Total
— $
Operating revenues ..................................... $
Earnings (losses) from unconsolidated
affiliates ......................................................
Earnings (losses) from consolidated
affiliates ...................................................... (1,017,338)
2
Investment income (loss) ...........................
—
Intercompany interest income (loss) ..........
Total revenues and other income ............. (1,017,336)
—
— $ 2,227,839 $
— $ 2,227,839
—
(221,914)
—
(221,914)
(231,960)
132
569
(231,259)
(359,751)
12,972
—
1,659,146
1,609,049
(11,923)
(569)
1,596,557
—
1,183
—
2,007,108
Costs and other deductions:
Direct costs .................................................
General and administrative expenses .........
Research and engineering ...........................
Depreciation and amortization ...................
Interest expense ..........................................
Impairments and other charges ...................
Other, net ....................................................
Intercompany interest expense ...................
Total costs and other deductions ..............
—
10,559
—
—
—
1,366
482
(1)
12,406
—
603
—
124
204,010
—
(14)
—
204,723
1,344,298
217,333
33,582
871,507
(18,650)
497,133
42,850
570
2,988,623
—
(856)
—
—
—
—
856
(569)
(569)
1,344,298
227,639
33,582
871,631
185,360
498,499
44,174
—
3,205,183
Income (loss) from continuing operations
before income taxes ........................................ (1,029,742)
—
Income tax expense (benefit) .....................
Income (loss) from continuing operations,
net of tax ......................................................... (1,029,742)
Income (loss) from discontinued operations,
—
net of tax .........................................................
Net income (loss) ........................................... (1,029,742)
(435,982)
(76,231)
(1,329,477)
(110,600)
1,597,126
—
(1,198,075)
(186,831)
(359,751)
(1,218,877)
1,597,126
(1,011,244)
—
(359,751)
(18,363)
(1,237,240)
—
1,597,126
(18,363)
(1,029,607)
Less: Net (income) loss attributable to
noncontrolling interest ................................
(135)
—
Net income (loss) attributable to Nabors ......... $ (1,029,742) $ (359,751) $ (1,237,375) $ 1,597,126 $ (1,029,742)
(135)
—
—
97
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer/
Guarantor)
Year Ended December 31, 2015
Other
Subsidiaries
(Non-
Guarantors)
(In thousands)
Consolidating
Adjustments
Total
Revenues and other income:
Operating revenues ............................................ $
Earnings (losses) from unconsolidated
—
affiliates .............................................................
Earnings (losses) from consolidated affiliates ... (351,407)
—
Investment income (loss)...................................
—
Intercompany interest income ...........................
Total revenues and other income .................... (351,407)
— $
Costs and other deductions:
— $ 3,864,437 $
— $ 3,864,437
—
(41,826)
584
6,452
(34,790)
(75,081)
(164,697)
11,666
—
3,636,325
—
557,930
(9,942)
(6,452)
541,536
(75,081)
—
2,308
—
3,791,664
Direct costs ........................................................
General and administrative expenses ................
Research and engineering ..................................
Depreciation and amortization ..........................
Interest expense .................................................
Impairments and other charges ..........................
Other, net ...........................................................
Intercompany interest expense ..........................
Total costs and other deductions .....................
—
8,768
—
—
(1)
—
12,469
32
21,268
—
1
—
705
201,364
—
—
—
202,070
2,371,436
316,119
41,253
969,754
(19,435)
368,967
(52,201)
6,420
4,002,313
—
(560)
—
—
—
—
560
(6,452)
(6,452)
2,371,436
324,328
41,253
970,459
181,928
368,967
(39,172)
—
4,219,199
Income (loss) from continuing operations before
income taxes ........................................................... (372,675)
—
Income tax expense (benefit) ............................
Income (loss) from continuing operations,
net of tax ................................................................ (372,675)
Income (loss) from discontinued operations,
—
net of tax ................................................................
Net income (loss) .................................................. (372,675)
(236,860)
(72,163)
(365,988)
(25,875)
547,988
—
(427,535)
(98,038)
(164,697)
(340,113)
547,988
(329,497)
—
(164,697)
(42,797)
(382,910)
—
547,988
(42,797)
(372,294)
Less: Net (income) loss attributable to
noncontrolling interest .......................................
(381)
—
Net income (loss) attributable to Nabors ................ $ (372,675) $ (164,697) $ (383,291) $ 547,988 $ (372,675)
(381)
—
—
98
Condensed Consolidating Statements of Comprehensive Income (Loss)
Year Ended December 31, 2017
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer/
Guarantor)
Other
Subsidiaries
(Non-
Guarantors)
(In thousands)
Consolidating
Adjustments
Total
Net income (loss) attributable to Nabors . . . . . . . . . $ (546,811) $ (343,233) $ (497,883) $ 841,116 $ (546,811)
Other comprehensive income (loss) before tax:
Translation adjustment attributable to Nabors . .
Unrealized gains (losses) on marketable
securities:
Unrealized gains (losses) on marketable
securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: reclassification adjustment for (gains)
losses included in net income (loss) . . . . . . . . .
Unrealized gains (losses) on marketable
securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Pension liability amortization and adjustment . .
Unrealized gains (losses) and amortization
on cash flow hedges . . . . . . . . . . . . . . . . . . . . . . .
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 adjustment attributable to
noncontrolling interest . . . . . . . . . . . . . . . . . . . . .
28,372
—
28,372
(28,372)
28,372
(6,061)
—
(6,061)
6,061
(6,061)
970
—
970
(970)
970
(5,091)
(275)
613
23,619
315
23,304
—
(275)
(5,091)
(550)
5,091
825
(5,091)
(275)
613
338
315
23
613
23,344
(1,226)
(23,682)
613
23,619
630
22,714
(945)
(22,737)
315
23,304
(523,507)
(343,210)
(475,169)
818,379
(523,507)
—
—
—
—
6,178
282
—
—
6,178
282
Comprehensive income (loss) attributable to
noncontrolling interest . . . . . . . . . . . . . . . . . . . . . . .
6,460
Comprehensive income (loss) . . . . . . . . . . . . . . . . . $ (523,507) $ (343,210) $ (468,709) $ 818,379 $ (517,047)
6,460
—
—
—
99
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer/
Guarantor)
Year Ended December 31, 2016
Other
Subsidiaries
(Non-
Guarantors)
(In thousands)
Consolidating
Adjustments
Total
Net income (loss) attributable to Nabors . . . . . . . . $(1,029,742) $ (359,751) $(1,237,375) $ 1,597,126 $(1,029,742)
Other comprehensive income (loss) before tax:
Translation adjustment attributable
to Nabors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unrealized gains (losses) on marketable
securities:
Unrealized gains (losses) on marketable
securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Less: reclassification adjustment for (gains)
losses included in net income (loss) . . . . . . . .
Unrealized gains (losses) on marketable
securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Pension buyout . . . . . . . . . . . . . . . . . . . . . . . . . .
Pension liability amortization and
adjustment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unrealized gains (losses) and amortization on
cash flow hedges . . . . . . . . . . . . . . . . . . . . . . . .
Other comprehensive income (loss) before tax . . .
Income tax expense (benefit)
related to items of other comprehensive
income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . .
17,743
(21)
17,743
(17,722)
17,743
11,054
—
11,054
(11,054)
11,054
3,495
—
3,495
(3,495)
3,495
14,549
3,059
—
3,059
14,549
6,118
(14,549)
(9,177)
14,549
3,059
1,061
1,061
2,122
(3,183)
1,061
613
37,025
613
4,712
613
41,145
(1,226)
(45,857)
613
37,025
1,551
1,551
3,102
(4,653)
1,551
Other comprehensive income (loss),
net of tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Comprehensive income (loss) attributable to
Nabors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (994,268) (356,590) (1,199,332) 1,555,922 (994,268)
(41,204)
38,043
35,474
3,161
35,474
Net income (loss) attributable to
noncontrolling interest . . . . . . . . . . . . . . . . . . . .
Translation adjustment attributable to
noncontrolling interest . . . . . . . . . . . . . . . . . . . .
—
—
135
—
135
—
—
251
—
251
Comprehensive income (loss) attributable to
386
noncontrolling interest . . . . . . . . . . . . . . . . . . . . . .
Comprehensive income (loss) . . . . . . . . . . . . . . . . $ (994,268) $ (356,590) $(1,198,946) $ 1,555,922 $ (993,882)
386
—
—
—
100
Year Ended December 31, 2015
Nabors
(Parent/
Guarantor)
Nabors
Delaware
(Issuer/
Guarantor)
Other
Subsidiaries
(Non-
Guarantors)
(In thousands)
Consolidating
Adjustments
Total
Net income (loss) attributable to Nabors ................... $ (372,675) $ (164,697) $ (383,291) $ 547,988 $ (372,675)
Other comprehensive income (loss) before tax
Translation adjustment attributable to Nabors:
Unrealized gain (loss) on translation
adjustment .......................................................... (116,239)
Less: reclassification adjustment for realized
(gain) loss on translation adjustment .................
5,365
Translation adjustment attributable to Nabors ...... (110,874)
Unrealized gains (losses) on marketable
securities:
67
(116,172)
116,105
(116,239)
—
67
5,365
(110,807)
(5,365)
110,740
5,365
(110,874)
Unrealized gains (losses) on marketable
securities ............................................................
Less: reclassification adjustment for (gains)
losses included in net income (loss) ...................
(15,310)
—
(15,310)
15,310
(15,310)
—
—
—
—
—
Unrealized gains (losses) on marketable
securities ...............................................................
Pension liability amortization and adjustment......
Unrealized gains (losses) and amortization on
cash flow hedges ..................................................
613
Other comprehensive income (loss) before tax ......... (124,467)
Income tax expense (benefit) related to items of
other comprehensive income (loss) ......................
648
Other comprehensive income (loss), net of tax ......... (125,115)
Comprehensive income (loss) attributable to
Nabors ....................................................................... (497,790)
Net income (loss) attributable to
noncontrolling interest ..........................................
Translation adjustment attributable to
noncontrolling interest ..........................................
—
—
(15,310)
1,104
—
1,104
(15,310)
2,208
15,310
(3,312)
(15,310)
1,104
613
1,784
613
(123,296)
(1,226)
121,512
613
(124,467)
648
1,136
1,056
(124,352)
(1,704)
123,216
648
(125,115)
(163,561)
(507,643)
671,204
(497,790)
—
381
—
381
—
(1,461)
—
(1,461)
Comprehensive income (loss) attributable to
(1,080)
noncontrolling interest ..............................................
Comprehensive income (loss) ................................... $ (497,790) $ (163,561) $ (508,723) $ 671,204 $ (498,870)
(1,080)
—
—
—
101
Condensed Consolidating Statements of Cash Flows
Year Ended December 31, 2017
Nabors
(Parent/
Nabors
Delaware
(Issuer/
Other
Subsidiaries
(Non-
Consolidating
Guarantor) Guarantor) Guarantors) Adjustments
Net cash provided by (used for) operating
activities ....................................................................... $ 143,444 $ (90,229) $ 142,527 $ (132,986) $
Cash flows from investing activities:
(In thousands)
Total
62,756
Purchases of investments ........................................
Sales and maturities of investments ........................
Cash paid for acquisitions of businesses, net of
cash acquired ...........................................................
Cash paid for investments in consolidated
affiliates ...................................................................
Capital expenditures ................................................
Proceeds from sales of assets and insurance
claims ......................................................................
Change in intercompany balances ...........................
Other changes in investing ......................................
Net cash provided by (used for) investing activities ....
Cash flows from financing activities:
Increase (decrease) in cash overdrafts .....................
Proceeds from issuance of long-term debt ..............
Debt issuance costs ..................................................
Proceeds from revolving credit facilities .................
Proceeds from parent contributions .........................
Proceeds from (payments for) issuance of
common shares ........................................................
Purchase of capped call hedge transactions ...........
Reduction of long-term debt ..................................
Dividends to shareholders .......................................
Proceeds from (payment for) commercial paper,
net ............................................................................
Reduction in revolving credit facilities ...................
Payments on term loan ............................................
Proceeds from (payments for) short-term
borrowings ...............................................................
Cash proceeds from equity component of
exchangeable debt ...................................................
Proceeds from issuance of intercompany debt ........
Noncontrolling interest contribution ......................
Paydown of intercompany debt ..............................
Distributions to Non-controlling interest ...............
Distribution from subsidiary to parent ....................
Repurchase of common shares ................................
Redeemable noncontrolling interest
contribution .............................................................
Other changes ..........................................................
—
—
—
—
(6,722)
13,069
—
—
(6,722)
13,069
—
—
9,040
—
9,040
(100)
—
—
(85,960)
— (574,467)
86,060
—
— (574,467)
57,933
—
—
— (599,974) 599,974
(856)
—
—
12,011
(100) (599,974)
—
—
—
57,933
—
(856)
86,060 (502,003)
—
—
— 411,200
—
(11,043)
— 725,000
42,980
—
(188)
—
—
—
43,080
—
(188)
— 411,200
—
(11,043)
— 725,000
—
(86,060)
—
(40,250)
1
8,299
—
—
— (270,269) (111,545)
—
—
(80,419)
8,300
—
—
(40,250)
— (381,814)
(68,503)
11,916
—
40,000
— (215,000)
— (162,500)
—
—
—
—
40,000
— (215,000)
— (162,500)
—
—
(543)
—
(543)
— 159,952
20,000
—
—
(77,000)
20,000
(20,000) 122,000
(7,272)
— 159,952
—
—
20,000
—
—
—
(7,272)
—
—
—
— (121,070) 121,070
(18,071)
—
—
—
57,000
—
(102,000)
—
—
(18,071)
—
(8,210)
—
—
61,123
(1)
—
—
61,123
(8,211)
Net cash (used for) provided by financing
activities ....................................................................... (143,401) 680,070
Effect of exchange rate changes on cash and cash
equivalents ...................................................................
Net increase (decrease) in cash and cash
equivalents ...................................................................
Cash and cash equivalents, beginning of period ..........
Cash and cash equivalents, end of period .................... $
(57)
1,148
1,091 $
—
—
(71,415)
46,926 512,180
(29)
—
(29)
(10,133)
83,094
10,177 252,768
44 $ 335,862 $
—
72,904
— 264,093
— $ 336,997
102
Year Ended December 31, 2016
Other
Subsidiaries
(Non-
Guarantor) Guarantor) Guarantors) Adjustments Total
Nabors
Delaware
(Issuer/
Nabors
(Parent/
Consolidating
Net cash provided by (used for) operating
activities .......................................................... $
Cash flows from investing activities:
Purchases of investments ...........................
Sales and maturities of investments ...........
Cash paid for acquisitions of businesses,
net of cash acquired ....................................
Cash paid for investments in
consolidated affiliates .................................
Capital expenditures ...................................
Proceeds from sale of assets and
insurance claims .........................................
Change in intercompany balances ..............
Other ...........................................................
Net cash provided by (used for) investing
activities ..........................................................
Cash flows from financing activities:
Increase (decrease) in cash overdrafts ........
Debt issuance costs .....................................
Proceeds from (payments for) issuance
of common shares.......................................
Reduction in long-term debt .......................
Dividends to shareholders ..........................
Proceeds from (payments for)
commercial paper, net ................................
Proceeds from issuance of
intercompany debt ......................................
Proceeds from revolving credit facilities ....
Reduction in revolving credit facilities ......
Proceeds from issuance of long-term
debt .............................................................
Payments on term loan ...............................
Paydown of intercompany debt ..................
Repurchase of common shares ...................
Proceeds from (payments for) short-term
borrowings ..................................................
Proceeds from parent contributions ............
Payments on parent (Equity of N/P) ...........
Other changes .............................................
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 ......................................................
Cash and cash equivalents, beginning of
period ..............................................................
Cash and cash equivalents, end of period ....... $
(In thousands)
58,406 $ (233,738) $
757,660 $
(50,423) $ 531,905
—
—
—
—
—
—
—
—
—
—
(24)
739
—
—
(24)
739
—
(22,278)
—
(22,278)
(86,459)
—
(159,000)
(395,455)
245,459
—
— (395,455)
—
103,384
—
34,831
(103,384)
64
—
—
—
34,831
—
64
—
16,925
(644,507)
245,459 (382,123)
—
—
—
(11,520)
3
—
—
—
3
(11,520)
967
—
(59,866)
—
(350,000)
—
—
(143,612)
—
967
—
— (493,612)
(50,924)
8,942
—
(8,000)
—
—
(8,000)
45,500
—
—
—
610,000
(610,000)
—
—
(40,000)
—
600,000
(162,500)
—
—
—
—
—
(4,732)
—
159,000
—
—
(45,500)
1,500
(1,500)
—
—
40,000
(1,687)
(6,211)
86,458
(41,480)
—
—
—
— 611,500
— (611,500)
— 600,000
— (162,500)
—
—
(1,687)
—
—
(245,458)
41,480
—
(6,211)
—
—
(4,732)
(58,131)
226,980
(112,029)
(195,036) (138,216)
—
—
(2,003)
—
(2,003)
275
10,167
(879)
—
9,563
873
1,148 $
10
10,177 $
253,647
252,768 $
— 254,530
— $ 264,093
103
Year Ended December 31, 2015
Nabors
(Parent/
Nabors
Delaware
(Issuer/
Other
Subsidiaries
(Non-
Consolidating
Guarantor) Guarantor) Guarantors) Adjustments
Total
Net cash provided by (used for)
operating activities ....................................... $
Cash flows from investing activities:
Purchases of investments ........................
Sales and maturities of investments ........
Proceeds from merger transaction ...........
Cash paid for acquisition of businesses,
net of cash acquired .................................
Investment in unconsolidated
affiliates ...................................................
Capital expenditures ................................
Proceeds from sales of assets and
insurance claims ......................................
Changes in intercompany balances .........
Other .......................................................
Net cash provided by (used for) investing
activities .......................................................
Cash flows from financing activities:
Increase (decrease) in cash overdrafts .....
Proceeds from short-term borrowings .....
Debt issuance costs ..................................
Proceeds from (payments for) issuance
of common shares....................................
Reduction in long-term debt ....................
Proceeds from term loan .........................
Payments on term loan ............................
Dividends to shareholders .......................
Proceeds from (payments for)
commercial paper, net .............................
Cash proceeds from non-controlling
interest .....................................................
Reduction in revolving credit facilities ...
Repurchase of common shares ................
Proceeds (issuance) of intercompany
debt ..........................................................
Paydown of intercompany debt ...............
Payments on parent (Equity of N/P) ........
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 ...................................................
Cash and cash equivalents, beginning of
period ...........................................................
Cash and cash equivalents, end of period .... $
(In thousands)
39,478 $ (217,685) $ 1,066,026 $
(31,263) $ 856,556
—
—
5,500
—
—
646,078
(9)
961
(1,528)
—
—
—
(9)
961
650,050
—
—
—
—
—
—
—
—
—
—
135,518
—
(80,187)
—
(80,187)
(445)
(867,106)
68,206
(135,518)
1,081
—
—
(445)
(867,106)
—
—
—
68,206
—
1,081
5,500
781,596
(1,014,545)
—
(227,449)
—
—
—
—
—
(1,847)
1,296
—
—
—
(79,304)
—
—
625,000
(300,000)
—
645
318
—
—
(27,478)
—
—
—
—
—
—
645
318
(1,847)
—
—
—
—
9,941
1,296
(27,478)
625,000
(300,000)
(69,363)
—
(525,119)
—
—
(525,119)
—
—
—
—
(450,000)
—
67,500
(27,000)
—
(7,767)
88,058
—
—
—
3,972
—
(99,598)
(155,558)
27,000
(21,322)
—
—
—
—
3,972
(450,000)
(99,598)
—
—
21,322
—
—
—
—
(7,767)
(45,275)
(563,908)
(272,021)
31,263
(849,941)
—
—
(25,785)
—
(25,785)
(297)
3
(246,325)
—
(246,619)
1,170
873 $
7
10 $
499,972
253,647 $
—
501,149
— $ 254,530
104
Note 23 Subsequent Events
On February 23, 2018, our Board declared a cash dividend of $0.06 per common share, which will be paid on
April 3, 2018 to shareholders of record at the close of business on March 13, 2018.
On January 16 2018, Nabors Delaware completed an offering of $800 million aggregate principal amount of
5.75% senior unsecured notes due February 1, 2025, which are fully and unconditionally guaranteed by us. The proceeds
from this offering were used to repay indebtedness of Nabors and its subsidiaries, including all of Nabors Delaware’s
outstanding 6.15% senior notes due February 2018.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
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, 2017, 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.
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
105
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, 2017.
PricewaterhouseCoopers LLP has issued a report on the effectiveness of the Company’s internal control over
financial reporting as of December 31, 2017, 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,
2017 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over
financial reporting.
ITEM 9B. OTHER INFORMATION
Not applicable.
106
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
The information called for by this item will be contained in the definitive Proxy Statement to be distributed in
connection with our 2018 annual general meeting of shareholders under the captions “Election of 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 28, 2017, 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 our definitive Proxy Statement to be distributed in
connection with our 2018 annual general meeting of shareholders under the caption “Executive Compensation” 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.
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 2018 annual general meeting of shareholders under the caption “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
The information called for by this item will be contained in our definitive Proxy Statement to be distributed in
connection with our 2018 annual general meeting of shareholders under the caption “Certain Relationships and Related
Transactions” and 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 2018 annual general meeting of shareholders under the caption “Independent Auditor Fees” and is
incorporated into this document by reference.
107
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, 2017 and 2016 ....................................................................
Consolidated Statement of Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015 ..............
Consolidated Statement of Comprehensive Income (Loss) for the Years Ended December 31,
Page No.
47
48
49
2017, 2016 and 2015 ......................................................................................................................................
Consolidated Statement of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015 ..................
Consolidated Statement of Changes in Equity for the Years Ended December 31, 2017, 2016 and 2015 .......
Notes to Consolidated Financial Statements .....................................................................................................
50
51
52
(2)
Financial Statement Schedule
Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2017, 2016 and 2015 .....
Page No.
109
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.
108
SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2017, 2016 and 2015
Balance at
Beginning
of Period
Charged to
Costs and
Other
Deductions Accounts
Charged to
Other
Balance at
End of
Period
Deductions
(In thousands)
2017
43,757
Allowance for doubtful accounts ..................... $
Inventory reserve.............................................. $
26,537
Valuation allowance on deferred tax assets ..... $ 1,807,728
2016
44,553
Allowance for doubtful accounts ..................... $
Inventory reserve.............................................. $
46,813
Valuation allowance on deferred tax assets ..... $ 1,560,162
2015
23,545
Allowance for doubtful accounts ..................... $
Inventory reserve.............................................. $
45,141
Valuation allowance on deferred tax assets ..... $ 1,537,507
2,544
5,897
—
86
—
61,762
(2,011) $
(3,500) $
44,376
28,934
— $ 1,869,490
19,132
13,587
—
36,720
9,485
—
(58)
—
247,566
(19,870) $
(33,863) $
43,757
26,537
— $ 1,807,728
(288)
—
22,655
(15,424) $
(7,813) $
44,553
46,813
— $ 1,560,162
109
Exhibit No.
Description
Exhibit Index
2.1
2.2
2.3
2.4
2.5
3.1
3.2
4.1
4.2
4.3
4.4
4.5
Agreement and Plan of Merger, dated as of June 25, 2014, by and among Nabors Industries Ltd.,
Nabors Red Lion Limited and C&J Energy Services, Inc. (incorporated by reference to Exhibit 10.1
to our Form 8-K (File No. 001-32657) filed with the SEC on July 1, 2014).
Separation Agreement, dated as of June 25, 2014, by and between Nabors Industries Ltd. and Nabors
Red Lion Limited (incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-32657)
filed with the SEC on July 1, 2014).
Amendment No. 1 to the Agreement and Plan of Merger, by and among Nabors Industries Ltd.,
Nabors Red Lion Limited, C&J Energy Services, Inc., Nabors Merger Co. and CJ Holding Co.
(incorporated by reference to Exhibit 10.2 of our Form 8-K (File No. 001-32657) filed with the SEC
on February 9, 2015).
Amendment No. 1 to the Separation Agreement, by and between Nabors Industries Ltd. and Nabors
Red Lion Limited (incorporated by reference to Exhibit 10.1 of our Form 8-K (File No. 001-32657)
filed with the SEC on February 9, 2015).
Arrangement Agreement, dated August 13, 2017, by and among Nabors Industries Ltd., Nabors
Maple Acquisition Ltd., and Tesco Corporation (incorporated by reference to Exhibit 2.1 to our Form
8-K (File No. 001-32657) filed with the SEC on August 16, 2017).
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).
Amended and Restated Bye-laws of Nabors Industries Ltd. (incorporated by reference to Exhibit 3.2
to our Form S-8 (File No. 333-212781) filed with the SEC on July 29, 2016).
Indenture, dated February 20, 2008, among Nabors Industries, Inc., Nabors Industries Ltd. and Wells
Fargo Bank, N.A. (incorporated by reference to Exhibit 4.2 to Nabors Industries Ltd.’s Current
Report on Form 8-K (File No. 001-32657) filed with the Commission on February 25, 2008).
Indenture, dated as of January 12, 2009, among Nabors Industries, Inc., Nabors Industries Ltd. and
Wells Fargo Bank, National Association, as trustee, with respect to Nabors Industries, Inc.’s 9.25%
Senior Notes due 2019 (including form of 9.25% Senior Note due 2019) (incorporated by reference
to Exhibit 4.2 to our Form 8-K (File No. 001-32657) filed with the SEC on January 14, 2009).
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).
110
Exhibit No.
4.6
4.7
4.8
4.9
10.1
10.2
10.3
10.4
10.5
10.6
10.7(+)
10.7(a)(+)
10.7(b)(+)
Description
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).
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).
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).
Registration Rights Agreement relating to the 5.75% Senior Notes due 2025, dated as of January 23,
2018, by and among Nabors Industries, Inc. and the certain holders identified therein (incorporated
by reference to Exhibit 4.2 to Nabors Industries Ltd.’s Form 8-K (file No. 001-32657) filed with the
Commission on January 23, 2018).
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).
Purchase Agreement, dated January 16, 2018, among Nabors Industries, Inc., Nabors Industries Ltd.
and Goldman Sachs & Co. LLC, Citigroup Global Markets Inc., Deutsche Bank Securities Inc.,
Morgan Stanley & Co. LLC and Wells Fargo Securities, LLC as Initial Purchasers (incorporated by
reference to Exhibit 10.1 to Nabors Industries Ltd.’s Form 8-K (File No. 001-32657) filed with the
Commission on January 17, 2018).
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).
Call Option Transaction Confirmation, dated as of January 9, 2017, between Nabors Industries Ltd.,
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).
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).
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).
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).
First Amendment to Executive Employment Agreement, dated December 19, 2014, 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 December 19, 2014).
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).
111
Exhibit No.
10.7(c)(+)
10.7(d)(+)
10.8(+)
10.8(a)(+)
10.8(b)(+)
10.8(c)(+)
10.8(d)(+)
10.9(+)
10.10(+)
10.10(a)(+)
10.10(b)(+)
10.10(c)(+)
10.10(d)(+)
10.10(e)(+)
10.10(f)(+)
10.10(g)(+)
Description
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).
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).
Executive Employment Agreement, by and among Nabors Industries Ltd., Nabors Industries, Inc. and
William Restrepo, effective as of March 31, 2014 (incorporated by reference to Exhibit 10.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on March 4, 2014).
First Amendment to Executive Employment Agreement, dated December 19, 2014, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to
Exhibit 99.2 to our Form 8-K (File No. 001-32657) filed with the SEC on December 19, 2014).
Second Amendment to Executive Employment Agreement, dated as of June 5, 2015, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to
Exhibit 99.2 to our Form 8-K (File No. 001-32657) filed with the SEC on June 8, 2015).
Third Amendment to Executive Employment Agreement, dated as of December 31, 2015, among
Nabors Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to
Exhibit 99.2 to our Form 8-K (File No. 001-32657) filed with the SEC on January 5, 2016).
Fourth Amendment to Executive Employment Agreement, dated June 10, 2016, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to Exhibit
99.2 to our Form 8-K (File No. 001-32657) filed with the SEC on June 13, 2016).
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).
Nabors Industries Ltd. 2016 Stock Plan (incorporated by reference to Exhibit 99.1 to our Form S-8
(File No. 333-212781) filed with the SEC on July 29, 2016).
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).
Form of Restricted Stock Agreement – Others, pursuant to the 2016 Stock Plan (incorporated by
reference to Exhibit 10.1(c) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28,
2017).
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).
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).
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).
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).
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).
112
Exhibit No.
10.10(h)(+)
10.10(i)(+)
10.10(j)(+)
10.11(+)
10.11(a)(+)
10.11(b)(+)
10.11(c)(+)
10.11(d)(+)
10.11(e)(+)
10.11(f)(+)
10.11(g)(+)
10.11(h)(+)
10.11(i)(+)
10.12(+)
10.12(a)(+)
10.12(b)(+)
10.12(c)(+)
10.13(+)
Description
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).
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).
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).
Nabors Industries Ltd. 2013 Stock Plan (incorporated by reference to Appendix B of Nabors
Industries Ltd.’s Definitive Proxy Statement on Schedule 14A (File No. 001-32657) filed with the
SEC on April 30, 2013).
Form of Stock Option Agreement—Others, pursuant to the 2013 Stock Plan (incorporated by
reference to Exhibit 10.8(a) to our Form 10-K (File No. 001-32657) filed with the SEC on March 3,
2014).
Form of Restricted Stock Agreement—Others, pursuant to the 2013 Stock Plan (incorporated by
reference to Exhibit 10.8(b) to our Form 10-K (File No. 001-32657) filed with the SEC on March 3,
2014).
Form of Restricted Stock Agreement—Directors, pursuant to the 2013 Stock Plan (incorporated by
reference to Exhibit 10.8(c) to our Form 10-K (File No. 001-32657) filed with the SEC on March 3,
2014).
Form of TSR Stock Grant Agreement—Anthony G. Petrello, pursuant to the 2013 Stock Plan
(incorporated by reference to Exhibit 10.8(d) to our Form 10-K (File No. 001-32657) filed with the
SEC on March 3, 2014).
Form of Nabors Industries Ltd. Restricted Stock Agreement—Anthony G. Petrello, pursuant to the
2013 Stock Plan (incorporated by reference to Exhibit 10.8(e) to our Form 10-K (File No. 001-
32657) filed with the SEC on March 3, 2014).
Form of Nabors Corporate Services, Inc. Restricted Stock Agreement—Anthony G. Petrello,
pursuant to the 2013 Stock Plan (incorporated by reference to Exhibit 10.8(f) to our Form 10-K (File
No. 001-32657) filed with the SEC on March 3, 2014).
Form of TSR Stock Grant Agreement—William Restrepo, pursuant to the 2013 Stock Plan
(incorporated by reference to Exhibit 10.1 to the Form 10-Q (File No. 001-32657) filed with the SEC
on May 9, 2014).
Form of Nabors Industries Ltd. Restricted Stock Agreement—William Restrepo, pursuant to the 2013
Stock Plan (incorporated by reference to Exhibit 10.1 to the Form 10-Q (File No. 001-32657) filed
with the SEC on May 9, 2014).
Form of Nabors Corporate Services, Inc. Restricted Stock Agreement—William Restrepo, pursuant
to the 2013 Stock Plan (incorporated by reference to Exhibit 10.3 to the Form 10-Q (File No. 001-
32657) filed with the SEC on May 9, 2014).
Form of Restricted Stock Award—Isenberg/Petrello (incorporated by reference to Exhibit 10.01 to
Nabors Industries Ltd.’s Form 8-K, File No. 000-49887, filed March 2, 2005).
Form of Restricted Stock Award—Others (incorporated by reference to Exhibit 10.02 to Nabors
Industries Ltd.’s Form 8-K, File No. 000-49887, filed March 2, 2005).
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).
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).
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).
113
Exhibit No.
10.14(+)
10.14(a)(+)
10.15(+)
10.15(a)
10.16(+)
Description
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).
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).
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).
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).
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).
12 Computation of Ratios.*
21 Significant Subsidiaries.*
23.1
31.1
Consent of Independent Registered Public Accounting Firm—PricewaterhouseCoopers LLP—
Houston.*
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.*
101.INS XBRL Instance Document*
101.SCH XBRL Schema Document*
101.CAL XBRL Calculation Linkbase Document*
101.LAB XBRL Label Linkbase Document*
101.PRE XBRL Presentation Linkbase Document*
101.DEF XBRL Definition Linkbase Document*
* Filed herewith.
(+) Management contract or compensatory plan or arrangement.
114
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:
March 1, 2018
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
Chairman, President and Chief Executive
March 1, 2018
/s/ ANTHONY G. PETRELLO
Anthony G. Petrello
Officer
/s/ WILLIAM RESTREPO
William Restrepo
/s/ TANYA S. BEDER
Tanya S. Beder
/s/ JAMES R. CRANE
James R. Crane
/s/ MICHAEL C. LINN
Michael C. Linn
/s/ JOHN P. KOTTS
John P. Kotts
/s/ DAG SKATTUM
Dag Skattum
/s/ JOHN YEARWOOD
John Yearwood
Chief Financial Officer
March 1, 2018
March 1, 2018
March 1, 2018
March 1, 2018
March 1, 2018
March 1, 2018
March 1, 2018
Director
Director
Director
Director
Director
Director
115
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K/A
Amendment No. 1
(Mark One)
(cid:95) ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2017
(cid:134) 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)
980363970
(I.R.S. Employer
Identification No.)
N/A
(Zip Code)
(441) 292-1510
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:
Title of each class
Common shares, $.001 par value per share
Name of each exchange on which registered
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:95) NO (cid:134)
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:134) NO (cid:95)
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:95) NO (cid:134)
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to
be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to file such
reports). YES (cid:95) NO (cid:134)
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:95)
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:95)
Non-accelerated Filer (cid:134)
(Do not check if a smaller reporting company)
Accelerated Filer (cid:134)
Smaller Reporting Company (cid:134)
Emerging Growth Company (cid:134)
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or
revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. (cid:134)
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES (cid:134) NO (cid:95)
The aggregate market value of the 189,149,782 common shares held by non-affiliates of the registrant outstanding as of the last business day of our most
recently completed second fiscal quarter, June 30, 2017, based on the closing price of our common shares as of such date of $8.14 per share as reported on the New
York Stock Exchange, was $1,539,679,225. Common shares held by each officer and director and by each person who owns 5% or more of the outstanding common
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.
The number of common shares outstanding as of February 22, 2018 was 315,538,146, excluding 52,800,203 common shares held by our subsidiaries, or
368,338,349 in the aggregate.
DOCUMENTS INCORPORATED BY REFERENCE
Specified portions of the definitive Proxy
Statement to be distributed in connection with our 2018 Annual General Meeting of Shareholders (Part III).
NABORS INDUSTRIES LTD.
Form 10-K/A
For the Year Ended December 31, 2017
Explanatory Note
This Amendment No.1 on Form 10-K/A (this “Amendment”) is being filed to amend our Annual Report on
Form 10-K for the year ended December 31, 2017, originally filed with the Securities and Exchange Commission on
March 1, 2018 (the “Original Filing”). We are filing this Amendment solely to revise the selected financial information
included in Part II, Item 6.—Selected Financial Data for the operating data for the years ended December 31, 2014 and
2013 and balance sheet data as of December 31, 2015, 2014 and 2013 in the Original Filing. As required by Rule 12b-15
of the Securities and Exchange Act of 1934, as amended, the Company is also filing as exhibits to this Amendment the
required certifications of the Company’s principal executive and principal financial officers.
Except as described above, this Amendment does not amend any information set forth in the Original Filing and
we have not updated disclosures contained therein to reflect any events that occurred on a date subsequent to the date of
the Original Filing.
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)
2017
Three Months Ended December 31,
2015
(In thousands, except per share amounts and ratio data)
2014
2016
2013
Operating revenues . . . . . . . . . . . . . . . . . . . . . . $ 2,564,285 $ 2,227,839 $ 3,864,437 $ 6,804,197 $ 6,152,015
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 . . . . .
(18,363)
(1,029,607)
(135)
(1,029,742)
(42,797)
(372,294)
(6,178)
(546,811)
(381)
(372,675)
(43,519)
(540,633)
(1,415)
(670,659)
21
(669,244)
(11,179)
147,162
(7,180)
139,982
(1,011,244)
(329,497)
(497,114)
(669,265)
158,341
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:
(1.75) $
(0.15)
(1.90) $
(1.75) $
(0.15)
(1.90) $
(3.58) $
(0.06)
(3.64) $
(3.58) $
(0.06)
(3.64) $
(1.14) $
(0.15)
(1.29) $
(1.14) $
(0.15)
(1.29) $
(2.28) $
—
(2.28) $
(2.28) $
—
(2.28) $
0.51
(0.04)
0.47
0.51
(0.04)
0.47
Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
280,653
280,653
276,475
276,475
282,982
282,982
290,694
290,694
294,182
296,592
Capital expenditures and acquisitions of
businesses (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 600,909 $
Interest coverage ratio (4) . . . . . . . . . . . . . . . . .
2.4:1
414,379 $ 923,236 $ 1,923,779 $ 1,365,994
7.4:1
3.4:1
6.2:1
9.8:1
Balance Sheet Data (1)(2)
2017
2016
2015
2014
2013
(In thousands, except ratio data)
As of December 31,
Cash, cash equivalents and short-term
investments . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 365,366 $ 295,202 $ 274,589 $
Working capital . . . . . . . . . . . . . . . . . . . . . . . . .
Property, plant and equipment, net. . . . . . . . . .
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . .
Shareholders’ equity . . . . . . . . . . . . . . . . . . . . .
Debt to capital ratio:
469,398
7,027,802
9,537,840
3,655,200
4,282,710
333,905
6,267,583
8,187,015
3,578,335
3,247,025
527,860
6,109,565
8,401,984
4,027,766
2,911,816
536,169 $
1,174,399
8,599,125
11,862,923
4,331,840
4,908,619
507,133
1,442,406
8,597,813
12,137,749
3,882,055
5,969,086
Gross (5) . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Net (6) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
0.58:1
0.56:1
0.52:1
0.50:1
0.46:1
0.44:1
0.47:1
0.43:1
0.39:1
0.36:1
(1)
(2)
(3)
(4)
(5)
(6)
All periods present the operating activities of most of our wholly owned oil and gas businesses, our previously
held equity interests in oil and gas joint ventures in Canada and Colombia, aircraft logistics operations and
construction services as discontinued operations.
Our acquisitions’ results of operations and financial position have been included beginning on the respective
dates of acquisition and include RDS (September 2017), Tesco (December 2017), Nabors Arabia (May 2015),
2TD (October 2014), KVS (October 2013) and Navigate Energy Services, Inc. (January 2013). 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.
Represents capital expenditures and the total purchase price of acquisitions.
The interest coverage ratio is a trailing 12-month quotient of the sum of (x) operating revenues, direct costs,
general and administrative expenses and research and engineering expenses divided by (y) interest expense. The
interest coverage ratio is not a measure of operating performance or liquidity defined by generally accepted
accounting principles in the United States of America (“U.S. GAAP”) and may not be comparable to similarly
titled measures presented by other companies.
The gross debt to capital ratio is calculated by dividing total debt by total capitalization (total debt plus
shareholders’ equity). The gross debt to capital ratio is not a measure of operating performance or liquidity
defined by U.S. GAAP and may not be comparable to similarly titled measures presented by other companies.
The net debt to capital ratio is calculated by dividing net debt by net capitalization. Net debt is defined as total
debt minus the sum of cash and cash equivalents and short-term investments. Net capitalization is defined as net
debt plus shareholders’ equity. The net debt to capital ratio is not a measure of operating performance or
liquidity defined by U.S. GAAP and may not be comparable to similarly titled measures presented by other
companies.
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, 2017 and 2016 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statement of Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015 . . . . . . . . . .
Consolidated Statement of Comprehensive Income (Loss) for the Years Ended December 31, 2017, 2016
and 2015 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated Statement of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015 . . . . . . . . . . . .
Consolidated Statement of Changes in Equity for the Years Ended December 31, 2017, 2016 and 2015 . . . . . . .
Notes to Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
(2)
Financial Statement Schedule
Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2017, 2016 and 2015 . . .
Page No.
*
*
*
*
*
*
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.
*
Previously filed as part of the Original Filing.
(b)
Exhibit Index
Exhibit No.
2.1
2.2
2.3
2.4
2.5
3.1
3.2
4.1
4.2
Description
Agreement and Plan of Merger, dated as of June 25, 2014, by and among Nabors Industries Ltd., Nabors
Red Lion Limited and C&J Energy Services, Inc. (incorporated by reference to Exhibit 10.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on July 1, 2014).
Separation Agreement, dated as of June 25, 2014, by and between Nabors Industries Ltd. and Nabors
Red Lion Limited (incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-32657) filed
with the SEC on July 1, 2014).
Amendment No. 1 to the Agreement and Plan of Merger, by and among Nabors Industries Ltd., Nabors
Red Lion Limited, C&J Energy Services, Inc., Nabors Merger Co. and CJ Holding Co. (incorporated by
reference to Exhibit 10.2 of our Form 8-K (File No. 001-32657) filed with the SEC on February 9, 2015).
Amendment No. 1 to the Separation Agreement, by and between Nabors Industries Ltd. and Nabors Red
Lion Limited (incorporated by reference to Exhibit 10.1 of our Form 8-K (File No. 001-32657) filed with
the SEC on February 9, 2015).
Arrangement Agreement, dated August 13, 2017, by and among Nabors Industries Ltd., Nabors Maple
Acquisition Ltd., and Tesco Corporation (incorporated by reference to Exhibit 2.1 to our Form 8-K
(File No. 001-32657) filed with the SEC on August 16, 2017).
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).
Amended and Restated Bye-laws of Nabors Industries Ltd. (incorporated by reference to Exhibit 3.2 to
our Form S-8 (File No. 333-212781) filed with the SEC on July 29, 2016).
Indenture, dated February 20, 2008, among Nabors Industries, Inc., Nabors Industries Ltd. and Wells
Fargo Bank, N.A. (incorporated by reference to Exhibit 4.2 to Nabors Industries Ltd.’s Current Report on
Form 8-K (File No. 001-32657) filed with the Commission on February 25, 2008).
Indenture, dated as of January 12, 2009, among Nabors Industries, Inc., Nabors Industries Ltd. and Wells
Fargo Bank, National Association, as trustee, with respect to Nabors Industries, Inc.’s 9.25% Senior
Notes due 2019 (including form of 9.25% Senior Note due 2019) (incorporated by reference to
Exhibit 4.2 to our Form 8-K (File No. 001-32657) filed with the SEC on January 14, 2009).
Exhibit No.
4.3
4.4
4.5
4.6
4.7
4.8
4.9
10.1
10.2
10.3
10.4
10.5
10.6
10.7(+)
Description
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).
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).
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).
Registration Rights Agreement relating to the 5.75% Senior Notes due 2025, dated as of January 23,
2018, by and among Nabors Industries, Inc. and the certain holders identified therein (incorporated by
reference to Exhibit 4.2 to Nabors Industries Ltd.’s Form 8-K (file No. 001-32657) filed with the
Commission on January 23, 2018).
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).
Purchase Agreement, dated January 16, 2018, among Nabors Industries, Inc., Nabors Industries Ltd. and
Goldman Sachs & Co. LLC, Citigroup Global Markets Inc., Deutsche Bank Securities Inc., Morgan
Stanley & Co. LLC and Wells Fargo Securities, LLC as Initial Purchasers (incorporated by reference to
Exhibit 10.1 to Nabors Industries Ltd.’s Form 8-K (File No. 001-32657) filed with the Commission on
January 17, 2018).
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).
Call Option Transaction Confirmation, dated as of January 9, 2017, between Nabors Industries Ltd.,
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).
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).
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).
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).
Exhibit No.
10.7(a)(+)
10.7(b)(+)
10.7(c)(+)
10.7(d)(+)
10.8(+)
10.8(a)(+)
10.8(b)(+)
10.8(c)(+)
10.8(d)(+)
10.9(+)
10.10(+)
10.10(a)(+)
10.10(b)(+)
10.10(c)(+)
10.10(d)(+)
10.10(e)(+)
10.10(f)(+)
10.10(g)(+)
10.10(h)(+)
Description
First Amendment to Executive Employment Agreement, dated December 19, 2014, 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 December 19, 2014).
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).
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).
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).
Executive Employment Agreement, by and among Nabors Industries Ltd., Nabors Industries, Inc. and
William Restrepo, effective as of March 31, 2014 (incorporated by reference to Exhibit 10.1 to our
Form 8-K (File No. 001-32657) filed with the SEC on March 4, 2014).
First Amendment to Executive Employment Agreement, dated December 19, 2014, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to Exhibit 99.2
to our Form 8-K (File No. 001-32657) filed with the SEC on December 19, 2014).
Second Amendment to Executive Employment Agreement, dated as of June 5, 2015, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to Exhibit 99.2
to our Form 8-K (File No. 001-32657) filed with the SEC on June 8, 2015).
Third Amendment to Executive Employment Agreement, dated as of December 31, 2015, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to Exhibit 99.2
to our Form 8-K (File No. 001-32657) filed with the SEC on January 5, 2016).
Fourth Amendment to Executive Employment Agreement, dated June 10, 2016, among Nabors
Industries Ltd., Nabors Industries, Inc. and William Restrepo (incorporated by reference to Exhibit 99.2
to our Form 8-K (File No. 001-32657) filed with the SEC on June 13, 2016).
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).
Nabors Industries Ltd. 2016 Stock Plan (incorporated by reference to Exhibit 99.1 to our Form S-8
(File No. 333-212781) filed with the SEC on July 29, 2016).
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).
Form of Restricted Stock Agreement — Others, pursuant to the 2016 Stock Plan (incorporated by
reference to Exhibit 10.1(c) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28,
2017).
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).
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).
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).
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).
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).
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).
Exhibit No.
10.10(i)(+)
10.10(j)(+)
10.11(+)
10.11(a)(+)
10.11(b)(+)
10.11(c)(+)
10.11(d)(+)
10.11(e)(+)
10.11(f)(+)
10.11(g)(+)
10.11(h)(+)
10.11(i)(+)
10.12(+)
10.12(a)(+)
10.12(b)(+)
10.12(c)(+)
10.13(+)
10.14(+)
10.14(a)(+)
10.15(+)
10.15(a)
Description
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).
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).
Nabors Industries Ltd. 2013 Stock Plan (incorporated by reference to Appendix B of Nabors
Industries Ltd.’s Definitive Proxy Statement on Schedule 14A (File No. 001-32657) filed with the SEC
on April 30, 2013).
Form of Stock Option Agreement—Others, pursuant to the 2013 Stock Plan (incorporated by reference
to Exhibit 10.8(a) to our Form 10-K (File No. 001-32657) filed with the SEC on March 3, 2014).
Form of Restricted Stock Agreement—Others, pursuant to the 2013 Stock Plan (incorporated by
reference to Exhibit 10.8(b) to our Form 10-K (File No. 001-32657) filed with the SEC on March 3,
2014).
Form of Restricted Stock Agreement—Directors, pursuant to the 2013 Stock Plan (incorporated by
reference to Exhibit 10.8(c) to our Form 10-K (File No. 001-32657) filed with the SEC on March 3,
2014).
Form of TSR Stock Grant Agreement—Anthony G. Petrello, pursuant to the 2013 Stock Plan
(incorporated by reference to Exhibit 10.8(d) to our Form 10-K (File No. 001-32657) filed with the SEC
on March 3, 2014).
Form of Nabors Industries Ltd. Restricted Stock Agreement—Anthony G. Petrello, pursuant to the 2013
Stock Plan (incorporated by reference to Exhibit 10.8(e) to our Form 10-K (File No. 001-32657) filed
with the SEC on March 3, 2014).
Form of Nabors Corporate Services, Inc. Restricted Stock Agreement—Anthony G. Petrello, pursuant to
the 2013 Stock Plan (incorporated by reference to Exhibit 10.8(f) to our Form 10-K (File No. 001-32657)
filed with the SEC on March 3, 2014).
Form of TSR Stock Grant Agreement—William Restrepo, pursuant to the 2013 Stock Plan (incorporated
by reference to Exhibit 10.1 to the Form 10-Q (File No. 001-32657) filed with the SEC on May 9, 2014).
Form of Nabors Industries Ltd. Restricted Stock Agreement—William Restrepo, pursuant to the 2013
Stock Plan (incorporated by reference to Exhibit 10.1 to the Form 10-Q (File No. 001-32657) filed with
the SEC on May 9, 2014).
Form of Nabors Corporate Services, Inc. Restricted Stock Agreement—William Restrepo, pursuant to
the 2013 Stock Plan (incorporated by reference to Exhibit 10.3 to the Form 10-Q (File No. 001-32657)
filed with the SEC on May 9, 2014).
Form of Restricted Stock Award—Isenberg/Petrello (incorporated by reference to Exhibit 10.01 to
Nabors Industries Ltd.’s Form 8-K, File No. 000-49887, filed March 2, 2005).
Form of Restricted Stock Award—Others (incorporated by reference to Exhibit 10.02 to Nabors
Industries Ltd.’s Form 8-K, File No. 000-49887, filed March 2, 2005).
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).
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).
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).
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).
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).
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).
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).
Exhibit No.
10.16(+)
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).
Description
12 Computation of Ratios.**
Significant Subsidiaries.**
21
Consent of Independent Registered Public Accounting Firm—PricewaterhouseCoopers LLP—
23.1
Houston.**
Rule 13a-14(a)/15d-14(a) Certification of Anthony G. Petrello, Chairman, President and Chief Executive
Officer.**
Rule 13a-14(a)/15d-14(a) Certification of Anthony G. Petrello, Chairman, President and Chief Executive
Officer.*
31.1
31.1(a)
31.2 Rule 13a-14(a)/15d-14(a) Certification of William Restrepo, Chief Financial Officer.**
31.2(a) 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.**
101.INS XBRL Instance Document**
101.SCH XBRL Schema Document**
101.CAL XBRL Calculation Linkbase Document**
101.LAB XBRL Label Linkbase Document**
101.PRE XBRL Presentation Linkbase Document**
101.DEF XBRL Definition Linkbase Document**
*
**
Filed herewith.
Previously filed with the Original Filing.
(+)
Management contract or compensatory plan or arrangement.
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/ WILLIAM RESTREPO
William Restrepo
Chief Financial Officer
(Principal Financial Officer and Accounting Officer)
Date: March 29, 2018
Reconciliation of Non-GAAP Measures
2016
4Q
2017
4Q
$
$
Adjusted EBITDA:
Drilling & Rig Technologies:
U.S.
Canada
International
Drilling Solutions
Rig Technologies
Subtotal Drilling & Rig Technologies
Other reconciling items
Total adjusted EBITDA
Reconciliation of non-GAAP measures to GAAP:
Adjusted EBITDA
Depreciation and amortization
Operating income (loss)
Earnings (losses) from unconsolidated affiliates
Investment income (loss)
Other, net
Impairments and other charges
Income (loss) from continuing operations before income taxes
$
$
$
$
49,245
2,647
128,289
2,265
(1,351)
181,095
(35,074)
146,021
146,021
(216,187)
(70,166)
4
260
(17,599)
(257,671)
(392,729)
53,618
4,253
128,902
12,596
(4,292)
195,077
(32,520)
162,557
162,557
(214,106)
(51,549)
1
986
(6,827)
(23,416)
(137,881)
$
$
Income tax expense (benefit)
Subsidiary preferred stock dividend
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
(62,533)
(23,156)
-
(330,196)
(4,266)
(334,462)
(1,125)
(335,587)
$
-
(114,725)
(442)
(115,167)
(1,177)
(116,344)
$
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BOARD OF DIRECTORS
Anthony G. Petrello
Chairman, President & Chief Executive Officer
John Yearwood
Lead Director, Retired President,
CEO & COO of Smith International, Inc.
James R. Crane
Chairman & Chief Executive Officer,
Crane Capital Group, Inc.
John P. Kotts
CEO of J.P. Kotts & Co.
Michael C. Linn
President & CEO, MCL Ventures, LLC
Dag Skattum
Vice Chairman, Europe, the
Middle East & Africa, JPMorgan
Tanya S. Beder
Chairman & CEO of SBCC Group, Inc.
LEADERSHIP TEAM
Anthony G. Petrello
Chairman, President &
Chief Executive Officer
William Restrepo
Chief Financial Officer
Siggi Meissner
President, Global Drilling & Engineering
Christopher P. Papouras
President, Nabors Drilling Solutions
John Sanchez
Chief Operations Officer,
Canrig Drilling Technology
Dennis A. Smith
Vice President, Corporate Development
& Investor Relations
Mark D. Andrews
Corporate Secretary
Joe Bruce
President, Canada
Carina Lovato Gillenwater
Vice President, Human Resources
Sri Valleru
Vice President, Chief Information &
Procurement Officer
Steve Williams
Vice President, Risk Management, HSE & Quality
Clark Wood
Vice President & Chief Accounting Officer
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:
Dennis A. Smith
Vice President, Corporate Development &
Investor Relations
Independent Registered Public Accounting Firm
PricewaterhouseCoopers LLP
Houston, Texas
On April 6, 2018, the closing price of our common shares as reported on the NYSE was $6.69, and
there were approximately 2,094 shareholders of record of our common shares.
The common shares are listed on the New York Stock Exchange under the symbol “NBR.” The
following table sets forth the reported high and low sales prices of the common shares as reported
on the New York Stock Exchange for the calendar quarters indicated.
CALENDAR YEAR
STOCK PRICE
2016
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2017
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
HIGH
$9.84
$11.21
$12.33
$17.68
$18.40
$14.28
$8.70
$8.04
LOW
$4.93
$7.61
$8.46
$11.01
$11.89
$7.16
$6.18
$5.32
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.
Crown House
Second Floor
4 Par-la-Ville Road
Hamilton, Bermuda HM 08
W W W . N A B O R S . C O M