Nabors Industries (NBR) 10-K 2017 FY Annual report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10‑K

(Mark One)
☒	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2017
☐	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	Name of each exchange on which registered
Common shares, $.001 par value per share	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Securities Exchange Act of 1934: None.

Indicate by check mark whether the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.  YES ☒  NO ☐

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  YES ☐  NO ☒

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  YES ☒  NO ☐

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate 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 ☒  NO ☐

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non‑accelerated filer or a smaller reporting company. See 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 ☒ Accelerated Filer ☐ Non‑accelerated Filer ☐ (Do not check if a
smaller reporting company) Smaller Reporting Company ☐ Emerging Growth Company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐ 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  YES ☐  NO ☒

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
Item 1.	Business	4
Item 1A.	Risk Factors	11
Item 1B.	Unresolved Staff Comments	20
Item 2.	Properties	20
Item 3.	Legal Proceedings	20
Item 4.	Mine Safety Disclosures	21
PART II
Item 5.	Market Price of and Dividends on the Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity Securities	21
Item 6.	Selected Financial Data	24
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	26
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	41
Item 8.	Financial Statements and Supplementary Data	44
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	105
Item 9A.	Controls and Procedures	105
Item 9B.	Other Information	106
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	107
Item 11.	Executive Compensation	107
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters	107
Item 13.	Certain Relationships and Related Transactions and Director Independence	107
Item 14.	Principal Accounting Fees and Services	107
PART IV
Item 15.	Exhibits, Financial Statement Schedules	108
Item 16.	Form 10-K Summary	108

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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 equitysecurities;

· 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 inSaudi Arabia and recent acquisition of Tesco Corporation;

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· the recent changes in U.S. tax laws and the possibility of changes in other tax laws and otherlaws and regulations;

· 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

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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 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:

	Year Ended December 31,
	2017		2016		2015
	Average	Average	Average	Average	Average	Average
	Rigs Working	Utilization	Rigs Working	Utilization	Rigs Working	Utilization
U.S.	100.8	42%	62.0	24%	120.0	41%
Canada	15.4	30%	9.7	14%	16.7	25%
International	91.1	57%	100.2	62%	124.0	79%
	207.3	46%	171.9	35%	260.7	50%

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

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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.

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.

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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:

· 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

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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 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.

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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 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

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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.

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.

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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 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.

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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

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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.

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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;

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· 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

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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

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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.

		Share Price
Calendar Year		High		Low
2016	First Quarter	$	9.84	$	4.93
	Second Quarter		11.21		7.61
	Third Quarter		12.33		8.46
	Fourth Quarter		17.68		11.01
2017	First Quarter	$	18.40	$	11.89
	Second Quarter		14.28		7.16
	Third Quarter		8.70		6.18
	Fourth Quarter		8.04		5.32

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

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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				Total Payment
	2017		2016		2017			2016
	(in thousands, except per share amounts)
Quarter
First	$	0.06	$	0.06	$	17,154		$	16,923
Second		0.06		0.06		17,149			17,003
Third		0.06		0.06		17,153			17,001
Fourth		0.06		0.06		17,148	(1)		17,039	(2)

(1) This quarterly cash dividend was paid on January 3, 2018 to shareholders of record on December 13, 2017.

(2) 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:

					Approximated
				Total Number	Dollar Value of
				of Shares	Shares that May
	Total	Average		Purchased as	Yet Be
	Number of	Price		Part of Publicly	Purchased
Period	Shares	Paid per		Announced	Under the
(In thousands, except per share amounts)	Repurchased	Share (1)		Program	Program (2)
October 1 - October 31	<1	$	6.96	—	298,716
November 1 - November 30	6	$	5.85	—	298,716
December 1 - December 31	48	$	6.39	3,128	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

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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.

	2012	2013	2014	2015	2016	2017
Nabors Industries Ltd.	100	119	92	61	121	52
S&P 500 Index	100	132	151	153	171	208
Dow Jones Oil Equipment and Services Index	100	128	106	82	105	87
S&P MidCap 400 Index	100	134	147	143	173	201
Russell 3000 Index	100	134	150	151	170	206

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.

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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.

	Year Ended December 31,
	2017		2016		2015		2014		2013
Operating Data (1)(2)	(In thousands, except per share amounts and ratio data)
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		(497,114)		(1,011,244)		(329,497)		158,341		232,974
Income (loss) from discontinued operations, net of tax		(43,519)		(18,363)		(42,797)		(11,179)		(67,526)
Net income (loss)		(540,633)		(1,029,607)		(372,294)		147,162		165,448
Less: Net (income) loss attributable to noncontrolling interest		(6,178)		(135)		(381)		(7,180)		(621)
Net income (loss) attributable to Nabors		(546,811)		(1,029,742)		(372,675)		139,982		164,827
Earnings (losses) per share:
Basic from continuing operations	$	(1.75)	$	(3.58)	$	(1.14)	$	0.51	$	0.80
Basic from discontinued operations		(0.15)		(0.06)		(0.15)		(0.04)		(0.23)
Total Basic	$	(1.90)	$	(3.64)	$	(1.29)	$	0.47	$	0.57
Diluted from continuing operations	$	(1.75)	$	(3.58)	$	(1.14)	$	0.51	$	0.79
Diluted from discontinued operations		(0.15)		(0.06)		(0.15)		(0.04)		(0.23)
Total Diluted	$	(1.90)	$	(3.64)	$	(1.29)	$	0.47	$	0.56
Weighted-average number of common shares outstanding:
Basic		280,653		276,475		282,982		294,182		289,965
Diluted		280,653		276,475		282,982		296,592		292,323
Capital expenditures and acquisitions of businesses (3)	$	600,909	$	414,379	$	923,236	$	1,365,994	$	1,433,586
Interest coverage ratio (4)		2.4:1		3.4:1		6.2:1		9.8:1		7.4:1

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	As of December 31,
	2017		2016		2015		2014		2013
Balance Sheet Data (1)(2)	(In thousands, except ratio data)
Cash, cash equivalents and short-term investments	$	365,366	$	295,202	$	536,169	$	507,133	$	778,204
Working capital		527,860		333,905		1,174,399		1,442,406		2,000,475
Property, plant and equipment, net		6,109,565		6,267,583		8,599,125		8,597,813		8,712,088
Total assets		8,401,984		8,187,015		11,862,923		12,137,749		12,631,867
Long-term debt		4,027,766		3,578,335		4,331,840		3,882,055		4,355,181
Shareholders’ equity		2,911,816		3,247,025		4,908,619		5,969,086		5,944,929
Debt to capital ratio:
Gross (5)		0.58:1		0.52:1		0.47:1		0.39:1		0.42:1
Net (6)		0.56:1		0.50:1		0.43:1		0.36:1		0.38:1

(1) 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.

(2) 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.

(3) Represents capital expenditures and the total purchase price of acquisitions.

(4) 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.

(5) 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.

(6) 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.

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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

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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.

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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		2016 to 2017
	(In thousands, except percentages and rig activity)
U.S.
Operating revenues	$	805,223	$	554,072	$	251,151	45	%
Adjusted operating income (loss)	$	(213,877)	$	(197,710)	$	(16,167)	(8)	%
Average rigs working (1)		100.8		62.0		38.8	63	%
Canada
Operating revenues	$	82,929	$	51,472	$	31,457	61	%
Adjusted operating income (loss)	$	(22,262)	$	(36,818)	$	14,556	40	%
Average rigs working (1)		15.4		9.7		5.7	59	%
International
Operating revenues	$	1,474,060	$	1,508,890	$	(34,830)	(2)	%
Adjusted operating income (loss)	$	108,428	$	164,677	$	(56,249)	(34)	%
Average rigs working (1)		91.1		100.2		(9.1)	(9)	%
Drilling Solutions
Operating revenues	$	140,701	$	63,759	$	76,942	121	%
Adjusted operating income (loss)	$	16,738	$	(16,503)	$	33,241	201	%
Rig Technologies
Operating revenues	$	234,542	$	151,951	$	82,591	54	%
Adjusted operating income (loss)	$	(30,964)	$	(31,981)	$	1,017	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%,

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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.

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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

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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.

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Segment Results of Operations

The following tables set forth certain information with respect to our reportable segments and rig activity:

	Year Ended December 31,				Increase/(Decrease)
	2016		2015		2016 to 2015
U.S.
Operating revenues	$	554,072	$	1,256,989	$	(702,917)	(56)	%
Adjusted operating income (loss)	$	(197,710)	$	87,051	$	(284,761)	(327)	%
Average rigs working (1)		62.0		120.0		(58.0)	(48)	%
Canada
Operating revenues	$	51,472	$	137,494	$	(86,022)	(63)	%
Adjusted operating income (loss)	$	(36,818)	$	(7,029)	$	(29,789)	n/m	(2)
Average rigs working (1)		9.7		16.7		(7.0)	(42)	%
International
Operating revenues	$	1,508,890	$	1,862,393	$	(353,503)	(19)	%
Adjusted operating income (loss)	$	164,677	$	308,262	$	(143,585)	(47)	%
Average rigs working (1)		100.2		124.0		(23.8)	(19)	%
Drilling Solutions
Operating revenues	$	63,759	$	69,828	$	(6,069)	(9)	%
Adjusted operating income (loss)	$	(16,503)	$	(10,879)	$	(5,624)	(36)	%
Rig Technologies
Operating revenues	$	151,951	$	321,238	$	(169,287)	(53)	%
Adjusted operating income (loss)	$	(31,981)	$	(1,762)	$	(30,219)	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

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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.

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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:

	December 31,
	2017
	(In thousands)
Credit available	$	759,421
Less: Letters of credit outstanding, inclusive of financial and performance guarantees		153,489
Remaining availability	$	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

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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.

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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:

	Payments due by Period
	Total		< 1 Year			1-3 Years			3-5 Years			Thereafter
	(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)
Interest		638,311		177,664			277,541			142,425			40,681
Operating leases (6)		31,855		11,342			8,264			4,141			8,108
Purchase commitments (7)		215,540		213,873			1,667			—			—
Employment contracts (6)		4,552		4,252			300			—			—
Transportation and processing contracts (6)(8)		11,249		8,597			2,652			—			—

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) See Note 11—Debt in Part II, Item 8.—Financial Statements and Supplementary Data

(2) 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.

(3) 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.

(4) Represents the aggregate principal amount of Nabors Delaware’s 4.625% senior notes due September 2021.

(5) 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.

(6) See Note 17—Commitments and Contingencies in Part II, Item 8.—Financial Statements and Supplementary Data.

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(7) 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.

(8) 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

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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:

	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

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.

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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.

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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. 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						Effective
	Interest		Carrying		Fair		Interest		Carrying			Fair
	Rate		Value		Value		Rate		Value			Value
			(In thousands)						(In thousands)
6.15% senior notes due February 2018	6.27	%	$	460,762	$	462,674	6.40	%	$	827,539		$	865,300
9.25% senior notes due January 2019	9.77	%		303,489		321,028	9.33	%		303,489			337,443
5.00% senior notes due September 2020	5.43	%		669,846		670,757	5.21	%		669,540			689,211
4.625% senior notes due September 2021	4.76	%		695,108		665,003	4.75	%		694,868			708,765
5.50% senior notes due January 2023	5.85	%		600,000		584,850	5.85	%		600,000			627,000
5.10% senior notes due September 2023	5.28	%		346,576		325,844	5.26	%		346,448			348,613
0.75% senior exchangeable notes due January 2024	5.90	%		429,982		443,940	—	%		—			—
Term loan facility	—	%		—		—	1.76	%		162,500			162,500
Revolving credit facility	2.73	%		510,000		510,000	1.86	%		—			—
Commercial paper	1.87	%		40,000		40,000	1.16	%		—			—
Other	—	%		181		181	—	%		297			297
				4,055,944	$	4,024,277				3,604,681		$	3,739,129
Less: deferred financing costs				27,997						26,049
			$	4,027,947					$	3,578,632

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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-					Weighted-
					Average					Average
	Fair		Interest		Life	Fair		Interest		Life
	Value		Rates		(Years)	Value		Rates		(Years)
	(In thousands, except rates)
Cash and cash equivalents	$	336,997	0.49 - 1.50	%	—	$	264,093	0.24 - 0.69	%	—
Short-term investments:
Available-for-sale equity securities		28,359	—		—		31,097	—		—
Available-for-sale debt securities:
Mortgage-CMO debt securities		10	3.41 - 3.83	%	7.5		12	2.90 - 3.15	%	7.3
Total available-for-sale securities		28,369					31,109
Total short-term investments		28,369					31,109
Long-term investments		7,835	N/A				4,023	N/A
Total cash, cash equivalents, short-term and long-term investments	$	373,201				$	299,225

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.

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ITEM 8.  FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

INDEX

Report of Independent Registered Public Accounting Firm	45
Consolidated Balance Sheets as of December 31, 2017 and 2016	47
Consolidated Statements of Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015	48
Consolidated Statements of Comprehensive Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015	49
Consolidated Statements of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015	50
Consolidated Statements of Changes in Equity for the Years Ended December 31, 2017, 2016 and 2015	51
Notes to Consolidated Financial Statements	52

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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.

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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.

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NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

	December 31,
	2017		2016
	(In thousands, except per
	share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	336,997	$	264,093
Short-term investments		28,369		31,109
Accounts receivable, net		698,477		508,355
Inventory, net		166,307		103,595
Assets held for sale		37,052		76,668
Other current assets		180,134		172,019
Total current assets		1,447,336		1,155,839
Property, plant and equipment, net		6,109,565		6,267,583
Goodwill		173,226		166,917
Deferred income taxes		419,003		366,586
Other long-term assets		252,854		230,090
Total assets (1)	$	8,401,984	$	8,187,015
LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	181	$	297
Trade accounts payable		363,416		264,578
Accrued liabilities		533,044		543,248
Income taxes payable		22,835		13,811
Total current liabilities		919,476		821,934
Long-term debt		4,027,766		3,578,335
Other long-term liabilities		301,633		522,456
Deferred income taxes		10,338		9,495
Total liabilities (1)		5,259,213		4,932,220
Commitments and contingencies (Note 17)
Redeemable noncontrolling interest in subsidiary (Note 14)		203,998		—
Equity:
Shareholders’ equity:
Common shares, par value $0.001 per share:
Authorized common shares 800,000; issued 367,510 and 333,598, respectively		368		334
Capital in excess of par value		2,791,129		2,521,332
Accumulated other comprehensive income (loss)		11,185		(12,119)
Retained earnings		1,423,154		2,033,427
Less: treasury shares, at cost, 52,800 and 49,673 common shares, respectively		(1,314,020)		(1,295,949)
Total shareholders’ equity		2,911,816		3,247,025
Noncontrolling interest		26,957		7,770
Total equity		2,938,773		3,254,795
Total liabilities and equity	$	8,401,984	$	8,187,015

_____________________________

(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,
	2017		2016		2015
	(In thousands, except per share amounts)
Revenues and other income:
Operating revenues	$	2,564,285	$	2,227,839	$	3,864,437
Earnings (losses) from unconsolidated affiliates		7		(221,914)		(75,081)
Investment income (loss)		1,194		1,183		2,308
Total revenues and other income		2,565,486		2,007,108		3,791,664
Costs and other deductions:
Direct costs		1,718,069		1,344,298		2,371,436
General and administrative expenses		251,184		227,639		324,328
Research and engineering		51,069		33,582		41,253
Depreciation and amortization		842,943		871,631		970,459
Interest expense		222,889		185,360		181,928
Impairments and other charges		44,536		498,499		368,967
Other, net		14,880		44,174		(39,172)
Total costs and other deductions		3,145,570		3,205,183		4,219,199
Income (loss) from continuing operations before income taxes		(580,084)		(1,198,075)		(427,535)
Income tax expense (benefit):
Current		(102,080)		14,780		89,865
Deferred		19,110		(201,611)		(187,903)
Total income tax expense (benefit)		(82,970)		(186,831)		(98,038)
Income (loss) from continuing operations, net of tax		(497,114)		(1,011,244)		(329,497)
Income (loss) from discontinued operations, net of tax		(43,519)		(18,363)		(42,797)
Net income (loss)		(540,633)		(1,029,607)		(372,294)
Less: Net (income) loss attributable to noncontrolling interest		(6,178)		(135)		(381)
Net income (loss) attributable to Nabors	$	(546,811)	$	(1,029,742)	$	(372,675)
Amounts attributable to Nabors:
Net income (loss) from continuing operations	$	(503,292)	$	(1,011,379)	$	(329,878)
Net income (loss) from discontinued operations		(43,519)		(18,363)		(42,797)
Net income (loss) attributable to Nabors	$	(546,811)	$	(1,029,742)	$	(372,675)
Earnings (losses) per share:
Basic from continuing operations	$	(1.75)	$	(3.58)	$	(1.14)
Basic from discontinued operations		(0.15)		(0.06)		(0.15)
Total Basic	$	(1.90)	$	(3.64)	$	(1.29)
Diluted from continuing operations	$	(1.75)	$	(3.58)	$	(1.14)
Diluted from discontinued operations		(0.15)		(0.06)		(0.15)
Total Diluted	$	(1.90)	$	(3.64)	$	(1.29)
Weighted-average number of common shares outstanding:
Basic		280,653		276,475		282,982
Diluted		280,653		276,475		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)

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Net income (loss) attributable to Nabors	$	(546,811)	$	(1,029,742)	$	(372,675)
Other comprehensive income (loss), before tax:
Translation adjustment attributable to Nabors		28,372		17,743		(110,874)
Unrealized gains (losses) on marketable securities:
Unrealized gains (losses) on marketable securities		(6,061)		11,054		(15,310)
Less: reclassification adjustment for (gains) losses included in net income (loss)		970		3,495		—
Unrealized gains (losses) on marketable securities		(5,091)		14,549		(15,310)
Pension liability amortization and adjustment		(275)		1,061		1,104
Pension buyout		—		3,059		—
Unrealized gains (losses) and amortization on cash flow hedges		613		613		613
Other comprehensive income (loss), before tax		23,619		37,025		(124,467)
Income tax expense (benefit) related to items of other comprehensive income (loss)		315		1,551		648
Other comprehensive income (loss), net of tax		23,304		35,474		(125,115)
Comprehensive income (loss) attributable to Nabors		(523,507)		(994,268)		(497,790)
Net income (loss) attributable to noncontrolling interest		6,178		135		381
Translation adjustment attributable to noncontrolling interest		282		251		(1,461)
Comprehensive income (loss) attributable to noncontrolling interest		6,460		386		(1,080)
Comprehensive income (loss)	$	(517,047)	$	(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

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Cash flows from operating activities:
Net income (loss)	$	(540,633)	$	(1,029,607)	$	(372,294)
Adjustments to net income (loss):
Depreciation and amortization		845,439		874,296		973,318
Deferred income tax expense (benefit)		9,096		(206,670)		(203,145)
Impairments and other charges		42,188		236,745		129,341
Deferred financing costs amortization		7,088		4,381		5,290
Discount amortization on long-term debt		20,495		2,074		1,969
Losses (gains) on debt buyback		16,005		(6,665)		—
Losses (gains) on long-lived assets, net		19,064		85,064		63,338
Losses (gains) on investments, net		972		—		—
Impairments on equity method holdings		—		216,242		180,591
Losses (gains) on merger and acquisitions		—		—		(49,382)
Share-based compensation		31,896		32,000		47,313
Foreign currency transaction losses (gains), net		1,604		5,669		9,881
Pension buyout		—		3,059		—
Equity in (earnings) losses of unconsolidated affiliates, net of dividends		(7)		221,914		84,275
Other		(5,542)		1,333		627
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable		(165,353)		250,400		529,151
Inventory		(17,444)		40,647		23,852
Other current assets		16,518		37,904		34,390
Other long-term assets		28,772		98		(27,461)
Trade accounts payable and accrued liabilities		79,204		(180,200)		(566,042)
Income taxes payable		14,811		(46,576)		(1,680)
Other long-term liabilities		(341,417)		(10,203)		(6,776)
Net cash (used for) provided by operating activities		62,756		531,905		856,556
Cash flows from investing activities:
Purchases of investments		(6,722)		(24)		(9)
Sales and maturities of investments		13,069		739		961
Cash paid for acquisition of businesses, net of cash acquired		9,040		(22,278)		(80,187)
Investment in unconsolidated affiliates		—		—		(445)
Capital expenditures		(574,467)		(395,455)		(867,106)
Proceeds from sales of assets and insurance claims		57,933		34,831		68,206
Proceeds from merger transaction		—		—		650,050
Other		(856)		64		1,081
Net cash (used for) provided by investing activities		(502,003)		(382,123)		(227,449)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		(188)		3		645
Proceeds from issuance of long-term debt		411,200		600,000		—
Debt issuance costs		(11,043)		(11,520)		(1,847)
Proceeds from revolving credit facilities		725,000		611,500		—
Reduction in revolving credit facilities		(215,000)		(611,500)		(450,000)
Proceeds from (payments for) issuance of common shares		8,300		967		1,296
Repurchase of common shares		(18,071)		(1,687)		(99,598)
Distributions to noncontrolling interest		(7,272)		—		—
Noncontrolling interest contribution		20,000		—		3,972
Reduction in long-term debt		(381,814)		(493,612)		(27,478)
Dividends to shareholders		(68,503)		(50,924)		(69,363)
Proceeds from (payment for) commercial paper, net		40,000		(8,000)		(525,119)
Cash proceeds from equity component of exchangeable debt		159,952		—		—
Proceeds from term loan		—		—		625,000
Payments on term loan		(162,500)		(162,500)		(300,000)
Redeemable noncontrolling interest contribution		61,123		—		—
Proceeds from (payments for) short-term borrowings		(543)		(6,211)		318
Purchase of capped call hedge transactions		(40,250)		—		—
Other		(8,211)		(4,732)		(7,767)
Net cash (used for) provided by financing activities		512,180		(138,216)		(849,941)
Effect of exchange rate changes on cash and cash equivalents		(29)		(2,003)		(25,785)
Net increase (decrease) in cash and cash equivalents		72,904		9,563		(246,619)
Cash and cash equivalents, beginning of period		264,093		254,530		501,149
Cash and cash equivalents, end of period	$	336,997	$	264,093	$	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

				Capital		Accumulated
	Common Shares			in Excess		Other						Non-
		Par		of Par		Comprehensive		Retained		Treasury		controlling		Total
(In thousands)	Shares	Value		Value		Income		Earnings		Shares		Interest		Equity
As of December 31, 2014	328,196		328		2,452,261		77,522		3,573,172		(1,194,664)		10,170		4,918,789
Net income (loss)	—		—		—		—		(372,675)		—		381		(372,294)
Dividends to shareholders	—		—		—		—		(69,363)		—		—		(69,363)
Repurchase of treasury shares	—		—		—		—		—		(99,598)		—		(99,598)
Other comprehensive income (loss), net of tax	—		—		—		(125,115)		—		—		(1,461)		(126,576)
Issuance of common shares for stock options exercised, net of surrender of unexercised stock options	141		—		1,296		—		—		—		—		1,296
Share-based compensation	—		—		47,863		—		—		—		—		47,863
Other	2,189		3		(8,320)		—		—		—		2,068		(6,249)
As of December 31, 2015	330,526	$	331	$	2,493,100	$	(47,593)	$	3,131,134	$	(1,294,262)	$	11,158	$	4,293,868
Net income (loss)	—		—		—		—		(1,029,742)		—		135		(1,029,607)
Dividends to shareholders	—		—		—		—		(67,965)		—		—		(67,965)
Repurchase of treasury shares	—		—		—		—		—		(1,687)		—		(1,687)
Other comprehensive income (loss), net of tax	—		—		—		35,474		—		—		251		35,725
Issuance of common shares for stock options exercised, net of surrender of unexercised stock options	102		—		967		—		—		—		—		967
Share-based compensation	—		—		32,000		—		—		—		—		32,000
Other	2,970		3		(4,735)		—		—		—		(3,774)		(8,506)
As of December 31, 2016	333,598	$	334	$	2,521,332	$	(12,119)	$	2,033,427	$	(1,295,949)	$	7,770	$	3,254,795
Net income (loss)	—		—		—		—		(546,811)		—		6,178		(540,633)
Dividends to shareholders	—		—		—		—		(68,612)		—		—		(68,612)
Repurchase of treasury shares	—		—		—		—		—		(18,071)		—		(18,071)
Other comprehensive income (loss), net of tax	—		—		—		23,304		—		—		282		23,586
Issuance of common shares for stock options exercised, net of surrender of unexercised stock options	842		1		(10,736)		—		—		—		—		(10,735)
Equity component of exchangeable debt	—		—		116,195		—		—		—		—		116,195
Capped call transaction	—		—		(40,250)		—		—		—		—		(40,250)
Adoption of ASU No. 2016-09	—		—		1,943		—		5,150		—		—		7,093
Share-based compensation	—		—		31,896		—		—		—		—		31,896
Issuance of common shares to Tesco shareholders	32,078		32		178,961		—		—		—		—		178,993
Noncontrolling interest contributions (distributions), net	—		—		—		—		—		—		13,018		13,018
Other	992		1		(8,212)		—		—		—		(291)		(8,502)
As of December 31, 2017	367,510	$	368	$	2,791,129	$	11,185	$	1,423,154	$	(1,314,020)	$	26,957	$	2,938,773

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	$	84,431
Work-in-progress		19,113		1,204
Finished goods		22,559		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
	Balance at		Purchase		Disposals		Cumulative		Balance at
	December 31,		Price		and		Translation		December 31,
	2015		Adjustments		Impairments		Adjustment		2016
	(In thousands)
Drilling & Rig Technologies:
U.S.	$	50,149	$	—	$	—	$	—	$	50,149
International		75,634		—		—		—		75,634
Rig Technologies		40,876		—		—		258		41,134
Total	$	166,659	$	—	$	—	$	258	$	166,917

			Acquisitions
			and
	Balance at		Purchase			Disposals		Cumulative		Balance at
	December 31,		Price			and		Translation		December 31,
	2016		Adjustments			Impairments		Adjustment		2017
	(In thousands)
Drilling & Rig Technologies:
U.S.	$	50,149	$	—		$	—	$	—	$	50,149
International		75,634		—			—		—		75,634
Rig Technologies		41,134		5,690	(1)		—		619		47,443
Total	$	166,917	$	5,690		$	—	$	619	$	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

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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.

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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

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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.

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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:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Tangible Assets & Equipment:
Provision for retirement of assets	$	—	$	69,072	$	65,633
Impairment of long-lived assets		6,895		216,355		74,464
Subtotal		6,895		285,427		140,097
Other Charges:
Other-than-temporary impairment		—		219,737		180,591
Provision for International operations		—		—		48,279
Transaction related costs		21,628		—		—
Loss (gain) on early extinguishment of debt		16,013		(6,665)		—
Total	$	44,536	$	498,499	$	368,967

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.

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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:

	Provision for		Tangible Asset
	Retirements		Impairments		Total
Drilling & Rig Technologies:
U.S.	$	25,365	$	163,182	$	188,547
Canada		19,573		1,125		20,698
International		23,275		12,721		35,996
Drilling Solutions		859		—		859
Rig Technologies		—		15,343		15,343
Other		—		23,984		23,984
Total	$	69,072	$	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.

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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:

	Provisionfor		TangibleAsset
	Retirements		Impairments		Total
Drilling & Rig Technologies:
U.S.	$	47,247	$	—	$	47,247
Canada		7,547		—		7,547
International		10,839		52,479		63,318
Rig Technologies		—		3,879		3,879
Other		—		18,106		18,106
Total	$	65,633	$	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.

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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.

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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		2016		2015
	(In thousands, except percentages)
Operating revenues (1)	$	6,169	$	2,859	$	3,212
Income (loss) from Oil & Gas discontinued operations:
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 owned assets	$	—	$	—	$	3,146	(3)
Less: Income tax expense (benefit)	$	—	$	—	$	(787)
Income (loss) from Rig Technologies discontinued operations, net of tax	$	—	$	—	$	(2,359)
Income (loss) from discontinued operations, net of tax	$	(43,519)	$	(18,363)	$	(42,797)

Oil and Gas

(1) Reflects operating revenues of our historical oil and gas reportable segment.

(2) 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.

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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.

	Fair Value
(In thousands)	at Acquisition
Assets:
Cash and cash equivalents	$	59,804
Accounts receivable		41,565
Inventory		44,525
Other current assets		13,889
Property, plant and equipment		61,650
Other long-term assets		3,647
Total assets		225,080
Liabilities:
Accounts payable	$	14,111
Accrued liabilities		29,542
Other long-term liabilities		2,436
Total liabilities		46,089
Net assets acquired	$	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.

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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)	2017		2016
Operating revenues	$	2,717,933	$	2,362,576
Income (loss) from continuing operations, net of tax		(554,235)		(1,129,172)
Income (loss) from continuing operations per share - basic	$	(1.75)	$	(3.59)
Income (loss) from continuing operations per share - diluted	$	(1.75)	$	(3.59)

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.

	Fair Value
(In thousands)	at Acquisition
Assets:
Cash	$	48,058
Accounts receivable		153,819
Other current assets		58,021
Property, plant and equipment, net		89,643
Intangible assets		28,784
Goodwill		75,634
Other long-term assets		7,709
Total assets		461,668
Liabilities:
Accounts payable	$	206,599
Accrued liabilities		74,393
Intangible liability		13,472
Deferred tax liability		4,823
Other long-term liabilities		9,400
Total liabilities		308,687
Net assets acquired	$	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.

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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 1		Level 2		Level 3
	(In thousands)
Assets:
Short-term investments:
Available-for-sale equity securities	$	22,909	$	5,450	$	—
Mortgage-CMO debt securities		—		10		—
Total short-term investments	$	22,909	$	5,460	$	—

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

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quoted from third‑party financial institutions, thus a level 2 measurement. The carrying and fair values of these liabilities were as follows:

	As of December 31,
				2017							2016
	Effective						Effective
	Interest		Carrying		Fair		Interest		Carrying			Fair
	Rate		Value		Value		Rate		Value			Value
			(In thousands)						(In thousands)
6.15% senior notes due February 2018	6.27	%	$	460,762	$	462,674	6.40	%	$	827,539		$	865,300
9.25% senior notes due January 2019	9.77	%		303,489		321,028	9.33	%		303,489			337,443
5.00% senior notes due September 2020	5.43	%		669,846		670,757	5.21	%		669,540			689,211
4.625% senior notes due September 2021	4.76	%		695,108		665,003	4.75	%		694,868			708,765
5.50% senior notes due January 2023	5.85	%		600,000		584,850	5.85	%		600,000			627,000
5.10% senior notes due September 2023	5.28	%		346,576		325,844	5.26	%		346,448			348,613
0.75% senior exchangeable notes due January 2024	5.90	%		429,982		443,940	—	%		—			—
Term loan facility	—	%		—		—	1.76	%		162,500			162,500
Revolving credit facility	2.73	%		510,000		510,000	1.86	%		—			—
Commercial paper	1.87	%		40,000		40,000	1.16	%		—			—
Other	—	%		181		181	—	%		297			297
				4,055,944	$	4,024,277				3,604,681		$	3,739,129
Less: deferred financing costs				27,997						26,049
			$	4,027,947					$	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

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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:

				Weighted-
		Weighted-		Average
		Average		Remaining		Aggregate
		Exercise		Contractual		Intrinsic
Options	Shares	Price		Term		Value
	(In thousands, except exercise price)
Options outstanding as of December 31, 2016	5,217	$	12.56
Granted	124		8.59
Exercised	(842)		9.85
Forfeited	(105)		9.43
Options outstanding as of December 31, 2017	4,394	$	13.04	2.81	years	$	—
Options exercisable as of December 31, 2017	4,360	$	13.03	2.77	years	$	—

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:

	Year Ended December 31,
	2017		2016		2015
Weighted average fair value of options granted	$	2.86	$	3.52	$	4.40
Weighted average risk free interest rate		1.85%		1.09%		1.29%
Dividend yield		2.94%		2.21%		2.05%
Volatility (1)		50.82%		45.69%		50.01%
Expected life (in years)		4.0		4.0		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.

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A summary of our unvested stock options as of December 31, 2017, and the changes during the year then ended is presented below:

		Weighted-Average
		Grant-Date Fair
Unvested Stock Options	Outstanding	Value
	(In thousands, except fair value)
Unvested as of December 31, 2016	57	$	5.34
Granted	124		2.86
Vested	(147)		3.27
Forfeited	—		—
Unvested as of December 31, 2017	34	$	5.21

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:

		Weighted-Average
		Grant-Date Fair
Restricted shares	Outstanding	Value
	(In thousands, except fair value)
Unvested as of December 31, 2016	3,885	$	13.41
Granted	1,130		12.84
Vested	(1,567)		14.65
Forfeited	(150)		12.33
Unvested as of December 31, 2017	3,298	$	12.67

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.

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The following table sets forth information regarding outstanding restricted shares based on performance conditions as of December 31, 2017:

		Weighted-Average
		Grant-Date Fair
Performance based restricted shares	Outstanding	Value
	(In thousands, except fair value)
Outstanding as of December 31, 2016	1,595	$	12.01
Granted	462		15.31
Vested	(644)		13.33
Outstanding as of December 31, 2017	1,413	$	12.49

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,
	2017		2016		2015
Risk free interest rate		1.62%		1.41%		1.18%
Expected volatility		55.00%		52.00%		50.00%
Closing stock price at grant date	$	16.81	$	8.64	$	12.98
Expected term (in years)		3.0		3.0		3.00

The following table sets forth information regarding outstanding restricted shares based on market conditions as of December 31, 2017:

		Weighted-Average
		Grant-Date Fair
Market based restricted shares	Outstanding	Value
	(In thousands, except fair value)
Outstanding as of December 31, 2016	1,690	$	7.94
Granted	398		11.16
Vested	(237)		11.40
Forfeited	(159)		11.40
Outstanding as of December 31, 2017	1,692	$	7.89

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.

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Note 8 Property, Plant and Equipment

The major components of our property, plant and equipment are as follows:

	December 31,
	2017		2016
	(In thousands)
Land	$	52,000	$	46,319
Buildings		134,318		115,502
Drilling, workover and well-servicing rigs, and related equipment		12,997,470		12,638,749
Marine transportation and supply vessels		4,377		—
Oilfield hauling and mobile equipment		272,384		274,137
Other machinery and equipment		172,674		181,069
Oil and gas properties		12,286		12,286
Construction-in-process (1)		284,348		288,673
	$	13,929,857	$	13,556,735
Less: accumulated depreciation and amortization		(7,820,292)		(7,289,152)
	$	6,109,565	$	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

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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
Current liabilities	$	147,699
Long-term liabilities	$	41,613

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	Nine Months Ended		Year Ended
	September 30,		December 31,
	2016		2015
Gross revenues	$	727,320	$	1,748,889
Gross margin	$	18,943	$	225,773
Net income (loss)	$	(825,921)	$	(872,542)
Nabors' share of equity method earnings (losses)	$	(221,933)	$	(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

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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,
	2017		2016
	(In thousands)
6.15% senior notes due February 2018 (1)	$	460,762	$	827,539
9.25% senior notes due January 2019		303,489		303,489
5.00% senior notes due September 2020		669,846		669,540
4.625% senior notes due September 2021		695,108		694,868
5.50% senior notes due January 2023		600,000		600,000
5.10% senior notes due September 2023		346,576		346,448
0.75% senior exchangeable notes due January 2024		429,982		—
Term loan facility		—		162,500
Revolving credit facility		510,000		—
Commercial paper		40,000		—
Other		181		297
		4,055,944		3,604,681
Less: current portion		181		297
Less: deferred financing costs		27,997		26,049
	$	4,027,766	$	3,578,335

(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:

	Paid at Maturity
	(In thousands)
2018	$	460,837	(1)
2019		303,489	(2)
2020		1,220,675	(3)
2021		696,000	(4)
2022		—
Thereafter		1,522,300	(5)
	$	4,203,301

(1) Represents our 6.15% senior notes due February 2018.

(2) Represents our 9.25% senior notes due January 2019.

(3) Represents our 5.0% senior notes due September 2020 and amounts outstanding under our commercial paper program and revolving credit facility due July 2020.

(4) Represents our 4.625% senior notes due September 2021.

(5) 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

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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

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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:

	December 31,
	2017
	(In thousands)
Credit available	$	759,421
Less: Letters of credit outstanding, inclusive of financial and performance guarantees		153,489
Remaining availability	$	605,932

Note 12 Income Taxes

Income (loss) from continuing operations before income taxes consisted of the following:

	Year Ended December 31,
United States and Other Jurisdictions	2017		2016		2015
	(In thousands)
United States	$	(369,162)	$	(728,589)	$	(264,919)
Other jurisdictions		(210,922)		(469,486)		(162,616)
Income (loss) from continuing operations before income taxes	$	(580,084)	$	(1,198,075)	$	(427,535)

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Income tax expense (benefit) from continuing operations consisted of the following:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Current:
U.S. federal	$	(160,761)	$	(19,937)	$	5,088
Outside the U.S.		59,491		31,846		76,550
State		(810)		2,871		8,227
	$	(102,080)	$	14,780	$	89,865
Deferred:
U.S. federal	$	49,020	$	(164,297)	$	(182,518)
Outside the U.S.		(26,684)		(14,641)		1,757
State		(3,226)		(22,673)		(7,142)
	$	19,110	$	(201,611)	$	(187,903)
Income tax expense (benefit)	$	(82,970)	$	(186,831)	$	(98,038)

A reconciliation of our statutory tax rate to our worldwide effective tax rate consists of the following:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Income tax provision at statutory (Bermuda rate of 0%)	$	—	$	—	$	—
Taxes (benefit) on U.S. and other international earnings (losses) at greater than the Bermuda rate		(98,119)		(181,426)		(109,101)
Increase (decrease) in valuation allowance		29,165		17,865		22,655
Impact of Tax Reform Act		138,635		—		—
Tax reserves and interest		(148,615)		(3,468)		(12,679)
State income taxes (benefit)		(4,036)		(19,802)		1,087
Income tax expense (benefit)	$	(82,970)	$	(186,831)	$	(98,038)
Effective tax rate		14.3%		15.6%		22.9 %

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.

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The components of our net deferred taxes consisted of the following:

	December 31,
	2017		2016
	(In thousands)
Deferred tax assets:
Net operating loss carryforwards	$	1,974,658	$	1,826,656
Equity compensation		10,281		36,972
Deferred revenue		14,005		31,082
Tax credit and other attribute carryforwards		131,640		91,680
Insurance loss reserves		6,626		5,118
Accrued interest		234,033		357,285
Other		80,492		115,909
Subtotal		2,451,735		2,464,702
Valuation allowance		(1,869,490)		(1,807,728)
Deferred tax assets:	$	582,245	$	656,974
Deferred tax liabilities:
Depreciation and amortization for tax in excess of book expense	$	146,448	$	288,088
Variable interest investments		—		641
Other		27,132		11,154
Deferred tax liability	$	173,580	$	299,883
Net deferred tax assets (liabilities)	$	408,665	$	357,091
Balance Sheet Summary:
Net noncurrent deferred tax asset (1)	$	419,003	$	366,586
Net noncurrent deferred tax liability		(10,338)		(9,495)
Net deferred tax asset (liability)	$	408,665	$	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:

	Year Ended December 31,
	2017			2016			2015
	(In thousands)
Balance as of January 1	$	179,255		$	188,376		$	201,338
Additions based on tax positions related to the current year		—			—			384
Additions for tax positions of prior years		25,119	(1)		3,873			—
Reductions for tax positions for prior years		(171,171)	(2)		(11,547)	(3)		(9,234)	(4)
Settlements		—			(1,447)			(4,112)	(5)
Balance as of December 31	$	33,203		$	179,255		$	188,376

(1) Includes $12.0 million reduction in Norway, $9.0 million in the U.S. and $2.0 million in Egypt.

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(2) Includes $167.0 million related to internal restructuring.

(3) 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.

(4) 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.

	December 31,
(In thousands)	2017
Assets:
Cash and cash equivalents	$	94,496
Accounts receivable		10,580
Other current assets		10,834
Property, plant and equipment, net		130,218
Other long-term assets		23,091
Total assets	$	269,219
Liabilities:
Accounts payable	$	7,236
Accrued liabilities		2,592
Total liabilities	$	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.

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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.

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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:

	(In thousands)
2018	$	11,342
2019		4,864
2020		3,400
2021		2,265
2022		1,876
Thereafter		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:

	(In thousands)
2018	$	8,597
2019		2,652
2020		—
2021		—
2022		—
Thereafter (1)		—
	$	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.

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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:

	(In thousands)
2018	$	4,252
2019		300
2020		—
2021		—
2022		—
Thereafter		—
	$	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.

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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

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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.

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A reconciliation of the numerators and denominators of the basic and diluted earnings (losses) per share computations is as follows:

	Year Ended December 31,
	2017		2016		2015
	(In thousands, except per share amounts)
BASIC EPS:
Net income (loss) (numerator):
Income (loss) from continuing operations, net of tax	$	(497,114)	$	(1,011,244)	$	(329,497)
Less: net (income) loss attributable to noncontrolling interest		(6,178)		(135)		(381)
Less: (earnings) losses allocated to unvested shareholders		13,210		22,730		7,820
Numerator for basic earnings per share:
Adjusted income (loss) from continuing operations, net of tax - basic	$	(490,082)	$	(988,649)	$	(322,058)
Income (loss) from discontinued operations, net of tax	$	(43,519)	$	(18,363)	$	(42,797)
Weighted-average number of shares outstanding - basic		280,653		276,475		282,982
Earnings (losses) per share:
Basic from continuing operations	$	(1.75)	$	(3.58)	$	(1.14)
Basic from discontinued operations		(0.15)		(0.06)		(0.15)
Total Basic	$	(1.90)	$	(3.64)	$	(1.29)
DILUTED EPS:
Adjusted income (loss) from continuing operations, net of tax - basic	$	(490,082)	$	(988,649)	$	(322,058)
Add: effect of reallocating undistributed earnings of unvested shareholders		—		—		—
Adjusted income (loss) from continuing operations, net of tax - diluted	$	(490,082)	$	(988,649)	$	(322,058)
Income (loss) from discontinued operations, net of tax	$	(43,519)	$	(18,363)	$	(42,797)
Weighted-average number of shares outstanding - basic		280,653		276,475		282,982
Add: dilutive effect of potential common shares		—		—		—
Weighted-average number of shares outstanding - diluted		280,653		276,475		282,982
Earnings (losses) per share:
Diluted from continuing operations	$	(1.75)	$	(3.58)	$	(1.14)
Diluted from discontinued operations		(0.15)		(0.06)		(0.15)
Total Diluted	$	(1.90)	$	(3.64)	$	(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:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
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.

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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
Deferred revenue		218,370		255,626
Other taxes payable		32,095		16,419
Workers’ compensation liabilities		13,987		18,255
Interest payable		65,642		57,233
Litigation reserves		18,830		24,896
Current liability to discontinued operations		6,074		5,462
Dividends declared and payable		17,148		17,039
Other accrued liabilities		29,928		31,543
	$	533,044	$	543,248

Other, net includes the following:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Losses (gains) on sales, disposals and involuntary conversions of long-lived assets	$	19,026	$	14,830	$	(2,293)
Gain on Merger transaction		—		—		(96,719)
Charges related to our CJES holdings (1)		—		12,879		49,645
Litigation expenses and reserves		1,273		3,936		8,194
Foreign currency transaction losses (gains)		1,603		5,669		392
(Gain) loss on debt buyback		—		—		—
Other losses (gains)		(7,022)		6,860		1,609
	$	14,880	$	44,174	$	(39,172)

(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.

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The changes in accumulated other comprehensive income (loss), by component, include the following:

			Unrealized
	Gains		gains (losses)		Defined
	(losses) on		on available-		benefit		Foreign
	cash flow		for-sale		pension plan		currency
	hedges		securities		items		items		Total
	(In thousands (1) )
As of January 1, 2016	$	(1,670)	$	(314)	$	(6,568)	$	(39,041)	$	(47,593)
Other comprehensive income (loss) before reclassifications		—	$	11,054	$	—	$	17,743	$	28,797
Amounts reclassified from accumulated other comprehensive income (loss)		374	$	3,495	$	2,808	$	—	$	6,677
Net other comprehensive income (loss)		374		14,549		2,808		17,743		35,474
As of December 31, 2016	$	(1,296)	$	14,235	$	(3,760)	$	(21,298)	$	(12,119)

(1) All amounts are net of tax.

			Unrealized
	Gains		gains (losses)		Defined
	(losses) on		on available-		benefit		Foreign
	cash flow		for-sale		pension plan		currency
	hedges		securities		items		items		Total
	(In thousands (1) )
As of January 1, 2017	$	(1,296)	$	14,235	$	(3,760)	$	(21,298)	$	(12,119)
Other comprehensive income (loss) before reclassifications		—		(6,061)		—		28,372		22,311
Amounts reclassified from accumulated other comprehensive income (loss)		374		970		(351)		—		993
Net other comprehensive income (loss)		374		(5,091)		(351)		28,372		23,304
As of December 31, 2017	$	(922)	$	9,144	$	(4,111)	$	7,074	$	11,185

(1) All amounts are net of tax.

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The line items that were reclassified to net income include the following:

Line item in consolidated statement of income (loss)

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Investment income (loss)	$	—	$	—	$	—
Impairments and other charges		970		3,495		—
Interest expense		613		613		613
General and administrative expenses		200		1,061		1,104
Other expense (income), net		—		3,059		5,365
Total income (loss) from continuing operations before income tax		(1,783)		(8,228)		(7,082)
Tax expense (benefit)		(315)		(1,551)		(648)
Reclassification adjustment for (gains)/ losses included in net income (loss)	$	(1,468)	$	(6,677)	$	(6,434)

Supplemental cash flow information includes the following:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
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	$	—	$	327,857
Goodwill		5,690		—		86,502
Liabilities assumed		(55,742)		—		(306,084)
Gain on acquisition		—		—		(2,308)
Share issuance as consideration (non-cash financing activity)		(178,993)		—		—
Payments on future consideration		—		22,278		22,278
Cash paid for acquisitions of businesses		51,664		22,278		128,245
Cash acquired in acquisitions of businesses		(60,704)		—		(48,058)
Cash (acquired in) paid for acquisitions of businesses, net	$	(9,040)	$	22,278	$	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	$	662,103	$	708,277
Income (loss) from continuing operations, net of tax	$	(147,628)	$	(115,476)	$	(119,285)	$	(114,725)
Income (loss) from discontinued operations, net of tax		(439)		(15,504)		(27,134)		(442)
Net income (loss)		(148,067)		(130,980)		(146,419)		(115,167)
Less: Net (income) loss attributable to noncontrolling interest		(917)		(1,971)		(2,113)		(1,177)
Net income (loss) attributable to Nabors	$	(148,984)	$	(132,951)	$	(148,532)	$	(116,344)
Earnings (losses) per share: (1)
Basic from continuing operations	$	(0.52)	$	(0.41)	$	(0.42)	$	(0.40)
Basic from discontinued operations		—		(0.05)		(0.10)		—
Total Basic	$	(0.52)	$	(0.46)	$	(0.52)	$	(0.40)
Diluted from continuing operations	$	(0.52)	$	(0.41)	$	(0.42)	$	(0.40)
Diluted from discontinued operations		—		(0.05)		(0.10)		—
Total Diluted	$	(0.52)	$	(0.46)	$	(0.52)	$	(0.40)

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	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	$	519,729	$	538,948
Income (loss) from continuing operations, net of tax	$	(396,644)	$	(186,565)	$	(97,839)	$	(330,196)
Income (loss) from discontinued operations, net of tax		(926)		(984)		(12,187)		(4,266)
Net income (loss)		(397,570)		(187,549)		(110,026)		(334,462)
Less: Net (income) loss attributable to noncontrolling interest		(724)		2,899		(1,185)		(1,125)
Net income (loss) attributable to Nabors	$	(398,294)	$	(184,650)	$	(111,211)	$	(335,587)
Earnings (losses) per share: (1)
Basic from continuing operations	$	(1.41)	$	(0.65)	$	(0.35)	$	(1.17)
Basic from discontinued operations		—		—		(0.04)		(0.01)
Total Basic	$	(1.41)	$	(0.65)	$	(0.39)	$	(1.18)
Diluted from continuing operations	$	(1.41)	$	(0.65)	$	(0.35)	$	(1.17)
Diluted from discontinued operations		—		—		(0.04)		(0.01)
Total Diluted	$	(1.41)	$	(0.65)	$	(0.39)	$	(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).

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The following table sets forth financial information with respect to our reportable operating segments:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Operating revenues:
Drilling & Rig Technologies:
U.S.	$	805,223	$	554,072	$	1,256,989
Canada		82,929		51,472		137,494
International		1,474,060		1,508,890		1,862,393
Drilling Solutions		140,701		63,759		69,828
Rig Technologies		234,542		151,951		321,238
Subtotal Drilling & Rig Technologies		2,737,455		2,330,144		3,647,942
Completion & Production Services:
Completion Services		—		—		207,860
Production Services		—		—		158,512
Subtotal Completion & Production Services		—		—		366,372
Other reconciling items (1)		(173,170)		(102,305)		(149,877)
Total	$	2,564,285	$	2,227,839	$	3,864,437

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Adjusted operating income (loss): (2)
Drilling & Rig Technologies:
U.S.	$	(213,877)	$	(197,710)	$	87,051
Canada		(22,262)		(36,818)		(7,029)
International		108,428		164,677		308,262
Drilling Solutions		16,738		(16,503)		(10,879)
Rig Technologies		(30,964)		(31,981)		(1,762)
Subtotal Drilling & Rig Technologies		(141,937)		(118,335)		375,643
Completion & Production Services:
Completion Services		—		—		(55,243)
Production Services		—		—		(3,559)
Subtotal Completion & Production Services		—		—		(58,802)
Total segment adjusted operating income (loss)	$	(141,937)	$	(118,335)	$	316,841

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
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)	$	(118,335)	$	316,841
Other reconciling items (3)		(157,043)		(130,976)		(159,880)
Earnings (losses) from unconsolidated affiliates		7		(221,914)		(75,081)
Investment income (loss)		1,194		1,183		2,308
Interest expense		(222,889)		(185,360)		(181,928)
Impairments and other charges		(44,536)		(498,499)		(368,967)
Other, net		(14,880)		(44,174)		39,172
Income (loss) from continuing operations before income taxes	$	(580,084)	$	(1,198,075)	$	(427,535)

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	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Depreciation and amortization
Drilling & Rig Technologies:
U.S.	$	375,171	$	388,367	$	425,952
Canada		39,597		42,143		46,786
International		400,753		411,372		411,004
Drilling Solutions		16,188		18,598		11,221
Rig Technologies		11,530		14,552		22,398
Subtotal Drilling & Rig Technologies		843,239		875,032		917,361
Completion & Production Services:
Completion Services		—		—		27,133
Production Services		—		—		26,602
Subtotal Completion & Production Services		—		—		53,735
Other reconciling items (3)		(296)		(3,401)		(637)
Total	$	842,943	$	871,631	$	970,459

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Capital expenditures and acquisitions of businesses:
Drilling & Rig Technologies:
U.S.	$	330,875	$	183,146	$	224,819
Canada		17,197		4,546		24,167
International		159,817		169,640		578,896
Drilling Solutions		58,925		21,606		5,506
Rig Technologies		42,368		2,003		7,285
Subtotal Drilling & Rig Technologies		609,182		380,941		840,673
Completion & Production Services		—		—		45,691
Other reconciling items (3)		(8,273)		33,438		36,872
Total	$	600,909	$	414,379	$	923,236

	December 31,
	2017		2016
	(In thousands)
Total assets:
Drilling & Rig Technologies:
U.S.	$	3,203,560	$	3,172,767
Canada		347,773		329,620
International		3,540,829		3,600,057
Drilling Solutions		182,162		81,490
Rig Technologies		459,665		277,945
Subtotal Drilling & Rig Technologies		7,733,989		7,461,879
Other reconciling items (3)		667,995		725,136
Total	$	8,401,984	$	8,187,015

(1) Represents the elimination of inter-segment transactions.

(2) 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.

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(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:

	Year Ended December 31,
	2017		2016		2015
	(In thousands)
Operating revenues
U.S.	$	973,464	$	642,835	$	1,823,906
Outside the U.S.		1,590,821		1,585,004		2,040,531
	$	2,564,285	$	2,227,839	$	3,864,437
Property, plant and equipment, net:
U.S.	$	3,163,425	$	3,048,749	$	3,703,533
Outside the U.S.		2,946,140		3,218,834		3,324,269
	$	6,109,565	$	6,267,583	$	7,027,802
Goodwill:
U.S.	$	54,198	$	54,199	$	54,198
Outside the U.S.		119,028		112,718		112,461
	$	173,226	$	166,917	$	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

	December 31, 2017
					Other
	Nabors			Nabors	Subsidiaries
	(Parent/		Delaware		(Non-		Consolidating
	Guarantor)		(Issuer)		Guarantors)		Adjustments		Total
	(In thousands)
	ASSETS
Current assets:
Cash and cash equivalents	$	1,091	$	44	$	335,862	$	—	$	336,997
Short-term investments		—		—		28,369		—		28,369
Accounts receivable, net		—		—		698,477		—		698,477
Inventory, net		—		—		166,307		—		166,307
Assets held for sale		—		—		37,052		—		37,052
Other current assets		50		56		180,028		—		180,134
Total current assets		1,141		100		1,446,095		—		1,447,336
Property, plant and equipment, net		—		—		6,109,565		—		6,109,565
Goodwill		—		—		173,226		—		173,226
Intercompany receivables		133,602		481,092		—		(614,694)		—
Investment in consolidated affiliates		2,799,320		5,531,799		3,799,933		(12,131,052)		—
Deferred income taxes		—		333,349		419,003		(333,349)		419,003
Other long-term assets		—		78		324,919		(72,143)		252,854
Total assets	$	2,934,063	$	6,346,418	$	12,272,741	$	(13,151,238)	$	8,401,984
	LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	—	$	—	$	181	$	—	$	181
Trade accounts payable		147		124		363,145		—		363,416
Accrued liabilities		21,100		67,760		444,184		—		533,044
Income taxes payable		—		—		22,835		—		22,835
Total current liabilities		21,247		67,884		830,345		—		919,476
Long-term debt		—		4,099,909		—		(72,143)		4,027,766
Other long-term liabilities		—		16,284		285,349		—		301,633
Deferred income taxes		—		—		343,687		(333,349)		10,338
Intercompany payable		1,000		—		613,694		(614,694)		—
Total liabilities		22,247		4,184,077		2,073,075		(1,020,186)		5,259,213
Redeemable noncontrolling interest in subsidiary		—		—		203,998		—		203,998
Shareholders’ equity		2,911,816		2,162,341		9,968,711		(12,131,052)		2,911,816
Noncontrolling interest		—		—		26,957		—		26,957
Total equity		2,911,816		2,162,341		9,995,668		(12,131,052)		2,938,773
Total liabilities and equity	$	2,934,063	$	6,346,418	$	12,272,741	$	(13,151,238)	$	8,401,984

94

	December 31, 2016
					Other
	Nabors		Nabors		Subsidiaries
	(Parent/		Delaware		(Non-		Consolidating
	Guarantor)		(Issuer)		Guarantors)		Adjustments		Total
	(In thousands)
	ASSETS
Current assets:
Cash and cash equivalents	$	1,148	$	10,177	$	252,768	$	—	$	264,093
Short-term investments		—		—		31,109		—		31,109
Accounts receivable, net		—		—		508,355		—		508,355
Inventory, net		—		—		103,595		—		103,595
Assets held for sale		—		—		76,668		—		76,668
Other current assets		50		22,209		149,760		—		172,019
Total current assets		1,198		32,386		1,122,255		—		1,155,839
Property, plant and equipment, net		—		—		6,267,583		—		6,267,583
Goodwill		—		—		166,917		—		166,917
Intercompany receivables		142,448		—		1,342,942		(1,485,390)		—
Investment in consolidated affiliates		3,170,254		4,830,572		1,083,948		(9,084,774)		—
Deferred tax assets		—		443,049		366,586		(443,049)		366,586
Other long-term assets		—		344		447,962		(218,216)		230,090
Total assets	$	3,313,900	$	5,306,351	$	10,798,193	$	(11,231,429)	$	8,187,015
	LIABILITIES AND EQUITY
Current liabilities:
Current portion of debt	$	—	$	—	$	297	$	—	$	297
Trade accounts payable		205		8		264,365		—		264,578
Accrued liabilities		20,669		65,246		457,333		—		543,248
Income taxes payable		—		—		13,811		—		13,811
Total current liabilities		20,874		65,254		735,806		—		821,934
Long-term debt		—		3,796,550		—		(218,215)		3,578,335
Other long-term liabilities		—		22,659		499,797		—		522,456
Deferred income taxes		—		—		452,544		(443,049)		9,495
Intercompany payable		46,000		1,439,390		—		(1,485,390)		—
Total liabilities		66,874		5,323,853		1,688,147		(2,146,654)		4,932,220
Shareholders’ equity		3,247,026		(17,502)		9,102,276		(9,084,775)		3,247,025
Noncontrolling interest		—		—		7,770		—		7,770
Total equity		3,247,026		(17,502)		9,110,046		(9,084,775)		3,254,795
Total liabilities and equity	$	3,313,900	$	5,306,351	$	10,798,193	$	(11,231,429)	$	8,187,015

95

Condensed Consolidating Statements of Income (Loss)

	Year Ended December 31, 2017
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
Revenues and other income:
Operating revenues	$	—	$	—	$	2,564,285	$	—	$	2,564,285
Earnings (losses) from unconsolidated affiliates		—		—		7		—		7
Earnings (losses) from consolidated affiliates		(528,180)		18,380		(343,233)		853,033		—
Investment income (loss)		17		63		13,031		(11,917)		1,194
Total revenues and other income		(528,163)		18,443		2,234,090		841,116		2,565,486
Costs and other deductions:
Direct costs		—		—		1,718,069		—		1,718,069
General and administrative expenses		10,995		715		240,139		(665)		251,184
Research and engineering		—		—		51,069		—		51,069
Depreciation and amortization		—		125		842,818		—		842,943
Interest expense		—		232,103		(9,214)		—		222,889
Impairments and other charges		—		—		44,536		—		44,536
Other, net		7,662		19,033		(12,480)		665		14,880
Intercompany interest expense		(9)		—		9		—		—
Total costs and other deductions		18,648		251,976		2,874,946		—		3,145,570
Income (loss) from continuing operations before income taxes		(546,811)		(233,533)		(640,856)		841,116		(580,084)
Income tax expense (benefit)		—		109,700		(192,670)		—		(82,970)
Income (loss) from continuing operations, net of tax		(546,811)		(343,233)		(448,186)		841,116		(497,114)
Income (loss) from discontinued operations, net of tax		—		—		(43,519)		—		(43,519)
Net income (loss)		(546,811)		(343,233)		(491,705)		841,116		(540,633)
Less: Net (income) loss attributable to noncontrolling interest		—		—		(6,178)		—		(6,178)
Net income (loss) attributable to Nabors	$	(546,811)	$	(343,233)	$	(497,883)	$	841,116	$	(546,811)

96

	Year Ended December 31, 2016
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
Revenues and other income:
Operating revenues	$	—	$	—	$	2,227,839	$	—	$	2,227,839
Earnings (losses) from unconsolidated affiliates		—		—		(221,914)		—		(221,914)
Earnings (losses) from consolidated affiliates		(1,017,338)		(231,960)		(359,751)		1,609,049		—
Investment income (loss)		2		132		12,972		(11,923)		1,183
Intercompany interest income (loss)		—		569		—		(569)		—
Total revenues and other income		(1,017,336)		(231,259)		1,659,146		1,596,557		2,007,108
Costs and other deductions:
Direct costs		—		—		1,344,298		—		1,344,298
General and administrative expenses		10,559		603		217,333		(856)		227,639
Research and engineering		—		—		33,582		—		33,582
Depreciation and amortization		—		124		871,507		—		871,631
Interest expense		—		204,010		(18,650)		—		185,360
Impairments and other charges		1,366		—		497,133		—		498,499
Other, net		482		(14)		42,850		856		44,174
Intercompany interest expense		(1)		—		570		(569)		—
Total costs and other deductions		12,406		204,723		2,988,623		(569)		3,205,183
Income (loss) from continuing operations before income taxes		(1,029,742)		(435,982)		(1,329,477)		1,597,126		(1,198,075)
Income tax expense (benefit)		—		(76,231)		(110,600)		—		(186,831)
Income (loss) from continuing operations, net of tax		(1,029,742)		(359,751)		(1,218,877)		1,597,126		(1,011,244)
Income (loss) from discontinued operations, net of tax		—		—		(18,363)		—		(18,363)
Net income (loss)		(1,029,742)		(359,751)		(1,237,240)		1,597,126		(1,029,607)
Less: Net (income) loss attributable to noncontrolling interest		—		—		(135)		—		(135)
Net income (loss) attributable to Nabors	$	(1,029,742)	$	(359,751)	$	(1,237,375)	$	1,597,126	$	(1,029,742)

97

	Year Ended December 31, 2015
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
Revenues and other income:
Operating revenues	$	—	$	—	$	3,864,437	$	—	$	3,864,437
Earnings (losses) from unconsolidated affiliates		—		—		(75,081)		—		(75,081)
Earnings (losses) from consolidated affiliates		(351,407)		(41,826)		(164,697)		557,930		—
Investment income (loss)		—		584		11,666		(9,942)		2,308
Intercompany interest income		—		6,452		—		(6,452)		—
Total revenues and other income		(351,407)		(34,790)		3,636,325		541,536		3,791,664
Costs and other deductions:
Direct costs		—		—		2,371,436		—		2,371,436
General and administrative expenses		8,768		1		316,119		(560)		324,328
Research and engineering		—		—		41,253		—		41,253
Depreciation and amortization		—		705		969,754		—		970,459
Interest expense		(1)		201,364		(19,435)		—		181,928
Impairments and other charges		—		—		368,967		—		368,967
Other, net		12,469		—		(52,201)		560		(39,172)
Intercompany interest expense		32		—		6,420		(6,452)		—
Total costs and other deductions		21,268		202,070		4,002,313		(6,452)		4,219,199
Income (loss) from continuing operations before income taxes		(372,675)		(236,860)		(365,988)		547,988		(427,535)
Income tax expense (benefit)		—		(72,163)		(25,875)		—		(98,038)
Income (loss) from continuing operations, net of tax		(372,675)		(164,697)		(340,113)		547,988		(329,497)
Income (loss) from discontinued operations, net of tax		—		—		(42,797)		—		(42,797)
Net income (loss)		(372,675)		(164,697)		(382,910)		547,988		(372,294)
Less: Net (income) loss attributable to noncontrolling interest		—		—		(381)		—		(381)
Net income (loss) attributable to Nabors	$	(372,675)	$	(164,697)	$	(383,291)	$	547,988	$	(372,675)

98

Condensed Consolidating Statements of Comprehensive Income (Loss)

	Year Ended December 31, 2017
��			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
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		28,372		—		28,372		(28,372)		28,372
Unrealized gains (losses) on marketable securities:
Unrealized gains (losses) on marketable securities		(6,061)		—		(6,061)		6,061		(6,061)
Less: reclassification adjustment for (gains) losses included in net income (loss)		970		—		970		(970)		970
Unrealized gains (losses) on marketable securities		(5,091)		—		(5,091)		5,091		(5,091)
Pension liability amortization and adjustment		(275)		(275)		(550)		825		(275)
Unrealized gains (losses) and amortization on cash flow hedges		613		613		613		(1,226)		613
Other comprehensive income (loss) before tax		23,619		338		23,344		(23,682)		23,619
Income tax expense (benefit) related to items of other comprehensive income (loss)		315		315		630		(945)		315
Other comprehensive income (loss), net of tax		23,304		23		22,714		(22,737)		23,304
Comprehensive income (loss) attributable to Nabors		(523,507)		(343,210)		(475,169)		818,379		(523,507)
Net income (loss) attributable to noncontrolling interest		—		—		6,178		—		6,178
Translation adjustment attributable to noncontrolling interest		—		—		282		—		282
Comprehensive income (loss) attributable to noncontrolling interest		—		—		6,460		—		6,460
Comprehensive income (loss)	$	(523,507)	$	(343,210)	$	(468,709)	$	818,379	$	(517,047)

99

	Year Ended December 31, 2016
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
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		17,743		(21)		17,743		(17,722)		17,743
Unrealized gains (losses) on marketable securities:
Unrealized gains (losses) on marketable securities		11,054		—		11,054		(11,054)		11,054
Less: reclassification adjustment for (gains) losses included in net income (loss)		3,495		—		3,495		(3,495)		3,495
Unrealized gains (losses) on marketable securities		14,549		—		14,549		(14,549)		14,549
Pension buyout		3,059		3,059		6,118		(9,177)		3,059
Pension liability amortization and adjustment		1,061		1,061		2,122		(3,183)		1,061
Unrealized gains (losses) and amortization on cash flow hedges		613		613		613		(1,226)		613
Other comprehensive income (loss) before tax		37,025		4,712		41,145		(45,857)		37,025
Income tax expense (benefit) related to items of other comprehensive income (loss)		1,551		1,551		3,102		(4,653)		1,551
Other comprehensive income (loss), net of tax		35,474		3,161		38,043		(41,204)		35,474
Comprehensive income (loss) attributable to Nabors		(994,268)		(356,590)		(1,199,332)		1,555,922		(994,268)
Net income (loss) attributable to noncontrolling interest		—		—		135		—		135
Translation adjustment attributable to noncontrolling interest		—		—		251		—		251
Comprehensive income (loss) attributable to noncontrolling interest		—		—		386		—		386
Comprehensive income (loss)	$	(994,268)	$	(356,590)	$	(1,198,946)	$	1,555,922	$	(993,882)

100

	Year Ended December 31, 2015
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
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)		67		(116,172)		116,105		(116,239)
Less: reclassification adjustment for realized (gain) loss on translation adjustment		5,365		—		5,365		(5,365)		5,365
Translation adjustment attributable to Nabors		(110,874)		67		(110,807)		110,740		(110,874)
Unrealized gains (losses) on marketable securities:
Unrealized gains (losses) on marketable securities		(15,310)		—		(15,310)		15,310		(15,310)
Less: reclassification adjustment for (gains) losses included in net income (loss)		—		—		—		—		—
Unrealized gains (losses) on marketable securities		(15,310)		—		(15,310)		15,310		(15,310)
Pension liability amortization and adjustment		1,104		1,104		2,208		(3,312)		1,104
Unrealized gains (losses) and amortization on cash flow hedges		613		613		613		(1,226)		613
Other comprehensive income (loss) before tax		(124,467)		1,784		(123,296)		121,512		(124,467)
Income tax expense (benefit) related to items of other comprehensive income (loss)		648		648		1,056		(1,704)		648
Other comprehensive income (loss), net of tax		(125,115)		1,136		(124,352)		123,216		(125,115)
Comprehensive income (loss) attributable to Nabors		(497,790)		(163,561)		(507,643)		671,204		(497,790)
Net income (loss) attributable to noncontrolling interest		—		—		381		—		381
Translation adjustment attributable to noncontrolling interest		—		—		(1,461)		—		(1,461)
Comprehensive income (loss) attributable to noncontrolling interest		—		—		(1,080)		—		(1,080)
Comprehensive income (loss)	$	(497,790)	$	(163,561)	$	(508,723)	$	671,204	$	(498,870)

101

Condensed Consolidating Statements of Cash Flows

	Year Ended December 31, 2017
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
Net cash provided by (used for) operating activities	$	143,444	$	(90,229)	$	142,527	$	(132,986)	$	62,756
Cash flows from investing activities:
Purchases of investments		—		—		(6,722)		—		(6,722)
Sales and maturities of investments		—		—		13,069		—		13,069
Cash paid for acquisitions of businesses, net of cash acquired		—		—		9,040		—		9,040
Cash paid for investments in consolidated affiliates		(100)		—		(85,960)		86,060		—
Capital expenditures		—		—		(574,467)		—		(574,467)
Proceeds from sales of assets and insurance claims		—		—		57,933		—		57,933
Change in intercompany balances		—		(599,974)		599,974		—		—
Other changes in investing		—		—		(856)		—		(856)
Net cash provided by (used for) investing activities		(100)		(599,974)		12,011		86,060		(502,003)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		—		—		(188)		—		(188)
Proceeds from issuance of long-term debt		—		411,200		—		—		411,200
Debt issuance costs		—		(11,043)		—		—		(11,043)
Proceeds from revolving credit facilities		—		725,000		—		—		725,000
Proceeds from parent contributions		—		42,980		43,080		(86,060)		—
Proceeds from (payments for) issuance of common shares		8,299		—		1		—		8,300
Purchase of capped call hedge transactions		—		(40,250)		—		—		(40,250)
Reduction of long-term debt		—		(270,269)		(111,545)		—		(381,814)
Dividends to shareholders		(80,419)		—		—		11,916		(68,503)
Proceeds from (payment for) commercial paper, net		—		40,000		—		—		40,000
Reduction in revolving credit facilities		—		(215,000)		—		—		(215,000)
Payments on term loan		—		(162,500)		—		—		(162,500)
Proceeds from (payments for) short-term borrowings		—		—		(543)		—		(543)
Cash proceeds from equity component of exchangeable debt		—		159,952		—		—		159,952
Proceeds from issuance of intercompany debt		57,000		20,000		(77,000)		—		—
Noncontrolling interest contribution		—		—		20,000		—		20,000
Paydown of intercompany debt		(102,000)		(20,000)		122,000		—		—
Distributions to Non-controlling interest		—		—		(7,272)		—		(7,272)
Distribution from subsidiary to parent		—		—		(121,070)		121,070		—
Repurchase of common shares		(18,071)		—		—		—		(18,071)
Redeemable noncontrolling interest contribution		—		—		61,123		—		61,123
Other changes		(8,210)		—		(1)		—		(8,211)
Net cash (used for) provided by financing activities		(143,401)		680,070		(71,415)		46,926		512,180
Effect of exchange rate changes on cash and cash equivalents		—		—		(29)		—		(29)
Net increase (decrease) in cash and cash equivalents		(57)		(10,133)		83,094		—		72,904
Cash and cash equivalents, beginning of period		1,148		10,177		252,768		—		264,093
Cash and cash equivalents, end of period	$	1,091	$	44	$	335,862	$	—	$	336,997

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	Year Ended December 31, 2016
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
Net cash provided by (used for) operating activities	$	58,406	$	(233,738)	$	757,660	$	(50,423)	$	531,905
Cash flows from investing activities:
Purchases of investments		—		—		(24)		—		(24)
Sales and maturities of investments		—		—		739		—		739
Cash paid for acquisitions of businesses, net of cash acquired		—		—		(22,278)		—		(22,278)
Cash paid for investments in consolidated affiliates		—		(86,459)		(159,000)		245,459		—
Capital expenditures		—		—		(395,455)		—		(395,455)
Proceeds from sale of assets and insurance claims		—		—		34,831		—		34,831
Change in intercompany balances		—		103,384		(103,384)		—		—
Other		—		—		64		—		64
Net cash provided by (used for) investing activities		—		16,925		(644,507)		245,459		(382,123)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		—		—		3		—		3
Debt issuance costs		—		(11,520)		—		—		(11,520)
Proceeds from (payments for) issuance of common shares		967		—		—		—		967
Reduction in long-term debt		—		(350,000)		(143,612)		—		(493,612)
Dividends to shareholders		(59,866)		—		—		8,942		(50,924)
Proceeds from (payments for) commercial paper, net		—		(8,000)		—		—		(8,000)
Proceeds from issuance of intercompany debt		45,500		—		(45,500)		—		—
Proceeds from revolving credit facilities		—		610,000		1,500		—		611,500
Reduction in revolving credit facilities		—		(610,000)		(1,500)		—		(611,500)
Proceeds from issuance of long-term debt		—		600,000		—		—		600,000
Payments on term loan		—		(162,500)		—		—		(162,500)
Paydown of intercompany debt		(40,000)		—		40,000		—		—
Repurchase of common shares		—		—		(1,687)		—		(1,687)
Proceeds from (payments for) short-term borrowings		—		—		(6,211)		—		(6,211)
Proceeds from parent contributions		—		159,000		86,458		(245,458)		—
Payments on parent (Equity of N/P)		—		—		(41,480)		41,480		—
Other changes		(4,732)		—		—		—		(4,732)
Net cash (used for) provided by financing activities		(58,131)		226,980		(112,029)		(195,036)		(138,216)
Effect of exchange rate changes on cash and cash equivalents		—		—		(2,003)		—		(2,003)
Net increase (decrease) in cash and cash equivalents		275		10,167		(879)		—		9,563
Cash and cash equivalents, beginning of period		873		10		253,647		—		254,530
Cash and cash equivalents, end of period	$	1,148	$	10,177	$	252,768	$	—	$	264,093

103

	Year Ended December 31, 2015
			Nabors		Other
	Nabors		Delaware		Subsidiaries
	(Parent/		(Issuer/		(Non-		Consolidating
	Guarantor)		Guarantor)		Guarantors)		Adjustments		Total
	(In thousands)
Net cash provided by (used for) operating activities	$	39,478	$	(217,685)	$	1,066,026	$	(31,263)	$	856,556
Cash flows from investing activities:
Purchases of investments		—		—		(9)		—		(9)
Sales and maturities of investments		—		—		961		—		961
Proceeds from merger transaction		5,500		646,078		(1,528)		—		650,050
Cash paid for acquisition of businesses, net of cash acquired		—		—		(80,187)		—		(80,187)
Investment in unconsolidated affiliates		—		—		(445)		—		(445)
Capital expenditures		—		—		(867,106)		—		(867,106)
Proceeds from sales of assets and insurance claims		—		—		68,206		—		68,206
Changes in intercompany balances		—		135,518		(135,518)		—		—
Other		—		—		1,081		—		1,081
Net cash provided by (used for) investing activities		5,500		781,596		(1,014,545)		—		(227,449)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		—		—		645		—		645
Proceeds from short-term borrowings		—		—		318		—		318
Debt issuance costs		—		(1,847)		—		—		(1,847)
Proceeds from (payments for) issuance of common shares		1,296		—		—		—		1,296
Reduction in long-term debt		—		—		(27,478)		—		(27,478)
Proceeds from term loan		—		625,000		—		—		625,000
Payments on term loan		—		(300,000)		—		—		(300,000)
Dividends to shareholders		(79,304)		—		—		9,941		(69,363)
Proceeds from (payments for) commercial paper, net		—		(525,119)		—		—		(525,119)
Cash proceeds from non-controlling interest		—		—		3,972		—		3,972
Reduction in revolving credit facilities		—		(450,000)		—		—		(450,000)
Repurchase of common shares		—		—		(99,598)		—		(99,598)
Proceeds (issuance) of intercompany debt		67,500		88,058		(155,558)		—		—
Paydown of intercompany debt		(27,000)		—		27,000		—		—
Payments on parent (Equity of N/P)		—		—		(21,322)		21,322		—
Other		(7,767)		—		—		—		(7,767)
Net cash (used for) provided by financing activities		(45,275)		(563,908)		(272,021)		31,263		(849,941)
Effect of exchange rate changes on cash and cash equivalents		—		—		(25,785)		—		(25,785)
Net increase (decrease) in cash and cash equivalents		(297)		3		(246,325)		—		(246,619)
Cash and cash equivalents, beginning of period		1,170		7		499,972		—		501,149
Cash and cash equivalents, end of period	$	873	$	10	$	253,647	$	—	$	254,530

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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

	Page No.
Consolidated Balance Sheets as of December 31, 2017 and 2016	47
Consolidated Statement of Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015	48
Consolidated Statement of Comprehensive Income (Loss) for the Years Ended December 31, 2017, 2016 and 2015	49
Consolidated Statement of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015	50
Consolidated Statement of Changes in Equity for the Years Ended December 31, 2017, 2016 and 2015	51
Notes to Consolidated Financial Statements	52

(2)Financial Statement Schedule

	Page No.
Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2017, 2016 and 2015	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

			Charged to			Balance at
	Balance at		Costs and	Charged to
	Beginning		Other	Other		End of
	of Period		Deductions	Accounts	Deductions	Period
	(In thousands)
2017
Allowance for doubtful accounts	$	43,757	2,544	86	(2,011)	$	44,376
Inventory reserve	$	26,537	5,897	—	(3,500)	$	28,934
Valuation allowance on deferred tax assets	$	1,807,728	—	61,762	—	$	1,869,490
2016
Allowance for doubtful accounts	$	44,553	19,132	(58)	(19,870)	$	43,757
Inventory reserve	$	46,813	13,587	—	(33,863)	$	26,537
Valuation allowance on deferred tax assets	$	1,560,162	—	247,566	—	$	1,807,728
2015
Allowance for doubtful accounts	$	23,545	36,720	(288)	(15,424)	$	44,553
Inventory reserve	$	45,141	9,485	—	(7,813)	$	46,813
Valuation allowance on deferred tax assets	$	1,537,507	—	22,655	—	$	1,560,162

109

Exhibit Index

Exhibit No.	Description
2.1	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).
2.2	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).
2.3	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).
2.4	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).
2.5	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).
3.1	Memorandum of Association of Nabors Industries Ltd. (incorporated by reference to Annex II to the proxy statement/prospectus included in our Registration Statement on Form S-4 (File No. 333-76198) filed with the SEC on May 10, 2002, as amended).
3.2	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).
4.1	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).
4.2	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).
4.3	Indenture, dated as of September 14, 2010, among Nabors Industries, Inc., Nabors Industries Ltd., Wilmington Trust Company, as trustee, and Citibank, N.A. as securities administrator, with respect to Nabors Industries, Inc.’s 5.0% Senior Notes due 2020 (including form of 5.0% Senior Note due 2020) (incorporated by reference to Exhibit 4.2 to our Form 8-K (File No. 001-32657) filed with the SEC on September 15, 2010).
4.4	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).
4.5	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.	Description
4.6	Indenture, dated as of December 9, 2016 by and among Nabors Industries, Inc., as issuer, Nabors Industries Ltd., as guarantor, Citibank, N.A., as securities administrator and Wilmington Trust, National Association, as trustee with respect to Nabors Industries, Inc.’s 5.50% Senior Notes due 2023 (incorporated by reference to Exhibit 4.1 to our Form 8-K (File No. 001-32657) filed with the SEC on December 9, 2016).
4.7	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).
4.8	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).
4.9	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).
10.1	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).
10.2	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).
10.3	Call Option Transaction Confirmation, dated as of January 9, 2017, between Nabors Industries Ltd., Nabors Industries, Inc. and Citigroup Global Markets Inc. (incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-32657) filed with the SEC on January 11, 2017).
10.4	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).
10.5	Additional Call Option Transaction Confirmation, dated as of January 10, 2017, between Nabors Industries Ltd., Nabors Industries, Inc. and Citigroup Global Markets Inc. (incorporated by reference to Exhibit 10.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 13, 2017).
10.6	Additional Call Option Transaction Confirmation, dated as of January 10, 2017, between Nabors Industries Ltd., Nabors Industries, Inc. and Goldman, Sachs & Co. (incorporated by reference to Exhibit 10.2 to our Form 8-K (File No. 001-32657) filed with the SEC on January 13, 2017).
10.7(+)	Executive Employment Agreement by and among Nabors Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello, effective as of January 1, 2013 (incorporated by reference to Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on March 11, 2013).
10.7(a)(+)	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).
10.7(b)(+)	Second Amendment to Executive Employment Agreement, dated as of June 5, 2015, among Nabors Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on June 8, 2015).

111

Exhibit No.	Description
10.7(c)(+)	Third Amendment to Executive Employment Agreement, dated as of December 31, 2015, among Nabors Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on January 5, 2016).
10.7(d)(+)	Fourth Amendment to Executive Employment Agreement, dated June 10, 2016, among Nabors Industries Ltd., Nabors Industries, Inc. and Anthony G. Petrello (incorporated by reference to Exhibit 99.1 to our Form 8-K (File No. 001-32657) filed with the SEC on June 13, 2016).
10.8(+)	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).
10.8(a)(+)	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).
10.8(b)(+)	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).
10.8(c)(+)	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).
10.8(d)(+)	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).
10.9(+)	Form of Indemnification Agreement entered into between Nabors Industries Ltd. and the directors and executive officers (incorporated by reference to Exhibit 10.28 to our Form 10-K (File No. 000-49887) filed with the SEC on March 31, 2003).
10.10(+)	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).
10.10(a)(+)	Form of Stock Option Agreement – Others, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(b) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(b)(+)	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).
10.10(c)(+)	Form of Nabors Industries Ltd. TSR Stock Grant Agreement – Anthony G. Petrello, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(d) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(d)(+)	Form of Nabors Corporate Services, Inc. TSR Stock Grant Agreement – Anthony G. Petrello, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(e) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(e)(+)	Form of Nabors Industries Ltd. TSR Stock Grant Agreement – William Restrepo, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(f) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(f)(+)	Form of Nabors Corporate Services, Inc. TSR Grant Agreement – William Restrepo, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(g) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(g)(+)	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.	Description
10.10(h)(+)	Form of Nabors Corporate Services, Inc. Restricted Stock Agreement – Anthony G. Petrello, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(i) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(i)(+)	Form of Nabors Industries Ltd. Restricted Stock Agreement – William Restrepo, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(j) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.10(j)(+)	Form of Nabors Corporate Services, Inc. Restricted Stock Agreement – William Restrepo, pursuant to the 2016 Stock Plan (incorporated by reference to Exhibit 10.1(k) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.11(+)	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).
10.11(a)(+)	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).
10.11(b)(+)	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).
10.11(c)(+)	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).
10.11(d)(+)	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).
10.11(e)(+)	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).
10.11(f)(+)	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).
10.11(g)(+)	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).
10.11(h)(+)	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).
10.11(i)(+)	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).
10.12(+)	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).
10.12(a)(+)	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).
10.12(b)(+)	Form of Stock Option Agreement—Petrello/Isenberg (incorporated by reference to Exhibit 10.03 to our Form 8-K (File No. 000-49887) filed with the SEC on March 2, 2005).
10.12(c)(+)	Form of Stock Option Agreement—Others (incorporated by reference to Exhibit 10.04 to our Form 8-K (File No. 000-49887) filed with the SEC on March 2, 2005).
10.13(+)	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.	Description
10.14(+)	Amended and Restated 1999 Stock Option Plan for Non-Employee Directors (amended on May 2, 2003) (incorporated by reference to Exhibit 10.29 to our Form 10-Q (File No. 000-49887) filed with the SEC on May 12, 2003).
10.14(a)(+)	Form of Stock Option Agreement to the Amended and Restated 1999 Stock Option Plan for Non-Employee Directors (incorporated by reference to Exhibit 10.2 to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.15(+)	Nabors Industries, Inc. Executive Deferred Compensation Plan (as Amended and Restated Effective as of April 1, 2017) (incorporated by reference to Exhibit 10.3(a) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.15(a)	Form of Deferred Bonus Agreement under the Nabors Industries, Inc. Executive Deferred Compensation Plan (incorporated by reference to Exhibit 10.3(b) to our Form 10-Q (File No. 001-32657) filed with the SEC on April 28, 2017).
10.16(+)	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).
12	Computation of Ratios.*
21	Significant Subsidiaries.*
23.1	Consent of Independent Registered Public Accounting Firm—PricewaterhouseCoopers LLP—Houston.*
31.1	Rule 13a-14(a)/15d-14(a) Certification of Anthony G. Petrello, Chairman, President and Chief Executive Officer.*
31.2	Rule 13a-14(a)/15d-14(a) Certification of William Restrepo, Chief Financial Officer.*
32.1	Certifications required by Rule 13a-14(b) or Rule 15d-14(b) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350), executed by Anthony G. Petrello, Chairman, President and Chief Executive Officer and William Restrepo, Chief Financial Officer.*
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

SIGNATURES

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.

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
/s/ ANTHONY G. PETRELLO	Chairman, President and Chief Executive Officer	March 1, 2018
Anthony G. Petrello
/s/ WILLIAM RESTREPO
William Restrepo	Chief Financial Officer	March 1, 2018
/s/ TANYA S. BEDER
Tanya S. Beder	Director	March 1, 2018
/s/ JAMES R. CRANE
James R. Crane	Director	March 1, 2018
/s/ MICHAEL C. LINN
Michael C. Linn	Director	March 1, 2018
/s/ JOHN P. KOTTS
John P. Kotts	Director	March 1, 2018
/s/ DAG SKATTUM
Dag Skattum	Director	March 1, 2018
/s/ JOHN YEARWOOD
John Yearwood	Director	March 1, 2018

115