Toggle SGML Header (+)


Section 1: 10-K (10-K)

nbr_Current folio_10K

Table of Contents

 

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, 2018

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

Preferred shares, 6.00% Mandatory Convertible Preferred Shares, Series A, $.001 par value per share

 

New York Stock Exchange

 

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

 

Indicate by check mark whether the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.  YES ☒  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 every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to 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 ☐

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 344,852,460 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 29, 2018, based on the closing price of our common shares as of such date of $6.41 per share as reported on the New York Stock Exchange, was $2,210,504,269. 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 21, 2019 was 358,791,975, excluding 52,800,203 common shares held by our subsidiaries, or 411,592,178 in the aggregate.

 

DOCUMENTS INCORPORATED BY REFERENCE

 

Specified portions of the definitive Proxy

Statement to be distributed in connection with our 2019 Annual General Meeting of Shareholders (Part III).

 

 

 


 

Table of Contents

NABORS INDUSTRIES LTD.

Form 10-K Annual Report

For the Year Ended December 31, 2018

 

Table of Contents

 

 

 

 

 

PART I 

Item 1. 

Business

    

4

Item 1A. 

Risk Factors

 

10

Item 1B. 

Unresolved Staff Comments

 

21

Item 2. 

Properties

 

21

Item 3. 

Legal Proceedings

 

21

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

 

 

2


 

Table of Contents

Our internet address is www.nabors.com. We make available free of charge through our website our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission (the “SEC”). Reference in this document to our website address does not constitute incorporation by reference of the information contained on the website into this annual report on Form 10-K. The SEC maintains an internet site (www.sec.gov) that contains reports, proxy and information statements and other information regarding issuers that file electronically with the SEC. In addition, documents relating to our corporate governance (such as committee charters, governance guidelines and other internal policies) can be found on our website.

 

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, covenant restrictions, availability under our unsecured revolving credit facilities, and future issuances of debt or equity securities;

 

·

our dependence on our operating subsidiaries and investments to meet our financial obligations;

 

·

our ability to retain skilled employees;

 

·

our ability to complete, and realize the expected benefits of strategic transactions;

 

·

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

 

3


 

Table of Contents

·

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.

 

PART I

 

ITEM 1.  BUSINESS

 

Nabors Industries, Ltd. (NYSE: NBR) was formed as a Bermuda exempted company on December 11, 2001. Unless the context requires otherwise, references in this annual report to “we,” “us,” “our,” “the Company,” or “Nabors” mean Nabors Industries Ltd., together with our subsidiaries where the context requires. References in this annual report to “Nabors Delaware” mean Nabors Industries, Inc., a wholly owned subsidiary of Nabors.

 

Overview

 

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, tubular 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 tubular services, wellbore placement solutions and are a leading provider of directional drilling and measurement while drilling (“MWD”) systems and services.

 

Our business consists of five reportable segments:  U.S. Drilling, Canada Drilling, International Drilling, Drilling Solutions and Rig Technologies.

 

With operations in over 25 countries, we are a global provider of drilling and drilling-related services for land-based and offshore oil and natural gas wells, with a fleet of rigs and drilling-related equipment which, as of December 31, 2018 included:

 

·

384 actively marketed rigs for land-based drilling operations in the United States, Canada and approximately 18 other countries throughout the world; and

 

·

33 actively marketed rigs for offshore drilling operations in the United States and multiple international markets.

 

4


 

Table of Contents

The following table presents our average rigs working (a measure of activity and utilization over the year) for the years ended December 31, 2018, 2017 and 2016:

 

 

 

 

 

 

 

 

 

    

Year Ended December 31,

 

 

2018

 

2017

 

2016

Average Rigs Working:

 

 

 

 

 

 

U.S. Drilling

 

113.2

 

100.8

 

62.0

Canada Drilling

 

16.9

 

15.4

 

9.7

International Drilling

 

92.9

 

91.1

 

100.2

 

 

223.0

 

207.3

 

171.9

 

Average rigs working represents a measure of the number of equivalent rigs operating during a given period. For example, one rig operating 182.5 days during a 365-day period represents 0.5 average rigs working.

 

Additional information regarding the geographic markets in which we operate and our business segments can be found in Note 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 drilling activities in the Gulf of Mexico. We operate one of the largest land-based drilling rig fleets in the United States, consisting of 188 AC rigs and 22 SCR rigs which were actively marketed as of December 31, 2018.

 

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.

 

During the second half of 2016, we introduced our PACE®-M800 and PACE®-M1000 rigs which complement our existing PACE®-X800 rigs. The PACE®-M800 rig is designed for lower-density multi-well pads whereas the PACE®-M1000 is designed for higher density pads. Both are designed to move rapidly between pads. Featuring the same advanced walking capabilities as the PACE®-X800 rig, the PACE®-M800 rig can quickly move efficiently on pads and over short distances, with minimal rig-up and rig-down components.

 

In addition to land drilling operations throughout the lower 48 states and Alaska, we also actively marketed 12 platform rigs in the U.S. Gulf of Mexico as of December 31, 2018.

 

Canada Drilling

 

Our rig fleet consisted of 41 land-based drilling rigs in Canada as of December 31, 2018. Over the past few years, the Canada market has moved away from the conventional drilling of vertical wells and now focuses virtually exclusively on horizontal wells. Our focus in recent years has been on the market for larger, more capable rigs. The majority of our work in Canada is in this market segment.

 

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, 2018, our international fleet consisted of 133 land-based drilling rigs in approximately 18 countries. We also actively marketed 18 platforms and three jackup rigs in the international offshore drilling markets as of the same date. We continue to upgrade

5


 

Table of Contents

and deploy high-specification desert rigs specifically for gas drilling in the Middle East. We have increased the utilization of the PACE®-X800 rigs in international markets by deploying six such rigs in Latin America.

 

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:

 

RigWatch® Suite

 

Nabors’ RigWatch® suite of software solutions that turns rig site data into wellsite knowledge to help customers track and trend drilling practices to drive performance.

 

REVit®  Software

 

Nabors REVit® technology features advanced top drive automation that eliminates stick slip, a common mode of vibration that limits drilling performance.

 

DrillSmart® Software

 

A best-in-class automatic driller based on proprietary technology that allows the system to adapt to operating parameters and drilling conditions while optimizing performance.

 

ROCKit® Software

 

A patented directional steering control system that oscillates drill pipe to reduce friction and increase rate of penetration.

 

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 dynamic 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.

 

Rig Technologies

 

Our Rig Technologies segment is primarily comprised of Canrig, which manufactures and sells top drives, catwalks, wrenches, drawworks and other drilling related equipment such as robotic systems and downhole tools which are installed on both onshore and offshore drilling rigs. Rig Technologies also provides aftermarket sales and services for the installed base of its equipment. 

 

Our Business Strategy

 

Our business strategy is to build shareholder value and enhance our competitive position by:

 

·

achieving superior operational and health, safety and environmental performance;

6


 

Table of Contents

 

·

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 2018 we achieved several milestones in our drive to automate and integrate the well construction process. As the industry recovered 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 417 rigs is the fundamental platform for our business. We enter 2019 with nearly 100 Nabors SmartRig™ units deployed in the U.S. Lower 48, and contracted commitments to deploy an additional eight units during the first half of 2019. Our new PACE®-M750 rig was introduced in early 2018, as a significant, and capital efficient, retrofit to the existing PACE®-M550. This design bolsters capabilities for faster drilling, improved mobility and extended reach at a fraction of the cost of a newbuild unit.

 

During 2018, we made further progress commercializing our drilling technology portfolio. We believe this positions us well to address the changing market dynamic both in the United States and internationally. Our technological development efforts drive toward a seamless integration of the rig’s operations with downhole sensing. 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.

 

In late 2018, Nabors acquired PetroMar Technologies, a developer and operator of downhole LWD tools that focuses on high-value formation data to facilitate well completion optimization. The addition of PetroMar expands the Company’s portfolio of value-added services.

 

Oil prices declined sharply during the fourth quarter of 2018. This volatility has driven certain exploration and production companies in the U.S. to announce reductions in planned year-over-year capital spending for 2019. We have positioned the Company for this volatility, while still pursuing the primary goal of reducing net debt in 2019. As the year begins, Nabors holds contracts to deploy additional drilling rigs during 2019 with multiple customers in our global markets.  

 

Drilling Contracts

 

Our drilling contracts are typically daywork contracts. A daywork contract generally provides for a basic rate per day when drilling (the dayrate for providing a rig and crew) and for lower rates when the rig is moving between drilling locations, or when drilling operations are interrupted or restricted by equipment breakdowns, adverse weather conditions or other conditions beyond our control. In addition, daywork contracts may provide for a lump-sum fee for the mobilization and demobilization of the rig, which in most cases approximates our anticipated costs. A daywork contract differs from a footage contract (in which the drilling contractor is paid on the basis of a rate per foot drilled) and a turnkey contract (in which the drilling contractor is paid for drilling a well to a specified depth for a fixed price). We also offer performance enhancing drilling services, performance software and equipment such as managed pressure services, directional drilling, rotary steering systems and measurement while drilling. These additional products and services are additive to our rig charges.

 

Our contracts for land-based and offshore drilling have durations that are single-well, multi-well or term. Term contracts generally have durations ranging from six months to five years. Under term contracts, our rigs are committed to one customer. Offshore workover projects are often contracted on a single-well basis. We generally receive drilling 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

7


 

Table of Contents

competitive conditions, the geographical area, the geological formation to be drilled, the equipment and services to be supplied, the on-site drilling conditions and the anticipated duration of the work to be performed.

 

Our Customers

 

Our customers include major international, national and independent oil and gas companies. One customer, Saudi Aramco, accounted for approximately 24%, 29% and 33% of our consolidated operating revenues during the years ended December 31, 2018, 2017 and 2016, respectively, which operating revenues are primarily included in the results of our International Drilling reportable segment. Our contracts with Saudi Aramco are on a per rig basis. These contracts are primarily operated through SANAD, our joint venture with Saudi Aramco. See Part I, Item

1A.—Risk Factors—The loss of one or a number of our large customers could have a material adverse effect on our business, financial condition and results of operations.

 

Our Employees

 

As of December 31, 2018, we employed approximately 15,000 people in approximately 25 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.

 

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 reached a near ten-year low of $26 per barrel in February 2016. Oil prices began to stabilize during 2017 and steadily increased throughout much of 2018, hitting a four-year high of $76 per barrel in September. However, during the fourth quarter of 2018, oil prices declined dramatically to a low of $42 per barrel. 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—Our drilling contracts may in certain instances be renegotiated, suspended or terminated without an early termination payment 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.

8


 

Table of Contents

 

In addition to price, other competitive factors in the markets we serve are the overall quality of service and safety record, the technical specification and condition of equipment, the availability of skilled personnel and the ability to offer ancillary services. Our drilling business is subject to certain additional competitive factors. For example, we believe our ability to deliver rigs with new technology and features and, in certain international markets, our experience operating in certain environments and strong customer relationships have been significant factors in the selection of Nabors for the provision of drilling services. We expect that the market for our drilling services will continue to be highly competitive. See Part I, Item 1A.—Risk Factors—We operate in a highly competitive industry with excess drilling capacity, which may adversely affect our results of operations.

 

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 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, 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 384 land drilling rigs, 30 offshore platform rigs and three 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. We undertook the following strategic transactions over the last three years.

 

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 in the fourth quarter of 2017. The joint venture leverages our established business in Saudi Arabia, with a focus on Saudi Arabia's existing and future onshore oil and gas fields.

 

In September 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.

 

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. Tesco was a provider of products such as top drives and automated pipe handling equipment as well as tubular services to upstream companies. The combination of Tesco with Nabors’ current product offerings strengthens our ability to accelerate and scale deployment in drilling automation and analytics.

 

In October 2018, we purchased PetroMar Technologies, a small developer and operator of LWD downhole tools focusing on high-value formation data to facilitate completion optimization particularly in unconventional reservoirs. The tools complement our existing wellbore placement capabilities and are included in our Drilling Solutions operating segment. Under the terms of the transaction, we paid an initial purchase price of $25.0 million. We may also be required to make future payments that are contingent upon the future financial performance of this operation.

 

9


 

Table of Contents

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 2019. 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, have been highly volatile over the past few years and are expected to continue to be volatile for the foreseeable future. For example, oil prices were as high as $107 per barrel during 2014 and reached a near ten-year low of $26 per barrel in February 2016. Oil prices began to stabilize during 2017 and steadily increased throughout much of 2018, hitting a four-year high of $76 per barrel in September. However, during the fourth quarter of 2018, oil prices declined dramatically to a low of $42 per barrel. Declines in oil prices are primarily caused by, among other things, an excess of supply of crude oil in relation to demand. Worldwide military, political and economic events, including initiatives by the Organization of Petroleum Exporting Countries (“OPEC”) and OPEC+, 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, oil and gas production levels by non-OPEC countries, decisions by more expensive production sources to continue producing oil and gas despite excess supply, the availability and demand for drilling equipment and pipeline capacity, availability and pricing of alternative energy sources, and other factors beyond our control may also affect the supply of and demand for oil and natural gas.

 

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.

 

Our customers and thereby our business and profitability could be adversely affected by low oil prices and/or 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

10


 

Table of Contents

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 with a significant amount of excess capacity, especially in low oil price environments. Contract drilling companies compete primarily on a regional basis, and competition may vary significantly from region to region at any particular time. Most rigs and drilling-related equipment can be moved from one region to another in response to changes in levels of activity and market conditions, which may result in an oversupply of such rigs and drilling-related equipment in certain areas, and accordingly, increased price competition. In addition, 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, including environmental and weather-related risks, that could adversely affect our results of operations.

 

Our operations are subject to many hazards inherent in the drilling and workover industries, including environmental pollution, blowouts, cratering, explosions, fires, loss of well control, loss of or damage to the wellbore or underground reservoir, damaged or lost drilling equipment and damage or loss from inclement weather or natural disasters. Any of these hazards could result in personal injury or death, damage to or destruction of equipment and 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 pollution of coastal waters, damage to wildlife and natural habitats, 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.

 

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

11


 

Table of Contents

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 2018, 2017 and 2016, we recognized impairment charges of $46.1 million, $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 2018, 2017 and 2016, we received approximately 41%, 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 24%, 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 contracts, which could adversely affect our liquidity and profitability. Financial difficulties experienced by customers could also adversely affect our utilization rates in the affected market and may cause our counterparties to seek modifications to our contracts with them.

 

12


 

Table of Contents

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, South America, 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.

 

For example, we are exposed to risks related to political instability in Venezuela. On January 28, 2019, the United States Treasury Department’s Office of Foreign Assets Control designated Petroleos de Venezuela S.A. (“PdVSA”)  as a Specially Designated National under Executive Order 13850 (the “Order”). The Order prohibited, among other things, business dealings with PdVSA or any entity in which PdVSA owns, directly or indirectly, a 50 percent or greater interest. As of December 31, 2018, Nabors operated four rigs in Venezuela, under contracts with Chevron and two joint ventures that are majority-owned by PdVSA, Petroboscán and Petrocedeño. The political uncertainty and civil unrest in Venezuela could have a significant impact on our operations there, including the risk that one or more of our rigs could be nationalized by the government or that we will not be paid for our services. Nabors continues to evaluate the potential impact of these developments on its business and operations in Venezuela.

 

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, 2018, we had approximately $3.6 billion in outstanding debt, resulting in a gross debt to capital ratio of 0.57:1, a net debt to capital ratio of 0.53:1 and an asset to debt coverage ratio of approximately 3.82:1.

 

Availability under both the 2012 Revolving Credit Facility and the 2018 Revolving Credit Facility is subject to a covenant not to exceed a net debt to capital ratio of 0.60:1. In addition, availability under the 2018 Revolving Credit Facility is subject to a covenant to maintain an asset to debt coverage ratio of at least 2.50:1. 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 (total debt minus the sum of cash and cash equivalents and short-term investments) by net capitalization (net debt plus shareholders’ equity).  The asset to debt coverage ratio is calculated by dividing (x) drilling-related fixed assets wholly owned by the 2018 Revolver Guarantors or wholly owned subsidiaries of the 2018 Revolver Guarantors by (y) total debt of the 2018 Revolver Guarantors (subject to certain exclusions).  The asset to debt coverage ratio applies only during any period which Nabors Delaware fails to maintain an investment grade rating from at least two ratings agencies. The gross debt to capital ratio, the net debt to capital ratio and the asset to debt coverage ratio are not measures of operating performance or liquidity defined by U.S. GAAP and may not be comparable to similarly titled measures presented by other companies.  The gross debt to capital ratio and the net debt to capital ratio are methods for calculating the amount of leverage a company has in relation to its capital.

 

As of December 31, 2018, we would have been able to borrow $1.267 billion in aggregate under our 2018 Revolving Credit Facility and an additional $496.25 million in aggregate under our 2012 Revolving Credit Facility, in each case subject to compliance with the conditions and covenants contained therein, including compliance with applicable financial ratios.

 

We also have various financial commitments, such as leases, contracts and purchase commitments. Our ability to service our debt and other financial obligations depends in large part upon the level of cash flows generated by our operating subsidiaries’ operations, our ability to monetize and/or divest non-core assets, availability under our unsecured revolving credit facilities and our ability to access the capital markets and/or other sources of financing. If we cannot repay or refinance our debt as it becomes due, we may be forced to sell assets or reduce funding in the future for working capital, capital expenditures and general corporate purposes, any of which could negatively impact our stock price or financial condition.

13


 

Table of Contents

 

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 or adversely affected by, among other things, oil and gas prices, our existing capital structure, our credit ratings, interest rates 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.

 

Changes in the method of determining London Interbank Offered Rate ("LIBOR"), or the replacement of LIBOR with an alternative reference rate, may adversely affect interest expense related to outstanding debt.

 

Amounts drawn under the 2012 Revolving Credit Facility and the 2018 Revolving Credit Facility bear interest rates in relation to LIBOR. On July 27, 2017, the Financial Conduct Authority (“FCA”) in the United Kingdom announced that it would phase out LIBOR as a benchmark by the end of 2021. It is unclear whether new methods of calculating LIBOR will be established such that it continues to exist after 2021. The U.S. Federal Reserve is considering replacing U.S. dollar LIBOR with a newly created index called the Broad Treasury Financing Rate, calculated with a broad set of short-term repurchase agreements backed by treasury securities. If LIBOR ceases to exist and a generally accepted market replacement is not available, we may need to renegotiate the 2012 Revolving Credit Facility or the 2018 Revolving Credit Facility and may not able to do so with terms that are favorable to us. The overall financial markets may be disrupted as a result of the phase-out or replacement of LIBOR. Disruption in the financial market or the inability to renegotiate the 2012 Revolving Credit Facility or the 2018 Revolving Credit Facility with favorable terms could have a material adverse effect on our financial condition, results of operations and cash flows.

 

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 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. Although the Tax Reform Act has not had a material impact on our 2018 financial statements, if these tax laws, treaties

14


 

Table of Contents

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.

 

The Company’s ability to use its net operating loss carryforwards, and possibly other tax attributes, to offset future taxable income for U.S. federal income tax purposes may be significantly limited due to various circumstances, including future transactions involving the sale or issuance of Company equity securities, or if taxable income does not reach sufficient levels.

 

As of December 31, 2018, the Company reported consolidated federal net operating loss (“NOL”) carryforwards of approximately $578.0 million and certain other favorable federal income tax attributes. The Company’s ability to use its NOL carryforwards and certain other attributes may be limited if it experiences an “ownership change” as defined in Section 382 (“Section 382”) of the Internal Revenue Code of 1986, as amended (the “Code”). An ownership change generally occurs if there is a more than 50 percentage point increase in the aggregate equity ownership of the Company by one or more “5 percent shareholders” (as that term is defined for purposes of Sections 382 and 383 of the Code) in any testing period, which is generally the three-year period preceding any potential ownership change, measured against their lowest percentage ownership at any time during such period.

 

There is no assurance that the Company will not experience an ownership change under Section 382 as a result of future actions that may significantly limit or possibly eliminate its ability to use its NOL carryforwards and potentially certain other tax attributes. Potential future transactions involving the sale, issuance, redemption or other disposition of common or preferred shares, the exercise of conversion or exchange options under the terms of any convertible or exchangeable debt, the repurchase of any such debt with Company shares, in each case, by a person owning, or treated as owning, 5% or more of the Company’s shares, or a combination of such transactions, may cause or increase the possibility that the Company will experience an ownership change under Section 382. Under Section 382, an ownership change would subject the Company to an annual limitation that applies to the amount of pre-ownership change NOLs (and possibly certain other tax attributes) that may be used to offset post-ownership change taxable income. If a Section 382 limitation applies, the limitation could cause the Company’s U.S. federal income taxes to be greater, or to be paid earlier, than they otherwise would be, and could cause all or a portion of the Company’s NOL carryforwards to expire unused. Similar rules and limitations may apply for state income tax purposes. The Company’s ability to use its NOL carryforwards will also depend on the amount of taxable income it generates in future periods. The Company’s NOL carryforwards may expire before it can generate sufficient taxable income to use them in full.

 

Changes to or noncompliance with laws and regulations or exposure to environmental liabilities could adversely affect our results of operations.

 

Drilling of oil and natural gas wells is subject to various laws and regulations in the jurisdictions where we operate, including comprehensive and frequently changing laws and regulations relating to the protection of human health and the environment, including those regulating the transport, storage, use, treatment, 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.

15


 

Table of Contents

 

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.  The requirements of the June 2016 standards currently remain in effect, pending the EPA taking final action on its proposed two-year stay, which will likely be promptly challenged. In October 2018, the EPA issued a proposed rule that would reconsider limits on methane emissions set by the June 2016 standards and reduce inspection and repair requirements. 

 

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 Nations Framework Convention on Climate Change in Paris, France finalized an agreement, referred to as the “Paris 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, including pledges to voluntarily limit or make future greenhouse gas emissions. The United States signed the Paris Agreement in 2016 but formally withdrew in August 2017. The withdrawal will take effect in November 2020. Several U.S. states formed the United States Climate Alliance to advance the objectives of the Paris Agreement at the state level despite the federal withdrawal.

 

In addition, the EPA has published findings that emissions of greenhouse gases present an endangerment to public health and the environment, which could lead to further regulation of greenhouse gas emissions under the Clean Air Act. 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. Although in November 2016, the Bureau of Land Management (‘‘BLM’’) issued a rule requiring reductions in methane emissions from venting, flaring, and leaking activities on public lands, the BLM  rescinded the rule in September 2018. Several states have sued the BLM seeking to restore the November 2016 rule, and other states may regulate methane emissions by state law. 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.

 

16


 

Table of Contents

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 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, these provisions and those in our outstanding debt and Saudi joint venture documents may deter a change of control transaction and decrease the likelihood of a shareholder receiving a change of control premium.

 

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.

 

17


 

Table of Contents

Certain actions taken by us could make it easier for another party to acquire control of the Company. For instance, in June 2012 we adopted an amendment to our bye-laws to declassify the Board, we did not renew our shareholder rights plan when it expired in July 2016, and in 2017 we amended our policy regarding nomination and proxy access for director candidates recommended by shareholders. Conversely, the provisions designed to prevent hostile takeovers, or protect holders of our debt instruments and our joint venture partner, may deter transactions in which shareholders would receive a change of control premium. For example, certain change of control transactions could accelerate the principal amounts outstanding, and require premiums payments, under our debt instruments, or trigger a call option to purchase our interest in SANAD, our joint venture with Saudi Aramco.

 

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.

 

Our business is subject to cybersecurity risks.

 

Our operations are increasingly dependent on information technologies and services. Threats to information technology systems associated with cybersecurity risks and cyber incidents or attacks continue to grow, and include, among other things, storms and natural disasters, terrorist attacks, utility outages, theft, viruses, phishing, malware, design defects, human error, and complications encountered as existing systems are maintained, repaired, replaced, or upgraded. Risks associated with these threats include, among other things:

 

·

theft or misappropriation of funds;

 

·

loss, corruption, or misappropriation of intellectual property, or other proprietary, confidential or personally identifiable information (including customer, supplier, or employee data);

 

·

disruption or impairment of our and our customers’ business operations and safety procedures;

 

·

damage to our reputation with our customers and the market;

 

·

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 cyberattacks. Any cyber incident could have a material adverse effect on our business, financial condition and results of operations.

 

18


 

Table of Contents

Changes to United States tax, tariff and import/export regulations may have a negative effect on global economic conditions, financial markets and our business.

 

There have been ongoing discussions and commentary regarding potential significant changes to the United States trade policies, treaties, tariffs and taxes, including trade policies and tariffs regarding China. In 2018, the Office of the U.S. Trade Representative (the “USTR”) enacted tariffs on imports into the U.S. from China. In September 2018, the USTR enacted another tariff on the import of other Chinese products with an additional combined import value of approximately $200 billion. The tariff became effective on September 24, 2018, with an initial rate of 10%, with the potential for significant increases if the U.S. and China do not reach a new trade deal in the near term. There is significant uncertainty about the future relationship between the United States and other countries with respect to the trade policies, treaties, taxes, government regulations and tariffs that would be applicable. It is unclear what changes might be considered or implemented and what response to any such changes may be by the governments of other countries. Significant tariffs or other restrictions placed on Chinese imports and any related counter-measures that are taken by China could have an adverse effect on our financial condition or results of operations. Even in the absence of further tariffs, the related uncertainty and the market's fear of an escalating trade war might create forecasting difficulties for us and cause our customers and business partners to place fewer orders for our products and services, which could have a material adverse effect on our business, liquidity, financial condition, and/or results of operations. These developments, or the perception that any of them could occur, may have a material adverse effect on global economic conditions and the stability of global financial markets, and may significantly reduce global trade and, in particular, trade between these nations and the United States. Any of these factors could depress economic activity and restrict our access to suppliers or customers and have a material adverse effect on our business, financial condition and results of operations and affect our strategy around the world. Given the relatively fluid regulatory environment in China and the United States and relative uncertainty with respect to tariffs, international trade agreements and policies, a trade war, further governmental action related to tariffs or international trade policies, or additional tax or other regulatory changes in the future could directly and adversely impact our financial results and results of operations.

 

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. We are still attempting to obtain certain regulatory approvals related to the Tesco acquisition, and may not be able to do so in certain jurisdictions.

 

The anticipated benefits of the Saudi joint venture, the Tesco acquisition, and other strategic transactions may not be fully realized, or may be realized more slowly than expected, and may result in operational and financial consequences, including, but not limited to, the loss of key customers, suppliers or employees, or the disposition of certain assets or operations, which may have an adverse effect on our business, financial condition and results of operations.

 

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 depends, in part, on the continued service of certain key executive officers and employees. We have employment agreements with some of our key personnel within the company, but no assurance can be given that any employee will remain with us, whether or not they have entered into an employment agreement 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.

 

19


 

Table of Contents

Significant issuances of common shares or exercises of stock options could adversely affect the market price of our common shares.

 

As of February 21, 2019, we had 800,000,000 authorized common shares, of which 411,592,178 shares were outstanding and entitled to vote, including 52,800,203 million held by our subsidiaries. In addition, 17,352,792 common shares were reserved for issuance pursuant to stock option and employee benefit plans, 31,997,773 common shares were reserved for issuance upon exchange of outstanding Exchangeable Notes , and 37,096,700 common shares were reserved for issuance upon conversion of outstanding mandatory convertible preferred shares. The sale, or availability for sale, of substantial amounts of our common shares in the public market, whether directly by us or resulting from the exercise of options (and, where applicable, sales pursuant to Rule 144 under the Securities Act) or the exchange of Exchangeable Notes or the conversion of mandatory convertible preferred shares for common shares, would be dilutive to existing shareholders, could adversely affect the prevailing market price of our common shares and could impair our ability to raise additional capital through the sale of equity securities.

 

Our common share price has been and may continue to be volatile.

 

The trading price of our common shares has fluctuated in the past and is subject to significant fluctuations in response to the following factors, some of which are beyond our control:

 

·

variations in quarterly operating results;

 

·

deviations in our earnings from publicly disclosed forward-looking guidance;

 

·

variability in our revenues;

 

·

our announcements of significant contracts, acquisitions, strategic partnerships or joint ventures;

 

·

general conditions in the oil and gas industry;

 

·

uncertainty about current global economic conditions;

 

·

fluctuations in stock market price and volume; and

 

·

other general economic conditions.

 

The trading market for our common stock is influenced by the research and reports that industry or securities analysts may publish about us, our business, our markets or our competitors. We do not have any control over these analysts and we cannot provide any assurance that analysts will cover us or provide favorable coverage. If any of the analysts who may cover us adversely change their recommendation regarding our stock, or provide more favorable relative recommendations about our competitors, our stock price could materially decline. If any analyst who may cover us were to cease coverage of our Company or fail to regularly publish reports on us, we could lose visibility in the financial markets, which in turn could cause our stock price or trading volume to materially decline.

 

During 2018, our stock price on the NYSE ranged from a high of $8.87 per common share to a low of $1.81 per common share. In recent years, the stock market in general has experienced extreme price and volume fluctuations that have affected the market price for many companies in industries similar to ours. Some of these fluctuations have been unrelated to the operating performance of the affected companies. These market fluctuations may decrease the market price of our common shares in the future.

 

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

20


 

Table of Contents

prohibit these types of upstream payments to Nabors. Nabors’ debt instruments do not contain covenants prohibiting any such contractual restrictions. There may also be adverse tax consequences associated with such operating subsidiaries paying dividends. Finally, the ability of our subsidiaries to make distributions to us, may be restricted by the laws of the applicable subsidiaries’ jurisdictions of organization and other laws and regulations. If subsidiaries are unable to 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. Our principal physical properties are rigs which are more fully described in Part I, Item 1.—Business.

 

Many of the international drilling rigs and some of the Alaska rigs in our fleet are supported by mobile camps which house the drilling crews and a significant inventory of spare parts and supplies. In addition, we own various 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.

 

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. See Note 17 — Commitments and Contingencies in Part II, Item 8.—Financial Statements and Supplementary Data for a description of such proceedings.  

 

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”.

 

21


 

Table of Contents

On February 21, 2019, the closing price of our common shares as reported on the NYSE was $3.14.

 

Holders.

 

At February 21, 2019, there were approximately 1,908 shareholders of record of our common shares.

 

Dividends.

 

On February 22, 2019, our Board declared cash dividends of (i) $0.01 per outstanding Common Share, par value $0.001 per share, which will be paid on April 2, 2019, to holders of record at the close of business on March 12, 2018, and (ii) $0.75 per outstanding share of our 6.00% Mandatory Convertible Preferred Shares, Series A, par value $0.001 per share, which will be paid on May 1, 2019, to holders of record at the close of business on April 15, 2019.

 

The declaration and payment of future dividends will be at the discretion of the Board and will depend, among other things, on future earnings, general financial condition and liquidity, success in business activities, capital requirements and general business conditions in addition to legal requirements.

 

See Part I, Item 1A.—Risk Factors—As a holding company, we depend on our operating subsidiaries to meet our financial obligations. 

 

Issuer Purchases of Equity Securities.

 

The following table provides information relating to our repurchase of common shares during the three months ended December 31, 2018:

 

 

 

 

 

 

 

 

 

 

 

 

 

    

 

    

    

 

    

    

    

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

 

 5

 

$

6.27

 

 —

 

280,645

 

November 1 - November 30

 

 5

 

$

5.62

 

 —

 

280,645

 

December 1 - December 31

 

27

 

$

3.23

 

 —

 

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 2013 Stock Plan and 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. The program was renewed by the Board in February 2019.  Through December 31, 2018, we repurchased 14.0 million of our common shares for an aggregate purchase price of approximately $119.4 million under this program. As of December 31, 2018, 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, 2018, 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, S&P MidCap 400 Index, S&P SmallCap 600 Index, Russell 3000 Index and Dow Jones Oil Equipment and Services Index. We were included in the S&P MidCap 400 Index until the close of business on December 7, 2018, at which time we were moved to the S&P SmallCap 600 Index. We also are included in the Russell 3000 Index. We

22


 

Table of Contents

present all of these indices. Total return assumes $100 invested on December 31, 2013 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.

Picture 3

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

    

2013

    

2014

    

2015

    

2016

    

2017

    

2018

 

Nabors Industries Ltd.

 

100

 

77

 

52

 

102

 

44

 

13

 

S&P 500 Index

 

100

 

114

 

115

 

129

 

157

 

150

 

S&P MidCap 400 Index

 

100

 

110

 

107

 

130

 

151

 

134

 

S&P SmallCap 600 Index

 

100

 

106

 

104

 

131

 

149

 

136

 

Russell 3000 Index

 

100

 

113

 

113

 

128

 

154

 

146

 

Dow Jones Oil Equipment and Services Index

 

100

 

83

 

64

 

82

 

68

 

39

 

 

The foregoing graph is based on historical data and is not necessarily indicative of future performance. This graph shall not be deemed to be “soliciting material” or “filed” with the SEC or subject to Regulations 14A or 14C under the Exchange Act or to the liabilities of Section 18 under the Exchange Act.

 

Related Shareholder Matters

 

Bermuda has exchange controls which apply to residents in respect of the Bermuda dollar. As an exempted company, Nabors is designated as non-resident for Bermuda exchange control purposes by the Bermuda Monetary Authority. Pursuant to our non-resident status, there are no Bermuda restrictions on our ability to transfer funds (other than funds denominated in Bermuda dollars) in and out of Bermuda or to pay dividends to non-residents who are holders of our common shares in all other currencies, including currency of the United States.

 

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

23


 

Table of Contents

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,

 

 

    

2018

    

2017

    

2016

    

2015

    

2014

 

Operating Data (1)(2)

 

(In thousands, except per share amounts and ratio data)

 

Operating revenues

 

$

3,057,619

 

$

2,564,285

 

$

2,227,839

 

$

3,864,437

 

$

6,152,015

 

Income (loss) from continuing operations, net of tax

 

 

(598,063)

 

 

(497,114)

 

 

(1,011,244)

 

 

(329,497)

 

 

158,341

 

Income (loss) from discontinued operations, net of tax

 

 

(14,663)

 

 

(43,519)

 

 

(18,363)

 

 

(42,797)

 

 

(11,179)

 

Net income (loss)

 

 

(612,726)

 

 

(540,633)

 

 

(1,029,607)

 

 

(372,294)

 

 

147,162

 

Less: Net (income) loss attributable to noncontrolling interest

 

 

(28,222)

 

 

(6,178)

 

 

(135)

 

 

(381)

 

 

(7,180)

 

Net income (loss) attributable to Nabors

 

 

(640,948)

 

 

(546,811)

 

 

(1,029,742)

 

 

(372,675)

 

 

139,982

 

Less: Preferred stock dividend

 

 

(12,305)

 

 

 —

 

 

 —

 

 

 —

 

 

 —

 

Net income (loss) attributable to Nabors common shareholders

 

 

(653,253)

 

 

(546,811)

 

 

(1,029,742)

 

 

(372,675)

 

 

139,982

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings (losses) per share:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic from continuing operations

 

$

(1.95)

 

$

(1.75)

 

$

(3.58)

 

$

(1.14)

 

$

0.51

 

Basic from discontinued operations

 

 

(0.04)

 

 

(0.15)

 

 

(0.06)

 

 

(0.15)

 

 

(0.04)

 

Total Basic

 

$

(1.99)

 

$

(1.90)

 

$

(3.64)

 

$

(1.29)

 

$

0.47

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Diluted from continuing operations

 

$

(1.95)

 

$

(1.75)

 

$

(3.58)

 

$

(1.14)

 

$

0.51

 

Diluted from discontinued operations

 

 

(0.04)

 

 

(0.15)

 

 

(0.06)

 

 

(0.15)

 

 

(0.04)

 

Total Diluted

 

$

(1.99)

 

$

(1.90)

 

$

(3.64)

 

$

(1.29)

 

$

0.47

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted-average number of common shares outstanding:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

 

334,397

 

 

280,653

 

 

276,475

 

 

282,982

 

 

294,182

 

Diluted

 

 

334,397

 

 

280,653

 

 

276,475

 

 

282,982

 

 

296,592

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures and acquisitions of businesses (3)

 

$

478,435

 

$

769,848

 

$

414,379

 

$

925,544

 

$

1,899,042

 

Interest coverage ratio (4)

 

 

3.3:1

 

 

2.4:1

 

 

3.4:1

 

 

6.2:1

 

 

9.8:1

 

 

24


 

Table of Contents

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of December 31,

 

 

    

2018

    

2017

    

2016

    

2015

    

2014

 

Balance Sheet Data (1)(2)

 

(In thousands, except ratio data)

 

Cash, cash equivalents and short-term investments

 

$

481,802

 

$

365,366

 

$

295,202

 

$

536,169

 

$

507,133

 

Working capital

 

 

761,486

 

 

527,860

 

 

333,905

 

 

1,174,399

 

 

1,442,406

 

Property, plant and equipment, net

 

 

5,467,870

 

 

6,109,565

 

 

6,267,583

 

 

8,599,125

 

 

8,597,813

 

Total assets

 

 

7,853,944

 

 

8,401,984

 

 

8,187,015

 

 

11,862,923

 

 

12,137,749

 

Long-term debt

 

 

3,585,884

 

 

4,027,766

 

 

3,578,335

 

 

4,331,840

 

 

3,882,055

 

Shareholders’ equity

 

 

2,700,850

 

 

2,911,816

 

 

3,247,025

 

 

4,908,619

 

 

5,969,086

 

Debt to capital ratio:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gross (5)

 

 

0.57:1

 

 

0.58:1

 

 

0.52:1

 

 

0.47:1

 

 

0.39:1

 

Net (6)

 

 

0.53:1

 

 

0.56:1

 

 

0.50:1

 

 

0.43:1

 

 

0.36:1

 


(1)

All periods present the operating activities of most of our wholly owned oil and gas businesses and our previously held equity interests in oil and gas joint ventures in Canada and Colombia as discontinued operations.

 

(2)

Our acquisitions’ results of operations and financial position have been included beginning on the respective dates of acquisition and include PetroMar (October 2018), SANAD (December 2017), Tesco (December 2017), RDS (September 2017), Nabors Arabia (May 2015) and 2TD (October 2014). 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 operating revenues, direct costs, general and 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 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.

 

25


 

Table of Contents

ITEM 7.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

The following discussion and analysis of our financial condition and results of operations is based on, and should be read in conjunction with, our consolidated financial statements and the related notes thereto included under Part II, Item 8.—Financial Statements and Supplementary Data. This discussion and analysis contains forward-looking statements that involve risks and uncertainties. Actual results may differ materially from those anticipated in these forward-looking statements as a result of certain factors, including those set forth under Part I, Item 1A.—Risk Factors and elsewhere in this annual report. See “Forward-Looking Statements.”

 

Management Overview

 

We own and operate one of the world’s largest land-based drilling rig fleets and 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 tubular services, wellbore placement solutions and are a leading provider of directional drilling and MWD systems and services.

 

Outlook

 

The demand for our services is a function of the level of spending by oil and gas companies for exploration, development and production activities. The primary driver of customer spending is their cash flow and earnings which are largely driven by oil and natural gas prices and customers’ production volumes. The oil and natural gas markets have traditionally been volatile and tend to be highly sensitive to supply and demand cycles.

 

Throughout most of 2018, oil prices steadily increased and reached a four-year high in September. The increase in the price of oil spurred rig count growth in the U.S. and Canada, as evidenced by the 12% and 10% increases, respectively, in our average rigs working during 2018 compared to 2017.  Internationally, rig counts were relatively in line with the previous year. Oil prices took a sharp decline in the fourth quarter of 2018, but have since moderately recovered to approximately $50 on average during early 2019. Although we expect demand for our high-specification rigs in the U.S. Lower 48 to remain strong, it is uncertain to what extent the late-2018 oil price volatility will lead our U.S. customers to delay or scale back investment. 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.

 

Recent Developments

 

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. A portion of the proceeds from this offering were used to repay all of Nabors Delaware’s outstanding 6.15% senior notes due February 2018. The remaining proceeds not used for such purposes were allocated for general corporate purposes, including to repay amounts outstanding under the commercial paper program and to repurchase or repay other indebtedness.

 

In May 2018, we issued 35,000,000 of our common shares at a price to the public of $7.75 per share and 5,750,000 (including the underwriters option for 750,000) of our 6% Series A Mandatory Convertible Preferred Shares (the “mandatory convertible preferred shares”), par value $.001 per share, with a liquidation preference of $50 per share. In connection with the common shares offering, in June 2018 the underwriters exercised in full their option to purchase 5,250,000 additional common shares. Nabors received aggregate net proceeds of approximately $580.6 million from these offerings after deducting underwriting discounts, commissions, and offering expenses. The net proceeds from these offerings were used to repay amounts outstanding under the 2012 Revolving Credit Facility, which we may re-borrow from time to time for the repayment of other indebtedness, and for general corporate purposes.

 

The dividends on the mandatory convertible preferred shares are payable on a cumulative basis at a rate of 6% annually on the initial liquidation preference of $50 per share. Dividends accumulate and are paid quarterly to the extent that we have available funds and our Board of Directors declares a dividend payable. We may elect to pay any accumulated and unpaid dividends in cash or common shares or any combination thereof. At issuance, each mandatory convertible preferred share was automatically convertible into between 5.3763 and 6.4516 of our common shares based

26


 

Table of Contents

on the average share price over a period of twenty consecutive trading days ending prior to May 1, 2021, subject to anti-dilution adjustments. As a result of the dividends paid on our common shares since the offering, the conversion rate for each mandatory convertible preferred share has been adjusted to between 5.5775 and 6.6931 of our common shares. At any time prior to May 1, 2021, a holder of mandatory convertible preferred shares may convert such mandatory convertible preferred shares into our common shares at the minimum conversion rate, subject to adjustment.

 

In October 2018, Nabors Delaware, Nabors Drilling Canada Limited, Nabors and certain of Nabors’ wholly owned subsidiaries entered into a new five-year unsecured revolving facility with the lenders and issuing banks party thereto and Citibank, N.A., as administrative agent (the “2018 Revolving Credit Facility”). The 2018 Revolving Credit Facility has a borrowing capacity of $1.267 billion and is fully and unconditionally guaranteed by Nabors and certain of its wholly owned subsidiaries. The 2018 Revolving Credit Facility matures at the earlier of (a) October 11, 2023 and (b) July 19, 2022, if any of Nabors Delaware’s existing 5.5% senior notes due January 2023 remain outstanding as of such date. The 2018 Revolving Credit Facility can be used for general corporate purposes, including capital expenditures and working capital. As of the date of this report, we had no borrowings under the 2018 Revolving Credit Facility.

 

In connection with the 2018 Revolving Credit Facility, Nabors Delaware entered into Amendment No. 3 to its existing credit agreement dated November 29, 2012 (as amended, including such amendment, the “2012 Revolving Credit Facility”), among itself, Nabors, Nabors Canada, HSBC Bank Canada, the other lenders party thereto, Citibank, N.A., and Wilmington Trust, National Association, as successor administrative agent (the “Amendment”). The Amendment, among other things, reduces the overall commitments available to $666.25 million and provides for certain lenders to exit the facility. At December 31, 2018, we had $170.0 million outstanding under our 2012 Revolving Credit Facility.

 

In October 2018, we purchased PetroMar Technologies, a small developer and operator of LWD downhole tools focusing on high-value formation data to facilitate completion optimization particularly in unconventional reservoirs. The tools complement our existing wellbore placement capabilities and will be included in our Drilling Solutions operating segment. Under the terms of the transaction, we paid an initial purchase price of $25.0 million. We may also be required to make future payments that are contingent upon the future financial performance of this operation.

 

Financial Results

 

Comparison of the years ended December 31, 2018 and 2017

 

Operating revenues in 2018 totaled $3.1 billion, representing an increase of $493.3 million, or 19%, from 2017. We experienced an increase in operating revenue across all of our operating segments, aside from International Drilling. Activity and pricing both increased in most of the segments, as a result of the improved market conditions with the most impactful increase in our U.S. Drilling and Drilling Solutions operating segments, followed by Canada Drilling and Rig Technologies. Additionally, we benefited from incremental operating revenues of approximately $187.4 million as a result of our acquisition of Tesco, which was consummated in December 2017.

 

Net loss from continuing operations attributable to Nabors common shareholders totaled $638.6 million for 2018 ($1.95 per diluted share) compared to a net loss from continuing operations attributable to Nabors common shareholders of $503.3 million ($1.75 per diluted share) in 2017, or a $135.3 million increase in the net loss. Although our segments’ adjusted operating income improved by approximately $200.6 million compared to the prior period, our net loss was adversely impacted by an increase in impairments and other charges of $99.9 million. This increase is primarily attributable to the decline in oil prices at year end, and is comprised of rig-related impairments and retirements of approximately $60.2 million. Also contributing to the increase was a loss of $64.7 million on the sale of three offshore drilling rigs and eight workover rigs within our International Drilling reportable segment.

 

General and administrative expenses in 2018 totaled $265.8 million, representing an increase of $14.6 million, or 6% from 2017. This is reflective of a slight increase in salaries and other compensation as well as increases in headcount as a result of increased activity, including entry into new markets and product lines from the Company’s acquisition of Tesco in the fourth quarter of 2017.

 

Research and engineering expenses in 2018 totaled $56.1 million, representing an increase of $5.1 million, or 10%, from 2017. The increase is a result of increased efforts towards a number of strategic research and engineering

27


 

Table of Contents

projects as the market rebalanced and activity increased, including a full year of costs from the acquisition of RDS in September 2017, the Tesco acquisition in December 2017 and a partial year of costs from the PetroMar acquisition in October 2018.

 

Depreciation and amortization expense in 2018 was $866.9 million, representing an increase of $23.9 million, or 3%, from 2017. The slight increase was primarily due to the increased number of rigs that were working during the period, which results in a higher active depreciation rate coupled with incremental depreciation expense associated with the acquisition of Tesco in December 2017.

 

Segment Results of Operations

 

Our business consists of five reportable segments: U.S. Drilling, Canada Drilling, International Drilling, Drilling Solutions and Rig Technologies.

 

Management evaluates the performance of our reportable segments using adjusted operating income (loss), which is our segment performance measure, because it believes that this financial measure reflects our ongoing profitability and performance. In addition, securities analysts and investors use this measure as one of the metrics on which they analyze our performance. Adjusted operating income (loss) represents income (loss) from continuing operations before income taxes, interest expense, earnings (losses) from unconsolidated affiliates, investment income (loss), impairments and other charges and other, net. A reconciliation of adjusted operating income to net income (loss) from continuing operations before income taxes can be found in Note 21—Segment Information in Part II, Item 8. —Financial Statements and Supplementary Data.

 

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

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year Ended December 31,

 

Increase/(Decrease)

 

 

 

 

2018

 

2017

 

2018 to 2017

 

 

 

 

(In thousands, except percentages and rig activity)

U.S. Drilling

 

 

 

 

    

    

 

    

    

 

    

    

    

    

Operating revenues

 

 

 

$

1,083,227

 

$

805,223

 

$

278,004

 

35

%  

Adjusted operating income (loss)

 

 

 

$

(21,298)

 

$

(213,877)

 

$

192,579

 

90

%  

Average rigs working (1)

 

 

 

 

113.2

 

 

100.8

 

 

12.4

 

12

%  

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Canada Drilling

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

$

105,000

 

$

82,929

 

$

22,071

 

27

%  

Adjusted operating income (loss)

 

 

 

$

(6,166)

 

$

(22,262)

 

$

16,096

 

72

%  

Average rigs working (1)

 

 

 

 

16.9

 

 

15.4

 

 

1.5

 

10

%  

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

International Drilling

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

$

1,469,038

 

$

1,474,060

 

$

(5,022)

 

(0)

%  

Adjusted operating income (loss)

 

 

 

$

74,221

 

$

108,428

 

$

(34,207)

 

(32)

%  

Average rigs working (1)

 

 

 

 

92.9

 

 

91.1

 

 

1.8

 

 2

%  

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Drilling Solutions

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

$

250,242

 

$

140,701

 

$

109,541

 

78

%  

Adjusted operating income (loss)

 

 

 

$

37,626

 

$

16,738

 

$

20,888

 

125

%  

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Rig Technologies

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

 

 

$

270,988

 

$

234,542

 

$

36,446

 

16

%  

Adjusted operating income (loss)

 

 

 

$

(25,762)

 

$

(30,964)

 

$

5,202

 

17

%  


(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.

 

U.S. Drilling

 

Operating results increased in 2018 compared to 2017 primarily due to an increase in dayrates as market prices have continued to improve, resulting in approximately $123.8 million of the increase in adjusted operating income. Additionally, we experienced an increase in activity as reflected by a 12% increase in the average number of rigs working, which represented approximately $65.6 million of the increase in adjusted operating income. The majority of

28


 

Table of Contents

the increase in activity and dayrates was attributable to the Lower 48 land market, but activity also increased in our U.S. Gulf of Mexico market, including our MODS-400 rig commencing operations during the year.

 

Canada Drilling

 

Operating results increased in 2018 compared to 2017 primarily due to a 10% increase in the average number of rigs working. Additionally, this segment benefited from the mix of higher margin active rigs during the period supplemented by an increase in dayrates as market prices have improved.

 

International Drilling

 

Operating results decreased slightly in 2018 compared to 2017. Operating results for the period were unfavorably impacted by the expiration of higher margin contracts and dayrate reductions in certain regions, which were partially offset by new rig awards in lower margin regions. Further contributing to the decline in operating results was decreased activity resulting from the sale of three working jackup rigs.

 

Drilling Solutions

 

Operating results increased in 2018 compared to 2017 primarily due to the significant increase in drilling activity in the U.S. and in the demand for our products and services, including tubular services and performance tools. This segment benefited from incremental operating revenues of approximately $113.8 million primarily related to the addition of our tubular services product lines acquired from Tesco in December 2017.

 

Rig Technologies

 

Operating results increased in 2018 compared to 2017 primarily due to approximately $73.5 million in incremental revenue as a result of the acquisition of Tesco during the fourth quarter of 2017. However, operating income (loss) was adversely impacted by the relatively unfavorable mix between higher margin capital equipment sales and other lower margin activity. The Rig Technologies segment continues to carry a high level of research and engineering investment related to our 2TD and RDS product offerings, which amounted to approximately $14.5 million in 2018.

 

Other Financial Information

 

Interest expense

 

Interest expense for 2018 was $227.1 million, representing an increase of $4.2 million, or 2%, compared to 2017. The increase was primarily due to the additional interest expense related to our issuance of $800 million in aggregate principal amount of 5.75% senior notes due 2025 in January 2018. This increase was partially offset by the repayment of the 6.15% senior notes due February 2018 and 9.25% senior notes due January 2019.

 

Impairments and other charges

 

Impairments and other charges for 2018 was $144.4 million, which primarily included impairments of long-lived assets of $60.2 million comprised of underutilized rigs in our U.S. and International Drilling segments and obsolete inventory within our Rig Technologies segment as well as a loss of $64.7 million on the sale of three offshore drilling rigs and eight workover rigs within our International Drilling reportable segment. Additionally, we recognized $14.3 million in transaction related costs and a $5.3 million net loss recognized on the early extinguishment of debt resulting from debt repurchases.

 

Other, net

 

Other, net for 2018 was $29.5 million of expense, which included net losses on sales and disposals of assets of approximately $11.8 million, an increase in litigation reserves of $9.9 million and foreign currency exchange losses of $4.2 million.

 

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.

 

29


 

Table of Contents

Income tax expense (benefit)

 

Income tax expense for 2018 was $79.3 million, representing an increase of $162.2 million compared to 2017. The increase was primarily attributable to the change in our geographic mix of pre-tax earnings (losses), primarily due to pre-tax earnings in certain high tax jurisdictions causing a net income tax despite a consolidated pre-tax loss. In addition, management has continued to assess the Company’s ability to more likely than not realize deferred tax assets associated with its Canada Drilling operations and concluded during the fourth quarter of 2018 that the pace of market recovery did not support realization at this time. Accordingly, a non-cash tax expense of $52 million was recorded to reflect the valuation allowance. 

 

Discontinued operations

 

Our discontinued operations during 2018 and 2017 consisted of our historical wholly owned oil and gas businesses. Income (loss) from discontinued operations during 2018 was a loss of $14.7 million compared to a loss of $43.5 million during 2017. During 2018 and 2017, we recognized impairment charges of $17.0 million and $35.3 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. During November 2018, we sold our remaining wholly owned oil and gas business in Canada for approximately $8.0 million.

 

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, 2017 and 2016

 

Operating revenues in 2017 totaled $2.6 billion, representing an increase of $336.4 million, or 15%, from 2016. We had a significant increase in the number of rigs working in the U.S. compared to the same period in the prior year, which 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 partially offset the increases realized in the U.S. Drilling segment.

 

Net loss from continuing operations attributable to Nabors common shareholders totaled $503.3 million for 2017 ($1.75 per diluted share) compared to a net loss from continuing operations attributable to Nabors common shareholders of $1.0 billion ($3.58 per diluted share) in 2016, or a $508.1 million decrease in net loss. 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%, over 2016. The increase was 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%, over 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.

 

30


 

Table of Contents

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)

 

 

 

2017

 

2016

 

2017 to 2016

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S. Drilling

 

 

 

    

    

 

    

    

 

    

    

    

 

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 Drilling

 

 

 

 

 

 

 

 

 

 

 

 

 

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 Drilling

 

 

 

 

 

 

 

 

 

 

 

 

 

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. Drilling

 

Operating revenues increased 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%, 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 Drilling

 

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 Drilling

 

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 were lower in the U.S., we experienced increased pricing throughout

31


 

Table of Contents

2017, most notably during the fourth quarter as contracts were renegotiated. Additionally, we 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.

 

Impairments and other charges

 

Impairments and other charges for 2017 were $44.5 million, including $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 income, 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.

 

32


 

Table of Contents

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 $43.5 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.

 

Liquidity and Capital Resources

 

Financial Condition and Sources of Liquidity

 

Our primary sources of liquidity are cash and investments, availability under our revolving credit facilities and cash generated from operations. As of December 31, 2018, we had cash and short-term investments of $481.8 million and working capital of $761.5 million. As of December 31, 2017, we had cash and short-term investments of $365.4 million and working capital of $527.9 million. At December 31, 2018, we had $170.0 million of borrowings outstanding under our revolving credit facilities.

 

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. A portion of the proceeds from this offering were used to repay all of Nabors Delaware’s outstanding 6.15% senior notes due February 2018. The remaining proceeds not used for such purposes were allocated for general corporate purposes, including to repay amounts outstanding under the commercial paper program and to repurchase or repay other indebtedness.

 

In May 2018, we issued 35,000,000 of our common shares at a price to the public of $7.75 per share and 5,750,000 (including the underwriters option for 750,000) of our 6% Series A Mandatory Convertible Preferred Shares (the “mandatory convertible preferred shares”), par value $.001 per share, with a liquidation preference of $50 per share. In connection with the common shares offering, in June 2018 the underwriters exercised in full their option to purchase 5,250,000 additional common shares. Nabors received aggregate net proceeds of approximately $580.6 million from these offerings after deducting underwriting discounts, commissions, and offering expenses. The net proceeds from these offerings were used to repay amounts outstanding under the 2012 Revolving Credit Facility, which we may re-borrow from time to time for the repayment of other indebtedness, and for general corporate purposes.

 

The dividends on the mandatory convertible preferred shares are payable on a cumulative basis at a rate of 6% annually on the initial liquidation preference of $50 per share. Dividends accumulate and are paid quarterly to the extent that we have available funds and our Board of Directors declares a dividend payable. We may elect to pay any accumulated and unpaid dividends in cash or common shares or any combination thereof. At issuance, each mandatory convertible preferred share was automatically convertible into between 5.3763 and 6.4516 of our common shares based on the average share price over a period of twenty consecutive trading days ending prior to May 1, 2021, subject to anti-dilution adjustments. As a result of the dividends paid on our common shares since the offering, the conversion rate for each mandatory convertible preferred share has been adjusted to between 5.5775 and 6.6931 of our common shares. At any time prior to May 1, 2021, a holder of mandatory convertible preferred shares may convert such mandatory convertible preferred shares into our common shares at the minimum conversion rate, subject to adjustment.

 

In October 2018, Nabors Delaware, Nabors Drilling Canada Limited, Nabors and certain of Nabors’ wholly owned subsidiaries entered into a new five-year unsecured revolving facility with the lenders and issuing banks party thereto and Citibank, N.A., as administrative agent (the “2018 Revolving Credit Facility”). The 2018 Revolving Credit Facility has a borrowing capacity of $1.267 billion and is fully and unconditionally guaranteed by Nabors and certain of its wholly owned subsidiaries. The 2018 Revolving Credit Facility matures at the earlier of (a) October 11, 2023 and (b) July 19, 2022, if any of Nabors Delaware’s existing 5.5% senior notes due January 2023 remain outstanding as of such date. The 2018 Revolving Credit Facility can be used for general corporate purposes, including capital expenditures and working capital. As of the date of this report, we had no borrowings under the 2018 Revolving Credit Facility. In order to make any future borrowings under the 2018 Revolving Credit Facility, Nabors and certain of its wholly owned subsidiaries are subject to compliance with the conditions and covenants contained therein, including compliance with applicable financial ratios.

33


 

Table of Contents

 

In connection with the 2018 Revolving Credit Facility, Nabors Delaware entered into Amendment No. 3 to its existing credit agreement dated November 29, 2012 (as amended, including such amendment, the “2012 Revolving Credit Facility”), among itself, Nabors, Nabors Canada, HSBC Bank Canada, the other lenders party thereto, Citibank, N.A., and Wilmington Trust, National Association, as successor administrative agent (the “Amendment”). The Amendment, among other things, reduces the overall commitments available to $666.25 million and provides for certain lenders to exit the facility.

 

We had 15 letter-of-credit facilities with various banks outstanding as of December 31, 2018. Availability under these facilities as of December 31, 2016 was as follows:

 

 

 

 

 

 

 

    

December 31,

 

 

 

2018

 

 

 

(In thousands)

 

Credit available

 

$

759,321

 

Less: Letters of credit outstanding, inclusive of financial and performance guarantees

 

 

105,036

 

Remaining availability

 

$

654,285

 

 

Our ability to access capital markets or to otherwise obtain sufficient financing may be affected by our senior unsecured debt ratings as provided by the major credit rating agencies in the United States and our historical ability to access these markets as needed. While there can be no assurances that we will be able to access these markets in the future, or access them on favorable terms, we believe that we will be able to access capital markets or otherwise obtain financing in order to satisfy any payment obligation that might arise upon maturity, exchange or purchase of our notes and our debt facilities, loss of availability of our revolving credit facilities, and 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 I, Item 1A.—Risk Factors—A downgrade in our credit rating could negatively impact our cost of and ability to access capital markets or other financing sources.

 

Our gross debt to capital ratio was 0.57:1 as of December 31, 2018 and 0.58:1 as of December 31, 2017. Our net debt to capital ratio was 0.53:1 as December 31, 2018 and 0.56:1 as of December 31, 2017. 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 both the 2012 Revolving Credit Facility and the 2018 Revolving Credit Facility is subject to a covenant not to exceed a net debt to capital ratio of 0.60:1. In addition, availability under the new 2018 Revolving Credit Facility is subject to a covenant that during any period in which Nabors Delaware fails to maintain an investment grade rating from at least two ratings agencies, the guarantors under the facility and their subsidiaries will be required to maintain an asset to debt coverage ratio of at least 2.50:1. As of December 31, 2018, our asset to debt coverage ratio was 3.82:1. The asset to debt coverage ratio is calculated by dividing (x) drilling-related fixed assets wholly owned by certain of Nabors’ subsidiaries that are guaranteeing the 2018 Revolving Credit Facility (the “2018 Revolver Guarantors”) or wholly owned subsidiaries of the 2018 Revolver Guarantors by (y) total debt of the 2018 Revolver Guarantors (subject to certain exclusions).

 

As of the date of this report, we were in compliance with all covenants under the 2018 Revolving Credit Facility and 2012 Revolving Credit Facility. If we fail to perform our obligations under the covenants, the revolving credit commitments under the 2012 Revolving Credit Facility and the 2018 Revolving Credit Facility could be terminated, and any outstanding borrowings under the facilities could be declared immediately due and payable. If necessary, we have the ability to manage these ratios by taking certain actions including reductions in discretionary capital or other types of controllable expenditures, monetization of assets, amending or renegotiating the revolving credit agreement, accessing capital markets through a variety of alternative methods, or any combination of these alternatives. The gross debt to capital ratio, the net debt to capital ratio and the asset to debt coverage ratio are not measures of operating performance or liquidity defined by U.S. GAAP and may not be comparable to similarly titled measures presented by other companies.

 

34


 

Table of Contents

Our interest coverage ratio was 3.3:1 as of December 31, 2018 and 2.4:1 as of December 31, 2017. 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.

 

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.

 

Future Cash Requirements

 

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.

 

We expect capital expenditures over the next 12 months to be approximately $0.4 billion. Purchase commitments outstanding at December 31, 2018 totaled approximately $243.3 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 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 using existing cash or debt or by issuing 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 the Company. Such capital expenditures and acquisitions will depend on our view of market conditions and other factors.

 

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. Authorization for the program, which was renewed in February 2019, does not have an expiration date and does not obligate us to repurchase any of our common shares. Since establishing the program, we have repurchased 14.0 million of our common shares for an aggregate purchase price of approximately $119.4 million under this program. As of December 31, 2018, 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, 2018, 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)”.

 

35


 

Table of Contents

The following table summarizes our contractual cash obligations as of December 31, 2018:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Payments due by Period

 

 

    

Total

    

< 1 Year

    

1-3 Years

    

3-5 Years

    

More than 5 years

 

 

 

(In thousands)

 

Contractual cash obligations:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Long-term debt: (1)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Principal

 

$

3,750,291

 

$

 —

 

$

1,454,270

(2)  

$

929,519

(3)  

$

1,366,502

(4)

Interest

 

 

718,684

 

 

167,357

 

 

297,872

 

 

183,032

 

 

70,423

 

Operating leases (5)

 

 

32,955

 

 

10,701

 

 

10,878

 

 

3,894

 

 

7,482

 

Purchase commitments (6)

 

 

243,340

 

 

239,976

 

 

3,364

 

 

 —

 

 

 —

 

Transportation and processing contracts (5)(7)

 

 

2,445

 

 

2,445

 

 

 —

 

 

 —

 

 

 —

 


The table above excludes liabilities for uncertain tax positions totaling $24.0 million as of December 31, 2018 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 5.0% senior notes due September 2020, amounts outstanding under our 2012 Revolving Credit Facility due July 2020 and Nabors Delaware’s 4.625% senior notes due September 2021.

 

(3)

Represents the aggregate principal amount of Nabors Delaware’s 5.50% senior notes due January 2023 and 5.10% senior notes due September 2023.

 

(4)

Represents the aggregate principal amount of Nabors Delaware’s 0.75% senior exchangeable notes due January 2024 and 5.75% senior notes due January 2025.

 

(5)

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

 

(6)

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.

 

(7)

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, 2018, our Board declared a cash dividend of $0.06 per common share. This quarterly cash dividend was paid on January 3, 2019 to shareholders of record on December 13, 2018 in the amount of $21.0 million. Additionally, during the three months ended December 31, 2018, our Board declared a cash dividend of $0.75 per mandatory convertible preferred share, which was be paid on February 1, 2019 to shareholders of record at the close of business on January 15, 2019 in the amount of $4.3 million. During the year ended December 31, 2018, we paid cash dividends totaling $87.1 million. See Part II, Item 5.—Market Price of and Dividends on the Registrant’s Common Equity, Related Shareholder Matters and Issuer Purchases of Equity—Dividends.

 

36


 

Table of Contents

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 2018 and 2017 cash flows below.

 

Operating Activities.  Net cash provided by operating activities totaled $325.8 million during 2018, compared to $62.8 million during 2017. Operating cash flows are our primary source of capital and liquidity. The increase in cash flows from operations is primarily attributable to increases in activity and margins. 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 $216.2 million in cash flows during 2018 and $388.0 million in cash flows during 2017.

 

Investing Activities.  Net cash used for investing activities totaled $367.1 million during 2018 compared to net cash used of $497.9 million in 2017. 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 2018 and 2017, we used cash for capital expenditures totaling $458.9 million and $574.5 million, respectively.

 

We received $109.1 million in proceeds from sales of assets and insurance claims during 2018 compared to $57.9 million in 2017. Additionally, we paid $20.9 million, net, for businesses acquired in 2018.

 

Financing Activities.  Net cash provided by financing activities totaled $155.6 million during 2018. In 2018, we received net proceeds of $579.3 million from the issuance of common and mandatory convertible preferred shares and redeemable noncontrolling interest contributions totaling $156.9 million from our joint partner in SANAD. During 2018, we paid dividends totaling $87.1 million to our common and preferred shareholders. Additionally, we received net proceeds of $778.7 million in connection with the issuance of our 5.75% senior notes. This was offset by the repayment of the remaining balances of our 6.15% and 9.25% senior notes totaling $774.8 million, repurchase of $103.5 million of senior notes that matured in 2020 and beyond, and $380.0 million pay down on our 2012 Revolving Credit Facility and commercial paper program.

 

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 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 redeemable noncontrolling interest contributions from our joint venture partner in SANAD.

 

Off-Balance Sheet Arrangements (Including Guarantees)

 

We are a party to some transactions, agreemen