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EX-95.1 - EXHIBIT 95.1 - NEWPARK RESOURCES INCa2017q4exhibit951.htm
EX-32.2 - EXHIBIT 32.2 - NEWPARK RESOURCES INCa2017q4exhibit322.htm
EX-32.1 - EXHIBIT 32.1 - NEWPARK RESOURCES INCa2017q4exhibit321.htm
EX-31.2 - EXHIBIT 31.2 - NEWPARK RESOURCES INCa2017q4exhibit312.htm
EX-31.1 - EXHIBIT 31.1 - NEWPARK RESOURCES INCa2017q4exhibit311.htm
EX-23.1 - EXHIBIT 23.1 - NEWPARK RESOURCES INCa2017q4exhibit231.htm
EX-21.1 - EXHIBIT 21.1 - NEWPARK RESOURCES INCa2017q4exhibit211.htm
EX-10.13 - EXHIBIT 10.13 - NEWPARK RESOURCES INCa2017q4exhibit1013.htm


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549 
FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2017
OR
[  ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Transition Period From to
Commission File Number 001-2960
Newpark Resources, Inc.
(Exact name of registrant as specified in its charter)
Delaware
72-1123385
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
9320 Lakeside Blvd., Suite 100
 
The Woodlands, Texas
77381
(Address of principal executive office)
(Zip Code)
Registrant’s telephone number, including area code (281) 362-6800
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Name of each exchange on which registered
Common Stock, $0.01 par value
New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ___ No  √  
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ___ No  √  
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes  √     No ___
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). 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, a smaller reporting company or an emerging growth company. See definitions of “large accelerated filer”, “accelerated filer”, “small reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act. 
Large accelerated filer ___
Accelerated filer   √   
Non-accelerated filer ___ (Do not check if a smaller reporting company)
Smaller Reporting Company ___
Emerging growth company           
 
                
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.          
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ___ No  √  
The aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant, computed by reference to the price at which the common equity was last sold as of June 30, 2017, was $613.1 million. The aggregate market value has been computed by reference to the closing sales price on such date, as reported by The New York Stock Exchange.
As of February 16, 2018, a total of 89,218,581 shares of Common Stock, $0.01 par value per share, were outstanding.
Documents Incorporated by Reference
Pursuant to General Instruction G(3) to this Form 10-K, the information required by Items 10, 11, 12, 13 and 14 of Part III hereof is incorporated by reference from the registrant’s definitive Proxy Statement for its 2018 Annual Meeting of Stockholders.




NEWPARK RESOURCES, INC.
INDEX TO ANNUAL REPORT ON FORM 10-K
FOR THE YEAR ENDED DECEMBER 31, 2017

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 


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CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS
This Annual Report on Form 10-K contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995, as amended. We also may provide oral or written forward-looking information in other materials we release to the public. Words such as “will”, “may”, “could”, “would”, “anticipates”, “believes”, “estimates”, “expects”, “plans”, “intends”, and similar expressions are intended to identify these forward-looking statements but are not the exclusive means of identifying them. These forward-looking statements reflect the current views of our management; however, various risks, uncertainties, contingencies and other factors, some of which are beyond our control, are difficult to predict and could cause our actual results, performance or achievements to differ materially from those expressed in, or implied by, these statements, including the success or failure of our efforts to implement our business strategy. 
We assume no obligation to update, amend or clarify publicly any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by securities laws. In light of these risks, uncertainties and assumptions, the forward-looking events discussed in this Annual Report might not occur.
For further information regarding these and other factors, risks and uncertainties affecting us, we refer you to the risk factors set forth in Item 1A of this Annual Report on Form 10-K. 



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PART I
ITEM 1. Business
General
Newpark Resources, Inc. was organized in 1932 as a Nevada corporation. In 1991, we changed our state of incorporation to Delaware. We are a geographically diversified supplier providing products, rentals and services primarily to the oil and gas exploration and production (“E&P”) industry. We operate our business through two reportable segments: Fluids Systems and Mats and Integrated Services. Our Fluids Systems segment provides drilling fluids products and technical services to customers in the North America, Europe, the Middle East and Africa (“EMEA”), Latin America and Asia Pacific regions. Our Mats and Integrated Services segment provides composite mat rentals, site construction and related site services to customers in various markets including oil and gas exploration and production, electrical transmission & distribution, pipeline, solar, petrochemical and construction across the U.S., Canada and Europe. We also sell composite mats to customers outside of the U.S. and to domestic customers outside of the E&P market.
Our principal executive offices are located at 9320 Lakeside Blvd., Suite 100, The Woodlands, Texas 77381. Our telephone number is (281) 362-6800. You can find more information about us at our website located at www.newpark.com. Our Annual Report on Form 10-K, our Quarterly Reports on Form 10-Q, our Current Reports on Form 8-K and any amendments to those reports are available free of charge through our website. These reports are available as soon as reasonably practicable after we electronically file these materials with, or furnish them to, the Securities and Exchange Commission (“SEC”). Our Code of Ethics, our Corporate Governance Guidelines, our Audit Committee Charter, our Compensation Committee Charter and our Nominating and Corporate Governance Committee Charter are also posted to the corporate governance section of our website. We make our website content available for informational purposes only. It should not be relied upon for investment purposes, nor is it incorporated by reference in this Form 10-K. Information filed with the SEC may be read or copied at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, D.C., 20549. Information on operation of the Public Reference Room may be obtained by calling the SEC at 1-800-SEC-0330. The SEC also maintains a website at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC, including us.
When referring to “Newpark” and using phrases such as the “Company”, “we”, “us” and “our”, our intent is to refer to Newpark Resources, Inc. and its subsidiaries as a whole or on a segment basis, depending on the context in which the statements are made.
Industry Fundamentals
Historically, several factors have driven demand for our products and services, including the supply, demand and pricing of oil and gas commodities, which drive E&P drilling and development activity. Demand for most of our Fluids Systems’ products and services is also driven, in part, by the level, type, depth and complexity of oil and gas drilling. Historically, drilling activity levels in North America have been volatile, primarily driven by the price of oil and natural gas. Beginning in the fourth quarter of 2014 and continuing through early 2016, the price of oil declined dramatically from the price levels in previous years. As a result, E&P drilling activity significantly declined in North America and many global markets over this period. While oil prices and drilling activity have improved from the lows reached in early 2016, both oil price and activity levels remain significantly lower than pre-downturn levels. The most widely accepted measure of activity for our North American operations is the Baker Hughes Rotary Rig Count. The average North America rig count was 1,083 in 2017, compared to 639 in 2016, 1,170 in 2015, and 2,241 in 2014.
The declining E&P drilling activity levels in 2015 and 2016 reduced the demand for our services, negatively impacted customer pricing and resulted in elevated costs associated with workforce reductions, all of which negatively impacted our profitability. Further, due to the fact that our business contains substantial levels of fixed costs, including significant facility and personnel expenses, North American operating margins in both operating segments were negatively impacted by the lower customer demand during this period.
Outside of North America, drilling activity is generally more stable, as drilling activity in many countries is based upon longer term economic projections and multiple year drilling programs, which tend to reduce the impact of short-term changes in commodity prices on overall drilling activity. While drilling activity in certain of our international markets (including Brazil and Australia) has declined in recent years, as a whole, our international activities have remained relatively stable. This stability is primarily driven by new contract awards, which include geographical expansion into new markets as well as market share gains in existing markets.
In addition to our ongoing activity in the E&P industry, our Mats and Integrated Services segment is continuing to expand into other industries in North America, including electrical transmission & distribution and pipeline construction and maintenance. The demand for our composite matting systems from customers in these industries, is driven in part, by the level of construction and maintenance activity associated with the electrical transmission & distribution grid, as well as the oil and natural gas pipeline infrastructure within the U.S.


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Reportable Segments
Fluids Systems
Our Fluids Systems business provides drilling fluids products and technical services to customers in the North America, EMEA, Latin America, and Asia Pacific regions. We offer customized solutions for highly technical drilling projects involving complex subsurface conditions such as horizontal, directional, geologically deep or drilling in deep water. These projects require increased monitoring and critical engineering support of the fluids system during the drilling process. In addition, our Fluids Systems offering is expanding into adjacent areas to drilling fluids, including completion and stimulation chemistry, which are typically utilized by customers following the drilling process.
We also have industrial mineral grinding operations for barite, a critical raw material in drilling fluids products, which serve to support our activity in the North American drilling fluids market. We grind barite and other industrial minerals at four facilities, including locations in Texas, Louisiana and Tennessee. We use the resulting products in our drilling fluids business, and also sell them to third party users, including other drilling fluids companies. We also sell a variety of other minerals, principally to third-party industrial (non-oil and gas) markets.
Raw Materials — We believe that our sources of supply for materials and equipment used in our drilling fluids business are adequate for our needs, however, we have experienced periods of short-term scarcity of barite ore, which have resulted in significant cost increases. Our specialty milling operation is our primary supplier of barite used in our North American drilling fluids business. Our mills obtain raw barite ore under supply agreements from foreign sources, primarily China and India. We obtain other materials used in the drilling fluids business from various third party suppliers. We have encountered no serious shortages or delays in obtaining these raw materials. 
Technology — Proprietary technology and systems are an important aspect of our business strategy. We seek patents and licenses on new developments whenever we believe it creates a competitive advantage in the marketplace. We own patent rights in a family of high-performance water-based fluids systems, which we market as Evolution® and DeepDrill® systems, which are designed to enhance drilling performance and provide environmental benefits. We also rely on a variety of unpatented proprietary technologies and know-how in many of our applications. We believe that our reputation in the industry, the range of services we offer, ongoing technical development and know-how, responsiveness to customers and understanding of regulatory requirements are of equal or greater competitive significance than our existing proprietary rights.
Competition — We face competition from larger companies, including Halliburton and Schlumberger, which compete vigorously on fluids performance and/or price. In addition, these companies have broad product and service offerings in addition to their drilling fluids. We also have smaller regional competitors competing with us mainly on price and local relationships. We believe that the principal competitive factors in our businesses include a combination of technical proficiency, reputation, price, reliability, quality, breadth of services offered and experience. We believe that our competitive position is enhanced by our proprietary products and services.
Customers — Our customers are principally major integrated and independent oil and gas E&P companies operating in the markets that we serve. During 2017, approximately 51% of segment revenues were derived from the 20 largest segment customers, of which the largest customer represented 10% of our segment revenues. The segment also generated 55% of revenues domestically during 2017. Typically, in North America, we perform services either under short-term standard contracts or under “master” service agreements. Internationally, some customers issue multi-year contracts, but many are on a well-by-well, or project basis. As most agreements with our customers can be terminated upon short notice, our backlog is not significant. We do not derive a significant portion of our revenues from government contracts. See “Note 12 – Segment and Related Information” in our Consolidated Financial Statements for additional information on financial and geographic data.
Mats and Integrated Services 
Our Mats and Integrated Services segment provides composite mat rentals, site construction and related site services to customers in various markets including oil and gas exploration and production (“E&P”), electrical transmission & distribution, pipeline, solar, petrochemical and construction across North America and Europe. We also sell composite mats to customers outside of the U.S. and to domestic customers outside of the E&P market. Following our efforts in recent years to diversify our customer base, Mats and Integrated Services segment revenues from non-E&P markets represented approximately two-thirds of our segment revenues in 2017.
We manufacture our DURA-BASE® Advanced Composite Mats for use in our rental operations as well as for third-party sales. Our mats provide environmental protection and ensure all-weather access to sites with unstable soil conditions. In order to support our efforts to expand our markets globally, we completed an expansion of our mats manufacturing facility in 2015 which nearly doubled our manufacturing capacity and significantly expanded our research and development capabilities. We continue to expand our product offerings, which now include the EPZ Grounding System™ for enhanced safety and efficiency for contractors working on power line maintenance and construction projects and the T-REX™ automated mat cleaning system to provide customers with a cost effective system to clean composite mats on site.


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In November 2017, we acquired certain assets and assumed certain liabilities of Well Service Group, Inc. and Utility Access Solutions, Inc. (together, “WSG”). Since 2012, WSG has been a strategic logistics and installation service provider for our Mats and Integrated Service segment, offering a variety of complementary services to our composite matting systems, including access road construction, site planning and preparation, environmental protection, fluids and spill storage/containment, erosion control, and site restoration services. The completion of the WSG acquisition expanded our service offering as well as our U.S. geographic footprint across the Northeast, Midwest, Rockies, and West Texas regions of the U.S.
Raw Materials — We believe that our sources of supply for materials used in our business are adequate for our needs. We are not dependent upon any one supplier and we have encountered no serious shortages or delays in obtaining any raw materials. The resins, chemicals and other materials used to manufacture composite mats are widely available. Resin is the largest material component in the manufacturing of our composite mat products.
Technology — We have obtained patents related to the design and manufacturing of our DURA-BASE mats and several of the components, as well as other products and systems related to these mats (including the connecting pins and the EPZ Grounding System™). Using proprietary technology and systems is an important aspect of our business strategy. We believe that these products provide us with a distinct advantage over our competition. While we continue to add to our patent portfolio, two patents related to our DURA-BASE matting system will expire in May of 2020, and competitors may begin offering mats that include features described in those patents. We also believe that our reputation in the industry, the range of services we offer, ongoing technical development and know-how, responsiveness to customers and understanding of regulatory requirements also have competitive significance in the markets we serve.
Competition — Our market is fragmented and competitive, with many competitors providing various forms of site preparation products and services. The mat sales component of our business is not as fragmented as the rental and services segment with only a few competitors providing various alternatives to our DURA-BASE mat products, such as Signature Systems Group and Checkers Group. This is due to many factors, including large capital start-up costs and proprietary technology associated with this product. We believe that the principal competitive factors in our businesses include product capabilities, price, reputation, and reliability. We also believe that our competitive position is enhanced by our proprietary products, services and experience.
Customers — Our customers are principally infrastructure construction and oil and gas E&P companies operating in the markets that we serve. Approximately 63% of our segment revenues in 2017 were derived from the 20 largest segment customers, of which, the largest customer represented 15% of our segment revenues. The segment generated 91% of its revenues domestically during 2017. As a result of our efforts to expand beyond our traditional oilfield customer base, revenues from non E&P customers represented approximately 67% of segment revenues in 2017. Typically, we perform services either under short-term contracts or rental service agreements. As most agreements with our customers are cancelable upon short notice, our backlog is not significant. We do not derive a significant portion of our revenues from government contracts. See “Note 12 - Segment and Related Information” in our Consolidated Financial Statements for additional information on financial and geographic data.
Employees
At January 31, 2018, we employed approximately 2,400 full and part-time personnel none of which are represented by unions. We consider our relations with our employees to be satisfactory.
Environmental Regulation
We seek to comply with all applicable legal requirements concerning environmental matters. Our business is affected by governmental regulations relating to the oil and gas industry in general, as well as environmental, health and safety regulations that have specific application to our business. Our activities are impacted by various federal and state regulatory agencies, and provincial pollution control, health and safety programs that are administered and enforced by regulatory agencies.
Additionally, our business exposes us to environmental risks. We have implemented various procedures designed to ensure compliance with applicable regulations and reduce the risk of damage or loss. These include specified handling procedures and guidelines for waste, ongoing employee training, and monitoring and maintaining insurance coverage.
We also employ a corporate-wide web-based health, safety and environmental management system (“HSEMS”), which is ISO 14001:2004 compliant. The HSEMS is designed to capture information related to the planning, decision-making, and general operations of environmental regulatory activities within our operations. We also use the HSEMS to capture the information generated by regularly scheduled independent audits that are done to validate the findings of our internal monitoring and auditing procedures.
 


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ITEM 1A. Risk Factors
The following summarizes the most significant risk factors to our business. Our success will depend, in part, on our ability to anticipate and effectively manage these and other risks. Any of these risk factors, either individually or in combination, could have significant adverse impacts to our results of operations and financial condition, or prevent us from meeting our profitability or growth objectives.
Risks Related to the Worldwide Oil and Natural Gas Industry
We derive a significant portion of our revenues from customers in the worldwide oil and natural gas industry; therefore, our risk factors include those factors that impact the demand for oil and natural gas. Spending by our customers for exploration, development and production of oil and natural gas is based on a number of factors, including expectations of future hydrocarbon demand, energy prices, the risks associated with developing reserves, our customers' ability to finance exploration and development of reserves, regulatory developments and the future value of the reserves. Reductions in customer spending levels adversely affect the demand for our services and consequently, our revenue and operating results; and the presence of these market conditions negatively affects our revenue and operating results. The key risk factors that we believe influence the worldwide oil and natural gas markets are discussed below.
Demand for oil and natural gas is subject to factors beyond our control
Demand for oil and natural gas, as well as the demand for our services, is highly correlated with global economic growth and in particular by the economic growth of countries such as the U.S., India, China, and developing countries in Asia and the Middle East. Weakness in global economic activity could reduce demand for oil and natural gas and result in lower oil and natural gas prices. In addition, demand for oil and natural gas could be impacted by environmental regulation, including cap and trade legislation, regulation of hydraulic fracturing, and carbon taxes. Weakness or deterioration of the global economy could reduce our customers’ spending levels and reduce our revenue and operating results.
Supply of oil and natural gas is subject to factors beyond our control
The ability to produce oil and natural gas can be affected by the number and productivity of new wells drilled and completed, as well as the rate of production and resulting depletion of existing wells. Productive capacity in excess of demand is also an important factor influencing energy prices and spending by oil and natural gas exploration companies. Oil and natural gas storage inventory levels are indicators of the relative balance between supply and demand. Supply can also be impacted by the degree to which individual Organization of Petroleum Exporting Countries (“OPEC”) nations and other large oil and natural gas producing countries are willing and able to control production and exports of hydrocarbons, to decrease or increase supply and to support their targeted oil price or meet market share objectives. Any of these factors could affect the supply of oil and natural gas and could have a material effect on our results of operations.
Volatility of oil and natural gas prices can adversely affect demand for our products and services
Volatility in oil and natural gas prices can also impact our customers’ activity levels and spending for our products and services. The level of energy prices is important to the cash flow for our customers and their ability to fund exploration and development activities. Compared to 2011 to 2014 levels, oil prices have declined significantly due in large part to increasing supplies, weakening demand growth and the decision by OPEC countries to maintain production levels throughout 2015 and most of 2016. While OPEC production limits were put in place in late 2016 and maintained throughout 2017, expectations about future commodity prices and price volatility are important for determining future spending levels. Our customers also take into account the volatility of energy prices and other risk factors by requiring higher returns for individual projects if there is higher perceived risk.
Our customers’ activity levels, spending for our products and services and ability to pay amounts owed us could be impacted by the ability of our customers to access equity or credit markets
Our customers’ access to capital is dependent on their ability to access the funds necessary to develop oil and gas prospects. Limited access to external sources of funding has and may continue to cause customers to reduce their capital spending plans. In addition, a reduction of cash flow to our customers resulting from declines in commodity prices or the lack of available debt or equity financing may impact the ability of our customers to pay amounts owed to us.
Risks Related to our Customer Concentration and Reliance on the U.S. Exploration and Production Market
In 2017, approximately 45% of our consolidated revenues were derived from our 20 largest customers, although no customer accounted for more than 10% of our consolidated revenues. In addition, approximately 62% of our consolidated revenues were derived from our U.S. operations.


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Beginning in the fourth quarter of 2014 and continuing through early 2016, the price of oil declined dramatically from the price levels in previous years. Following this decline, North American drilling activity decreased significantly, which reduced the demand for our services and negatively impacted customer pricing in our North American operations, relative to pre-downturn levels. While oil prices and drilling activity have since improved from the lows reached in early 2016, there are no assurances that the price for oil or activity levels will not decline again in the future. Due to these changes, our quarterly and annual operating results have fluctuated significantly and may continue to fluctuate in future periods. Because our business has substantial fixed costs, including significant facility and personnel expenses, downtime or low productivity due to reduced demand can have a significant adverse impact on our profitability.
Risks Related to International Operations
We have significant operations outside of the United States, including certain areas of Canada, EMEA, Latin America, and Asia Pacific. In 2017, these international operations generated approximately 38% of our consolidated revenues. Algeria represents our largest international market with our total Algerian operations representing 12% of our consolidated revenues in 2017 and 8% of our total assets at December 31, 2017, including 28% of our total cash balance at December 31, 2017.
In addition, we may seek to expand to other areas outside the United States in the future. International operations are subject to a number of risks and uncertainties, including:
difficulties and cost associated with complying with a wide variety of complex foreign laws, treaties and regulations;
uncertainties in or unexpected changes in regulatory environments or tax laws;
legal uncertainties, timing delays and expenses associated with tariffs, export licenses and other trade barriers;
difficulties enforcing agreements and collecting receivables through foreign legal systems;
risks associated with failing to comply with the U.S. Foreign Corrupt Practices Act, the U.K. Bribery Act, export laws, and other similar laws applicable to our operations in international markets;
exchange controls or other limitations on international currency movements, including restrictions on the repatriation of funds to the U.S. from certain countries, such as Algeria;
sanctions imposed by the U.S. government that prevent us from engaging in business in certain countries or with certain counter-parties;
inability to obtain or preserve certain intellectual property rights in the foreign countries in which we operate;
our inexperience in certain international markets;
fluctuations in foreign currency exchange rates;
political and economic instability; and
acts of terrorism.
In addition, several North African markets in which we operate, including Tunisia, Egypt, Libya, and Algeria have experienced social and political unrest in past years, which, when they occur, negatively impact our operating results, and can include the temporary suspension of our operations. More recently in Brazil, the ongoing widely-publicized corruption investigation has continued to disrupt Petrobras’ operations, which could negatively impact our operating results in Brazil.
Risks Related to the Cost and Continued Availability of Borrowed Funds, including Risks of Noncompliance with Debt Covenants
We employ borrowed funds as an integral part of our long-term capital structure and our future success is dependent upon continued access to borrowed funds to support our operations. The availability of borrowed funds on reasonable terms is dependent on the condition of credit markets and financial institutions from which these funds are obtained. Adverse events in the financial markets may significantly reduce the availability of funds, which may have an adverse effect on our cost of borrowings and our ability to fund our business strategy. Our ability to meet our debt service requirements and the continued availability of funds under our existing or future loan agreements is dependent upon our ability to generate operating income and remain in compliance with the covenants in our debt agreements. This, in turn, is subject to the volatile nature of the oil and natural gas industry, and to competitive, economic, financial and other factors that are beyond our control.
We fund our ongoing operational needs through a $150 million asset-based revolving credit facility (the “Amended ABL Facility”). Borrowing availability under the Amended ABL Facility is calculated based on eligible accounts receivable, inventory, and, subject to satisfaction of certain financial covenants as described below, composite mats included in the rental fleet, net of reserves and limits on such assets included in the borrowing base calculation. To the extent pledged by us, the borrowing base calculation shall also include the amount of eligible pledged cash. The lender may establish reserves, in part based on appraisals of the asset base, and other limits at its discretion which could reduce the amounts otherwise available under the Amended ABL Facility. Availability associated with eligible rental mats will also be subject to maintaining a minimum consolidated fixed charge coverage ratio and a minimum level of operating income for the Mats and Integrated Services segment. The availability under the


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Amended ABL Facility is expected to fluctuate directionally with changes in our domestic accounts receivable, inventory, and composite mat rental fleet.
The Amended ABL Facility terminates on October 17, 2022; however, the Amended ABL Facility has a springing maturity date that will accelerate the maturity of the Amended ABL Facility to September 1, 2021 if, prior to such date, the convertible notes due 2021 (“2021 Convertible Notes”) have not either been repurchased, redeemed, converted or we have not provided sufficient funds to repay the 2021 Convertible Notes in full on their maturity date. For this purpose, funds may be provided in cash to an escrow agent or a combination of cash to an escrow agent and the assignment of a portion of availability under the Amended ABL Facility. The Amended ABL Facility requires compliance with a minimum fixed charge coverage ratio and minimum unused availability of $25.0 million to utilize borrowings or assignment of availability under the Amended ABL Facility towards funding the repayment of the 2021 Convertible Notes.
We are subject to compliance with a fixed charge coverage ratio covenant if our borrowing availability falls below $22.5 million. If we are unable to make required payments under the Amended ABL Facility or other indebtedness of more than $25.0 million, or if we fail to comply with the various covenants and other requirements of the Amended ABL Facility, we would be in default thereunder, which would permit the holders of the indebtedness to accelerate the maturity thereof, unless we are able to obtain, on a timely basis, a necessary waiver or amendment. Any waiver or amendment may require us to revise the terms of our agreements which could increase the cost of our borrowings, require the payment of additional fees, and adversely impact the results of our operations. Upon the occurrence of any event of default that is not waived, the lenders could elect to exercise any of their available remedies, which include the right to not lend any additional amounts or, in the event we have outstanding indebtedness under the Amended ABL Facility, to declare any outstanding indebtedness, together with any accrued interest and other fees, to be immediately due and payable. If we are unable to repay the outstanding indebtedness, if any, under the Amended ABL Facility when due, the lenders would be permitted to proceed against their collateral. In the event any outstanding indebtedness in excess of $25.0 million is accelerated, this could also cause an event of default under our 2021 Convertible Notes. The acceleration of any of our indebtedness and the election to exercise any such remedies could have a material adverse effect on our business and financial condition.
Risks Related to Operating Hazards Present in the Oil and Natural Gas Industry
Our operations are subject to hazards present in the oil and natural gas industry, such as fire, explosion, blowouts, oil spills and leaks or spills of hazardous materials (both onshore and offshore). These incidents as well as accidents or problems in normal operations can cause personal injury or death and damage to property or the environment. Our customers’ operations can also be interrupted and it is possible that such incidents can interrupt our ongoing operations and the ability to provide our services. From time to time, customers seek recovery for damage to their equipment or property that occurred during the course of our service obligations. Damage to our customers’ property and any related spills of hazardous materials could be extensive if a major problem occurred. We purchase insurance which may provide coverage for incidents such as those described above, however, the policies may not provide coverage or a sufficient amount of coverage for all types of damage claims that could be asserted against us. See the section entitled “Risks Related to the Inherent Limitations of Insurance Coverage” for additional information. 
Risks Related to Business Acquisitions and Capital Investments
Our ability to successfully execute our business strategy will depend, among other things, on our ability to make capital investments and acquisitions which provide us with financial benefits. In November 2017, we acquired certain assets and assumed certain liabilities of WSG for approximately $78 million. WSG has been a strategic logistics and installation service provider for our Mats and Integrated Service segment, offering a variety of complementary services to the composite matting systems, including access road construction, site planning and preparation, environmental protection, fluids and spill storage/containment, erosion control, and site restoration services. In addition, our 2018 capital expenditures are expected to range between $20 million to $25 million (exclusive of any acquisitions). These acquisitions and investments are subject to a number of risks and uncertainties, including:
incorrect assumptions regarding business activity levels or results from our capital investments, acquired operations or assets;
failure to complete a planned acquisition transaction or to successfully integrate the operations or management of any acquired businesses or assets in a timely manner, including the WSG acquisition mentioned above;
diversion of management’s attention from existing operations or other priorities;
unanticipated disruptions to our business associated with the implementation of our enterprise-wide operational and financial system; and
delays in completion and cost overruns associated with large capital investments.
Any of the factors above could have an adverse effect on our business, financial condition or results of operations.


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Risks Related to the Availability of Raw Materials and Skilled Personnel
Our ability to provide products and services to our customers is dependent upon our ability to obtain the raw materials and qualified personnel necessary to operate our business.
Barite is a naturally occurring mineral that constitutes a significant portion of our drilling fluids systems. We currently secure the majority of our barite ore from foreign sources, primarily China and India. The availability and cost of barite ore is dependent on factors beyond our control including transportation, political priorities and government imposed export fees in the exporting countries, as well as the impact of weather and natural disasters. The future supply of barite ore from existing sources could be inadequate to meet the market demand, particularly during periods of increasing world-wide demand, which could ultimately restrict industry activity or our ability to meet customer’s needs.
Our mats business is highly dependent on the availability of high-density polyethylene (“HDPE”), which is the primary raw material used in the manufacture of our DURA-BASE mats. The cost of HDPE can vary significantly based on the energy costs of the producers of HDPE, demand for this material, and the capacity/operations of the plants used to make HDPE. Should our cost of HDPE increase, we may not be able to increase our customer pricing to cover our costs, which may result in a reduction in future profitability.
All of our businesses are also highly dependent on our ability to attract and retain highly-skilled engineers, technical sales and service personnel. The market for these employees is competitive, and if we cannot attract and retain quality personnel, our ability to compete effectively and to grow our business will be severely limited. Also, a significant increase in the wages paid by competing employers could result in a reduction in our skilled labor force or an increase in our operating costs.
Risk Related to our Market Competition
We face competition in the Fluids Systems business from larger companies, including Halliburton and Schlumberger, which compete vigorously on fluids performance and/or price. In addition, these companies have broad product and service offerings in addition to their drilling fluids. At times, these larger companies attempt to compete by offering discounts to customers to use multiple products and services from our competitors, some of which we do not offer. We also have smaller regional competitors competing with us mainly on price and local relationships. Our competition in the Mats and Integrated Services business is fragmented, with many competitors providing various forms of mat products and services. More recently, several competitors have begun marketing composite products to compete with our DURA-BASE mat system. While we believe the design and manufacture of our mat products provide a differentiated value to our customers, many of our competitors seek to compete on pricing. Some of the early patents we received related to our DURA-BASE mat system will expire in 2020 and competitors may begin offering mats that include features described in those patents. We have filed legal actions against competitors in the U.S. to enforce our patents, and have filed for additional patents, but there is no assurance that these actions will be successful or that competitors will not be able to offer matting products that are substantially similar to the DURA-BASE mat system.
Risk Related to Offering New Products and Offering Existing Products in New Markets
As a key component of our long-term strategy in both operating segments, we seek to continue to expand our product and service offerings and enter new customer markets with our existing products. As with any market expansion effort, new customer and product markets include inherent uncertainties regarding customer expectations, industry-specific regulatory requirements, product performance and customer-specific risk profiles. As such, new market entry is subject to a number of risks and uncertainties, which could have an adverse effect on our business, financial condition or results of operations.
Risks Related to Legal and Regulatory Matters, Including Environmental Regulations
We are responsible for complying with numerous federal, state, local and foreign laws, regulations and policies that govern environmental protection, zoning and other matters applicable to our current and past business activities, including the activities of our former subsidiaries. Failure to remain compliant with these laws, regulations and policies may result in, among other things, fines, penalties, costs of cleanup of contaminated sites and site closure obligations, or other expenditures. Further, any changes in the current legal and regulatory environment could impact industry activity and the demands for our products and services, the scope of products and services that we provide, or our cost structure required to provide our products and services, or the costs incurred by our customers.
Many of the markets for our products and services are dependent on the continued exploration for and production of fossil fuels (predominantly oil and natural gas). Climate change is receiving increased attention worldwide. Many scientists, legislators and others attribute climate change to increased levels of greenhouse gases, including carbon dioxide attributed to the use of fossil fuels, which has led to significant legislative and regulatory efforts to limit greenhouse gas emissions. The Environmental Protection Agency (the “EPA”) and other domestic and foreign regulatory agencies have adopted regulations that potentially limit greenhouse gas emissions and impose reporting obligations on large greenhouse gas emission sources. In addition, the EPA has adopted rules that could require the reduction of certain air emissions during exploration and production of oil and gas. To the extent that laws and regulations enacted as part of climate change legislation increase the costs of drilling for or


9



producing such fossil fuels, limit or restrict oil and natural gas exploration and production, or reduce the demand for fossil fuels, such legislation could have a material adverse impact on our operations and profitability.
Hydraulic fracturing is a common practice used by E&P operators to stimulate production of hydrocarbons, particularly from shale oil and gas formations in the United States. The process of hydraulic fracturing, which involves the injection of sand (or other forms of proppants) laden fluids into oil and gas bearing zones, has come under increasing scrutiny from a variety of regulatory agencies, including the EPA and various state authorities. Several states have adopted regulations requiring operators to identify the chemicals used in fracturing operations, others have adopted moratoriums on the use of fracturing, and the State of New York has banned the practice altogether. In addition, concerns have been raised about whether injection of waste associated with hydraulic fracturing operations or from the fracturing operations themselves, may cause or increase the impact of earthquakes. Studies are in process regarding the correlation between hydraulic fracturing and earthquakes. Although we do not provide hydraulic fracturing services, we have begun to offer stimulation fluids used in the hydraulic fracturing process. Regulations which have the effect of limiting the use or significantly increasing the costs of hydraulic fracturing, could have a significant negative impact on both the drilling and stimulation activity levels of our customers, and, therefore, the demand for our products and services.
Risks Related to the Inherent Limitations of Insurance Coverage
While we maintain liability insurance, this insurance is subject to coverage limitations. Specific risks and limitations of our insurance coverage include the following:
self-insured retention limits on each claim, which are our responsibility;
exclusions for certain types of liabilities and limitations on coverage for damages resulting from pollution;
coverage limits of the policies, and the risk that claims will exceed policy limits; and
the financial strength and ability of our insurance carriers to meet their obligations under the policies.
In addition, our ability to continue to obtain insurance coverage on commercially reasonable terms is dependent upon a variety of factors impacting the insurance industry in general, which are outside our control. Any of the issues noted above, including insurance cost increases, uninsured or underinsured claims, or the inability of an insurance carrier to meet their financial obligations could have a material adverse effect on our profitability.
Risks Related to the Ongoing Effects of the U.S. Tax Cuts and Jobs Act and the Refinement of Provisional Estimates
The U.S. Tax Cuts and Jobs Act (“Tax Act”) was enacted on December 22, 2017, resulting in broad and complex changes to U.S. income tax law. Our effective tax rate may fluctuate in the future as a result of the Tax Act, which introduces significant changes to U.S. income tax law that will have a meaningful impact on our provision for income taxes. Accounting for the income tax effects of the Tax Act requires significant judgments and estimates in the interpretation and calculations of the provisions of the Tax Act. Due to the timing of the enactment and the complexity involved in applying the provisions of the Tax Act, we made reasonable estimates of the effects and recorded provisional amounts in our financial statements for the year ended December 31, 2017. The U.S. Treasury Department, the U.S. Internal Revenue Service (“IRS”), and other standard-setting bodies may issue guidance on how the provisions of the Tax Act will be applied or otherwise administered that is different from our interpretation. As we finalize the necessary data, and interpret the Tax Act and any additional guidance issued by the U.S. Treasury Department, the IRS or other standard-setting bodies, we may make adjustments to the provisional amounts that could materially affect our financial position and results of operations as well as our effective tax rate in the period in which the adjustments are made.
Risks Related to Potential Impairments of Long-lived Intangible Assets
As of December 31, 2017, our consolidated balance sheet includes $43.6 million in goodwill and $30.0 million of intangible assets, net, substantially all of which relates to the Mats and Integrated Services segment. Goodwill and indefinite-lived intangible assets are tested for impairment annually, or more frequently as the circumstances require, if any qualitative factors exist. In completing this annual evaluation during the fourth quarter of 2017, we determined that no reporting unit has a fair value below its net carrying value, and therefore, no impairment is required.
However, if the financial performance or future projections for our operating segments deteriorate from current levels, a future impairment of goodwill or indefinite-lived intangible assets may be required, which would negatively impact our financial results in the period of impairment. 
Risks Related to Technological Developments and Intellectual Property in our Industry
The market for our products and services is characterized by continual technological developments that generate substantial improvements in product functions and performance. If we are not successful in continuing to develop product enhancements or new products that are accepted in the marketplace or that comply with industry standards, we could lose market share to competitors, which would negatively impact our results of operations and financial condition.


10



Our success can be affected by our development and implementation of new product designs and improvements and by our ability to protect and maintain critical intellectual property assets related to these developments. Although in many cases our products are not protected by any registered intellectual property rights, in other cases we rely on a combination of patents and trade secret laws to establish and protect this proprietary technology. While patent rights give the owner of a patent the right to exclude third parties from making, using, selling, and offering for sale the inventions claimed in the patents, they do not necessarily grant the owner of a patent the right to practice the invention claimed in a patent. It may also be possible for a third party to design around our patents. We do not have patents in every country in which we conduct business and our patent portfolio will not protect all aspects of our business. When patent rights expire, competitors are generally free to offer the technology and products that were covered by the patents.
We also protect our trade secrets by customarily entering into confidentiality and/or license agreements with our employees, customers and potential customers and suppliers. Our rights in our confidential information, trade secrets, and confidential know-how will not prevent third parties from independently developing similar information. Publicly available information (such as information in expired patents, published patent applications, and scientific literature) can also be used by third parties to independently develop technology. We cannot provide assurance that this independently developed technology will not be equivalent or superior to our proprietary technology.
We may from time to time engage in litigation to determine the enforceability, scope and validity of our patent rights. In addition, we can seek to enforce our rights in trade secrets, or “know-how,” and other proprietary information and technology in the conduct of our business. However, it is possible that our competitors may infringe upon, misappropriate, violate or challenge the validity or enforceability of our intellectual property, and we may not able to adequately protect or enforce our intellectual property rights in the future.
Risks Related to Severe Weather, Particularly in the U.S. Gulf Coast
We have significant operations located in market areas in the U.S. Gulf of Mexico and related near-shore areas which are susceptible to hurricanes and other adverse weather events. In these market areas, we generated approximately 16% of our consolidated revenue in 2017 and had approximately $215 million of inventory and property, plant and equipment as of December 31, 2017. Such adverse weather events can disrupt our operations and result in damage to our properties, as well as negatively impact the activity and financial condition of our customers. Our business may be adversely affected by these and other negative effects of future hurricanes or other adverse weather events in regions in which we operate.
Risks Related to Cybersecurity Breaches or Business System Disruptions
We utilize various management information systems and information technology infrastructure to manage or support a variety of our business operations, and to maintain various records, which may include confidential business or proprietary information as well as information regarding our customers, business partners, employees or other third parties. Failures of or interference with access to these systems, such as communication disruptions, could have an adverse effect on our ability to conduct operations or directly impact consolidated financial reporting. Security breaches pose a risk to confidential data and intellectual property which could result in damages to our competitiveness and reputation. We have policies and procedures in place, including system monitoring and data back-up processes, to prevent or mitigate the effects of these potential disruptions or breaches, however there can be no assurance that existing or emerging threats will not have an adverse impact on our systems or communications networks. These risks could harm our reputation and our relationships with our customers, business partners, employees or other third parties, and may result in claims against us. In addition, these risks could have a material adverse effect on our business, consolidated results of operations, and consolidated financial condition.
Risks Related to Fluctuations in the Market Value of our Common Stock
The market price of our common stock may fluctuate due to a number of factors, including the general economy, stock market conditions, general trends in the E&P industry, announcements made by us or our competitors, and variations in our operating results. Investors may not be able to predict the timing or extent of these fluctuations.

ITEM 1B. Unresolved Staff Comments
None.



11



ITEM 2. Properties
We lease office space to support our operating segments as well as our corporate offices. All material domestic owned properties are subject to liens and security interests under our Amended ABL Facility.
Fluids Systems.  We own a facility containing approximately 103,000 square feet of office space on approximately 11 acres of land in Katy, Texas, which houses the divisional headquarters and technology center for this segment. We own a distribution warehouse and fluids blending facility containing approximately 65,000 square feet of office and industrial space on approximately 21 acres of land in Conroe, Texas. We lease approximately 9 acres of industrial space in Fourchon, Louisiana which houses a drilling fluids blending, storage, and transfer station to serve the Gulf of Mexico deepwater market. Additionally, we own six warehouse facilities and have 12 leased warehouses and 13 contract warehouses to support our customers and operations in the U.S. We own two warehouse facilities and have 22 contract warehouses in Canada to support our Canadian operations. For our international operations in the EMEA, Latin America and Asia Pacific regions, we lease 35 warehouses and own two warehouses to support these operations. Some of the warehouses also include blending facilities.
We operate four specialty product grinding facilities in the U.S. These facilities are located in Houston, Texas on approximately 18 acres of owned land, in New Iberia, Louisiana on 15.7 acres of leased land, in Corpus Christi, Texas on 6 acres of leased land, and in Dyersburg, Tennessee on 13.2 acres of owned land.
Mats and Integrated Services.  We own a facility containing approximately 93,000 square feet of office and industrial space on approximately 34 acres of land in Carencro, Louisiana, which houses our manufacturing facilities and technology center for this segment. We also own three facilities and lease 18 sites throughout the U.S. which serve as bases for our well site service activities. Additionally, we lease two facilities in the United Kingdom to support field operations.
ITEM 3. Legal Proceedings
Escrow Claims Related to the Sale of the Environmental Services Business
Newpark Resources, Inc. v. Ecoserv, LLC. On July 13, 2015, we filed a declaratory action in the District Court in Harris County, Texas (80th Judicial District) seeking release of $8.0 million of funds placed in escrow by Ecoserv in connection with its purchase of our Environmental Services business. Ecoserv filed a counterclaim asserting that we breached certain representations and covenants contained in the purchase/sale agreement including, among other things, the condition of certain assets. In addition, Ecoserv has alleged that Newpark committed fraud in connection with the March 2014 transaction.
Under the terms of the March 2014 sale of the Environmental Services business to Ecoserv, $8.0 million of the sales price was withheld and placed in an escrow account to satisfy claims for possible breaches of representations and warranties contained in the purchase/sale agreement. For the amount withheld in escrow, $4.0 million was scheduled for release to Newpark at each of the nine-month and 18-month anniversary of the closing. In December 2014, we received a letter from Ecoserv asserting that we had breached certain representations and warranties contained in the purchase/sale agreement, including failing to disclose operational problems and service work performed on injection/disposal wells and increased barge rental costs. The letter indicated that Ecoserv expected the damages associated with these claims to exceed the escrow amount. Following a further exchange of letters, in July 2015, we filed the action against Ecoserv referenced above. Thereafter, Ecoserv filed a counterclaim seeking recovery in excess of the escrow funds based on the alleged breach of representations and covenants in the purchase/sale agreement. Ecoserv also alleged that we committed fraud in connection with the March 2014 transaction. Discovery in the case provided more information about Ecoserv’s claims, which included, among other things, alleged inadequate disclosures regarding the condition of a disposal cavern (at the time of the execution of the purchase/sale agreement and as it relates to the time period between execution of the purchase/sale agreement and at closing) and the lack of appropriate reserves/accruals/provisions in the financial statements of the business relating to certain regulatory obligations (such as plug and abandonment costs for injection wells and costs associated with a solids drying facility). Ecoserv sought to use a damage model for most of its damages based on its calculation of the difference between (a) the value of the business at closing, and (b) the sales price ($100.0 million), and had claimed damages of approximately $20.0 million. Following commencement of the trial in December 2017, we reached a settlement agreement with Ecoserv, under which Ecoserv will receive $22.0 million in cash effectively reducing the net sales price of the Environmental Services business by such amount in exchange for dismissal of the pending claims in the lawsuit, and release of any future claims related to the March 2014 transaction.  The impact of this settlement results in a $17.4 million loss from disposal of discontinued operations, net of tax in 2017 to reduce the previously recognized gain from the sale of the Environmental Services business. The reduction in sales price will be funded, in part, through the release of the $8.0 million that has been held in escrow since the March 2014 transaction. The remaining $14 million will be funded in the first quarter of 2018 through available cash on hand and borrowings under our Amended ABL Facility. Litigation expenses related to this matter are included in corporate office expenses in operating income.


12



ITEM 4. Mine Safety Disclosures
The information concerning mine safety violations and other regulatory matters required by Section 1503 (a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95.1 of this Annual Report on Form 10-K, which is incorporated by reference.
PART II
ITEM 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Our common stock is traded on the New York Stock Exchange under the symbol “NR.”
The following table sets forth the range of the high and low sales prices for our common stock for the periods indicated: 
Period
 
High
 
Low
2017
 
 
 
 
Fourth Quarter
 
$
10.05

 
$
8.20

Third Quarter
 
$
10.15

 
$
7.00

Second Quarter
 
$
8.25

 
$
6.65

First Quarter
 
$
8.45

 
$
6.75

 
 
 
 
 
2016
 
 
 
 
Fourth Quarter
 
$
8.20

 
$
5.80

Third Quarter
 
$
7.72

 
$
5.48

Second Quarter
 
$
5.89

 
$
3.74

First Quarter
 
$
5.47

 
$
3.35

As of February 1, 2018, we had 1,305 stockholders of record as determined by our transfer agent.
The following table details our repurchases of shares of our common stock for the three months ended December 31, 2017:
Period
 
Total Number of
Shares Purchased (1)
 
Average Price
per Share
 
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
 
Maximum Approximate Dollar Value of Shares that May Yet be Purchased Under Plans or Programs ($ in millions)
October 2017
 
8,195

 
$
8.54

 

 
$
33.5

November 2017
 
41,950

 
$
9.45

 

 
$
33.5

December 2017
 

 

 

 
$
33.5

Total
 
50,145

 
$
9.30

 

 
 

 
(1)
During the three months ended December 31, 2017, we purchased an aggregate of 50,145 shares surrendered in lieu of taxes under vesting of restricted stock awards.
Our Board of Directors has approved a repurchase program that authorizes us to purchase up to $100.0 million of our outstanding shares of common stock and prior to their maturity, our outstanding 2017 Convertible Notes in the open market or as otherwise determined by management, subject to certain limitations under the Amended ABL Facility and other factors. The repurchase program has no specific term. Repurchases are expected to be funded from operating cash flows and available cash on-hand. As part of the share repurchase program, our management has been authorized to establish trading plans under Rule 10b5-1 of the Securities Exchange Act of 1934.
There were no share or 2017 Convertible Notes repurchases under the program during 2017. At December 31, 2017, there was $33.5 million of authorization remaining under the program. During 2017, we repurchased 415,418 of shares surrendered in lieu of taxes under vesting of restricted stock awards. All of the shares repurchased are held as treasury stock.
We have not paid any dividends during the three most recent fiscal years or any subsequent interim period, and we do not intend to pay any cash dividends in the foreseeable future. In addition, our Amended ABL Facility contains covenants which limit the payment of dividends on our common stock. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources - Asset-Based Loan Facility.”


13



Performance Graph
The following graph reflects a comparison of the cumulative total stockholder return of our common stock from January 1, 2013 through December 31, 2017, with the New York Stock Exchange Market Value Index, a broad equity market index, and the Morningstar Oil & Gas Equipment & Services Index, an industry group index. The graph assumes the investment of $100 on January 1, 2013 in our common stock and each index and the reinvestment of all dividends, if any. This information shall be deemed furnished not filed, in this Form 10-K, and shall not be deemed incorporated by reference into any filing under the Securities Act of 1933, or the Securities Exchange Act of 1934, except to the extent we specifically incorporate it by reference.
chart-a2a66c5a4f9c563ab49.jpg




14



ITEM 6. Selected Financial Data
The selected consolidated historical financial data presented below for the five years ended December 31, 2017 is derived from our consolidated financial statements. The following data should be read in conjunction with the consolidated financial statements and notes thereto and with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Items 7 and 8 below.
 
As of and for the Year Ended December 31,
(In thousands, except share data)
2017
 
2016
 
2015
 
2014
 
2013
Consolidated Statements of Operations Data:
 
 
 
 
 
 
 
 
 
Revenues
$
747,763

 
$
471,496

 
$
676,865

 
$
1,118,416

 
$
1,042,356

Operating income (loss)
31,436

 
(57,213
)
 
(99,099
)
 
130,596

 
94,445

Interest expense, net
13,273

 
9,866

 
9,111

 
10,431

 
11,279

Income (loss) from continuing operations
11,219

 
(40,712
)
 
(90,828
)
 
79,009

 
52,622

Income from discontinued operations, net of tax

 

 

 
1,152

 
12,701

Gain (loss) from disposal of discontinued operations, net of tax
(17,367
)
 

 

 
22,117

 

Net income (loss)
(6,148
)
 
(40,712
)
 
(90,828
)
 
102,278

 
65,323

 
 
 
 
 
 
 
 
 
 
Basic income (loss) per share from continuing operations
$
0.13

 
$
(0.49
)
 
$
(1.10
)
 
$
0.95

 
$
0.62

Basic net income (loss) per share
$
(0.07
)
 
$
(0.49
)
 
$
(1.10
)
 
$
1.23

 
$
0.77

 
 
 
 
 
 
 
 
 
 
Diluted income (loss) per share from continuing operations
$
0.13

 
$
(0.49
)
 
$
(1.10
)
 
$
0.84

 
$
0.56

Diluted net income (loss) per share
$
(0.07
)
 
$
(0.49
)
 
$
(1.10
)
 
$
1.07

 
$
0.69

 
 
 
 
 
 
 
 
 
 
Consolidated Balance Sheet Data:
 
 
 
 
 
 
 
 
 
Working capital
$
346,623

 
$
283,139

 
$
380,950

 
$
440,098

 
$
395,159

Total assets
902,716

 
798,183

 
848,893

 
1,007,672

 
954,918

Foreign bank lines of credit
1,000

 

 
7,371

 
11,395

 
12,809

Other current debt
518

 
83,368

 
11

 
253

 
58

Long-term debt, less current portion
158,957

 
72,900

 
171,211

 
170,462

 
170,009

Stockholders' equity
547,480

 
500,543

 
520,259

 
625,458

 
581,054

 
 
 
 
 
 
 
 
 
 
Consolidated Cash Flow Data:
 
 
 
 
 
 
 
 
 
Net cash provided by operations
$
38,381

 
$
11,095

 
$
121,517

 
$
89,173

 
$
151,903

Net cash used in investing activities
(68,374
)
 
(28,260
)
 
(84,366
)
 
(14,002
)
 
(60,063
)
Net cash used in financing activities
(2,290
)
 
(650
)
 
(6,730
)
 
(49,158
)
 
(72,528
)
During 2016 and 2015, operating loss includes charges totaling $14.8 million and $80.5 million, respectively, resulting from the reduction in value of certain assets, the wind-down of our operations in Uruguay and the resolution of certain wage and hour litigation claims. Charges in 2016 include $6.9 million of non-cash impairments in the Asia Pacific region, $4.1 million of charges for the reduction in carrying values of certain inventory, $4.5 million of charges in the Latin America region associated with the wind-down of our operations in Uruguay, partially offset by a $0.7 million gain in 2016 associated with the change in final settlement amount of certain wage and hour litigation claims. Charges in 2015 include a $70.7 million non-cash impairment of goodwill, a $2.6 million non-cash impairment of assets, a $2.2 million charge to reduce the carrying value of inventory and a $5.0 million charge for the resolution of certain wage and hour litigation claims and related costs.


15



ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion of our financial condition, results of operations, liquidity and capital resources should be read together with our Consolidated Financial Statements and Notes to Consolidated Financial Statements included in Item 8 of this Annual Report.
Overview
We are a geographically diversified supplier providing products, rentals and services primarily to the oil and gas exploration and production (“E&P”) industry. We operate our business through two reportable segments: Fluids Systems and Mats and Integrated Services. In recent years, our Mats and Integrated Services segment has expanded beyond the E&P industry, and now serves a variety of industries, including the electrical transmission & distribution, pipeline, solar, petrochemical and construction industries.
Our operating results depend, to a large extent, on oil and gas drilling activity levels in the markets we serve, and particularly for the Fluids Systems segment, the nature of the drilling operations (including the depth and whether the wells are drilled vertically or horizontally), which governs the revenue potential of each well. Drilling activity, in turn, depends on oil and gas commodity pricing, inventory levels, product demand and regulatory restrictions. Oil and gas prices and activity are cyclical and volatile. This market volatility has a significant impact on our operating results.
Beginning in the fourth quarter of 2014 and continuing through early 2016, the price of oil declined dramatically from the price levels in previous years. As a result, E&P drilling activity declined sharply in North America and many global markets over this period. Since reaching a low point in early 2016, oil prices and North American drilling activity have steadily improved, although both remain significantly lower than pre-downturn levels. While our revenue potential is driven by a number of factors including those described above, rig count data remains the most widely accepted indicator of drilling activity. Average North America rig count data for the last three years is as follows:
 
 
Year Ended December 31,
 
2017 vs 2016
 
2016 vs 2015
 
 
2017
 
2016
 
2015
 
Count
 
%
 
Count
 
%
U.S. Rig Count
 
877

 
509

 
978

 
368

 
72
%
 
(469
)
 
(48
%)
Canadian Rig Count
 
206

 
130

 
192

 
76

 
58
%
 
(62
)
 
(32
%)
Total
 
1,083

 
639

 
1,170

 
444

 
69
%
 
(531
)
 
(45
%)
________________
Source: Baker Hughes, a GE Company
As of February 16, 2018, the U.S. and Canadian rig counts were 975 and 318, respectively. The Canadian rig count reflects the normal seasonality for this market, with the highest rig count levels generally observed in the first quarter of each year, prior to Spring break-up.
Outside of North America, drilling activity has remained generally more stable during this period as drilling activity in many countries is based upon longer term economic projections and multiple year drilling programs, which tends to reduce the impact of short term changes in commodity prices on overall drilling activity. While drilling activity in certain of our international markets (including Brazil and Australia) has declined in recent years, as a whole, our international activities have remained relatively stable. This stability is primarily driven by new contract awards, including those described below, which include geographical expansion into new markets as well as market share gains in existing markets. While our international contracts vary in revenue potential and duration, certain international contracts are scheduled to conclude in 2018, including those with Sonatrach and Petrobras. Our future revenue levels in international markets are largely dependent on our ability to maintain existing market share upon contract renewals which may be subject to a competitive bid process and can be impacted by our customers’ procurement strategies and allocation of contract awards.
Segment Overview
Our Fluids Systems segment, which generated 82% of consolidated revenues in 2017, provides customized fluids solutions to E&P customers globally, operating through four geographic regions: North America, Europe, the Middle East and Africa (“EMEA”), Latin America, and Asia Pacific.





16



International expansion is a key element of our Fluids Systems strategy, which in recent years, has helped to stabilize revenues as North American oil and gas exploration activities have fluctuated significantly. Significant international contract awards in recent years include:
A five year contract with Kuwait Oil Company to provide drilling fluids and related services for land operations. Work under this contract began in the second half of 2014.
Lot 1 and Lot 3 of a restricted tender by Sonatrach to provide drilling fluids and related services, which expanded our market share with Sonatrach in Algeria. Work under this three-year contract began in the second quarter of 2015, with activity levels ramping up during the second half of 2015 and early 2016. While revenues from this contract represented less than 10% of consolidated revenues in 2017, the contract contributed approximately 14% of our consolidated revenues in 2016.
A contract with Total S.A. to provide drilling fluids and related services for an exploratory ultra-deepwater well in Block 14 of offshore Uruguay. This project was completed in 2016, contributing approximately $12 million of revenue for the year in 2016.
A two-year contract with Shell Oil in Albania to provide drilling fluids and related services for onshore drilling activity. Work under this contract began in 2016.
A three-year contract with Cairn Oil & Gas to provide drilling and completion fluids, along with associated services, in support of Cairn’s onshore drilling in India. Work under this contract began in the third quarter of 2017.
A contract with Baker Hughes, a GE Company, to provide drilling fluids and related services as part of Baker Hughes’ integrated service offering in support of the Greater Enfield project in offshore Western Australia. Work under this contract began in January 2018.
Within the U.S. operations of our Fluids Systems segment we invested approximately $40 million in recent years to significantly expand existing capacity and upgrade the drilling fluids blending, storage, and transfer capabilities in our Fourchon, Louisiana facility which serves customers in the Gulf of Mexico deepwater market. This project is part of our Fluids Systems strategy to penetrate the Gulf of Mexico deepwater market and was substantially completed in the second quarter of 2017. Capital expenditures related to the Fourchon expansion totaled $6.9 million, $22.2 million and $10.1 million in 2017, 2016 and 2015, respectively.
Our Mats and Integrated Services segment, which generated 18% of consolidated revenues in 2017, provides composite mat rentals, site construction and related site services to customers in various markets including oil and gas exploration and production, electrical transmission & distribution, pipeline, solar, petrochemical and construction across North America and Europe. We also sell composite mats to customers outside of the U.S. and to domestic customers outside of the E&P market. Following our efforts in recent years to diversify our customer base, Mats and Integrated Services segment revenues from non-E&P markets represented approximately two-thirds of our segment revenues in 2017.
In November 2017, we acquired certain assets and assumed certain liabilities of Well Service Group, Inc. and Utility Access Solutions, Inc. (together, “WSG”) for $77.9 million, which included $45.5 million of cash consideration and $32.4 million of our common equity. Since 2012, WSG has been a strategic logistics and installation service provider for our Mats and Integrated Service segment, offering a variety of complementary services to our composite matting systems, including access road construction, site planning and preparation, environmental protection, fluids and spill storage/containment, erosion control, and site restoration services. The completion of the WSG acquisition expanded our service offering as well as our geographic footprint across the Northeast, Midwest, Rockies, and West Texas regions of the U.S. Following the mid-November acquisition, WSG contributed approximately $9 million of revenues to the Mats and Integrated Services segment in 2017, reflecting an annualized revenue level of approximately $70 million.
Impact of U.S. Tax Reform
The U.S. Tax Cuts and Jobs Act (“Tax Act”) was enacted on December 22, 2017, resulting in broad and complex changes to U.S. income tax law. The Tax Act includes a one-time transition tax in 2017 on accumulated foreign subsidiary earnings not previously subject to U.S. income tax, reduces the U.S. corporate statutory tax rate from 35% to 21% effective January 1, 2018, generally eliminates U.S. federal income tax on dividends from foreign subsidiaries, creates new tax on certain foreign-sourced earnings, makes other changes to limit certain deductions and changes rules on how certain tax credits and net operating loss carryforwards can be utilized.
Due to the timing of the enactment and the complexity involved in applying the provisions of the Tax Act, we made reasonable estimates of the effects and recorded provisional amounts in our 2017 financial statements. As we finalize the necessary data, and interpret the Tax Act and any additional guidance issued by the U.S. Treasury Department, the IRS, or other standard-setting bodies, we may make adjustments to the provisional amounts.


17



We recorded a net tax benefit of $3.4 million in 2017, reflecting provisional amounts for the following income tax effects of the Tax Act:
One-time transition tax — The Tax Act requires us to pay U.S. income taxes on accumulated foreign subsidiary earnings not previously subject to U.S. income tax at a rate of 15.5% to the extent of foreign cash and certain other net current assets and 8% on the remaining earnings. We recorded a provisional amount in 2017 for our one-time transitional tax liability and income tax expense of $6.9 million.
Taxes on repatriation of foreign earnings — We previously considered the unremitted earnings in our non-US subsidiaries held directly by a U.S. parent to be indefinitely reinvested and, accordingly, had not provided any deferred income taxes. We intend to pursue repatriation of unremitted earnings in our non-US subsidiaries held directly by a U.S. parent to the extent that such earnings have been included in the one-time transition tax discussed above, and subject to cash requirements to support the strategic objectives of the non-US subsidiary. We recorded a provisional amount in 2017 for the estimated liability and income tax expense for any U.S. federal or state income taxes or additional foreign withholding taxes related to repatriation of such earnings of $7.0 million.
Deferred tax effects The Tax Act reduces the U.S. corporate statutory tax rate from 35% to 21% for years after 2017. Accordingly, we have remeasured our U.S. net deferred tax liabilities as of December 31, 2017 to reflect the reduced rate that will apply in future periods when these deferred taxes are settled or realized. We recognized a provisional deferred tax benefit in 2017 of $17.4 million to reflect the reduced U.S. tax rate on our estimated U.S. net deferred tax liabilities.
While we have not completed our analysis of the impacts of the Tax Act on our effective tax rate going forward, we anticipate the overall impacts of the Tax Act described above will reduce our effective tax rate in 2018 compared to 2017, excluding the $3.4 million net benefit included in our 2017 income tax provision as described above. The impact of the Tax Act on our effective tax rate in 2018 will depend in large part on the relative contribution of our domestic earnings and finalization of the provisional accounting for the Tax Act.
2016 and 2015 Impairments and Restructuring Charges
After achieving an average North America rig count of 2,241 in 2014, the declining E&P drilling activity levels throughout 2015 through early 2016 reduced the demand for our services, negatively impacted customer pricing and resulted in elevated costs associated with workforce reductions, negatively impacting our profitability. Further, due to the fact that our business contains substantial levels of fixed costs, including significant facility and personnel expenses, North American operating margins in both operating segments were negatively impacted by the lower customer demand during these years.
In response to these significant activity declines in North America, we implemented cost reduction programs in 2015 including workforce reductions, reduced discretionary spending, and implemented temporary salary freezes for substantially all employees, including executive officers. In September 2015, we also implemented a voluntary early retirement program with certain eligible employees in the United States. As a result of the continuing declines in activity in the first half of 2016, we implemented further cost reduction actions including additional workforce reductions and beginning in March 2016, a temporary salary reduction for a significant number of North American employees, including executive officers, suspension of the Company’s matching contribution to the U.S. defined contribution plan as well as a reduction in cash compensation paid to our Board of Directors in order to further align our cost structure to activity levels. In the second quarter of 2017, we restored salaries to pre-reduction levels for our North American employees, as well as the Company matching contribution to the U.S. defined contribution plan.
As part of these workforce reductions, we recognized charges for employee termination costs as shown in the table below:
 
Year Ended December 31,
(In thousands)
2016
 
2015
Fluids systems
$
4,125

 
$
7,218

Mats and integrated services
285

 
717

Corporate office
162

 
228

Total employee termination costs
$
4,572

 
$
8,163

During 2016 and 2015 we also recorded charges totaling $14.8 million and $80.5 million, respectively, resulting from the reduction in value of certain assets, the wind-down of our operations in Uruguay and the resolution of certain wage and hour litigation claims. The Fluids Systems segment operating results included $15.5 million and $75.5 million of these charges in 2016 and 2015, respectively. The remaining $0.7 million benefit and $5.0 million charge was included in Corporate Office expenses in 2016 and 2015, respectively, related to the resolution of certain wage and hour litigation claims.


18



The $15.5 million of Fluids Systems charges in 2016 included $6.9 million of non-cash impairments in the Asia Pacific region resulting from the continuing unfavorable industry market conditions and outlook for the region in 2016, $4.1 million of charges for the reduction in carrying values of certain inventory, primarily resulting from lower of cost or market adjustments and $4.5 million of charges in the Latin America region associated with the wind-down of our operations in Uruguay, including $0.5 million to write-down property, plant and equipment. The $6.9 million of impairments in the Asia Pacific region included a $3.8 million charge to write-down property, plant and equipment to its estimated fair value and a $3.1 million charge to fully impair the customer related intangible assets in the region.
The $75.5 million of Fluids Systems charges in 2015 included $70.7 million of non-cash charges for the impairment of goodwill, following our November 1, 2015 annual evaluation, a $2.6 million non-cash impairment of assets, following our decision to exit a facility, and a $2.2 million charge to reduce the carrying value of diesel-based drilling fluid inventory, resulting from lower of cost or market adjustments.
Year Ended December 31, 2017 Compared to Year Ended December 31, 2016
Consolidated Results of Operations
Summarized results of operations for the year ended December 31, 2017 compared to the year ended December 31, 2016 are as follows:
 
Year Ended December 31,
 
2017 vs 2016
(In thousands)
2017
 
2016
 
 
%
Revenues
$
747,763

 
$
471,496

 
$
276,267

 
59
%
Cost of revenues
607,899

 
437,836

 
170,063

 
39
%
Selling, general and administrative expenses
108,838

 
88,473

 
20,365

 
23
%
Other operating income, net
(410
)
 
(4,345
)
 
3,935

 
91
%
Impairments and other charges

 
6,745

 
(6,745
)
 
NM

Operating income (loss)
31,436

 
(57,213
)
 
88,649

 
155
%
 
 
 
 
 
 
 
 
Foreign currency exchange (gain) loss
2,051

 
(710
)
 
2,761

 
NM

Interest expense, net
13,273

 
9,866

 
3,407

 
35
%
Gain on extinguishment of debt

 
(1,615
)
 
1,615

 
NM

Income (loss) from continuing operations before income taxes
16,112

 
(64,754
)
 
80,866

 
125
%
 
 
 
 
 
 
 
 
Provision (benefit) for income taxes
4,893

 
(24,042
)
 
28,935

 
120
%
Income (loss) from continuing operations
11,219

 
(40,712
)
 
51,931

 
128
%
 
 
 
 
 
 
 
 
Loss from disposal of discontinued operations, net of tax
(17,367
)
 

 
(17,367
)
 
NM

Net Loss
$
(6,148
)
 
$
(40,712
)
 
$
34,564

 
85
%
Revenues
Revenues increased 59% to $747.8 million in 2017, compared to $471.5 million in 2016. This $276.3 million increase includes a $268.0 million (108%) increase in revenues in North America, comprised of a $212.5 million increase in our Fluids Systems segment and a $55.5 million increase in the Mats and Integrated Services segment. Revenues from our international operations increased by $8.3 million (4%), as activity gains in the EMEA region, Brazil and Chile were mostly offset by the completion of the offshore Uruguay project, which contributed $12.3 million of revenue in 2016. Additional information regarding the change in revenues is provided within the operating segment results below.
Cost of Revenues
Cost of revenues increased 39% to $607.9 million in 2017, compared to $437.8 million in 2016. This increase was primarily driven by the 59% increase in revenues; however, cost of revenues contain substantial levels of fixed costs in each business, including significant depreciation, facility costs and personnel expenses, resulting in the lower increase in cost of revenues relative to the change in revenues. In addition, 2016 included $4.6 million of employee severance costs which did not recur in 2017.


19



Selling, General and Administrative Expenses
Selling, general and administrative expenses increased $20.4 million to $108.8 million in 2017 from $88.5 million in 2016. The increase in expenses is primarily attributable to a $10.6 million increase in performance-based incentive compensation as well as elevated spending related to strategic planning efforts and legal matters, including the WSG acquisition described above. Selling, general and administrative expenses as a percentage of revenues decreased to 14.6% in 2017 from 18.8% in the prior year.
Other Operating Income, net
Other operating income was $0.4 million in 2017 as compared to $4.3 million in 2016, primarily reflecting gains on the sale of assets in both periods.
Impairments and Other Charges
During 2017, we did not recognize any impairments and other charges. During 2016, we recognized $6.7 million of impairments and other charges. As previously described, these charges primarily included $6.9 million of non-cash impairments in our Asia Pacific region including a $3.8 million charge to write-down property, plant and equipment to its estimated fair value and a $3.1 million charge to fully impair the customer related intangible assets. See “Note 12 – Segment Data” for additional information related to these charges. In addition, we recorded a $0.5 million charge in 2016 in the Latin America region of our Fluids Systems segment to write-down property, plant and equipment associated with the wind-down of our operations in Uruguay. These charges were partially offset by a $0.7 million gain in 2016 in our corporate office associated with the change in the final settlement amount of the wage and hour litigation claims.
Foreign Currency Exchange
Foreign currency exchange was a $2.1 million loss in 2017 compared to a $0.7 million gain in 2016, reflecting the impact of currency translation on assets and liabilities (including intercompany balances) that are denominated in currencies other than functional currencies.
Interest Expense, net
Interest expense totaled $13.3 million in 2017 compared to $9.9 million in 2016. This increase was primarily attributable to a $3.7 million increase in non-cash amortization of debt discount associated with the 2021 Convertible Notes and lower capitalized interest in 2017 as compared to 2016. These increases were partially offset by $1.1 million of charges in the second quarter of 2016 for the write-off of debt issuance costs related to the termination and replacement of our revolving Credit Agreement. See “Note 6 – Financing Arrangements” for further discussion of the accounting treatment for the 2021 Convertible Notes.
Gain on Extinguishment of Debt
The $1.6 million gain on extinguishment of debt in 2016 reflects the difference in the amount paid and the net carrying value of the extinguished debt, including debt issuance costs, related to the repurchase of $89.3 million aggregate principal amount of our 2017 Convertible Notes.
Provision (Benefit) for Income Taxes
The provision for income taxes for 2017 was $4.9 million, reflecting an effective tax rate of 30.4%, compared to a $24.0 million benefit in 2016, reflecting an effective tax rate of 37.1%. The provision for income taxes in 2017 includes a $3.4 million benefit resulting from the provisional accounting for the Tax Act as previously described. In addition, the 2017 effective tax rate was negatively impacted primarily by non-deductible expenses relative to the amount of pre-tax income.
The benefit for income taxes in 2016 included a $9.3 million benefit associated with a worthless stock deduction and related impacts from restructuring the investment in our Brazilian subsidiary, partially offset by the unfavorable impact of pretax losses incurred in Australia, including $6.9 million of impairment charges, for which the recording of a tax benefit is not permitted.
Loss from Disposal of Discontinued Operations
Loss from disposal of discontinued operations includes a $17.4 million charge, net of tax, in 2017 for the settlement of a pending litigation matter related to the March 2014 sale of our Environmental Services business. See “Note 14 – Discontinued Operations” and “Note 15 – Commitments and Contingencies” in our consolidated financial statements for additional information.







20





Operating Segment Results
Summarized financial information for our reportable segments is shown in the following table (net of inter-segment transfers):
 
Year ended December 31,
 
2017 vs 2016
(In thousands)
2017
 
2016
 
$
 
%
Revenues
 
 
 
 
 
 
 
Fluids systems
$
615,803

 
$
395,461

 
$
220,342

 
56
%
Mats and integrated services
131,960

 
76,035

 
55,925

 
74
%
Total revenues
$
747,763

 
$
471,496

 
$
276,267

 
59
%
 
 
 
 
 
 
 
 
Operating income (loss)
 
 
 
 
 
 
 
Fluids systems
$
27,580

 
$
(43,631
)
 
$
71,211

 
 

Mats and integrated services
40,491

 
14,741

 
25,750

 
 

Corporate office
(36,635
)
 
(28,323
)
 
(8,312
)
 
 

Operating income (loss)
$
31,436

 
$
(57,213
)
 
$
88,649

 
 

 
 
 
 
 
 
 
 
Segment operating margin
 
 
 
 
 
 
 
Fluids systems
4.5
%
 
(11.0
%)
 
 

 
 

Mats and integrated services
30.7
%
 
19.4
%
 
 

 
 

Fluids Systems
Revenues
Total revenues for this segment consisted of the following:  
 
Year ended December 31,
 
2017 vs 2016
(In thousands)
2017
 
2016
 
$
 
%
United States
$
341,075

 
$
149,876

 
$
191,199

 
128
%
Canada
54,322

 
33,050

 
21,272

 
64
%
Total North America
395,397

 
182,926

 
212,471

 
116
%
Latin America
36,965

 
40,736

 
(3,771
)
 
(9
%)
Total Western Hemisphere
432,362

 
223,662

 
208,700

 
93
%
 
 
 
 
 
 
 
 
EMEA
179,360

 
167,130

 
12,230

 
7
%
Asia Pacific
4,081

 
4,669

 
(588
)
 
(13
%)
Total Eastern Hemisphere
183,441

 
171,799

 
11,642

 
7
%
 
 
 
 
 
 
 
 
Total Fluids Systems
$
615,803

 
$
395,461

 
$
220,342

 
56
%
North America revenues increased 116% to $395.4 million in 2017 compared to $182.9 million in 2016. This increase in revenues is primarily attributable to the 69% increase in North American average rig count along with market share gains and higher customer spending per well in 2017 compared to the prior year. Canadian revenues also included a $4.8 million increase from the August 2016 acquisition of Pragmatic Drilling Fluids Additives, Ltd.
Internationally, revenues increased 4% to $220.4 million in 2017 compared to $212.5 million in 2016. The increase in the EMEA region is primarily attributable to an increase in customer activity levels in Algeria and Romania. The decrease in the Latin America region is attributable to completion of the offshore Uruguay project which contributed $12.3 million of revenue in 2016 partially offset by increased activity with Petrobras in Brazil and an increase in revenue from a customer contract in Chile which started in the fourth quarter of 2016.


21



Operating Income
The Fluids Systems segment generated operating income of $27.6 million in 2017 compared to an operating loss of $43.6 million in 2016, representing a $71.2 million improvement in operating results. The operating loss in 2016 includes $15.5 million of charges related to asset impairments and $4.1 million of charges related to workforce reductions, as previously described.
The remaining $51.6 million increase in operating results includes a $48.7 million improvement from North American operations and a $2.9 million increase in operating income from international operations. The improvement in North American operating results is largely attributable to the $212.5 million increase in revenues described above. The increase in international operating income is primarily attributable to the increase in revenues as well as the benefit of cost reduction programs in the Asia Pacific region.
Mats and Integrated Services
Revenues
Total revenues for this segment consisted of the following:  
 
Year ended December 31,
 
2017 vs 2016
(In thousands)
2017
 
2016
 
 
%
Mat rental and services
$
96,067

 
$
58,389

 
$
37,678

 
65
%
Mat sales
35,893

 
17,646

 
18,247

 
103
%
Total
$
131,960

 
$
76,035

 
$
55,925

 
74
%
Mat rental and services revenues for 2017 increased $37.7 million compared to 2016. This improvement includes an increase in revenue from E&P customer activity, attributable to the improvement in oil prices, as well as increases in non-E&P customer activity associated with our continued efforts to expand beyond our traditional oilfield customer base and strong weather-related demand for rental mats. The 2017 operating results also include approximately $9 million of services revenue from the WSG acquisition in mid-November.
Revenues from mat sales were $35.9 million in 2017 compared to $17.6 million in 2016. Revenues from mat sales have typically fluctuated based on the timing of mat orders from customers. The improvement in 2017 is primarily attributable to our continued efforts to further expand our sales into non-E&P markets.
Operating Income
Segment operating income increased by $25.8 million to $40.5 million for 2017 as compared to $14.7 million in 2016, attributable to the increases in both mat sales and rental and services revenues as described above. Due to the relatively fixed nature of operating expenses, increases in revenue have a higher incremental impact on segment operating margin.
As noted above, the 2017 operating results include approximately $9 million of revenues associated with the WSG acquisition completed in mid-November 2017. The acquired business is predominately focused on site services, as opposed to product sales and rentals, which we expect will drive a shift in sales mix toward service revenues in 2018, as compared to 2017. While we expect the incremental service revenues to provide a positive impact to segment operating income, the mix shift and higher depreciation and amortization expense related to the purchase accounting allocation is expected to reduce the overall segment operating margin from the 30.7% operating margin achieved in 2017. See “Note 2 - Business Combinations” for further discussion of the acquisition.
Corporate office
Corporate office expenses increased $8.3 million to $36.6 million in 2017, compared to $28.3 million for 2016. The increase is primarily attributable to a $2.7 million increase in performance-based incentive compensation and a $2.0 million increase in spending related to strategic planning efforts and legal matters, including the Ecoserv lawsuit described further in “Note 15 - Commitments and Contingencies.” The 2017 operating results also include a $1.0 million increase in acquisition related costs, primarily attributable to the WSG acquisition.


22



Year Ended December 31, 2016 Compared to Year Ended December 31, 2015 
Consolidated Results of Operations
Summarized results of operations for the year ended December 31, 2016 compared to the year ended December 31, 2015 are as follows:  
 
Year Ended December 31,
 
2016 vs 2015
(In thousands)
2016
 
2015
 
 
%
Revenues
$
471,496

 
$
676,865

 
$
(205,369
)
 
(30
%)
Cost of revenues
437,836

 
599,013

 
(161,177
)
 
(27
%)
Selling, general and administrative expenses
88,473

 
101,032

 
(12,559
)
 
(12
%)
Other operating income, net
(4,345
)
 
(2,426
)
 
(1,919
)
 
(79
%)
Impairments and other charges
6,745

 
78,345

 
(71,600
)
 
NM

Operating loss
(57,213
)
 
(99,099
)
 
41,886

 
42
%
 
 
 
 
 
 
 
 
Foreign currency exchange loss
(710
)
 
4,016

 
(4,726
)
 
NM

Interest expense, net
9,866

 
9,111

 
755

 
8
%
Gain on extinguishment of debt
(1,615
)
 

 
1,615

 
NM

Loss from operations before income taxes
(64,754
)
 
(112,226
)
 
47,472

 
42
%
 
 
 
 
 
 
 
 
Benefit for income taxes
(24,042
)
 
(21,398
)
 
(2,644
)
 
(12
%)
Net Loss
$
(40,712
)
 
$
(90,828
)
 
$
50,116

 
55
%
Revenues
Revenues decreased 30% to $471.5 million in 2016, compared to $676.9 million in 2015. This $205.4 million decrease included a $189.1 million (43%) decrease in revenues in North America, including a $169.0 million decline in our Fluids Systems segment and a $20.1 million decline in our Mats and Integrated Services segment. Revenues from our international operations decreased by $16.3 million (7%), as a $12.3 million revenue contribution from the offshore Uruguay project in 2016, along with activity gains in our EMEA region were more than offset by reduced drilling activity in Brazil and Asia Pacific, as well as a $12.0 million unfavorable impact of currency exchange related to the stronger U.S. dollar in 2016. Additional information regarding the change in revenues is provided within the operating segment results below.
Cost of Revenues
Cost of revenues decreased 27% to $437.8 million in 2016, compared to $599.0 million in 2015. The decrease was primarily driven by the decline in revenues, the benefits of cost reduction programs, a $6.1 million reduction in depreciation expense associated with the January 2016 change in estimated useful lives and residual values of our composite mats rental fleet and a $2.0 million reduction in employee termination costs. These decreases were partially offset by a $1.9 million increase in inventory impairments primary resulting from lower of cost or market adjustments. Additional information regarding the change in cost of revenues is provided within the operating segment results below.
Selling, General and Administrative Expenses
Selling, general and administrative expenses decreased $12.6 million to $88.5 million in 2016 from $101.0 million in 2015. The decrease is primarily attributable to the benefits of cost reduction programs, a $2.4 million decline in performance-based incentive compensation, a $1.9 million decline in spending related to legal matters, a $1.6 million decrease in employee termination costs and lower spending on strategic planning projects.
Other Operating Income, net
Other operating income was $4.3 million in 2016 as compared to $2.4 million in 2015, primarily reflecting gains on the sale of assets in both periods.


23



Impairments and Other Charges
As previously described, we recognized $6.7 million of impairments and other charges in 2016, which included $6.9 million of non-cash impairments in the Asia Pacific region of our Fluids Systems segment, reflecting a $3.8 million charge to write-down property, plant and equipment to its estimated fair value and a $3.1 million charge to fully impair the customer related intangible assets in the region. In addition, we recorded a $0.5 million charge in 2016 in the Latin America region of our Fluids Systems segment to write-down property, plant and equipment associated with the wind-down of our operations in Uruguay, partially offset by a $0.7 million gain in 2016 in our corporate office associated with the change in the final settlement amount of the wage and hour litigation claims.
In 2015, we recognized $78.3 million of impairments and other charges including $70.7 million of non-cash charges in the Fluids Systems segment for the impairment of goodwill and $2.6 million for the impairment of certain assets following our decision to exit a facility. In addition, corporate office expenses in 2015 included a $5.0 million charge for the resolution of certain wage and hour litigation claims and related costs.
Foreign Currency Exchange
Foreign currency exchange was a $0.7 million gain in 2016 compared to a $4.0 million loss in 2015, reflecting the impact of currency translation on assets and liabilities (including intercompany balances) that are denominated in currencies other than functional currencies. The foreign exchange loss in 2015 was primarily due to the strengthening of the U.S. dollar against the Brazilian real. In September 2015, approximately 70% of the inter-company balances due from our Brazilian subsidiary with foreign currency exposure were forgiven, which reduced the foreign currency volatility in 2016 in comparison to 2015.
Interest Expense, net
Interest expense, which primarily reflected the 4% interest associated with our unsecured 2017 Convertible Notes, totaled $9.9 million for 2016 compared to $9.1 million in 2015. The increase in 2016 was primarily attributable to a non-cash charge of $1.1 million in the second quarter of 2016 for the write-off of debt issuance costs related to the termination and replacement of our revolving Credit Agreement partially offset by the benefit from the repurchase of $11.2 million of our 2017 Convertible Notes in the first quarter of 2016.
Gain on Extinguishment of Debt
The $1.6 million gain in 2016 reflects the difference in the amount paid and the net carrying value of the extinguished debt, including debt issuance costs, related to the repurchase of $89.3 million aggregate principal amount of our 2017 Convertible Notes.
Provision (Benefit) for Income Taxes
The provision for income taxes for 2016 was a $24.0 million benefit, reflecting an effective tax rate of 37.1%, compared to a $21.4 million benefit in 2015, reflecting an effective tax rate of 19.1%. The benefit for income taxes in 2016 included a $9.3 million benefit associated with a worthless stock deduction and related impacts from restructuring the investment in our Brazilian subsidiary, partially offset by the unfavorable impact of pretax losses incurred in Australia for which the recording of a tax benefit is not permitted.
The benefit for income taxes in 2015 was unfavorably impacted by the impairment of non-deductible goodwill. In addition, the 2015 income tax provision also included a $4.6 million charge for increases to the valuation allowance for certain deferred tax assets which may not be realized (primarily related to our Australian subsidiary and certain U.S. state net operating losses). These 2015 charges were partially offset by a $4.4 million benefit associated with the forgiveness of certain inter-company balances due from our Brazilian subsidiary and a $2.2 million benefit from the release of U.S. tax reserves following the expiration of statutes of limitation.











24



Operating Segment Results
Summarized financial information for our reportable segments is shown in the following table (net of inter-segment transfers): 
 
Year ended December 31,
 
2016 vs 2015
(In thousands)
2016
 
2015
 
$
 
%
Revenues
 
 
 
 
 
 
 
Fluids systems
$
395,461

 
$
581,136

 
$
(185,675
)
 
(32
%)
Mats and integrated services
76,035

 
95,729

 
(19,694
)
 
(21
%)
Total revenues
$
471,496

 
$
676,865

 
$
(205,369
)
 
(30
%)
 
 
 
 
 
 
 
 
Operating income (loss)
 
 
 
 
 
 
 
Fluids systems
$
(43,631
)
 
$
(86,770
)
 
$
43,139

 
 

Mats and integrated services
14,741

 
24,949

 
(10,208
)
 
 

Corporate office
(28,323
)
 
(37,278
)
 
8,955

 
 

Operating loss
$
(57,213
)
 
$
(99,099
)
 
$
41,886

 
 

 
 
 
 
 
 
 
 
Segment operating margin
 
 
 
 
 
 
 
Fluids systems
(11.0
%)
 
(14.9
%)
 
 

 
 

Mats and integrated services
19.4
%
 
26.1
%
 
 

 
 

Fluids Systems
Revenues
Total revenues for this segment consisted of the following:  
 
Year ended December 31,
 
2016 vs 2015
(In thousands)
2016
 
2015
 
$
 
%
United States
$
149,876

 
$
299,266

 
$
(149,390
)
 
(50
%)
Canada
33,050

 
52,673

 
(19,623
)
 
(37
%)
Total North America
182,926

 
351,939

 
(169,013
)
 
(48
%)
Latin America
40,736

 
46,668

 
(5,932
)
 
(13
%)
Total Western Hemisphere
223,662

 
398,607

 
(174,945
)
 
(44
%)
 
 
 
 
 
 
 
 
EMEA
167,130

 
164,426

 
2,704

 
2
%
Asia Pacific
4,669

 
18,103

 
(13,434
)
 
(74
%)
Total Eastern Hemisphere
171,799

 
182,529

 
(10,730
)
 
(6
%)
 
 
 
 
 
 
 
 
Total Fluids Systems
$
395,461

 
$
581,136

 
$
(185,675
)
 
(32
%)
North America revenues decreased 48% to $182.9 million in 2016, compared to $351.9 million in 2015. This decrease in revenues is primarily attributable to the 45% decline in North American average rig count along with lower pricing and customer spending per well, partially offset by market share gains over this period.
Internationally, revenues decreased 7% to $212.5 million in 2016 compared to $229.2 million in 2015, which included a $10.7 million reduction from currency rate changes compared to 2015. The increase in the EMEA region was primarily driven by a $39.8 million increase for activity in Algeria, Kuwait, and the Republic of the Congo, partially offset by a $16.6 million decrease following the completion of customer drilling activity in the deepwater Black Sea and other reductions in customer drilling activity related to the current commodity price environment, as well as an $8.5 million reduction from the impact of currency exchange. The decrease in revenues in Latin America is primarily attributable to declines in Petrobras drilling activity in Brazil and the impact of currency exchange partially offset by the $12.3 million revenue contribution from the offshore Uruguay project in 2016. The decline in Asia Pacific is primarily attributable to reduced drilling activity in Australia.


25



Operating Income
The Fluids Systems segment incurred an operating loss of $43.6 million in 2016 compared to an operating loss of $86.8 million in 2015. The operating losses in 2016 and 2015 included $15.5 million and $75.5 million of charges, respectively, for the impairment of assets as previously discussed. The remaining $16.8 million net increase in operating loss in 2016 compared to 2015 included a $13.3 million increase in the North American operating loss and a $3.5 million decrease in international operating income. The increase in North American operating loss is largely attributable to the $169.0 million decline in revenues described above, partially offset by the benefits of cost reduction programs and a $3.1 million reduction in employee termination costs. The $3.5 million decrease in international operating income is primarily attributable to an unfavorable change in customer mix in EMEA along with the revenue declines in Asia Pacific and Latin America and a $1.8 million negative impact of currency exchange.
Mats and Integrated Services
Revenues
Total revenues for this segment consisted of the following:  
 
Year ended December 31,
 
2016 vs 2015
(In thousands)
2016
 
2015
 
 
%
Mat rental and services
$
58,389

 
$
73,037

 
$
(14,648
)
 
(20
%)
Mat sales
17,646

 
22,692

 
(5,046
)
 
(22
%)
Total
$
76,035

 
$
95,729

 
$
(19,694
)
 
(21
%)
Mat rental and services revenues decreased $14.6 million in 2016, as compared to 2015. The decrease is primarily due to weakness in North American drilling markets, including the U.S. Northeast region which has historically been the segment’s largest rental market. A 49% decline in the U.S. Northeast region’s drilling activity, along with a significant decline in completions activity, has resulted in lower rental fleet utilization and customer pricing from prior year levels. The revenue decline from North American drilling markets was partially offset by a $5.7 million increase in revenues from non-E&P customers in North America and Europe.
Revenues from mat sales declined by $5.0 million compared to 2015 and typically fluctuates based on the timing of mat orders from customers.
Operating Income
Segment operating income declined by $10.2 million to $14.7 million in 2016, as compared to $24.9 million in 2015, largely attributable to the decline in revenues described above. Due to the relatively fixed nature of operating expenses in our rental business, declines in rental and services revenue have a higher decremental impact on the segment’s operating margin. The impact of lower revenue was partially offset by a $6.1 million reduction in depreciation expense and a $1.4 million increase in gains recognized on the sale of used composite mats from our rental fleet. The reduction in depreciation expense was a result of a change in estimated useful lives and residual values of our composite mats included in rental fleet fixed assets in 2016 as further discussed in Note 1 to the Consolidated Financial Statements.
Corporate office
Corporate office expenses decreased $9.0 million to $28.3 million in 2016, compared to $37.3 million in 2015. The decrease is primarily attributable to a $5.7 million improvement from the settlement of the wage and hour litigation claims and a $2.0 million decrease in legal costs, primarily associated with such claims. The remaining $1.3 million decrease is primarily attributable to reduced spending on strategic projects and the benefits of cost reduction programs.
Liquidity and Capital Resources
Net cash provided by operating activities during 2017 totaled $38.4 million compared to $11.1 million during 2016. The increase in operating cash flow is primarily attributable to the improvements in operational performance in North America. As a result of the 59% improvement in consolidated revenues, net income adjusted for non-cash items provided $57.4 million of operating cash in 2017, while an increase in working capital required to support the growth used $19.1 million of cash in 2017, primarily reflecting increases in trade receivables offset by a $37.2 million tax refund received in the second quarter of 2017.
Net cash used in investing activities during 2017 was $68.4 million, including $44.8 million associated with the WSG acquisition. Investing activities also included capital expenditures of $31.4 million, including $17.6 million in the Fluids Systems segment, of which $6.9 million related to the facility upgrade and expansion of our Fourchon, Louisiana facility. The Mats and Integrated Services segment capital expenditures totaled $12.0 million during 2017, primarily reflecting investments in the mat rental fleet.


26



Net cash used in financing activities during 2017 was $2.3 million. We borrowed a net $81.6 million on our Amended ABL Facility in 2017, which largely funded repayment of the $83.3 million 2017 Convertible Notes that matured in October 2017.
As of December 31, 2017, we had cash on-hand of $56.4 million, substantially all of which resides within our international subsidiaries. As a result of the Tax Act as previously described, we intend to pursue repatriation of available cash in certain of our international subsidiaries subject to cash requirements to support the strategic objectives of these international subsidiaries and finalization of our analysis of the impacts of the Tax Act. We anticipate that our future working capital requirements for our operations will fluctuate directionally with revenues. In addition, we expect total 2018 capital expenditures to be approximately $20 million to $25 million. Availability under our Amended ABL Facility also provides additional liquidity as discussed further below. Total availability under the Amended ABL Facility will fluctuate directionally based on the level of eligible accounts receivable, inventory, and, subject to satisfaction of certain financial covenants as described below, composite mats included in the rental fleet. We expect our available cash on-hand, cash generated by operations and remaining availability under our Amended ABL Facility to be adequate to fund current operations during the next 12 months.
Our capitalization was as follows:  
(In thousands)
December 31, 2017
 
December 31, 2016
Convertible Notes due 2017
$

 
$
83,256

Convertible Notes due 2021
100,000

 
100,000

Amended ABL Facility
81,600

 

Other debt
1,518

 
380

Unamortized discount and debt issuance costs
(22,643
)
 
(27,368
)
Total debt
$
160,475

 
$
156,268

 
 
 
 
Stockholder's equity
547,480

 
500,543

Total capitalization
$
707,955

 
$
656,811

 
 
 
 
Total debt to capitalization
22.7
%
 
23.8
%
2017 Convertible Notes. In September 2010, we issued $172.5 million of unsecured convertible senior notes (“2017 Convertible Notes”) that matured on October 1, 2017. As of December 31, 2016, $83.3 million aggregate principal amount remained outstanding, all of which were repaid upon maturity in October 2017.
2021 Convertible Notes. In December 2016, we issued $100.0 million of unsecured convertible senior notes (“2021 Convertible Notes”) that mature on December 1, 2021, unless earlier converted by the holders pursuant to the terms of the notes. The notes bear interest at a rate of 4.0% per year, payable semiannually in arrears on June 1 and December 1 of each year.
Holders may convert the notes at their option at any time prior to the close of business on the business day immediately preceding June 1, 2021, only under the following circumstances:
during any calendar quarter (and only during such calendar quarter) if the last reported sale price of our common stock for at least 20 trading days (regardless of whether consecutive) during a period of 30 consecutive trading days ending on the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price of the notes in effect on each applicable trading day;
during the five business day period after any five consecutive trading day period in which the trading price per $1,000 principal amount of notes for each trading day was less than 98% of the last reported sale price of our common stock on such date multiplied by the conversion rate on each such trading day; or
upon the occurrence of specified corporate events, as described in the indenture governing the notes, such as a consolidation, merger, or share exchange.
On or after June 1, 2021 until the close of business on the business day immediately preceding the maturity date, holders may convert their notes at any time, regardless of whether any of the foregoing conditions have been satisfied. As of February 23, 2018, the notes were not convertible.
The notes are convertible into, at our election, cash, shares of common stock, or a combination of both, subject to satisfaction of specified conditions and during specified periods, as described above. If converted, we currently intend to pay cash for the principal amount of the notes converted. The conversion rate is initially 107.1381 shares of our common stock per $1,000 principal amount of notes (equivalent to an initial conversion price of $9.33 per share of common stock), subject to adjustment in certain circumstances. We may not redeem the notes prior to their maturity date.


27



In accordance with accounting guidance for convertible debt with a cash conversion option, we separately accounted for the debt and equity components of the notes in a manner that reflected our estimated nonconvertible debt borrowing rate. We estimated the fair value of the debt component of the notes to be $75.2 million at the issuance date, assuming a 10.5% non-convertible borrowing rate. The carrying amount of the equity component was determined to be approximately $24.8 million by deducting the fair value of the debt component from the principal amount of the notes, and was recorded as an increase to additional paid-in capital, net of the related deferred tax liability of $8.7 million. The excess of the principal amount of the debt component over its carrying amount (the “debt discount”) is being amortized as interest expense over the term of the notes using the effective interest method. See “Note 6 – Financing Arrangements” in our consolidated financial statements for further discussion of the accounting treatment for the 2021 Convertible Notes.
Revolving Credit Facility. In March 2015, we entered into a Third Amended and Restated Credit Agreement (the “Credit Agreement”) which provided for a $200.0 million revolving loan facility available for borrowings and letters of credit through March 2020. In December 2015, the Credit Agreement was amended, decreasing the revolving credit facility to $150.0 million and subsequently, we terminated the Credit Agreement in May 2016, replacing it with an asset-based revolving loan facility as discussed further below. As of the date of termination, we had no outstanding borrowings under the Credit Agreement. In the second quarter of 2016, we recognized a non-cash charge of $1.1 million in interest expense for the write-off of debt issuance costs in connection with the termination.
Asset-Based Loan Facility. In May 2016, we entered into an asset-based revolving credit agreement (the “ABL Facility”) which replaced the terminated Credit Agreement. The ABL Facility had a termination date of March 6, 2020 and provided financing of up to $90.0 million available for borrowings (inclusive of letters of credit) and subject to certain conditions, could be increased to a maximum capacity of $150.0 million. In October 2017, we entered into an Amended and Restated Credit Agreement (the “Amended ABL Facility”) which amends and restates our previous ABL Facility and increases the borrowing capacity from $90.0 million to $150.0 million, while also reducing applicable borrowing rates and fee terms. Subject to certain conditions, the Amended ABL Facility can be increased up to a maximum capacity of $225.0 million.
The Amended ABL Facility terminates on October 17, 2022; however, the Amended ABL Facility has a springing maturity date that will accelerate the maturity of the Amended ABL Facility to September 1, 2021 if, prior to such date, the 2021 Convertible Notes have not either been repurchased, redeemed, converted or we have not provided sufficient funds to repay the 2021 Convertible Notes in full on their maturity date. For this purpose, funds may be provided in cash to an escrow agent or a combination of cash to an escrow agent and the assignment of a portion of availability under the Amended ABL Facility. The Amended ABL Facility requires compliance with a minimum fixed charge coverage ratio and minimum unused availability of $25.0 million to utilize borrowings or assignment of availability under the Amended ABL Facility towards funding the repayment of the 2021 Convertible Notes.
Borrowing availability under the Amended ABL Facility is calculated based on eligible accounts receivable, inventory, and, subject to satisfaction of certain financial covenants as described below, composite mats included in the rental fleet, net of reserves and limits on such assets included in the borrowing base calculation. To the extent pledged by us, the borrowing base calculation shall also include the amount of eligible pledged cash. The lender may establish reserves, in part based on appraisals of the asset base, and other limits at its discretion which could reduce the amounts otherwise available under the Amended ABL Facility. Availability associated with eligible rental mats will also be subject to maintaining a minimum consolidated fixed charge coverage ratio and a minimum level of operating income for the Mats and Integrated Services segment. As of December 31, 2017, our total borrowing base availability under the Amended ABL Facility was $136.2 million, of which, $81.6 million was drawn, resulting in remaining availability of $54.6 million.
Under the terms of the Amended ABL Facility, we may elect to borrow at a variable interest rate plus an applicable margin based on either, (1) LIBOR subject to a floor of zero or (2) a base rate equal to the highest of: (a) the federal funds rate plus 50 basis points, (b) the prime rate of Bank of America, N.A. or (c) LIBOR, subject to a floor of zero, plus 100 basis points. The applicable margin ranges from 175 to 275 basis points for LIBOR borrowings, and 75 to 175 basis points for base rate borrowings, based on the ratio of debt to consolidated EBITDA as defined in the Amended ABL Facility. As of December 31, 2017, the applicable margin for borrowings under our Amended ABL Facility is 200 basis points with respect to LIBOR borrowings and 100 basis points with respect to base rate borrowings. The weighted average interest rate for the Amended ABL Facility is 3.9% at December 31, 2017. In addition, we are required to pay a commitment fee on the unused portion of the Amended ABL Facility ranging from 25 to 37.5 basis points, based on the ratio of debt to consolidated EBITDA, as defined in the Amended ABL Facility. The applicable commitment fee as of December 31, 2017 was 37.5 basis points.
The Amended ABL Facility is a senior secured obligation, secured by first liens on all of our U.S. tangible and intangible assets and a portion of the capital stock of our non-U.S. subsidiaries has also been pledged as collateral. The Amended ABL Facility contains customary operating covenants and certain restrictions including, among other things, the incurrence of additional debt, liens, dividends, asset sales, investments, mergers, acquisitions, affiliate transactions, stock repurchases and other restricted payments. The Amended ABL Facility also requires compliance with a fixed charge coverage ratio if availability under the Amended ABL Facility falls below $22.5 million. In addition, the Amended ABL Facility contains customary events of default, including,


28



without limitation, a failure to make payments under the facility, acceleration of more than $25.0 million of other indebtedness, certain bankruptcy events and certain change of control events.
Other Debt. Our foreign subsidiaries in Italy and India maintain local credit arrangements consisting primarily of lines of credit which are renewed on an annual basis. We utilize local financing arrangements in our foreign operations in order to provide short-term local liquidity needs. Advances under these short-term credit arrangements are typically based on a percentage of the subsidiary’s accounts receivable or firm contracts with certain customers. We had $1.0 million outstanding under these arrangements at December 31, 2017, and there were no balances outstanding at December 31, 2016.
At December 31, 2017, we had letters of credit issued and outstanding which totaled $7.2 million that are collateralized by $7.6 million in restricted cash.  Additionally, our foreign operations had $21.6 million outstanding in letters of credit and other guarantees, primarily issued under the line of credit in Italy as well as certain letters of credit that are collateralized by $1.5 million in restricted cash. At December 31, 2017 and December 31, 2016, prepaid expenses and other current assets in the accompanying balance sheet include total restricted cash related to letters of credit of $9.1 million and $7.4 million, respectively.
Off-Balance Sheet Arrangements
In conjunction with our insurance programs, we had established letters of credit in favor of certain insurance companies in the amount of $2.2 million and $3.0 million at December 31, 2017 and 2016, respectively. We also had $0.4 million in guarantee obligations in connection with facility closure bonds and other performance bonds issued by insurance companies outstanding as of December 31, 2017 and 2016.
Other than normal operating leases for office and warehouse space, rolling stock and other pieces of operating equipment, we do not have any off-balance sheet financing arrangements or special purpose entities. As such, we are not materially exposed to any financing, liquidity, market or credit risk that could arise if we had engaged in such financing arrangements.
Contractual Obligations
A summary of our outstanding contractual and other obligations and commitments at December 31, 2017 is as follows: 
(In thousands)
2018
 
2019
 
2020
 
2021
 
2022
 
Thereafter
 
Total
Current debt
$
1,518

 
$

 
$

 
$

 
$

 
$

 
$
1,518

2021 Convertible Notes

 

 

 
100,000

 

 

 
100,000

Interest on 2021 Convertible Notes
4,000

 
4,000

 
4,000

 
4,000

 

 

 
16,000

Amended ABL Facility

 

 

 

 
81,600

 

 
81,600

Operating leases
13,318

 
6,877

 
4,611

 
3,764

 
3,251

 
7,689

 
39,510

Trade accounts payable and accrued liabilities (1)
156,813

 

 

 

 

 

 
156,813

Purchase commitments, not accrued
15,005

 
1,800

 

 

 

 

 
16,805

Other long-term liabilities (2)

 

 

 

 

 
6,285

 
6,285

Performance bond obligations
444

 

 

 

 

 

 
444

Letter of credit commitments
23,889

 
1,815

 
1,494

 
213

 
1,383

 

 
28,794

Total contractual obligations
$
214,987

 
$
14,492

 
$
10,105

 
$
107,977

 
$
86,234

 
$
13,974

 
$
447,769

(1)
Excludes accrued interest on the 2021 Convertible Notes.
(2)
Table does not allocate by year expected tax payments and uncertain tax positions due to the inability to make reasonably reliable estimates of the timing of future cash settlements with the respective taxing authorities. For additional discussion on uncertain tax positions, see “Note 8 – Income Taxes” in our Consolidated Financial Statements.
We anticipate that the obligations and commitments listed above that are due in less than one year will be paid from available cash on-hand, cash generated by operations, and estimated availability under our Amended ABL Facility, subject to covenant compliance and certain restrictions as discussed further above. The specific timing of settlement for certain long-term obligations cannot be reasonably estimated.


29



Critical Accounting Policies
Critical Accounting Estimates
Our consolidated financial statements are prepared in accordance with accounting principles generally accepted within the United States (“U.S. GAAP”), which requires us to make assumptions, estimates and judgments that affect the amounts and disclosures reported. Significant estimates used in preparing our consolidated financial statements include the following: allowances for product returns, allowances for doubtful accounts, reserves for self-insured retentions under insurance programs, estimated performance and values associated with employee incentive programs, fair values used for goodwill impairment testing, undiscounted future cash flows used for impairment testing of long-lived assets, the provisional accounting for the Tax Act, and valuation allowances for deferred tax assets. See “Note 1 – Summary of Significant Accounting Policies” in our Consolidated Financial Statements for a discussion of the accounting policies governing each of these matters. Our estimates are based on historical experience and on our future expectations that are believed to be reasonable. The combination of these factors forms the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from our current estimates and those differences may be material.
We believe the critical accounting policies described below affect our more significant judgments and estimates used in preparing our consolidated financial statements.
Allowance for Doubtful Accounts
Reserves for uncollectible accounts receivable are determined on a specific identification basis when we believe that the required payment of specific amounts owed to us is not probable. The majority of our revenues are from mid-sized and international oil companies as well as government-owned or government-controlled oil companies, and we have receivables in several foreign jurisdictions. Changes in the financial condition of our customers or political changes in foreign jurisdictions could cause our customers to be unable to repay these receivables, resulting in additional allowances. For 2017, 2016, and 2015, provisions for uncollectible accounts receivable were $1.5 million, $2.4 million and $1.9 million, respectively.
Allowance for Product Returns
We maintain reserves for estimated customer returns of unused products in our Fluids Systems segment. The reserves are established based upon historical customer return levels and estimated gross profit levels attributable to product sales. Future customer return levels may differ from the historical return rate.
Impairment of Long-lived Assets
Goodwill and other indefinite-lived intangible assets are tested for impairment annually as of November 1, or more frequently, if an indication of impairment exists. When there are qualitative indicators of impairment, we use an impairment test which includes a comparison of the carrying value of net assets of our reporting units, including goodwill, with their estimated fair values, which we determine using a combination of a market multiple and discounted cash flow approach. We also compare the aggregate fair values of our reporting units with our market capitalization. If the carrying value exceeds the estimated fair value, an impairment charge is recorded in the period in which such review is performed. We identify our reporting units based on our analysis of several factors, including our operating segment structure, evaluation of the economic characteristics of our geographic regions within each of our operating segments, and the extent to which our business units share assets and other resources.
In completing our November 1, 2017 evaluation, we determined that each reporting unit’s fair value was in excess of the net carrying value and therefore, no impairment was required. At December 31, 2017, we had $43.6 million of goodwill, substantially all of which relates to the Mats and Integrated Services segment.
In 2015, we completed the annual evaluation of the carrying values of our goodwill and other indefinite-lived intangible assets as of November 1, 2015. As a result of the further decline in commodity prices and drilling activities in the fourth quarter of 2015, including the projection of lower commodity prices and drilling activities, as well as the further decline in the quoted market prices of our common stock, we determined that the carrying value of our drilling fluids reporting unit exceeded its estimated fair value such that goodwill was potentially impaired. As a result, we completed step two of the evaluation to measure the amount of goodwill impairment determining a full impairment of goodwill related to the drilling fluids reporting unit was required. As such, in the fourth quarter of 2015, we recorded a $70.7 million non-cash impairment charge to write-off the goodwill related to the drilling fluids reporting unit, which is included in impairments and other charges. In completing this annual evaluation as of November 1, 2015, we also determined that the mats and integrated services reporting unit did not have a fair value below its net carrying value and therefore, no impairment was required.
There are significant inherent uncertainties and management judgment in estimating the fair value of a reporting unit. While we believe we have made reasonable estimates and assumptions to estimate the fair value of our reporting units, it is possible that a material change could occur. If actual results are not consistent with our current estimates and assumptions, or if changes in macroeconomic conditions outside the control of management change such that it results in a significant negative impact on


30



our estimated fair values, the fair value of a reporting unit may decrease below its net carrying value, which could result in a material impairment of our goodwill.
We review property, plant and equipment, finite-lived intangible assets and certain other assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. In 2016, we recognized $6.9 million of non-cash impairments in the Asia Pacific region resulting from the continuing unfavorable industry market conditions and outlook for the region and a $0.5 million charge in the Latin America region to write-down property, plant and equipment associated with the wind-down of our operations in Uruguay. In 2015, we recognized a $2.6 million non-cash impairment charge for assets, following our decision to exit a drilling fluids facility.
We assess recoverability based on expected undiscounted future net cash flows. In estimating expected cash flows, we use a probability-weighted approach. Should the review indicate that the carrying value is not fully recoverable, the amount of impairment loss is determined by comparing the carrying value to the estimated fair value. Estimating future net cash flows requires us to make judgments regarding long-term forecasts of future revenues and costs related to the assets subject to review. These forecasts are uncertain in that they require assumptions about demand for our products and services, future market conditions and technological developments. If changes in these assumptions occur, our expectations regarding future net cash flows may change such that a material impairment could result.
Insurance
We maintain reserves for estimated future payments associated with our self-insured employee healthcare programs, as well as the self-insured retention exposures under our general liability, auto liability and workers compensation insurance policies. Our reserves are determined based on historical experience under these programs, including estimated development of known claims and estimated incurred-but-not-reported claims. Required reserves could change significantly based upon changes in insurance coverage, loss experience or inflationary impacts. As of December 31, 2017 and 2016, total insurance reserves were $3.8 million and $2.7 million, respectively.
Income Taxes
The Tax Act was enacted on December 22, 2017, resulting in broad and complex changes to U.S. income tax law. The Tax Act includes a one-time transition tax in 2017 on accumulated foreign subsidiary earnings not previously subject to U.S. income tax, reduces the U.S. corporate statutory tax rate from 35% to 21% effective January 1, 2018, generally eliminates U.S. federal income tax on dividends from foreign subsidiaries, creates new tax on certain foreign-sourced earnings, makes other changes to limit certain deductions and changes rules on how certain tax credits and net operating loss carryforwards can be utilized.
Due to the timing of the enactment and the complexity involved in applying the provisions of the Tax Act, we made reasonable estimates of the effects and recorded provisional amounts in our 2017 financial statements. As we finalize the necessary data, and interpret the Tax Act and any additional guidance issued by the U.S. Treasury Department, the IRS, or other standard-setting bodies, we may make adjustments to the provisional amounts.
The net tax benefit recognized in 2017 related to the Tax Act was $3.4 million. As we complete our analysis of the Tax Act and incorporate additional guidance that may be issued by the U.S. Treasury Department, the IRS or other standard-setting bodies, we may identify additional effects not reflected as of December 31, 2017. Those adjustments may materially impact our provision for income taxes and effective tax rate in the period in which the adjustments are made. The accounting for the tax effects of the Tax Act will be completed in 2018.
While we have not completed our analysis of the impacts of the Tax Act on our effective tax rate going forward, we anticipate the overall impacts of the Tax Act described above will reduce our effective tax rate in 2018 compared to 2017, excluding the $3.4 million net benefit included in our 2017 income tax provision. The impact of the Tax Act on our effective tax rate in 2018 will depend in large part on the relative contribution of our domestic earnings and finalization of the provisional accounting for the Tax Act.
We had total deferred tax assets of $61.9 million and $51.2 million at December 31, 2017 and 2016, respectively. A valuation allowance must be established to offset a deferred tax asset if, based on available evidence, it is more likely than not that some or all of the deferred tax asset will not be realized. In 2017, we recognized certain foreign tax credits of $5.5 million in the U.S. related to the provisional accounting for taxes on repatriation of foreign earnings, however, we also recognized a full valuation allowance related to such tax assets as it is more likely than not that these assets will not be realized. We have considered future taxable income and tax planning strategies in assessing the need for our valuation allowance. At December 31, 2017, a total valuation allowance of $30.2 million was recorded, which includes a valuation allowance on $22.2 million of net operating loss carryforwards for certain U.S. state and foreign jurisdictions, including Australia, as well as a valuation allowance of $5.5 million for certain tax credits recognized in 2017 related to the provisional accounting for the impact of the Tax Act as described above. Changes in the expected future generation of qualifying taxable income within these jurisdictions or in the realizability of other tax assets may result in an adjustment to the valuation allowance, which would be charged or credited to income in the period this


31



determination was made. In 2016, we recognized an increase in the valuation allowance for deferred tax assets, primarily related to our Australian subsidiary and certain U.S. state net operating losses, which are not expected to be realized. In addition, we decreased the valuation allowance in 2016 related to Brazil as we were able to utilize certain net operating loss carryforwards related to income in 2016 from the forgiveness of certain inter-company balances due from our Brazilian subsidiary.
We file income tax returns in the United States and several non-U.S. jurisdictions and are subject to examination in the various jurisdictions in which we file. We are no longer subject to income tax examinations for U.S. federal and substantially all state jurisdictions for years prior to 2012 and for substantially all foreign jurisdictions for years prior to 2008. We are currently under examination by the United States federal tax authorities for tax years 2014 and 2015. During the second quarter of 2017, we received a Revenue Agent Report from the IRS disallowing a deduction claimed on our 2015 tax return associated with the forgiveness of certain inter-company balances due from our Brazilian subsidiary and assessing tax due of approximately $3.9 million. We submitted our response to the IRS in the third quarter of 2017 and are proceeding with the tax appeals process. We believe our tax position is properly reported in accordance with applicable U.S. tax laws and regulations and intend to vigorously defend our position through the tax appeals process.
We are also under examination by various tax authorities in other countries, and certain foreign jurisdictions have challenged the amounts of taxes due for certain tax periods. These audits are in various stages of completion. We fully cooperate with all audits, but defend existing positions vigorously. We evaluate the potential exposure associated with various filing positions and record a liability for tax contingencies as circumstances warrant. Although we believe all tax positions are reasonable and properly reported in accordance with applicable tax laws and regulations in effect during the periods involved, the final determination of tax audits and any related litigation could be materially different than that which is reflected in historical income tax provisions and tax contingency accruals.
New accounting pronouncements
In May 2014, the Financial Accounting Standards Board (“FASB”) amended the existing accounting standards for revenue recognition. The amendments are based on the principle that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments are to be applied using a retrospective or modified retrospective approach. The new guidance is effective for us in the first quarter of 2018. In order to determine the impact of the new guidance on our financial statements, we formed an implementation work team and completed assessments of the new guidance across our revenue streams. Our process included performing reviews of representative contracts across our revenue streams and comparing historical accounting practices to the new standard.
We have completed our evaluation of the impacts of these amendments. As our performance obligations under customer contracts are primarily short-term in nature, we do not expect the new guidance to have a material impact on the amounts of revenue recognized in our consolidated financial statements. We will include incremental disclosures in our 2018 consolidated financial statements regarding our revenue recognition policies and related amounts. We have adopted the new guidance utilizing the modified retrospective method effective January 1, 2018. The cumulative-effect adjustment to retained earnings upon adoption is not material.
In October 2016, the FASB amended the guidance related to the recognition of current and deferred income taxes for intra-entity asset transfers. Under current U.S. GAAP, recognition of income taxes on intra-entity asset transfers is prohibited until the asset has been sold to an outside party. This update requires that entities recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. This update does not change U.S. GAAP for the pre-tax effects of an intra-entity asset transfer or for an intra-entity transfer of inventory. This guidance is effective for us in the first quarter of 2018 and should be applied using a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. We have adopted the new guidance utilizing the modified retrospective method effective January 1, 2018. The cumulative-effect adjustment to retained earnings upon adoption is not material.
In August 2016, the FASB issued updated guidance that clarifies how certain cash receipts and cash payments are presented and classified in the statement of cash flows. This update provides guidance on eight specific cash flow issues. This guidance is effective for us in the first quarter of 2018 and should be applied using the retrospective transition method to each period presented. Early adoption is permitted but all changes must be adopted in the same period. We do not expect the adoption of this new guidance to have a material impact on the presentation of our consolidated statements of cash flows.


32



In February 2016, the FASB issued updated guidance regarding accounting for leases. The new accounting standard provides principles for the recognition, measurement, presentation and disclosure of leases and requires lessees to recognize both assets and liabilities arising from financing and operating leases. The classification as either a financing or operating lease will determine whether lease expense is recognized based on an effective interest method basis or on a straight-line basis over the term of the lease, respectively. The new guidance is effective for us in the first quarter of 2019 with early adoption permitted. Based on our current lease portfolio, we anticipate the new guidance will require us to reflect additional assets and liabilities in our consolidated balance sheet; however, we have not yet completed an estimation of such amount and we are still evaluating the overall impact of the new guidance on our consolidated financial statements.
In June 2016, the FASB issued new guidance which requires financial assets measured at amortized cost basis to be presented at the net amount expected to be collected, including trade receivables. The new standard requires an entity to estimate its lifetime “expected credit loss” for such assets at inception which will generally result in the earlier recognition of allowances for losses. The new guidance is effective for us in the first quarter of 2020 with early adoption permitted in 2019. This guidance should be applied using a modified retrospective basis through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. We are currently evaluating the impact of the new guidance on our consolidated financial statements.
ITEM 7A. Quantitative and Qualitative Disclosures about Market Risk
We are exposed to market risk from changes in interest rates and changes in foreign currency exchange rates. A discussion of our primary market risk exposure in financial instruments is presented below.
Interest Rate Risk
At December 31, 2017, we had total principal amounts outstanding under financing arrangements of $183.1 million, including $100.0 million of borrowings under our 2021 Convertible Notes which bear interest at a fixed rate of 4% and $81.6 million of borrowings under the Amended ABL Facility. Borrowings under our Amended ABL Facility are subject to a variable interest rate as determined by the credit agreement. The weighted average interest rate at December 31, 2017 for the Amended ABL Facility is 3.9%. Based upon the balance of variable rate debt at December 31, 2017, a 100 basis-point increase in short-term interest rates would have increased pre-tax interest expense by $0.8 million.
Foreign Currency
Our principal foreign operations are conducted in certain areas of EMEA, Latin America, Asia Pacific, and Canada. We have foreign currency exchange risks associated with these operations, which are conducted principally in the foreign currency of the jurisdictions in which we operate including European euros, Algerian dinar, Romanian new leu, Canadian dollars, Australian dollars, British pounds and Brazilian reais. Historically, we have not used off-balance sheet financial hedging instruments to manage foreign currency risks when we enter into a transaction denominated in a currency other than our local currencies.



33



ITEM 8. Financial Statements and Supplementary Data

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
To the Board of Directors and Stockholders of
Newpark Resources, Inc.
The Woodlands, Texas

Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Newpark Resources, Inc. and subsidiaries (the "Company") as of December 31, 2017 and 2016, the related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows, for each of the three years in the period ended December 31, 2017, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2017, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 23, 2018, expressed an unqualified opinion on the Company's internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ DELOITTE & TOUCHE LLP
 
Houston, Texas
February 23, 2018 

We have served as the Company’s auditor since 2008.



34



Newpark Resources, Inc.
Consolidated Balance Sheets
December 31,
(In thousands, except share data)
2017
 
2016
ASSETS
 
 
 
Cash and cash equivalents
$
56,352

 
$
87,878

Receivables, net
265,866

 
214,307

Inventories
165,336

 
143,612

Prepaid expenses and other current assets
17,483

 
17,143

Total current assets
505,037

 
462,940

 
 
 
 
Property, plant and equipment, net
315,320

 
303,654

Goodwill
43,620

 
19,995

Other intangible assets, net
30,004

 
6,067

Deferred tax assets
4,753

 
1,747

Other assets
3,982

 
3,780

Total assets
$
902,716

 
$
798,183

 
 
 
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
Current debt
$
1,518

 
$
83,368

Accounts payable
88,648

 
65,281

Accrued liabilities
68,248

 
31,152

Total current liabilities
158,414

 
179,801

 
 
 
 
Long-term debt, less current portion
158,957

 
72,900

Deferred tax liabilities
31,580

 
38,743

Other noncurrent liabilities
6,285

 
6,196

Total liabilities
355,236

 
297,640

 
 
 
 
Commitments and contingencies (Note 15)


 


 
 
 
 
Common stock, $0.01 par value, 200,000,000 shares authorized and 104,571,839 and 99,843,094 shares issued, respectively
1,046

 
998

Paid-in capital
603,849

 
558,966

Accumulated other comprehensive loss
(53,219
)
 
(63,208
)
Retained earnings
123,375

 
129,873

Treasury stock, at cost; 15,366,504 and 15,162,050 shares, respectively
(127,571
)
 
(126,086
)
Total stockholders’ equity
547,480

 
500,543

Total liabilities and stockholders' equity
$
902,716

 
$
798,183

 
 
See Accompanying Notes to Consolidated Financial Statements


35



Newpark Resources, Inc.
Consolidated Statements of Operations
Years Ended December 31,  
(In thousands, except per share data)
2017
 
2016
 
2015
Revenues
 
 
 
 
 
    Product sales
$
628,401

 
$
390,306

 
$
569,290

    Rental and services
119,362

 
81,190

 
107,575

Total Revenues
747,763

 
471,496

 
676,865

Cost of revenues
 
 
 
 
 
    Cost of product sales
539,243

 
386,085

 
533,040

    Cost of rental and services
68,656

 
51,751

 
65,973

Total Cost of revenues
607,899

 
437,836

 
599,013

Selling, general and administrative expenses
108,838

 
88,473

 
101,032

Other operating income, net
(410
)
 
(4,345
)
 
(2,426
)
Impairments and other charges

 
6,745

 
78,345

Operating income (loss)
31,436

 
(57,213
)
 
(99,099
)
 
 
 
 
 
 
Foreign currency exchange (gain) loss
2,051

 
(710
)
 
4,016

Interest expense, net
13,273

 
9,866

 
9,111

Gain on extinguishment of debt

 
(1,615
)
 

Income (loss) from continuing operations before income taxes
16,112

 
(64,754
)
 
(112,226
)
 
 
 
 
 
 
Provision (benefit) for income taxes
4,893

 
(24,042
)
 
(21,398
)
Income (loss) from continuing operations
11,219

 
(40,712
)
 
(90,828
)
 
 
 
 
 
 
Loss from disposal of discontinued operations, net of tax
(17,367
)
 

 

Net loss
$
(6,148
)
 
$
(40,712
)
 
$
(90,828
)
 
 
 
 
 
 
 
 
 
 
 
 
Income (loss) per common share - basic:
 
 
 
 
 
Income (loss) from continuing operations
$
0.13

 
$
(0.49
)
 
$
(1.10
)
Loss from discontinued operations
(0.20
)
 

 

Net loss
$
(0.07
)
 
$
(0.49
)
 
$
(1.10
)
 
 
 
 
 
 
Income (loss) per common share - diluted:
 
 
 
 
 
Income (loss) from continuing operations
$
0.13

 
$
(0.49
)
 
$
(1.10
)
Loss from discontinued operations
(0.20
)
 

 

Net loss
$
(0.07
)
 
$
(0.49
)
 
$
(1.10
)
  
See Accompanying Notes to Consolidated Financial Statements


36



Newpark Resources, Inc.
Consolidated Statements of Comprehensive Income (Loss)
Years Ended December 31, 
(In thousands)
2017
 
2016
 
2015
 
 
 
 
 
 
Net loss
$
(6,148
)
 
$
(40,712
)
 
$
(90,828
)
 
 
 
 
 
 
Foreign currency translation adjustments
9,989

 
(4,932
)
 
(26,284
)
 
 
 
 
 
 
Comprehensive income (loss)
$
3,841

 
$
(45,644
)
 
$
(117,112
)
 
See Accompanying Notes to Consolidated Financial Statements


37



Newpark Resources, Inc.
Consolidated Statements of Stockholders’ Equity 
(In thousands)
Common
Stock
 
Paid-In
Capital
 
Accumulated
Other
Comprehensive
Loss
 
Retained
Earnings
 
Treasury
Stock
 
Total
Balance at January 1, 2015
$
992

 
$
521,228

 
$
(31,992
)
 
$
262,616

 
$
(127,386
)
 
$
625,458

Net loss

 

 

 
(90,828
)
 

 
(90,828
)
Employee stock options, restricted stock and employee stock purchase plan
2

 
(402
)
 

 

 
(607
)
 
(1,007
)
Stock-based compensation expense

 
14,202