UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

Form 10-K

 

 

Commission File Number 1-2960

Newpark Resources, Inc.

(Exact name of registrant as specified in its charter)

 

 

Registrant’s telephone number, including area code

(281) 362-6800

 

Securities registered pursuant to Section 12(b) of the Act:

 

 

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 o     No þ

 

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 o     No þ

 

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 þ     No o

 

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 o  No o

 

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulations 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 þ

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

 

(Do not check if a smaller reporting company)

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act.  Yes o  No þ

 

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, 2009, was $250.4 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, 2010, a total of 88,983,642 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 2010 Annual Meeting of Stockholders.

 

 

NEWPARK RESOURCES, INC.

 

INDEX TO ANNUAL REPORT ON FORM 10-K

FOR THE YEAR ENDED DECEMBER 31, 2009

 

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

 

The 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. The words “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 and contingencies, including the risks identified below, 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 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.

 

 

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 diversified oil and gas industry supplier with three reportable segments: Fluids Systems and Engineering, Mats and Integrated Services, and Environmental Services. We provide our products and services primarily to the oil and gas exploration and production (“E&P”) industry in the United States Gulf Coast, West Texas, East Texas, Oklahoma, North Louisiana, Rocky Mountains and Northeast regions, as well as Canada, Brazil, United Kingdom (“U.K.”), Mexico and certain areas of Europe and North Africa. Further, we have established a presence outside the E&P sector, particularly in Mats and Integrated Services, where we are marketing to utilities, municipalities, and government sectors.

 

Our principal executive offices are located at 2700 Research Forest Drive, Suite 100, The Woodlands, Texas 77381. Our telephone number is (281) 362-6800. You can find more information about us at our Internet 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 on or through our Internet 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 Internet website. We make our website content available for information 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 “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 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 services is related to the level, type, depth and complexity of oil and gas drilling. The most widely accepted measure of activity for our North American operations is the Baker Hughes Rotary Rig Count. After several consecutive years of elevated North American drilling activity through 2008, the weak economic environment, the instability in the credit markets and declines in oil and natural gas commodity prices significantly impacted North American activity, reducing the 2009 average North American rig count to 1,310, compared to 2,261 in 2008 and 2,111 in 2007. This decline in E&P activity negatively impacted our 2009 operating results as compared to the results achieved during 2008 and 2007. After declining in the first half of 2009 to a low point of 974 rigs in May 2009, North American drilling activity began to stabilize and improve modestly during the second half of the year. The North American rig count was 1,915 during the week of February 19, 2010, which included 1,345 in U.S. rigs and 570 Canadian rigs. Outside of North America, drilling activity has remained more stable, as drilling activity in many countries is based upon longer term economic projections and multiple year drilling programs, which tend to minimize the impact of short term changes of commodity prices on overall drilling activity.

 

Our historical customer base has primarily consisted of independent E&P companies. In recent years, we have expanded beyond this historical base by adding major integrated and national E&P customers.

 

In our core North American markets, we have seen significant growth in drilling activity in deep shales and other hard rock formations with limited permeability in East Texas, North Louisiana, Rocky Mountains, and

Northeast regions in recent years. These formations are being exploited with advanced fracture stimulation technology, which facilitates production of natural gas from these formations and drives higher drilling activities. While North American drilling expands into these new geologic formations, the shallower reserves available in the historic oil and gas-producing basins are approaching full development, and the longer-term economic potential of the remaining prospects appears to be declining, including basins along the U.S. Gulf Coast. Many operators have begun to shift the focus of their drilling programs towards unconventional geologic structures, which carry higher costs and inherently higher risks of both economic and physical failure for the operators.

 

Internationally, we have seen continued growth in drilling activity, which is more heavily focused on oil, rather than natural gas exploration. The elevation of oil prices in recent years and the expectation of continued increases in world-wide demand have supported continued expansion of the international E&P activity, benefiting our operations in certain areas of Europe, North Africa and Brazil.

 

Reportable Segments

 

Fluids Systems and Engineering

 

Our Fluids Systems and Engineering business offers unique solutions, including highly technical drilling projects involving complex subsurface conditions such as horizontal, directional, geologically deep or deep water drilling. These projects require increased monitoring and critical engineering support of the fluids system during the drilling process. We provide drilling fluids products and technical services to the North American, European, North African, and Brazilian markets. We also provide completion fluids services and equipment rental to customers in Oklahoma and Texas.

 

We have industrial mineral grinding operations for barite, a critical raw material in drilling fluids products, which serve to support our activity in the drilling fluids market. We grind barite and other industrial minerals at facilities in Houston and Corpus Christi, Texas, New Iberia, Louisiana and Dyersburg, Tennessee. We also have a contract grinding agreement under which a third party mill in Brownsville, Texas grinds raw barite supplied by us. 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, from our main plant in Houston, Texas and from the plant in Dyersburg, Tennessee.

 

Raw Materials — We believe that our sources of supply for materials and equipment used in our drilling fluids business are adequate for our needs. Our specialty milling operation is our primary supplier of barite used in our 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 any raw materials.

 

Technology — We seek patents and licenses on new developments whenever we believe it creates a competitive advantage in the marketplace. We own the patent rights to a family of high-performance water-based products, which we market as the DeepDrill^® and FlexDrill^tm systems. These systems include up to eight proprietary performance-enhancing components, each formulated for environmental protection. DeepDrill^® and FlexDrill^tm systems can provide improved penetration rates, superior lubricity, torque and drag reduction, shale inhibition, solids management, minimized hole enlargement and enhanced ability to log results and use measurement tools. This technology also led to the development of our NewPhase^tm product, originally a component of our water-based product line, which we now use to enhance high performance invert emulsion fluids systems tailored to the drilling problems created by reactive shales.

 

Proprietary technology and systems is an important aspect of our business strategy. 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 (primarily, M-I SWACO, Halliburton and Baker Hughes), which compete vigorously on fluids performance and/or price. 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 price, reputation, technical proficiency, reliability, quality, breadth of services offered and experience. We believe that we compete effectively on the basis of these factors. We also believe that our competitive position is enhanced by our proprietary products and services.

 

Customers — Our customers are principally major and independent oil and gas E&P companies operating in the markets that we serve. During 2009, approximately 59% of segment revenues were derived from the 20 largest segment customers, and 68% of segment revenues were generated domestically. Typically, we perform services either under short-term standard contracts or under longer term service agreements. 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 Item 8. Financial Statements and Supplementary Data for additional information on financial and geographic data.

 

Mats and Integrated Services

 

We provide mat rentals, location construction and related well site services to E&P customers in the onshore U.S. Gulf Coast, Western Colorado, and Northeast U.S. regions, and mat rentals to the utility industry in the U.K. which ensure all-weather access to sites with unstable soil conditions common to these areas. We also install access roads and temporary work sites for pipeline, electrical utility and highway construction projects where soil protection is required by environmental regulations or to assure productivity in unstable soil conditions.

 

We manufacture our DuraBase^tm composite mat system for sales as well as for use in our domestic and international rental operations. Our marketing efforts for this product remain focused in six principal oil and gas industry markets: Canada, Alaska and the Arctic, the Middle East, South America, Mexico, and Pacific Rim, as well as markets outside the E&P sector in the U.S. and Europe. We believe these mats have worldwide applications outside our traditional oilfield market, primarily in infrastructure construction, maintenance and upgrades of electric utility transmission lines, military logistics and as temporary roads for movement of oversized or unusually heavy loads.

 

Raw Materials — We believe that our sources of supply for materials and equipment 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 raw material component in the manufacturing of our composite mat products.

 

Technology — We have obtained patents related to several of the components utilized in our DuraBase^tm mat system as well as our composite mat manufacturing process. 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, which is generally using wooden mat products. 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 also have competitive significance in the markets we serve.

 

Competition — Our market is fragmented and competitive, with nine to ten competitors providing various forms of wooden mat products and services. We provide DuraBase^tm composite mat systems to many customers, both domestic and international. The mat sales component of our business is not as fragmented as the oilfield services segment with only a few competitors providing various alternatives to our DuraBase^tm mat products. 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 price, reputation, technical proficiency, reliability, quality and breadth of services offered. We believe that we compete effectively on the basis of these factors. We also believe that our competitive position is enhanced by our proprietary products, services and experience.

 

Customers — Our customers are principally major and independent oil and gas E&P companies operating in the markets that we serve. During 2009, approximately 71% of our segment revenues were derived from the 20 largest segment customers, of which, the largest customer represented 19% of our segment revenues. Typically, we perform services either under short-term standard contracts or under longer term 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 Item 8. Financial Statements and Supplementary Data for additional information on financial and geographic data.

Environmental Services

 

We process and dispose of waste generated by our oil and gas customers that is treated as exempt under the Resource Conservation and Recovery Act (“RCRA”). Primary revenue sources include onshore drilling waste management as well as reclamation services. Additionally, we provide disposal services in the West Texas market. We operate six receiving and transfer facilities located along the U.S. Gulf Coast. E&P waste is collected at the transfer facilities from drilling and production operations located offshore, onshore and within inland waters. Waste is accumulated at the transfer facilities and moved by barge through the Gulf Intracoastal Waterway to our processing and transfer facility at Port Arthur, Texas, and, if not recycled, is trucked to injection disposal facilities. We also recycle a portion of the material received and deliver it to municipal landfill facilities for application as a commercial product. Any remaining material is injected, after further processing, into environmentally secure geologic formations, effecting a permanent isolation of the material from the environment.

 

Under permits from Texas state regulatory agencies, we currently operate a 50-acre injection well facility in Jefferson County, Texas and a facility at a 400-acre site near Fannett, Texas. The Fannett site was placed in service in September 1995 and is our primary facility for disposing of E&P waste. Utilizing this same technology, we also receive and dispose of non-hazardous industrial waste principally from generators in the U.S. Gulf Coast market, including refiners, manufacturers, service companies and industrial municipalities that produce waste that is not regulated under RCRA. These non-hazardous waste streams are injected into a separate well utilizing the same low-pressure injection technology.

 

We are licensed to process E&P waste contaminated with naturally occurring radioactive material (“NORM”). We currently operate under a license that authorizes us to inject NORM directly into dedicated disposal wells at our Jefferson County facility. For more information on NORM, please refer to the discussion under Environmental Regulation below.

 

Technology — We use proprietary technology to dispose of E&P waste by low-pressure injection into unique geologic structures deep underground. In December 1996, we were issued patents covering our waste processing and injection operations. Our injection technology is distinguished from conventional methods in that it utilizes very low pressure to move the waste into the injection zone.

 

Competition — Our competition in this business consists of one large independent, US Liquids of Louisiana, and several smaller companies which utilize a variety of disposal methods and generally serve specific geographic markets. In addition, we face competition with our major customers, who continually re-evaluate their decision to use internal disposal methods or a third-party disposal company, such as ours. We believe that the principal competitive factors in our businesses include price, reputation and reliability. We believe that we compete effectively on the basis of these factors.

 

Customers — Our customers are principally major and independent oil and gas E&P companies operating in the markets that we serve. During 2009, approximately 64% of our segment revenues were derived from the 20 largest segment customers, of which, the largest customer represented 20% of our segment revenues. All of our segment revenues are generated domestically. Typically, we perform services either under short-term standard contracts or under longer term 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 Item 8. Financial Statements and Supplementary Data for additional information on financial and geographic data.

 

Employees

 

At January 31, 2010, we employed 1,664 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 environmental services business processes and disposes of several types of non-hazardous environmental waste. The non-

hazardous environmental wastes handled by our environmental services business are generally described as follows:

 

E&P Waste.  E&P waste typically contains levels of oil and grease, salts, dissolved solids and heavy metals within limits defined by state regulations. E&P waste also includes soils that have become contaminated by these materials.

 

NORM.  NORM is present throughout the earth’s crust at very low levels. Radium can co-precipitate with scale out of the production stream as it is drawn to the surface and encounters a pressure or temperature change in the well tubing or production equipment. This scale contains radioactive elements that can become concentrated on tank bottoms or at water discharge points at production facilities.

 

Non-hazardous Industrial Waste.  This category of waste is generated by industries not associated with the exploration or production of oil and gas. This includes refineries and petrochemical plants.

 

Our business is affected both directly and indirectly 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, state and provincial pollution control, health and safety programs that are administered and enforced by regulatory agencies.

 

Additionally, our business exposes us to environmental risks. For example, our environmental services business routinely handles, stores and disposes of non-hazardous regulated materials and waste. We could be held liable for improper cleanup and disposal based upon statute, negligence, strict liability, contract or otherwise. As is common in the oil and gas industry, we often are required contractually to indemnify our customers or other third-parties against certain risks related to the services we perform, including damages stemming from environmental contamination.

 

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 regulated waste, ongoing employee training and monitoring and maintaining insurance coverage.

 

We also employ a corporate-wide web-based environmental management system (“EMS”), which is ISO 14001:2004 compliant. The EMS is composed of modules designed to capture information related to the planning, decision-making, and general operations of environmental regulatory activities within our operations. We also use the EMS to capture the information generated by regularly scheduled independent audits that are done to validate the findings of our internal monitoring and auditing procedures.

 

 

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 our Customer Concentration and Cyclical Nature of the E&P Industry

 

We derive a significant portion of our revenues from companies in the E&P industry, and our customer base is highly concentrated in major and independent oil and gas E&P companies operating in the markets that we serve. In 2009, approximately 51% of our consolidated revenues were derived from our 20 largest customers. The E&P industry is historically cyclical, with levels of activity generally affected by the following factors:

 

 

Because of the cyclical nature of our industry and our customer concentration, our quarterly and annual operating results have fluctuated significantly in recent years and may continue to fluctuate in future periods. A prolonged decline in industry drilling rig activity or the loss of any of our large customers could materially affect the demand for our services. Because our business has high fixed costs, including significant facility and personnel expenses, downtime or low productivity due to reduced demand can have significant adverse impact on our profitability.

 

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 power shortages, political priorities and government imposed export fees in China as well as natural disasters such as the 2008 earthquake in Sichuan Province, China. The availability and cost of barite ore is further impacted by inland transportation and ocean freight. Due to recent wide swings in world wide demand for raw materials, the cost of transportation has fluctuated significantly. Significant fluctuations in either the cost of raw materials, including barite ore or their transportation costs, may impact our profitability.

 

Our business is also highly dependent on our ability to attract and retain highly-skilled engineers, technical sales and service personnel. The market for these employees is very 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 and Engineering business, where there are several companies larger than us that may have access to more capital, at lower costs, and greater geographic coverage. Numerous smaller companies also compete against us in the drilling fluids market.

 

Our competition in the Mats and Integrated Services business is very fragmented and competitive, with nine to ten competitors providing various forms of wooden mat products and services. No domestic competitors provide a product similar to our DuraBase^tm composite mat system at the present time.

 

Competition in the Environmental Services market could increase as the industry continues to develop, which could put downward pressure on our margins. We also face competition from efforts by oil and gas producing customers to improve their own methods of disposal and waste elimination.

 

Risks Related to the Cost and Continued Availability of Borrowed Funds

 

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, such as those experienced over the past two years, 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. Adverse events in the financial markets may also negatively impact our customers, as many of them finance their drilling and production operations through borrowed funds. The reduced availability and increased cost of borrowing could cause our customers to reduce their spending on drilling programs, thereby reducing demand and potentially pricing for our products and services.

 

Our ability to meet our debt service requirements and the continued availability of funds under our existing credit agreement is dependent upon our ability to continue generating operating income and remain in compliance with the covenants in our credit agreements. This, in turn, is subject to the volatile nature of the E&P industry, and to competitive, economic, financial and other factors that are beyond our control. We were not in compliance with our

covenant requirements as of June 30, 2009 and as a result, entered into the First Amendment to our Amended and Restated Credit Agreement (“First Amendment”) to obtain temporary relief from these requirements. Under the First Amendment, the covenants return to their original levels as of June 30, 2010. If we are unable to maintain compliance with our modified covenant requirements, our borrowing costs may increase, or our lenders may declare all amounts outstanding under our credit agreements immediately due and payable. The lenders also could terminate all commitments under the facility and enforce their rights to security interests in substantially all of our U.S. assets.

 

At December 31, 2009, $93.0 million of debt outstanding bears interest at variable rates. During 2009, borrowing rate indexes in the U.S. were at historic lows, which served to benefit our interest expense during the period. Any increases in borrowing rate indexes from current levels will increase our interest costs on our existing variable-rate debt or indebtedness incurred in the future.

 

Risks Related to International Operations

 

We have significant operations outside of the United Stated, including certain areas of Europe, North Africa, Brazil, Canada and Mexico. In 2009, these international operations generated approximately one-third of our consolidated revenues. 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:

 

 

Risks Related to Legal and Regulatory Matters, Including Environmental Regulations

 

We are responsible for complying with numerous federal, state and local 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 and regulations may result in 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.

 

We believe that the demand for our services in the Environmental Services business is directly related to regulation of E&P waste. In particular, E&P waste is currently exempt from the principal federal statute governing the handling of hazardous waste. In recent years, proposals have been made to rescind this exemption. If the exemption covering this type of E&P waste is repealed or modified, or if the regulations interpreting the rules

regarding the treatment or disposal of E&P waste or NORM waste were changed, it could have a material adverse effect on this business.

 

The markets for our products and services are dependent on the continued exploration for and production of fossil fuels (predominantly oil and natural gas). In December 2009, the U.S. Environmental Protection Agency (“EPA”) published findings that the emissions of carbon dioxide, methane and other greenhouse gases are contributing to the warming of the Earth’s atmosphere and other climatic changes, presenting an endangerment to human health and the environment. Further, the EPA has recently proposed regulations that could potentially limit greenhouse gas emissions and impose reporting obligations on large greenhouse emission sources. To the extent that laws and regulations enacted as part of climate change legislation increase the costs of drilling for or producing such fossil fuels, or reduce the demand for fossil fuels, such legislation could have a material adverse impact on our profitability.

 

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:

 

 

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 Potential Impairments of Long-lived Intangible Assets

 

As of December 31, 2009, our consolidated balance sheet includes $62.3 million in goodwill and $16.0 million of intangible assets, net. Goodwill and indefinite-lived intangible assets are tested for impairment annually, or more frequently as the circumstances require, using a combination of market multiple and discounted cash flow approaches. In completing this annual evaluation during the fourth quarter of 2009, we determined that no reporting unit has a fair value below its net carrying value, and therefore, no impairment is required. However, while our analysis indicated that the fair value of our drilling fluids business remains significantly in excess of carrying value, our mats and integrated services reporting unit exceeded net carrying value by less than 10%. If the financial performance or future projections for our Mats and Integrated Services segment or our other 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. As of December 31, 2009, the consolidated balance sheet includes $14.9 million of goodwill for the Mats and Integrated Services segment.

 

Risks Related to Technological Developments 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.

 

We hold U.S. and foreign patents for certain of our drilling fluids components and our mat systems. In our Environmental Services business, we also hold U.S. patents on certain aspects of our system to process and dispose of E&P waste, including E&P waste that is contaminated with NORM. However, these patents are not a guarantee

that we will have a meaningful advantage over our competitors, and there is a risk that others may develop systems that are substantially equivalent to those covered by our patents. If that were to happen, we would face increased competition from both a service and a pricing standpoint. In addition, costly and time-consuming litigation could be necessary to enforce and determine the scope of our patents and proprietary rights. It is possible that future innovation could change the way companies drill for oil and gas, reduce the amount of waste that is generated from drilling activities or create new methods of disposal or new types of drilling fluids. This could reduce the competitive advantages we may derive from our patents and other proprietary technology.

 

Risks Related to Severe Weather, Particularly in the U.S. Gulf Coast

 

Approximately 31% of our consolidated revenue in 2009 was generated 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, such as those which occurred in 2005 and 2008. These 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.

 

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.

 

 

None

 

 

We lease office space to support our operating segments as well as our corporate offices. This leased space is located in Lafayette, Louisiana, The Woodlands, Houston and Port Arthur, Texas, Calgary, Alberta, and Rome, Italy. We also own office space in Oklahoma City, Oklahoma. All owned properties serve as collateral to our Amended and Restated Credit Agreement (“Credit Amendment”).

 

Fluids Systems & Engineering.  We own eight warehouse facilities and have 19 leased warehouses and five contract warehouses to support our customers and operations in the U.S. We own two warehouse facilities in Western Canada and lease a warehouse with dock space in Novia Scotia to support our Canadian operations. Additionally, we lease 15 warehouses and own one warehouse in the Mediterranean region and lease six warehouses in Brazil to support our international operations.

 

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 13.7 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 & Integrated Services.  We own approximately 44,000 square feet of office and warehouse space on nine acres of land in Carencro, Louisiana, which houses manufacturing facilities for this segment. We also lease nine sites, throughout Texas, Louisiana and Colorado, which serve as bases for our well site service activities. Additionally, we own three facilities which are located in Louisiana, Colorado and Wyoming to support field operations.

 

Environmental Services.  We lease a 4.6 acre E&P waste processing and transfer facility in Port Arthur, Texas. We own three injection disposal sites located in Jefferson County, Texas with two of those properties immediately adjacent to each other, one 47 acre site for NORM disposal with five caprock injection wells and a 140 acre site for our industrial injection operation with two caprock injection wells. The remaining site consists of our nonhazardous oilfield waste processing and injection operations. This site is on 400+ acres and has 11 caprock injection wells and a disposal cavern. In addition, we own three facilities in West Texas on a total of approximately 100 acres of land. Additionally, we have six leased receiving facilities to support our injection and waste disposal services.

 

On March 12, 2007, we were advised that the SEC opened a formal investigation into the matters disclosed in Amendment No. 2 to our Annual Report on Form 10-K/A filed on October 10, 2006. We have and will continue to cooperate fully with the SEC’s investigation. On July 16, 2009, the SEC filed a civil lawsuit against our former Chief Financial Officer, the former Chief Financial Officer of our Soloco business unit and one former vendor in connection with the transactions that were described in the Amended Form 10-K/A. Subsequently, the SEC announced that it reached a settlement of its claims against the former vendor. We have not been named as a defendant in this lawsuit.

 

In the ordinary course of conducting our business, we become involved in litigation and other claims from private party actions, as well as judicial and administrative proceedings involving governmental authorities at the federal, state and local levels. In the opinion of management, any liability in these matters should not have a material effect on our consolidated financial statements.

 

 

 

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:

 

 

As of February 1, 2010, we had 1,817 stockholders of record as determined by our transfer agent.

 

During 2008, our Board of Directors approved a plan authorizing our repurchase of up to $25 million of outstanding common stock, of which $15.1 million of repurchases were made during 2008. No additional repurchases were made under this plan during 2009 and we do not intend to make any further repurchases under this plan in the foreseeable future. Additionally, during 2009 and 2008 we repurchased $0.3 million and $0.2 million of shares surrendered in lieu of taxes under vesting of restricted stock awards, respectively. Our Board of Directors currently intends to retain earnings for use in our business. We have not paid any dividends during the two recent fiscal years and any subsequent interim period, and we do not intend to pay any cash dividends in the foreseeable future. In addition, our credit facilities contain covenants which limit the payment of dividends on our common stock.

 

The following table details our repurchases of shares of our common stock for the three months ended December 31, 2009:

 

 

 

Performance Graph

 

The following graph reflects a comparison of the cumulative total stockholder return of our common stock from January 1, 2005 through December 31, 2009, with the New York Stock Exchange Market Value Index, a broad equity market index, and the Hemscott Oil & Gas Equipment/Services Index, an industry group index. The graph assumes the investment of $100 on January 1, 2005 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 Exchange Act of 1933, or the Securities Act of 1934, except to the extent we specifically incorporate it by reference.

 

 

The selected consolidated historical financial data presented below for the five years ended December 31, 2009 is derived from our consolidated financial statements and is not necessarily indicative of results to be expected in the future.

 

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.

 

 

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.

 

We have reclassified certain items previously reported to conform with the presentation for the year ended December 31, 2009. Effective January 1, 2009, we modified the presentation of expenses on the Consolidated Statement of Operations, expanding the presentation to include separate line items for selling, general and administrative expenses, and other (income) expense, net. Prior to the modification, the Consolidated Statements of Operations included a line item for general and administrative expenses, which reflected only the expenses associated with our corporate office, while all operating segment expenses were reported within cost of revenues. Following this reclassification, selling, general and administrative expenses includes all expenses of this nature from our operating segments as well as our corporate office. As a result of this reclassification, $54.8 million and $50.1 million of expenses previously reported in cost of revenues for the years ended December 31, 2008 and 2007, respectively, are now reflected in selling, general and administrative expenses.

 

Overview

 

We are a diversified oil and gas industry supplier, and have three reportable segments: Fluids Systems and Engineering, Mats and Integrated Services, and Environmental Services. We provide these products and services principally to the E&P industry domestically in the U.S. Gulf Coast, West Texas, Oklahoma, East Texas, North Louisiana, Rocky Mountains, and Northeast regions, as well as internationally in certain areas of Europe, North Africa, Brazil, Canada and Mexico. Further, we are expanding our presence outside the E&P sector through our Mats and Integrated Services segment, where we are marketing to utilities, municipalities and government sectors, both domestically and internationally.

 

Our operating results depend, to a large extent, on oil and gas drilling activity levels in the markets we serve, as well as the depth of drilling, which governs the revenue potential of each well. The drilling activity in turn, depends on oil and gas commodity pricing, inventory levels and product demand. The weak economic environment, the instability in the credit markets and declines in oil and natural gas commodity prices significantly impacted North American drilling activity in 2009, as compared to previous years. After significantly declining in the first half of 2009, North American drilling activity began to stabilize and improve modestly during the second half of 2009. This decline in E&P drilling activity negatively impacted our 2009 operating results as compared to the results achieved during 2008 and 2007.

 

Rig count data is the most widely accepted indicator of drilling activity. Key average North American rig count data for the last three years ended December 31 is as follows:

 

 

 

Source: Baker Hughes Incorporated

 

In response to the significant declines in activity and the increased price competition in 2009, we executed cost reduction programs including workforce reductions, reduced discretionary spending, salary reductions for substantially all North American employees including executive officers, the temporary elimination of 401(k) matching for U.S. employees, as well as reductions in capital expenditures in North America. As part of this cost reduction program, we reduced our North American workforce by 548 employees, or 38%, during 2009, in addition to eliminating substantially all contract employee positions. As a result of these workforce reductions, operating results for 2009 include $4.5 million of charges associated with employee termination and related exit costs, substantially all of which was incurred during the first half of the year.

Hurricane Impact

 

During 2008, our Environmental Services and Fluids Systems and Engineering operations along the U.S. Gulf Coast were impacted by Hurricanes Gustav and Ike, which interrupted business activities. During 2009, we recorded $2.3 million of other income within our Environmental Services segment, associated with the settlement and collection of business interruption insurance claims from the 2008 storms.

 

Year Ended December 31, 2009 Compared to Year Ended December 31, 2008

 

Consolidated Results of Operations

 

Summarized results of operations for the year ended December 31, 2009 compared to the year ended December 31, 2008 are as follows:

 

 

Revenues

 

Revenues were $490.3 million in 2009, reflecting a 43% decline from the $858.4 million reported in 2008. This decline in revenues is primarily driven by the 42% decline in North American drilling activity, as previously noted. North American revenues accounted for 71% and 84% of total revenues for 2009 and 2008, respectively. Additional information regarding these declines is provided within the discussions of the operating segment results below.

 

Cost of Revenues

 

Cost of revenues were $447.6 million in 2009, reflecting a 36% decline from the $703.4 million reported in 2008. This decline is primarily driven by the 42% decline in North American drilling activity, as previously noted above. Additional information regarding these declines is provided within the discussions of operating segment results below.

 

Selling, General and Administrative Expenses

 

Selling, general and administrative expenses declined $20.2 million to $61.2 million in 2009 from $81.4 million in 2008. The decrease includes $6.7 million in fluids systems and engineering, $3.3 million in mat and integrated services, $0.7 million in environmental services, and $9.5 million in the corporate office. The decline in corporate office spending includes $4.3 million of legal and selling costs associated with the abandoned sale of the environmental services business along with $2.2 million of expenses associated with the arbitration and settlement of a lawsuit with our former Chief Executive Officer, both which were recorded in 2008. The remainder of the

decrease in all segments is attributable to the impact of cost reduction programs implemented during 2009, as well as lower performance-based employee incentive costs in 2009.

 

Other (Income) Expense, Net

 

Other income, net was $3.2 million in 2009 compared to $2.0 million of other expense, net in 2008. The 2009 results include $2.3 million of income associated with the settlement of business interruption insurance claims within our environmental services business, resulting from hurricanes and storms in 2008. The 2008 results include a $2.6 million charge to write-down certain disposal assets within the Environmental Services segment, following the abandoned sale of the business in the fourth quarter of 2008.

 

Interest Expense

 

Interest expense totaled $9.3 million in 2009 compared to $10.9 million in 2008. The decrease in interest expense is attributable to lower debt levels, as total outstanding debt was $123.0 million and $188.2 million at December 31, 2009 and 2008, respectively. Our weighted average borrowing rate under our credit facilities increased to 5.72% at December 31, 2009 compared to a weighted average borrowing rate of 3.46% at December 31, 2008. In July 2009, we entered into the First Amendment which included adjustments in interest rates under our credit facility. See Liquidity and Capital Resources below for additional information.

 

Provision for Income Taxes

 

The provision for income taxes for 2009 was a $2.2 million benefit, reflecting an income tax rate of 9.7%, compared to $20.0 million of expense for 2008, reflecting an income tax rate of 33.8%. The low effective tax rate in 2009 is primarily due to current year losses generated in certain foreign countries, for which recording a tax benefit is not permitted, as well as the recording of valuation allowances against a previously recognized net operating loss carryforward tax asset in Canada, which serve to reduce the effective tax benefit rate in the period.

 

Operating Segment Results

 

Summarized financial information for our reportable segments is shown in the following table (net of inter-segment transfers):

 

Fluids Systems and Engineering

 

Revenues

 

Total revenues for this segment consisted of the following:

 

 

North America revenues decreased 53% to $268.1 million in 2009, as compared to $567.8 million in 2008. Drilling fluids and engineering revenues decreased 49%, which is largely attributable to the 42% decline in industry drilling activity noted above, along with increased pricing pressure resulting from the depressed activity levels. North American completion fluids and services and wholesale industrial minerals revenues were down a combined 62%, also driven by the lower industry activity and pricing pressure.

 

Mediterranean revenues decreased 6% in 2009 compared to 2008, due to the impact of the strengthening US dollar, as revenue levels increased 4% in local currency terms from 2008 to 2009. Brazil revenues increased 67% to $25.5 million in 2009, reflecting the ramp-up in activity under contracts entered into during 2008.

 

Operating Income

 

Operating income for this segment decreased $85.3 million in 2009 compared to 2008, on a $296.8 million decrease in revenues. The majority of this decline is attributable to the North American operations, which generated an $82.2 million decline in operating income on a $299.8 million decrease in revenues. This decrease in operating income is the result of the decline in North American drilling activity in 2009, and the related increase in pricing pressure from competition. Further, the benefits of cost reduction initiatives taken during 2009 had limited impact on full year 2009 results due to the timing of the actions, which resulted in only partial year benefits to 2009, along with $3.1 million of charges associated with employee termination and related costs, as the North American workforce of this business was reduced by 374 employees during this period. Operating income was further negatively impacted by lower gross profit on industrial mineral sales. Following the execution of significant cost reduction programs in the first half of 2009, and the stabilization of North American rig activity during the second half of 2009, the North American operating income improved from the levels generated during the first half of the year. Specifically, North American operating income in this segment increased by $12.7 million from the first half of 2009 to the second half of 2009.

 

Operating income from international operations decreased $3.1 million on a $3.0 million increase in revenues. The Mediterranean region operating income increased $2.3 million during this period, however, this increase was more than offset by a $5.4 million decrease in Brazil. The 2009 operating loss in Brazil is the result of the ramp up in personnel and facility costs for this operation, in advance of future anticipated revenues under existing contracts, along with an unfavorable sales mix.

Mats and Integrated Services

 

Revenues

 

Total revenues for this segment consisted of the following:

 

 

The $37.9 million decrease in mat rental and integrated services revenues in 2009 is primarily attributable to declines in the U.S. market served by this segment, particularly in the U.S. Gulf Coast region. The decline in revenue is further impacted by the increased pricing competition following the declines in market activity, and timing of projects from customers outside the E&P industry.

 

Mat sales primarily consist of export sales of composite mats to various international markets, as well as to non-oilfield industries domestically. Mat sales decreased by $14.3 million to $12.5 million in 2009 compared to 2008. The year-over-year decline is driven by reduced demand for these products from the E&P and utility industries, as well as governmental sectors in the current economic environment.

 

Operating Income

 

Mats and integrated services operating income decreased by $9.7 million in 2009, on a $52.2 million decrease in revenues compared to 2008. The decrease in operating income is primarily attributable to the declines in revenues and pricing pressures, which was partially offset by cost reductions. The benefits of cost reduction initiatives taken during 2009, including workforce reductions of 150 employees, had a limited impact on the full year 2009 operating results, due to the timing of the actions, which resulted in only partial year benefits to 2009, along with $1.0 million of charges associated with employee termination costs and $1.2 million of non-cash write-downs of inventory. Of the $7.8 million operating loss generated by this segment in 2009, $8.2 million was generated during the first half of the year, during which time the cost reduction actions were being executed.

 

We have evaluated the carrying values of our goodwill and other indefinite-lived intangible assets during the fourth quarter of 2009. The evaluation included consideration of the significant declines in revenues and profitability in 2009, along with the impact of cost reduction programs and forecasted cash flow projections for each reporting unit. In completing this analysis, we determined that no reporting unit has a fair value below its net carrying value. However, our analysis estimated that the fair value of the mats and integrated services reporting unit exceeded net carrying value by less than 10%. As noted above, this segment generated an operating loss of $8.2 million in the first half of 2009, during which time the business unit was executing on significant cost reduction actions in response to the market declines. Following the completion of these actions, the financial performance of this business unit improved significantly, generating revenues of $12.4 million and an operating profit of $1.2 million in the fourth quarter of 2009. Our estimated fair value is determined using a combination of a market multiple and discounted cash flow approach, using internally developed forecasts for the business unit. Deterioration in the operating income and cash flows provided by this reporting unit could potentially result in impairments of goodwill. As of December 31, 2009, the consolidated balance sheet includes $14.9 million of goodwill for the Mats and Integrated Services segment.

Environmental Services

 

Revenues

 

Total revenues for this segment consisted of the following:

 

 

E&P waste revenues in the U.S. Gulf Coast region decreased 36% to $29.3 million in 2009 compared to $46.0 million in 2008. Volumes processed by this region declined 47% during this period, reflective of the decline in U.S. Gulf Coast industry rig activity. This decline in volumes processed was partially offset by changes in sales mix and pricing increases.

 

E&P waste revenues in West Texas decreased by 60% to $3.1 million in 2009 compared to $8.0 million in 2008. The decline in revenues is driven by a 59% decrease in volumes processed during this period along with a decline in revenues from the sale of oil, which is recovered as part of the waste disposal process.

 

NORM and industrial waste revenues increased by 29% to $10.9 million in 2009, compared to $8.5 million in 2008. This increase is driven by higher volumes processed, as activity levels tend to fluctuate significantly from period to period based on the timing of customer projects.

 

Operating Income

 

Environmental services operating income decreased by $1.3 million on a $19.1 million decline in revenues in 2009, compared to 2008. The 2009 results include $2.3 million of income associated with the settlement of business interruption insurance claims resulting from hurricanes and storms in 2008. The 2008 results include a $2.6 million charge to write-down certain disposal assets, following the abandoned sale of the business in the fourth quarter of 2008. The remaining decline of $6.2 million is attributable to the lower revenue levels, partially offset by $12.9 million of operating expense reductions, including reductions in transportation costs, personnel expenses, and rent expense following the non-renewal of barge leases during the second half of 2009.

Year Ended December 31, 2008 Compared to Year Ended December 31, 2007

 

Consolidated Results of Operations

 

Summarized results of operations for the year ended December 31, 2008 compared to the year ended December 31, 2007 are as follows:

 

 

Revenues

 

Revenues were $858.4 million in 2008, reflecting a 28% increase from the $671.2 million reported in 2007. This increase in revenues is primarily driven by the Fluids Systems and Engineering segment, which benefited from market share growth in North America, along with $50.8 million of revenue growth internationally. Additional information regarding these increases is provided within the operating segment results below.

 

Cost of Revenues

 

Cost of revenues were $703.4 million in 2008, reflecting a 32% increase from the $531.1 million reported in 2007. This increase is primarily attributable to the 28% increase in revenues noted above. Additional information regarding these increases is provided within the operating segment results below.

 

Selling, General and Administrative Expenses

 

Selling, general and administrative expenses increased $8.3 million to $81.4 million in 2008 from $73.1 million in 2007. The increase includes $5.5 million in fluids systems and engineering and $3.7 million in the corporate office, slightly offset by decreases of $0.1 million in mat and integrated services and $0.8 million in environmental services. The 2008 corporate office expense includes $4.3 million of legal and selling costs associated with the abandoned sale of the environmental services business as well as $2.2 million of expenses associated with the arbitration and settlement of a lawsuit with our former Chief Executive Officer. Corporate office expenses in 2007 included $3.8 million of legal expenses related to the shareholder class action and derivative litigation. The remaining $1.0 million increase in corporate office spending in 2008 is attributable to increased performance-based employee incentive programs.

Other Expense, Net

 

Other expense, net was $2.0 million in 2008 compared to $0.6 million in 2007. The year ended 2008 included a $2.6 million charge to write-down certain disposal assets within the Environmental Services segment, following the abandoned sale of the business in the fourth quarter of 2008.

 

Interest Expense

 

Interest expense totaled $10.9 million for the year ended December 31, 2008 as compared to $20.3 million in 2007. The year ended December 31, 2007 included a $4.0 million non-cash charge to write-off capitalized debt issuance costs associated with termination of the credit facilities in December 2007. The remaining $5.4 million decrease is primarily attributable to lower interest rates throughout 2008, as compared to 2007. At December 31, 2008, our weighted average interest rate on borrowings was 3.46%, compared to 6.95% at December 31, 2007.

 

Provision for Income Taxes

 

For the year ended December 31, 2008, we recorded an income tax provision of $20.0 million, reflecting an income tax rate of 33.8%, compared to an income tax rate of 32.8% in 2007. The increase in effective tax rate from 2007 to 2008 is primarily attributable to a larger proportion of income being generated by our U.S. operations in 2008, which has a higher tax rate than our foreign jurisdictions.

 

Operating Segment Results

 

Summarized financial information for our reportable segments is shown in the following table (net of inter-segment transfers):

 

Fluids Systems and Engineering

 

Revenues

 

Total revenues for this segment consisted of the following:

 

 

North American revenues increased 31% to $567.8 million for the year ended December 31, 2008, as compared to $435.1 million for the year ended December 31, 2007. While North American rig activity increased 7% during this period, the number of rigs we serviced through this business segment increased 25%, reflecting market share growth within the markets that we service.

 

Revenues in our completion fluids and services business increased 22% in 2008 as compared to 2007, due to strong demand for rental equipment and services for well completion activities in the Oklahoma and Texas areas served by this business. Revenues in our industrial minerals business increased 50% in 2008, as compared to 2007, resulting from a 23% increase in sales volume, along with significant pricing increases to help offset higher barite transportation costs.

 

Mediterranean revenues increased 42% from 2007 to 2008, which was largely driven by the increased rig activity and continued market penetration into the North African and Eastern European markets. Revenues generated in Brazil in 2008 increased $14.7 million following the 2007 start-up of this business unit.

 

Operating Income

 

Operating income for this segment increased $21.2 million in 2008 on a $183.6 million increase in revenues, compared to 2007, resulting in a decrease in operating margin from 12.6% to 12.4%. Of the total segment change, North American operations generated a $19.0 million increase in operating income on a $132.7 million increase in revenues, while international operations generated a $2.2 million increase in operating income on a $50.8 million increase in revenues. Within the international operations, the incremental profits associated with higher revenues were somewhat offset by higher operating expenses attributable to personnel, higher transportation and logistics costs due to the location of projects, and start-up costs associated with new contracts.

 

Mats and Integrated Services

 

Revenues

 

Total revenues for this segment consisted of the following:

 

Mat rental and integrated services revenues decreased by $4.2 million in 2008 compared to 2007, as a $10.6 million increase in revenues generated by the Colorado business acquired in August 2007 was more than offset by a $14.8 million decline in rental and related service volume in the U.S. Gulf Coast region, driven largely by weakness in the South Louisiana land rig count in 2008 compared to 2007.

 

Mat sales primarily consist of export sales of composite mats to various international markets, as well as domestic sales to the U.S. government and customers outside the oil and gas industry. Mat sales increased by $3.8 million in 2008, as compared to 2007, due primarily to higher domestic sales activity.

 

Operating Income

 

Mats and integrated services operating income decreased by $10.9 million to $1.8 million for 2008 on a $0.4 million decrease in revenues compared to 2007, resulting in a decrease in operating margin to 2.1% from 14.2%. The decrease in operating margin is partially attributable to the change in sales mix. The Colorado business acquired in August 2007 generated an increase in rental and service revenues of $10.6 million in 2008; however, operating income from this business were unchanged over this period, as incremental profits generated by the higher revenues were offset by higher expenses, including a $1.9 million increase in depreciation and amortization related to acquired assets. Operating income for the remaining operations in this segment, which primarily service the U.S. Gulf Coast area, declined by $10.9 million on a $11.0 million decline in revenue. As noted above, this $11.0 million decline in revenue included a $14.8 million decrease in rental and integrated services revenue, offset by a $3.8 million increase in mat sales. The decline in U.S. Gulf Coast operating income is primarily due to the lower rental and integrated service revenues, as these activities have a relatively high fixed cost structure. In addition, the U.S. Gulf Coast service business was negatively impacted by additional pricing pressure resulting from the significantly lower rig counts in the region throughout 2008. Also, the business recorded $4.3 million of pre-tax charges in 2008 related primarily to inventory and receivable write-downs, transportation costs for the re-deployment of rental mats, as well as severance and related costs associated with restructuring activities in this segment.

 

Environmental Services

 

Revenues

 

Total revenues for this segment consisted of the following:

 

 

E&P waste revenues in the U.S. Gulf Coast region decreased 1% to $46.0 million in 2008 compared to 2007. Volumes processed by this region declined 5% during this period, reflective of the 3% decline in U.S. Gulf Coast rig activity during this period. This decline in volumes processed was partially offset by changes in sales mix and pricing increases.

 

E&P waste revenues in West Texas increased by 100% to $8.0 million in 2008 compared to 2007. Volumes processed by this region declined 20% during this period, however, this was more than offset by improvements in pricing. Also, this region generated $3.2 million of additional revenues from the sale of oil, which is a by-product of the waste disposal process. The increase in oil revenues is the result of the high commodity prices experienced during 2008.

 

NORM and industrial waste revenues increased by 5% to $8.5 million in 2008 compared to 2007.

Operating Income

 

Environmental services operating income decreased by $1.5 million to $9.0 million in 2008 on a $4.0 million increase in revenues compared to 2007, reflecting a decrease in operating margin to 14.5% from 18.0%. The 2008 operating income included a $2.6 million charge to write-down certain disposal assets which we decided not to develop following the abandoned sale of the business in the fourth quarter of 2008. In addition, 2008 includes $0.4 million of expenses associated with unrecoverable losses incurred at our U.S. Gulf Coast facilities associated with Hurricanes Ike and Gustav. The remaining $1.5 million increase in operating income reflects the impact of the higher revenues.

 

Liquidity and Capital Resources

 

Net cash provided by operating activities in 2009 totaled $88.8 million. The net loss adjusted for non-cash items generated $7.8 million of cash during the period, while decreases in working capital provided $81.0 million of cash. The decrease in working capital during the year includes $89.3 million from decreases in receivables and $35.2 million from decreases in inventories, partially offset by a $28.7 million decrease in accounts payable and a $14.0 million decrease in accrued liabilities and other. All of these changes are primarily due to lower sales levels and our lower purchasing and spending activities.

 

Net cash used in investing activities during in 2009 was $17.1 million, consisting primarily of capital expenditures which included $12.2 million for our operations outside of North America.

 

Net cash used in financing activities in 2009 was $66.3 million, reflecting net payments made on our credit facility during the period. During 2009, our total debt balance was reduced by $65.1 million to $123.0 million at December 31, 2009. In the near term, we anticipate that our debt requirements will be primarily driven by working capital needs, which will increase if revenue increases over current levels. Our 2010 capital expenditures are expected to be approximately $15 million. Cash generated by operations, along with availability under our existing credit agreement is expected to be adequate to fund our anticipated capital needs. Our capitalization was as follows as of December 31:

 

In December 2007, we entered into a $225.0 million Amended and Restated Credit Agreement (“Credit Agreement”) with a five year term, expiring in December 2012. The Credit Agreement consisted of a $175.0 million revolving credit facility and a $50.0 million term loan, which is to be repaid through annual principal payments of $10 million which began in December 2008. The Credit Agreement contained certain financial covenants including a minimum fixed charge coverage ratio, a maximum consolidated leverage ratio, and a maximum funded debt-to-capitalization ratio. At June 30, 2009, we were not in compliance with the fixed charge coverage ratio and consolidated leverage ratio covenants. However, in July 2009, we entered into the First Amendment, which provided a waiver of the financial covenant violations as of June 30, 2009 and modified certain covenant requirements in future periods, as follows:

 

 

Historically, our performance for financial covenant compliance purposes was based on our trailing four fiscal quarter results. Under the First Amendment, financial covenant calculations utilize annualized results beginning with the third quarter of 2009, and continuing through March 31, 2010, after which time the calculations will return to using trailing four fiscal quarter results.

 

We were in compliance with these modified covenants as of December 31, 2009, and expect to remain in compliance through December 31, 2010. The calculated performance for these covenants as of December 31, 2009, is as follows:

 

 

The First Amendment also reduced the revolving credit facility from $175.0 million to $150.0 million, and provided for adjustments in the interest rates and commitment fees under the credit facility. Under the Credit Agreement, as amended by the First Amendment, we can elect to borrow at an interest rate either based on LIBOR plus a margin based on our consolidated leverage ratio, ranging from 400 to 750 basis points, or at an interest rate based on the greatest of: (a) prime rate, (b) the federal funds rate in effect plus 50 basis points, or (c) the Eurodollar rate for a Eurodollar Loan with a one-month interest period plus 100 basis points, in each case plus a margin ranging from 300 to 650 basis points. The First Amendment also increased the commitment fee rate payable under the credit facility, which is now fixed at 50 basis points. The applicable margin on LIBOR borrowings at December 31, 2009 was 425 basis points.

 

As of December 31, 2009, $78.0 million of the outstanding principal of the revolving credit facility was bearing interest at LIBOR plus 425 basis points, or 4.53%, while the remaining $7.0 million in outstanding principal was bearing interest at Prime Rate plus 325 basis points, or 6.50%. In January 2008, we entered into interest rate swap agreements to effectively fix the underlying LIBOR rate on our borrowings under the term loan. The initial notional amount of the swap agreements totaled $50.0 million, reducing by $10.0 million each December, matching the required principal repayments under the term loan. As a result of the swap agreements, we will pay a fixed rate of 3.74% over the term of the loan plus the applicable LIBOR margin, which was 425 basis points at December 31, 2009. The weighted average interest rate on the outstanding balances under our Credit Agreement including the interest rate swaps as of December 31, 2009 and 2008 was 5.55% and 3.46%, respectively.

The Credit Agreement is a senior secured obligation, secured by first liens on all of our U.S. tangible and intangible assets, including our accounts receivable and inventory. Additionally, a portion of the capital stock of our non-U.S. subsidiaries has also been pledged as collateral.

 

Our foreign Fluid Systems and Engineering subsidiaries in Italy and Brazil maintain local credit arrangements consisting primarily of lines of credit with several banks, which are renewed on an annual basis. We utilize local financing arrangements in our foreign operations in order to preserve credit availability under our corporate credit agreement, as well as to reduce the net investment in foreign operations subject to foreign currency risk. 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. The weighted average interest rate for the $6.9 million balance outstanding under these arrangements was 6.83% at December 31, 2009.

 

At December 31, 2009, $9.9 million in letters of credit were issued and outstanding domestically, including $3.6 million related to our insurance programs. In addition, we had $85.0 million outstanding under our revolving credit facility at December 31, 2009. The outstanding balance and letters of credit under our credit facility leave $55.1 million of availability at December 31, 2009. Additionally, we had $1.8 million in letters of credit outstanding relating to foreign operations.

 

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 $3.6 million and $3.1 million at December 31, 2009 and 2008, respectively. In addition, as of December 31, 2009 and 2008, we had established other letters of credit in favor of our suppliers in the amount of $6.3 million and $0.3 million, respectively. We also had $8.5 million in guarantee obligations in connection with facility closure bonds and other performance bonds issued by insurance companies and outstanding as of December 31, 2009 and 2008.

 

Other than normal operating leases for office and warehouse space, barges, 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, 2009 is as follows:

 

 

The above table does not reflect expected tax payments and unrecognized tax benefits due to the inability to make a reasonably reliable estimate of the timing and amount to be paid. For additional discussion on unrecognized tax benefits, see “Note 8 — Income Taxes” to our Notes to Consolidated Financial Statements included in Part II Item 8 in this report.

We anticipate that the obligations and commitments listed above that are due in less than one year will be paid from operating cash flows and availability under our existing credit agreement. The specific timing of settlement for certain long-term obligations can not be reasonably estimated.

 

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 sales 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 cash flows used for impairment testing of long-lived assets and valuation allowances for deferred tax assets. Note 1 to the consolidated financial statements contains 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 2009, 2008 and 2007, provisions for uncollectible accounts receivable were $2.3 million, $2.7 million and $1.3 million, respectively.

 

Allowance for Sales Returns

 

We maintain reserves for estimated customer returns of unused materials in our Fluids Systems and Engineering 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.

 

Impairments 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. The impairment test 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. 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.

 

Our annual evaluation of goodwill and indefinite-lived intangible assets was completed during the fourth quarter of 2009. The evaluation included consideration of the significant declines in revenues and profitability encountered in 2009, along with the impact of cost reduction programs and forecasted cash flow projections for each reporting unit. In completing this evaluation, we determined that no reporting unit has a fair value below its net carrying value. However, while our analysis indicated that the fair value of our drilling fluids business remains significantly in excess of carrying value, our mats and integrated services reporting unit exceeded net carrying value

by less that 10%. Deterioration in the operating income and cash flows provided by this reporting unit could potentially result in requirement impairments in goodwill. At December 31, 2009, the consolidated balance sheet includes $14.9 million of goodwill for the Mats and Integrated Services segment.

 

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. 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.

 

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 cost experience under these programs, including estimated development of known claims under these programs 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, 2009 and 2008, total insurance reserves were $3.1 million and $3.2 million, respectively.

 

Income Taxes

 

We have total deferred tax assets of $65.2 million at December 31, 2009. 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. We have considered future taxable income and tax planning strategies in assessing the need for our valuation allowance. At December 31, 2009, a total valuation allowance of $19.5 million was recorded, substantially all of which offsets $18.2 million of net operating loss carryforwards for state tax purposes, as well as foreign jurisdictions, including Canada, Brazil and Mexico. No valuation allowance is recorded for our U.S. net operating loss carryforward. 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 determination was made. Specifically, we have a $3.5 million valuation allowance recorded on the net operating loss carryforward in Brazil which could be reversed in the near future, depending on our ability to generate taxable income.

 

New Accounting Standards

 

In October 2009, the Financial Accounting Standards Board (“FASB”) issued additional guidance on multiple-deliverable revenue arrangements. The guidance provides amendments to the criteria for separating consideration in multiple-deliverable arrangements. It replaces the term “fair value” in the revenue allocation guidance with “selling price” to clarify that the allocation of revenue is based on entity-specific assumptions rather than assumptions of a marketplace participant, and they establish a selling price hierarchy for determining the selling price of a deliverable. The amendments eliminate the residual method of allocation and require that arrangement consideration be allocated at the inception of the arrangement to all deliverables using the relative selling price method, and they significantly expand the required disclosures related to multiple-deliverable revenue arrangements. The amendments will be effective prospectively for revenue arrangements entered into or materially modified in fiscal years beginning after June 15, 2010 and we do not expect the impact of this statement to be material.

 

On October 1, 2009, we adopted new accounting guidance relating to fair value measurements and disclosures. The guidance provides clarification in circumstances in which a quoted price in an active market for when an identical liability is not available, a reporting entity is required to measure fair value using (a) a valuation technique that uses the quoted price of the identical liability when traded as an asset or quoted prices for similar liabilities and/or (b) an income approach valuation technique or a market approach valuation technique. The adoption did not have a material effect on our consolidated financial position or results of operations.

On September 15, 2009, we adopted new accounting guidance issued by the FASB, which established the FASB Accounting Standards Codification, a new source of authoritative accounting principles applicable to nongovernmental entities in the preparation of financial statements in conformity with U.S. GAAP known as “The Codification”. The Codification does not change current U.S. GAAP, but is intended to simplify user access to all authoritative U.S. GAAP by providing all the authoritative literature related to a particular topic in one place. As of the effective date, all existing non-SEC accounting standard documents were superseded.

 

On January 1, 2009, we adopted new accounting guidance relating to changes in the disclosure requirements for derivative instruments and hedging activities. Entities are required to provide enhanced disclosures about (1) how and why an entity uses derivative instruments, (2) how derivative instruments and related hedged items are accounted for and (3) how derivative instruments and related hedged items affect an entity’s financial position, financial performance, and cash flows. The adoption did not have a material effect on our consolidated financial position or results of operations. See Note 7 “Fair Value of Financial Instruments and Concentrations of Credit Risk” to our Notes to Consolidated Financial Statements included in Part II Item 8 in this report for additional details on our derivative instruments and hedging activities.

 

On January 1, 2009, we adopted new accounting guidance regarding factors that should be considered in developing renewal or extension assumptions used to determine the useful life of a recognized intangible asset. The objective of the new guidance is to improve the consistency between the useful life of a recognized intangible asset and the period of expected cash flows used to measure the fair value of the asset. The adoption did not have a material effect on our consolidated financial position or results of operations.

 

On January 1, 2009, we adopted revised accounting guidance on the accounting for acquisitions of businesses. The revision changed the previous guidance, requiring that all acquired assets, liabilities, minority interest and certain contingencies be measured at fair value, and certain other acquisition-related costs be expensed rather than capitalized. The revised guidance applies to acquisitions that were effective after December 31, 2008, and application of the standard to acquisitions prior to that date was not permitted. The adoption did not have a material effect on our consolidated financial position or results of operations.

 

We are exposed to market risk from changes in interest rates and changes in foreign currency rates. A discussion of our primary market risk exposure in financial instruments is presented below.

 

Interest Rate Risk

 

Our policy is to manage exposure to interest rate fluctuations by using a combination of fixed and variable-rate debt. At December 31, 2009, we had total debt outstanding of $123.0 million.

 

In January 2008, we entered into interest rate swap agreements to effectively fix the underlying LIBOR interest rate on our borrowings under the term loan portion of our credit facility. The initial notional amount of the swap agreements totaled $50.0 million, reducing by $10.0 million each December, matching the required principal repayments under the term loan. As of December 31, 2009, $30.0 million remained outstanding under this term loan. As a result of the swap agreements, we will pay a fixed rate of 3.74% plus the applicable LIBOR margin, over the term of the loan.

 

The remaining $93.0 million of debt outstanding at December 31, 2009 bears interest at a floating rate, which was a weighted average of 4.83% at December 31, 2009. At the December 31, 2009 balance, a 200 basis point increase in market interest rates during 2009 would cause our annual interest expense to increase approximately $1.9 million, resulting in a $0.01 per diluted share reduction in annual net earnings.

 

Foreign Currency

 

Our principal foreign operations are conducted in certain areas of Europe and North Africa, Brazil, Canada, U.K. and Mexico. 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 which include European euros, Canadian dollars 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 because the dollar amount of these transactions has not warranted our using hedging instruments.

 

Unremitted foreign earnings permanently reinvested abroad upon which deferred income taxes have not been provided aggregated approximately $52.3 million and $38.0 million at December 31, 2009 and 2008, respectively. We have the ability and intent to leave these foreign earnings permanently reinvested abroad.

 

To the Board of Directors and Stockholders of

Newpark Resources, Inc.

The Woodlands, Texas

 

We have audited the accompanying consolidated balance sheets of Newpark Resources, Inc. and subsidiaries (the “Company”) as of December 31, 2009 and 2008, and the related consolidated statements of operations, comprehensive (loss) income, stockholders’ equity, and cash flows for the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

 

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

 

In our opinion, such 2009 and 2008 consolidated financial statements present fairly, in all material respects, the financial position of Newpark Resources, Inc. and subsidiaries as of December 31, 2009 and 2008, and the results of their operations and their cash flows for the years then ended 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), the Company’s internal control over financial reporting as of December 31, 2009, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 3, 2010 expressed an unqualified opinion on the Company’s internal control over financial reporting.

 

 

Houston, Texas

March 3, 2010

Report of Independent Registered Public Accounting Firm

 

The Board of Directors and Stockholders

Newpark Resources, Inc.

 

We have audited the accompanying consolidated statements of operations, comprehensive (loss) income, stockholders’ equity, and cash flows of Newpark Resources, Inc. for the year ended December 31, 2007. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

 

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

 

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated results of operations and cash flows of Newpark Resources, Inc. for the year ended December 31, 2007, in conformity with U.S. generally accepted accounting principles.

 

As discussed in Note 8 to the consolidated financial statements, effective January 1, 2007 the Company adopted the provisions for the accounting for uncertainty in income taxes.

 

 

Houston, Texas

March 6, 2008 except as to the reclassification in 2008

of the U.S. Environmental Services business as continuing

operations as to which the date is March 6, 2009 and except as

to the reclassifications in the consolidated statement of operations

discussed in Note 1 as to which the date is March 3, 2010

Newpark Resources, Inc.

 

Consolidated Balance Sheets

December 31,

 

 

See Accompanying Notes to Consolidated Financial Statements

Newpark Resources, Inc.

 

Consolidated Statements of Operations

Years Ended December 31,