PART I
When used in this Annual Report, the terms Nuverra, the Company, we, our, and us refer to Nuverra Environmental Solutions, Inc. and its
consolidated subsidiaries, unless otherwise specified.
Overview
Nuverra Environmental Solutions, Inc. is among the largest companies in the United States dedicated to providing comprehensive, full-cycle
environmental solutions to customers focused on the development and ongoing production of oil and natural gas from shale formations. Nuverra provides one-stop, total environmental solutions, including delivery, collection, treatment, recycling, and
disposal of water, wastewater, waste fluids, hydrocarbons, and restricted solids that are part of the drilling, completion, and ongoing production of shale oil and natural gas.
To meet its customers environmental needs, Nuverra utilizes a broad array of assets to provide a comprehensive environmental
solution. The Companys logistics assets include trucks and trailers, pipelines, temporary pipelines, temporary and permanent storage facilities, ancillary rental equipment, treatment facilities, and liquid and solid waste disposal sites. The
Company continues to expand its suite of environmentally compliant and sustainable solutions to customers who demand environmental compliance and accountability from their service providers.
The following chart describes our focus on providing comprehensive environmental solutions and the assets we currently utilize or are in
the process of implementing to execute on our strategy:
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Delivery
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Collection
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Treatment
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Recycling
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Disposal
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Solutions
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Fresh water to drilling sites
Drilling mud
Water procurement
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Liquid waste from fracking
Liquid waste from ongoing well production
Solid waste
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Oily waste water
Liquid waste from fracking
Liquid waste from ongoing well production
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Liquid waste from fracking
Liquid waste from ongoing well production
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Liquid and solid waste
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Assets
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More than 1,100 trucks
Approximately 5,700 tanks
50 miles of freshwater delivery pipeline
50 miles of produced water collection pipeline
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Appalachian Water Services, LLC (AWS) planta
wastewater treatment recycling facility specifically designed to treat and recycle water involved in the hydraulic fracturing process in the Marcellus Shale area
Halliburton H2O Forward
SM
partnership treatment facilities
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56 liquid waste disposal wells
Solid waste landfill
Thermal treatment assets for solid waste
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Our Shale Solutions segment consists of our operations in shale basins where customer exploration and
production (E&P) activities are predominantly focused on shale oil and natural gas as follows:
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Oil shale areas
: includes our operations in the Bakken, the Utica, the Eagle Ford, the Mississippian, and the Permian Basin shale areas. During
2013, approximately 71% of our revenues from continuing operations were derived from these shale areas.
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Gas shale areas
: includes our operations in the Marcellus, the Haynesville, and the Barnett shale areas. During 2013, approximately 29% of our
revenues from continuing operations were derived from these shale areas.
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Nuverra supports its
customers demand for diverse, comprehensive and regulatory compliant environmental solutions required for the safe and efficient drilling, completion and production of oil and natural gas from shale formations. Current services include
(i) fluid logistics via water procurement, delivery, collection, storage, treatment, recycling and disposal, (ii) solid waste collection and disposal, (iii) permanent and portable pipeline facilities and water infrastructure services,
(iv) equipment rental services, and (v) other ancillary services for exploration and production (E&P) companies focused on the extraction of oil and natural gas resources from shale basins.
As part of its environmental solution for water and water-related services, Nuverra serves E&P customers seeking fresh water
acquisition, temporary or permanent water transmission and storage, transportation, treatment or disposal of fresh flowback and produced water in connection with shale oil and natural gas hydraulic fracturing operations. The Company also provides
services for water pit excavations, well site preparation and well site remediation. The Company owns a 50-mile underground pipeline network in the Haynesville Shale area for the efficient delivery of fresh water and removal of produced water, a
fleet of more than 1,100 trucks for delivery and collection, and approximately 5,700 storage tanks. The Company also owns or leases 56 operating saltwater disposal wells in the Bakken, Marcellus/Utica, Haynesville, Eagle Ford, and Tuscaloosa Marine
shale areas.
As part of its environmental solution for water treatment, Nuverra has a majority interest
investment in Appalachian Water Services, LLC (AWS), which owns and operates a wastewater treatment facility specifically designed to treat and recycle water resulting from the hydraulic fracturing process in the Marcellus Shale area.
Additionally, in July 2013, Nuverra entered into an agreement with Halliburton to advance the treatment and recycling of produced water to be re-used in the hydraulic fracturing process. As part of the agreement, Nuverra and Halliburton work
together in the Bakken Shale area to offer the H2O
Forward
SM
service to E&P companies. H2O Forward
SM
service allows customers to recycle waste streams of flowback and
produced water for use in well completions, reducing the need for fresh water. For hydraulic fracturing operations conducted by Halliburton using the H2O Forward
SM
system in the Bakken, Nuverra provides logistics, transportation, storage, and overall fluid management services.
As part of its environmental solution for solid waste, the Company owns an oilfield solids disposal landfill in the Bakken
Shale area. The landfill is located on a 60-acre site with permitted capacity of more than 1.7 million cubic yards of airspace. The Company believes that permitted capacity at this site could be expanded up to 5.8 million cubic yards of
permitted airspace capacity in the future, subject to receipt of requisite regulatory approvals. In addition, the Company has begun construction of a thermal treatment facility at the landfill site in North Dakota.
As part of its ongoing operations, Nuverra continually assesses its asset mix and, as needs and demand require, will invest in additional
equipment or make improvements to our existing assets.
During the fourth quarter of 2013, Nuverra announced a strategic
rationalization of its Shale Solutions business designed to maximize operating efficiencies, leverage future growth opportunities, and optimize sales and business development activities to align with its customers. The Company expects to complete
the initiative during 2014, which we expect to consist of the following divisions:
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Northeast Division
: comprising the Marcellus and Utica Shale areas;
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Southern Division
: comprising the Haynesville, Barnett, Eagle Ford, Mississippian Shale areas and the Permian Basin; and
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Rocky Mountain Division
: comprising the Bakken Shale area.
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Competitive Strengths
We believe our business possesses the following competitive strengths, which position us to better serve our customers and grow revenue and cash flow:
Leading Transportation and Logistics Network to Control Delivery, Collection, Treatment and Disposal.
We operate a
transportation and logistics network consisting of more than 1,100 trucks, 5,700 storage tanks, 50 miles of fresh water delivery pipeline and 50 miles of produced water collection pipeline. The products we move within our logistics network include
fresh water, drilling fluids, liquid and solid waste, and oily wastewater. Our business practices and standards promote the safe and responsible collection, treatment, recycling and/or disposal of restricted environmental waste on behalf of our
customers. As we expand our treatment, recycling, and disposal solutions, we believe controlling the environmental product that is processed by these assets through our transportation and logistics network is a competitive strength when compared to
competitors that rely on third-party providers for transportation and logistics expertise.
Our Customers are Highly
Focused on Environmental Responsibility and Compliance.
Our customers are committed to conducting their operations with high levels of environmental responsibility and compliance. They place a premium on a national environmental solutions
provider that is focused exclusively on the safe and responsible delivery, collection, treatment, recycling, and disposal of their restricted environmental products. There is a high level of scrutiny on the environmental impact of shale oil and
natural gas drilling and production. As a result, we believe there is significant demand for Nuverras exclusive focus on surface environmental matters. We provide customers the ability to effectively outsource many of the regulatory issues
surrounding their business, making it possible for them to focus on their core competencies.
National Operating
Footprint Appeals to Customers Operating in Multiple Shale Basins.
We are one of the few companies solely focused on surface environmental solutions that has a national operating capability with a strong presence in the majority of the North
American unconventional shale basins. An increasing number of E&P operators have a presence in multiple basins, including a growing number of super majors, majors, and large independent companies. As a result, we believe we have a competitive
advantage relative to many smaller competitors due to our national customer relationships and the growing demand for consistent and comprehensive solutions to their environmental needs across multiple basins.
Rapidly Growing Market Segment with Differentiated Value Proposition.
We believe that the growth of domestic production of
oil and natural gas in unconventional shale basins presents a unique growth opportunity. Many industry and financial analysts are forecasting significant growth in U.S. oil and natural gas production, largely as a result of advances in drilling and
completion techniques in the unconventional shale basins in which we operate. These new techniques require significant environmental solutions to manage restricted waste products, and our customers are committed to the responsible and safe handling
of these products. As such, we believe our strategy to provide comprehensive environmental solutionsfrom collection through recycling or disposalprovides us with a strong competitive advantage. Many of our competitors offer only a single
component of this value chain, with environmental solutions comprising a component of their overall business services. We believe our focus on the spectrum of surface-related environmental solutions makes it possible for us to provide our customers
with a consistent, compliant, professional, and highly differentiated value proposition.
Operational, Environmental and
Regulatory Expertise.
We believe our management team and employees have significant expertise regarding the issues surrounding environmental waste products and can efficiently and safely provide services to our customers to manage this
aspect of their business. We apply this experience to providing excellent service and identifying innovative, new solutions for our customers. We expect demand for our services to increase as regulatory mandates may increase the financial and
operational burdens on our customers.
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Strategy
Our strategy is to leverage our unique, full-cycle business model to expand relationships with current and new customers and to provide the most comprehensive environmental solutions, including delivery,
collection, treatment, recycling, and disposal of the environmental waste generated from unconventional shale oil and natural gas production. The principal elements of our business strategy are to:
Utilize Our Leading Transportation and Logistics Network to Expand Pipeline, Rental, Treatment, Recycling, and Disposal
Solutions.
We intend to leverage our advanced transportation and logistics system to continue to expand our pipeline, rental, treatment, recycling, and disposal services. We believe as the market in the unconventional shales evolves,
customers will increasingly value a one-stop provider for all of their environmental solutions, including pipeline, rental, treatment/recycling and disposal solutions for liquid and solid waste products. Our current transportation and logistics
footprint provides the platform from which we can continue to expand our customer network and provide end-to-end environmental solutions.
Establish and Maintain Leading Market Positions in Core Operating Areas.
We strive to establish and maintain leading market positions within our core operating areas to realize benefits from
scale and customer penetration, as well as maximize our returns on invested capital. As a result, we seek to maintain close customer relationships and to provide a comprehensive, end-to-end environmental solution, rather than one-off individual
services.
Providing Solutions in a Reliable and Responsible Manner.
Nuverra is a company focused on efficiency
and environmental sustainability through responsible practices. We are committed to protecting the health and safety of our employees, partners and other stakeholders, reducing the impact of our operations on the environment, supporting our
communities, and enhancing the operations of our partners. These are key tenets that govern our daily activities and strategic vision. Our customers require high levels of regulatory, environmental and safety compliance, which we support through
employee training, the maintenance of our asset base and our approach to developing environmentally sustainable solutions for customers. Combined with the increasing number of customers operating in multiple basins, we seek a national-level dialogue
with these customers in order to provide a consistent and comprehensive solutions-based approach to their environmental needs.
Development and Implementation of Best Practices to Drive Efficiency and Economy
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We believe that there are best-practices in certain of our current shale geographies that can be expanded to other areas of operations to drive efficiency. We also intend to pursue the implementation of new invoicing, and fleet management systems to
reduce costs, improve data collection and increase operating efficiency.
Maintain a Flexible Capital Structure to
Pursue Growth Opportunities.
We intend to maintain a capital structure that provides us with the flexibility to continue to expand our business, support ongoing operational advancements, minimize our overall cost of capital and support our
long-term growth strategies.
Industry Overview
Over the past several years, E&P companies have focused on utilizing the vast resource potential available across many of North Americas unconventional shale areas through the application of
horizontal drilling and completion technologies, including multi-stage hydraulic fracturing. We believe capital for the continued development of shale oil and natural gas resources will be provided in part by the large, well-capitalized domestic and
international oil and natural gas companies that have made and continue to make significant capital commitments in North Americas unconventional basins. We believe these companies are highly focused on environmental responsibility, compliance,
and regulatory issues and prefer to work with large, highly qualified national companies.
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Advances in drilling technology and the development of unconventional North American
hydrocarbon plays allow previously inaccessible or non-economical formations in the earths crust to be accessed by utilizing high pressure methods from millions of gallons of water (or the process known as hydraulic fracturing, or fracking)
combined with proppant fluids (containing sand grains or ceramic beads) to create new perforation depths and fissures to extract natural gas, oil, and other hydrocarbon resources. Significant amounts of water are required to be delivered to the well
for hydraulic fracturing operations, and subsequently, complex water flows, in the forms of flowback and produced water, represent a waste stream generated by these methods of hydrocarbon exploration and production. Produced water volumes, which
represent water from the formation produced alongside hydrocarbons over the life of the well, are generally driven by marginal costs of production and frequently create a multi-year demand for our services once the well has been drilled. In addition
to the liquid product stream involved in the hydraulic fracturing process, there are also significant environmental solid waste streams that are generated during the drilling and completion of a well. During the drilling process, a combination of
the cut rock, or cuttings, mixed with the liquid used to drill the well, is returned to the surface and must be handled in accordance with environmental and other regulations. Historically, much of this solid waste byproduct was buried
at the well site. We believe that customers will increasingly be focused on the treatment and offsite disposal of the solid waste byproduct.
We primarily operate in the Bakken, Marcellus/Utica, Haynesville, Eagle Ford, Mississippian Lime, Barnett, and Permian Basin shale areas.
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The Bakken and underlying Three Forks formations are the two primary reservoirs currently being exploited in the Williston Basin, which covers most of
western North Dakota, eastern Montana, northwest South Dakota and southern Saskatchewan. The Bakken formation occupies about 200,000 square miles of the subsurface of the Williston Basin in Montana, North Dakota and Saskatchewan, and the Three Forks
formation lies directly below North Dakotas portion of the Bakken formation, where oil-producing rock is located between layers of shale about two miles underground. According to the U.S. Energy Information Administration, or the
EIA, April 2013 Annual Energy Outlook, as of January 1, 2011, the Bakken Shale area had more than 8.04 billion barrels of technically recoverable oil reserves. The Bakken Shale area is now one of the most actively drilled
unconventional resources in North America, with North Dakota daily crude oil production reaching over 970,000 barrels per day as of November 2013, currently ranking second among U.S. states in daily average crude oil production.
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The Haynesville Shale area is located across northwest Louisiana and east Texas, and extends into Arkansas. The Haynesville Shale area is the third
largest natural gas-producing basin in North America, with an estimated 74.6 Tcf of technically recoverable gas and production of nearly 4.1 Bcf/d as of October 2013, or more than 3% of U.S. total natural gas production.
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The Eagle Ford Shale area is a gas and oil play located across southern Texas. The play contains a high liquid component, which has led to the
definition of three areas: oil, condensate and dry gas. The Eagle Ford Shale is estimated to have approximately 60.9 Tcf of technically recoverable gas and 10.7 billion barrels of technically recoverable oil, according to the EIA.
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The Marcellus Shale area is located in the Appalachian Basin in the Northeastern United States (primarily in Pennsylvania, West Virginia, New York and
Ohio). The Marcellus Shale is the largest natural gas field in North America with approximately 148.4 Tcf of technically recoverable gas, according to the EIA.
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Adjacent to the Marcellus Shale is the emerging Utica Shale, located primarily in southwestern Pennsylvania and eastern Ohio. Still in the early stages
of development, the Utica Shale play has three identified areas: oil, condensate and dry gas. According to the EIA, the Utica Shale is estimated to have approximately 38.2 Tcf of technically recoverable gas.
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The Barnett Shale is located in Texas and is estimated to have approximately 57.7 Tcf of technically recoverable gas, according to the EIA. The Barnett
Shale is the second largest natural gas-producing basin in the United States, producing approximately 4.5 Bcf/d as of October 2013, or approximately 4% of total U.S. natural gas production.
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The Mississippian play is an old producing conventional field with more than 17,000 vertical wells drilled since the 1930s, but it has recently become
an emerging horizontal shale play in Northern Oklahoma and Southern Kansas that is marked by significant amounts of produced water.
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Customers
Our customers include major domestic and international oil and
gas companies, foreign national oil and gas companies and independent oil and natural gas production companies that are active in our core areas of operations. In the year ended December 31, 2013, our three largest customers represented 14%,
14% and 11%, respectively, of our total consolidated revenues.
Competitors
We believe there are a limited number of competitors who approach the market similarly to Nuverra. Some competitors are focused primarily
on treatment, recycling, and disposal operations, preferring to avoid the logistical components of delivery and collection, and include Tervita Corporation, R360 Environmental Solutions (now part of Waste Connections, Inc.), and Clean Harbors, Inc.
We believe that offering a comprehensive environmental solution to our customers, which includes certainty of control of environmental products from generation through disposal, is an important value proposition and will only increase in importance
over time. We believe the logistics network we have built to provide delivery and collection is a significant competitive advantage relative to these competitors.
Other competitors offer certain environmental services as ancillary offerings to their core businesses, which are focused largely on the downhole aspects of oil and natural gas operations. Unlike us, many
of these competitors also conduct hydraulic fracturing and/or workover operations, examples of which would include Schlumberger Limited, Baker-Hughes, Inc., Key Energy Services, Inc. and Basic Energy Services, Inc. However, none of these companies
focus exclusively on the surface environmental aspects of unconventional oil and natural gas operations, a key aspect of our strategy. Other competitors focus primarily or exclusively on the fluids handling aspects of hydraulic fracturing and
include numerous small, regional enterprises.
The markets in which we operate are highly competitive and certain of our
competitors have longer industry tenure and greater resources than us. Competition is influenced by such factors as price, capacity, availability of work crews and equipment, health, safety and environment (HS&E) programs, legal
compliance, technology, reputation and experience. We believe we can compete effectively in the environmental solutions sector as a result of our extensive industry experience, depth and breadth of transport, treatment and disposal assets, focus on
HS&E and commitment to customer service.
Health, Safety & Environment
We are committed to excellence in HS&E in our operations, which we believe is a critical characteristic for our business. Our
customers in the unconventional shale basins, including many of the large integrated and international oil and gas companies, require us, as a service provider, to meet high standards on HS&E matters. As a result, we believe that being a leading
environmental solutions company with a national presence and a dedicated focus on environmental solutions is a competitive advantage relative to smaller, regional companies, as well as companies that provide certain environmental services as
ancillary offerings.
Seasonality
Our business segments are impacted by seasonal factors. Generally, our business is negatively impacted during the winter months due to inclement weather, fewer daylight hours and holidays. During periods
of heavy
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snow, ice or rain, we may be unable to move our trucks and equipment between locations, thereby reducing our ability to provide services and generate revenue. In addition, these conditions may
impact our customers operations, and, as our customers drilling and/or hydraulic fracturing activities are curtailed, our services may also be reduced. During the fourth quarter, we historically have experienced slowdowns during the
Thanksgiving and Christmas holiday seasons. In addition, demand sometimes slows during this period as our customers exhaust their annual capital spending budgets.
Intellectual Property
We operate under numerous trade names and own
several trademarks, the most important of which are Nuverra, HWR, Power Fuels, and Heckmann Water Resources. We also have access, through certain exclusive and business relationships, to various water
treatment technologies which, based on our experience, we utilize to create unique, cost-effective and proprietary total water treatment solutions for our customers.
Operating Risks
Our operations are subject to hazards inherent in our
industry, including accidents and fires that could cause personal injury or loss of life, damage to or destruction of property, equipment and the environment, suspension of operations and litigation, as described in Note 16 of the Notes to
Consolidated Financial Statements herein, associated with these hazards. Because our business involves the transportation of environmentally regulated materials, we may also experience traffic accidents or pipeline breaks that may result in spills,
property damage and personal injury. We have implemented a comprehensive HS&E program designed to minimize accidents in the workplace, enhance our safety programs, maintain environmental compliance and improve the efficiency of our operations.
Discontinued Operations
Following an assessment of various alternatives regarding our Industrial Solutions business in the third quarter of 2013 and a decision to focus exclusively on our Shale Solutions business, our board of
directors approved and committed to a plan to divest Thermo Fluids Inc. (TFI), which comprises our Industrial Solutions segment, in the fourth quarter of 2013. The results of operations and cash flows of TFI are presented as discontinued
operations in our consolidated statements of operations and consolidated statements of cash flows for the years ended December 31, 2013 and 2012 (since its acquisition on April 10, 2012). The assets and liabilities related to TFI are
presented separately as assets held for sale and liabilities of discontinued operations in our consolidated balance sheets at December 31, 2013 and 2012.
Our Industrial Solutions segment provides route-based environmental services and waste recycling solutions, offering customers a reliable, high-quality and environmentally responsible solution through our
one-stop
shop of collection and recycling services for waste products including used motor oil (UMO), oily water, spent antifreeze, used oil filters and parts washers. The Industrial
Solutions segment collects UMO and reprocesses it to be sold in the form of reprocessed fuel oil (RFO) to (i) refiners as a critical feedstock for the production of base lubricants and (ii) industrial customers as a lower cost,
higher BTU alternative to diesel fuel. Our assets focused on servicing industrial end-markets include processing facilities, tanker trucks, vacuum trucks and trailers, and railcars. UMO volume is sourced from participants within the
automotive service industry (e.g. quick lube shops, auto dealerships, retail automotive service providers, etc.) and a diverse array of commercial and industrial operations across the trucking, railroad, manufacturing and mining industries. We have
established relationships with RFO customers located throughout the United States, typically consisting of re-refiners and energy-intensive industries that require the use of a boiler or furnace, such as the asphalt, pulp, paper and bunker fuel
markets.
Based on currently available information we expect the sale of TFI to be completed in the second quarter of 2014 and
believe the carrying value of TFI at December 31, 2013 does not exceed its net realizable value. We plan to apply all net proceeds from the sale toward the reduction of debt and general corporate purposes.
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Governmental Regulation, including Environmental Regulation and Climate Change
Our operations are subject to stringent United States federal, state and local laws and regulations regulating the discharge of materials
into the environment or otherwise relating to health and safety or the protection of the environment. Additional laws and regulations, or changes in the interpretations of existing laws and regulations, that affect our business and operations may be
adopted, which may in turn impact our financial condition. The following is a summary of the more significant existing health, safety and environmental laws and regulations to which our operations are subject.
Hazardous Substances and Waste.
The United States Comprehensive Environmental Response, Compensation, and Liability Act, as
amended, referred to as CERCLA or the Superfund law, and comparable state laws, impose liability without regard to fault or the legality of the original conduct on certain defined persons, including current and prior owners
or operators of a site where a release of hazardous substances occurred and entities that disposed or arranged for the disposal of the hazardous substances found at the site. Under CERCLA, these responsible persons may be liable for the
costs of cleaning up the hazardous substances, for damages to natural resources and for the costs of certain health studies.
In the course of our operations, we occasionally generate materials that are considered hazardous substances and, as a
result, may incur CERCLA liability for cleanup costs. Also, claims may be filed for personal injury and property damage allegedly caused by the release of hazardous substances or other pollutants. We also generate solid wastes that are subject to
the requirements of the United States Resource Conservation and Recovery Act, as amended, or RCRA, and comparable state statutes.
Although we use operating and disposal practices that are standard in the industry, hydrocarbons or other wastes may have been released at properties owned or leased by us now or in the past, or at other
locations where these hydrocarbons and wastes were taken for treatment or disposal. Under CERCLA, RCRA and analogous state laws, we could be required to clean up contaminated property (including contaminated groundwater), or to perform remedial
activities to prevent future contamination.
Air Emissions.
The Clean Air Act, as amended, or CAA, and
similar state laws and regulations restrict the emission of air pollutants and also impose various monitoring and reporting requirements. These laws and regulations may require us to obtain approvals or permits for construction, modification or
operation of certain projects or facilities and may require use of emission controls.
Global Warming and Climate Change.
While we do not believe our operations raise climate change issues different from those generally raised by the commercial use of fossil fuels, legislation or regulatory programs that restrict greenhouse gas emissions in areas where we conduct
business or that would require reducing emissions from our truck fleet could increase our costs.
Water Discharges.
We
operate facilities that are subject to requirements of the United States Clean Water Act, as amended, or CWA, and analogous state laws for regulating discharges of pollutants into the waters of the United States and regulating quality
standards for surface waters. Among other things these laws impose restrictions and controls on the discharge of pollutants, including into navigable waters as well as protecting drinking water sources. Spill prevention, control and counter-measure
requirements under the CWA require implementation of measures to help prevent the contamination of navigable waters in the event of a hydrocarbon spill. Other requirements for the prevention of spills are established under the United States Oil
Pollution Act of 1990, as amended, or OPA, which amended the CWA and applies to owners and operators of vessels, including barges, offshore platforms and certain onshore facilities. Under OPA, regulated parties are strictly liable for
oil spills and must establish and maintain evidence of financial responsibility sufficient to cover liabilities related to an oil spill for which such parties could be statutorily responsible.
Oil Pollution Act.
The United States Oil Pollution Act, as amended, or OPA, governs any facility that has the capacity
to store more than 1,320 gallons of oil and/or petroleum products and has the potential to discharge
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to a navigable water of the United States. All our Industrial Solutions facilities are subject to this regulation, which requires that each facility develop and maintain a Spill
Prevention Control and Countermeasures Plan, or SPCC. The SPCC requires certain planning and training to minimize the potential for oil and/or other petroleum products to be released into a navigable waterway.
National Pollutant Discharge Elimination System.
Our Industrial Solutions Divisions storm water discharges and waste water
discharges are regulated by the National Pollutant Discharge Elimination System, or NPDES, permit program. Many of Industrial Solutions facilities are required to manage their storm water runoff according to a Multi Sector
General Permit issued by the EPA or by a particular state, if the state has been delegated authority to administer the program. Under NPDES, our regulated facilities must maintain a Storm Water Pollution Prevention Plan that identifies certain
best management practices to minimize the off-site impact of any pollutants that may be carried off-site by precipitation. Very few of Industrial Solutions locations require specific waste water discharge permits from industrial processes.
State Environmental Regulations.
Our operations involve the storage, handling, transport and disposal of bulk waste
materials, some of which contain oil, contaminants and other regulated substances. Various environmental laws and regulations require prevention, and where necessary, cleanup of spills and leaks of such materials and some of our operations must
obtain permits that limit the discharge of materials. Failure to comply with such environmental requirements or permits may result in fines and penalties, remediation orders and revocation of permits. In Texas, we are subject to rules and
regulations promulgated by the Texas Railroad Commission and the Texas Commission on Environmental Quality, including those designed to protect the environment and monitor compliance with water quality. In Louisiana, we are subject to rules and
regulations promulgated by the Louisiana Department of Environmental Quality and the Louisiana Department of Natural Resources as to environmental and water quality issues, and the Louisiana Public Service Commission as to allocation of intrastate
routes and territories for waste water transportation. In Pennsylvania, we are subject to the rules and regulations of the Pennsylvania Department of Environmental Protection and the Pennsylvania Public Service Commission. In Ohio, we are subject to
the rules and regulations of the Ohio Department of Natural Resources and the Ohio Environmental Protection Agency. In North Dakota, we are subject to the rules and regulations of the North Dakota Department of Health, the North Dakota Industrial
Commission, Oil and Gas Division, and the North Dakota State Water Commission. In Montana, we are subject to the rules and regulations of the Montana Department of Environmental Quality and the Montana Board of Oil and Gas.
In addition, Industrial Solutions operations involve the storage, handling, transport and disposal of bulk waste materials, some of
which contain oil, contaminants and other regulated substances. Various state environmental laws and regulations require prevention, and where necessary, cleanup of spills and leaks of such materials and some of our operations must obtain permits
that limit the discharge of materials. Failure to comply with such environmental requirements or permits may result in fines and penalties, remediation orders and revocation of permits. For example, in California, Industrial Solutions is subject to
the Department of Toxic Substances Control, or DTSC, controls on the shipment and management of used oil. Industrial Solutions has worked with the California DTSC to develop a testing and reporting agreement to assist transporters of
used motor oil with meeting the states standard.
Occupational Safety and Health Act.
We are subject to the
requirements of the United States Occupational Safety and Health Act, as amended, or OSHA, and comparable state laws that regulate the protection of employee health and safety. OSHAs hazard communication standard requires that
information about hazardous materials used or produced in our operations be maintained and provided to employees, state and local government authorities and citizens.
Saltwater Disposal Wells.
We operate saltwater disposal wells that are subject to the CWA, the Safe Drinking Water Act, or SDWA, and state and local laws and regulations, including
those established by the Underground Injection Control Program of the United States Environmental Protection Agency, or EPA, which establishes the minimum program requirements including for permitting, testing, monitoring, record keeping
and
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reporting of injection well activities. All of our saltwater disposal wells are located in Ohio, Mississippi, Texas, North Dakota and Montana. Regulations in Texas, Louisiana and Ohio, North
Dakota and Montana require us to obtain a permit to operate each of our saltwater disposal wells in those states. These regulatory agencies have the general authority to suspend or modify one or more of these permits if continued operation of one of
our saltwater wells is likely to result in pollution of freshwater, substantial violation of permit conditions or applicable rules, or leaks to the environment. Any leakage from the subsurface portions of the saltwater wells could cause degradation
of fresh groundwater resources, potentially resulting in cancellation of operations of a well, issuance of fines and penalties from governmental agencies, incurrence of expenditures for remediation of the affected resource and imposition of
liability by third parties for property damages and personal injuries.
Transportation regulations.
We conduct
interstate motor carrier (trucking) operations that are subject to federal regulation by the Federal Motor Carrier Safety Administration, or FMCSA, a unit within the United States Department of Transportation, or USDOT. The
FMCSA publishes and enforces comprehensive trucking safety regulations, including rules on commercial driver licensing, controlled substance testing, medical and other qualifications for drivers, equipment maintenance, and drivers hours of
service, referred to as HOS. The agency also performs certain functions relating to such matters as motor carrier registration (licensing), insurance, and extension of credit to motor carriers customers. Another unit within USDOT
publishes and enforces regulations regarding the transportation of hazardous materials, or hazmat, but the waste water and other water flows we transport by truck are not normally regulated as hazmat at this time.
In December 2010, the FMCSA launched a program called Compliance, Safety, Accountability, or CSA, in an effort to improve
commercial truck and bus safety. A component of CSA is the Safety Measurement System, or SMS, which will continuously analyze all safety violations recorded by the federal and state law enforcement personnel to determine a carriers
safety performance. The SMS is intended to allow the FMCSA to identify carriers with safety issues and intervene to address those problems. Although our trucking operations currently hold a Satisfactory safety rating from FMCSA (the best
rating available), the agency has announced a future intention to revise its safety rating system by making greater use of SMS data in lieu of on-site compliance audits of carriers. We cannot predict the effect of such a revision on our safety
rating.
Our intrastate trucking operations are also subject to the state environmental and waste water transportation
regulations discussed under Environmental Regulations above. Federal law also allows states to impose insurance and safety requirements on motor carriers conducting intrastate business within their borders, and to collect a variety of
taxes and fees on an apportioned basis reflecting miles actually operated within that state.
The HOS regulations establish
the maximum number of hours that a commercial truck driver may work. A new FMCSA rule reducing the number of hours a commercial truck driver may work each day became effective in February 2012 and the compliance date of selected provisions is
July 1, 2013. The new rule, which is intended to reduce the risk of fatigue and fatigue-related crashes and harm to driver health in several ways, among other things prohibits a driver from driving if more than eight hours have passed since the
drivers last off-duty or sleeper berth break of at least 30 minutes and limits the use of the restart to once a week, which, on average, will cut the maximum work week from 82 to 70 hours. The effect of reduced driver hours may raise operating
costs for many if not most truck fleets.
In addition, the USDOTs Pipeline and Hazardous Materials Safety Administration
regulates the transportation of materials deemed by to be hazardous while in transport. A small portion of the materials that Industrial Solutions transports are subject to these regulations, which require certain training and communication rules to
ensure the safe transport of hazardous materials.
Hydraulic Fracturing
. Although we do not directly engage in
hydraulic fracturing activities, certain of our Shale Solutions customers perform hydraulic fracturing operations. While we believe that the adoption of new federal and/or state laws or regulations imposing increased regulatory burdens on hydraulic
fracturing could increase demand for our services, it is possible that it could harm our business by making it more difficult to
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complete, or potentially suspending or prohibiting, crude oil and natural gas wells in shale formations, increasing our and our customers costs of compliance and adversely affecting the
hydraulic fracturing services that we provide for our customers.
Due at least in part to public concerns that have been
raised regarding the potential impact of hydraulic fracturing on drinking water, the EPA has commenced a comprehensive study, at the order of the United States Congress, of the potential environmental and health impacts of hydraulic fracturing
activities. A final draft report is expected to be issued by the EPA for public comment in 2014. On October 15, 2012, a new rule promulgated by the EPA that established new air emission controls for crude oil and natural gas production and
natural gas processing operations became effective. The rule includes New Source Performance Standards, or NSPS, to address emissions of sulfur dioxide and volatile organic compounds, or VOCs, and a separate set of emission
standards to address hazardous air pollutants associated with oil and natural gas production and processing activities. EPAs final rule requires the reduction of VOC emissions from crude oil and natural gas production facilities by mandating
the use of green completions for hydraulic fracturing, which requires the operator to recover rather than vent the gas and natural gas liquids that come to the surface during completion of the fracturing process.
Legislation, including bills known collectively as the Fracturing Responsibility and Awareness of Chemicals Act, or FRAC Act, has been
introduced before both houses of Congress in the last few sessions to remove the exemption of hydraulic fracturing under the SDWA and to require disclosure to a regulatory agency of chemicals used in the fracturing process and otherwise restrict
hydraulic fracturing. To date, this legislation has not been passed by either house.
Various state, regional and local
governments have implemented, or are considering, increased regulatory oversight of hydraulic fracturing through additional permit requirements, operational restrictions, disclosure requirements, and temporary or permanent bans on hydraulic
fracturing in certain environmentally sensitive areas such as certain watersheds. The North Dakota Industrial Commission, Oil and Gas Division recently proposed regulations requiring owners, operators, and service companies to post the composition
of the hydraulic fracturing fluid used during certain hydraulic fracturing stimulations on the FracFocus Chemical Disclosure Registry. The availability of information regarding the constituents of hydraulic fracturing fluids could potentially make
it easier for third parties opposing the hydraulic fracturing process to initiate legal proceedings based on allegations that specific chemicals used in the fracturing process could adversely affect groundwater. In addition, North Dakota recently
proposed regulations prohibiting the discharge of fluids, wastes, and debris other than drill cuttings into open pits.
Employees
As of December 31, 2013, we had approximately 2,200 full time employees, of whom approximately 300 were executive,
managerial, sales, general, administrative, and accounting staff, and 1,900 were truck drivers, service providers and field workers. None of our employees are under collective bargaining agreements. We believe that we maintain a satisfactory working
relationship with our employees and we have not experienced any significant labor disputes.
Additional Information
Information that we file with or furnish to the SEC, including our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current
Reports on Form 8-K, and any amendments to or exhibits included in these reports, are available free of charge on our website at www.nuverra.com soon after such reports are filed with or furnished to the SEC. From time to time, we also post
announcements, updates, events, investor information and presentations on our website in addition to copies of all recent press releases. Our reports, including any exhibits included in such reports, that are filed with or furnished to the SEC are
also available on the SECs website at www.sec.gov. You may also read and copy any materials we file with or furnish to the SEC at the SECs Public
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Reference Room at 100 F Street, NE, Room 1580, Washington, D.C. 20549; information on the operation of the Public Reference Room may be obtained by calling the SEC at 1-800-SEC-0330. You may
request copies of these documents from the SEC, upon payment of a duplicating fee, by writing to the SEC at its principal office at 100 F Street, NE, Room 1580, and Washington, D.C. 20549.
Neither the contents of our website nor that maintained by the SEC are incorporated into or otherwise a part of this filing. Further,
references to the URLs for these websites are intended to be inactive textual references only.
This section describes material risks to our businesses that currently are known to us. You should carefully consider the risks described below. If any of the risks and uncertainties described in the
cautionary factors described below actually occurs, our business, financial condition and results of operations could be materially and adversely affected. The risks and factors listed below, however, are not exhaustive. Other sections of this
Annual Report on Form 10-K include additional factors that could materially and adversely impact our business, financial condition and results of operations. Moreover, we operate in a rapidly changing environment. Other known risks that we currently
believe to be immaterial could become material in the future. We also are subject to legal and regulatory changes. New factors emerge from time to time and it is not possible to predict the impact of all these factors on our business, financial
condition or results of operations.
Risks Related to Our Company
We may not be able to grow successfully through future acquisitions or successfully manage future growth, and we may not be able to effectively
integrate the businesses we do acquire.
We have historically grown through strategic acquisitions of other businesses.
We may not be able to continue to identify attractive acquisition opportunities or successfully acquire those opportunities identified. In order to complete acquisitions, we would expect to require additional debt and/or equity financing, which
could increase our interest expense, leverage and shares outstanding. Businesses that we acquire may not perform as expected. Future revenues, profits and cash flows of an acquired business may not materialize due to the failure or inability to
capture expected synergies, increased competition, regulatory issues, changes in market conditions, or other factors beyond our control. In addition, we may not be successful in integrating future acquisitions into our existing operations, which may
result in unforeseen operational difficulties or diminished financial performance or require a disproportionate amount of our managements attention.
Even if we are successful in integrating our current or future acquisitions into our existing operations, we may not derive the benefits, such as operational or administrative synergies or earnings gains,
that we expected from such acquisitions, which may result in the commitment of our capital resources without the expected returns on such capital. Also, competition for acquisition opportunities may escalate, increasing our cost of making further
acquisitions or causing us to refrain from making additional acquisitions.
Additional risks related to acquisitions include,
but are not limited to:
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the potential disruption of our existing businesses;
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entering new markets or industries in which we have limited prior experience;
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difficulties integrating and retaining key management, sales, research and development, production and other personnel or diversion of management
attention from ongoing business concerns to integration matters;
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difficulties integrating or expanding information technology systems and other business processes or administrative infrastructures to accommodate the
acquired businesses;
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complexities associated with managing the combined businesses and consolidating multiple physical locations;
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risks associated with integrating financial reporting and internal control systems; and
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whether any necessary additional debt or equity financing will be available on terms acceptable to us, or at all, and the impact of such financing on
our operating performance and results of operations.
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Our historical mergers and acquisitions make evaluating our
operating results difficult given the significance of these transactions to our business, and historical and unaudited pro forma financial information may not give you an accurate indication of how we will perform in the future.
Our historical acquisition activities, in particular the Power Fuels merger, may make it more difficult for us to evaluate and predict our
future operating performance. Our results of operations for the year ended December 31, 2012 include the results of operations of Power Fuels from the date of acquisition, November 30, 2012, through December 31, 2012. Our results of
operations for the year ended December 31, 2013 include the results of operations of Power Fuels for the full fiscal year. Unaudited pro forma financial information giving effect to the Power Fuels merger does not represent, and should not be
relied upon as reflecting, what our financial position, results of operations or cash flows actually would have been if the transactions referred to therein had been consummated on the dates or for the periods indicated, or what such results will be
for any future date or any future period.
We are vulnerable to the potential difficulties associated with rapid growth.
We believe that our future success depends on our ability to manage the rapid growth that we have experienced, and the
continued growth that we expect to experience organically and through acquisitions. Our growth places additional demands and responsibilities on our management to, among other things, maintain existing customers and attract new customers, recruit,
retain and effectively manage employees, as well as expand operations and integrate customer support and financial control systems. The following factors could present difficulties to us: lack of sufficient executive-level personnel, increased
administrative burden, long lead times associated with acquiring additional equipment; availability of suitable acquisition candidates, trucks, saltwater disposal wells, frac tanks, rail cars, processing facilities and pipeline right-of-way; and the
ability to provide focused service attention to our customers, among others.
Future charges due to possible impairments of assets may
have a material adverse effect on our results of operations and stock price.
As discussed more fully in Note 7 of the
Notes to Consolidated Financial Statements and Managements Discussion and Analysis of Financial Condition and Results of OperationsRecent DevelopmentsImpairment of Long-Lived Assets and Goodwill included in Item 7
herein, during the year ended December 31, 2013 we recorded asset impairments totaling $210.4 million, including $98.5 million of goodwill related to TFI and $111.9 million of long-lived assets related to our Shale Solutions business. If there
is further deterioration in our business operations or prospects, our stock price, the broader economy or our industry, the value of our long-lived assets and goodwill, or those we may acquire in the future, could decrease significantly and result
in additional impairment and financial statement write-offs.
The testing of long-lived assets and goodwill for impairment
requires us to make significant estimates about our future performance and cash flows, as well as other assumptions. These estimates can be affected by numerous factors, including changes in the composition of our reporting units; changes in
economic, industry or market conditions; changes in business operations; changes in competition; or potential changes in the share price of our common stock and market capitalization. Changes in these factors, or differences in our actual
performance compared with estimates of our future performance, could affect the fair value of long-lived assets and goodwill, which may result in further impairment charges.
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The goodwill impairment test has two steps. The first step of the goodwill impairment test,
used to identify potential impairment, compares the fair value of a reporting unit with its carrying amount including goodwill. During the three months ended September 30, 2013, we performed step one of the goodwill impairment test for each of
our four reporting units: the Shale Solutions reporting unit, the Industrial Solutions reporting unit, the Pipeline reporting unit and the AWS reporting unit. To measure the fair value of each reporting unit, we used a combination of the discounted
cash flow method and the guideline public company method. Based on the results of the step-one goodwill impairment review we concluded the fair values of the Shale Solutions, Pipeline and AWS reporting units exceeded their respective carrying
amounts and accordingly, the second step of the impairment test was not necessary for these reporting units. Conversely, we concluded the fair value of the Industrial Solutions reporting unit was less than its carrying value thereby requiring us to
proceed to the second step of the two-step goodwill impairment test. The second step of the goodwill impairment test, used to measure the amount of the impairment loss, compares the implied fair value of reporting unit goodwill with its carrying
amount. The implied fair value of goodwill is determined in the same manner as the amount of goodwill recognized in a business combination. After allocating the fair value of Industrial Solutions to the assets and liabilities of the reporting unit,
we concluded the carrying value of reporting unit goodwill exceeded its implied fair value. Accordingly, we recognized a goodwill impairment charge of $98.5 million in 2013 which is recorded within loss from discontinued operations in the
accompanying Consolidated Statements of Operations.
We have $408.7 million in goodwill as of December 31, 2013 related to our
Shale Solutions reportable segment, which has been allocated to our Shale Solutions, Pipeline and AWS reporting units. As described in the preceding paragraphs, the results of our impairment test during the third quarter of 2013, which we updated
through September 30, 2013 (our annual testing date), indicated that the goodwill relating to each of these reporting units was not impaired at June 30, 2013 and September 30, 2013, since the estimated fair values of all reporting
units exceeded their carrying values. With respect to the Pipeline and AWS reporting units, the estimated fair values of the reporting units exceeded their carrying values by a substantial amount. However, while no impairment was indicated as a
result of our analysis and testing at June 30, 2013, September 30, 2013, or from our subsequent review at December 31, 2013, we determined that our Shale Solutions reporting unit, with goodwill of $390.7 million, had an estimated fair
value that exceeded its carrying value by less than 3.5 percent.
The fair values of each of the reporting units as well as
the related assets and liabilities utilized to assess the 2013 impairment were measured using Level 2 and Level 3 inputs as described in Note 11 of the Notes to Consolidated Financial Statements. We believe the assumptions used in our
discounted cash flow analysis are appropriate and result in reasonable estimates of the implied fair value of each reporting unit. However, these assumptions are subject to uncertainty and relatively small declines in the future performance or cash
flows of the Shale Solutions reporting unit or small changes in other key assumptions may result in the recognition of impairment charges, which could be significant. We believe the most significant assumption used in our analysis is the expected
improvement in the margins and overall profitability of our reporting units. In order to evaluate the sensitivity of the fair value calculations on the goodwill impairment test, a hypothetical decline of greater than 65 basis points in the operating
margin in our Shale Solutions reporting unit would result in an estimated carrying value in excess of its fair value, requiring us to proceed to the second step of the goodwill impairment test. Additionally, we may not meet our revenue growth
targets, our working capital needs and capital expenditures may be higher than forecast, changes in credit or equity markets may result in changes to our cost of capital and discount rate and general business conditions may result in changes to the
terminal value assumptions for our reporting units. One or more of these factors, among others, could result in additional impairment charges.
In evaluating the reasonableness of our fair value estimates, we consider (among other factors) the relationship between our book value, the market price of our common stock and the fair value of our
reporting units. At December 31, 2013, the closing market price of our common stock was $16.79 per share compared to our book value per share of $24.79 as of such date. Our assessment assumes this relationship is temporary; however, if our book
value per share continues to exceed our market price per share for an extended period of time, this would likely indicate the occurrence of events or changes that could cause us to revise our fair value estimates and perform a step-two goodwill
impairment analysis. While we believe that our estimates of fair value are reasonable, we will continue to monitor and evaluate this relationship in 2014.
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In the fourth quarter of 2013, we announced a plan to realign our Shale Solutions business
into three operating divisions: (1) the Northeast Division comprising the Marcellus and Utica Shale areas (2) the Southern Division comprising the Haynesville, Barnett, Eagle Ford, Mississippian Shale areas and Permian Basin and
(3) the Rocky Mountain Division comprising the Bakken Shale area. The implementation of this organizational realignment is ongoing and is expected to be completed in 2014. In connection with these planned organizational changes, we are
evaluating whether the new operating divisions constitute separate operating segments and if so, whether two or more of them can be aggregated into one or more reportable segments. As the organizational realignment progresses, we will continue to
evaluate its potential impact on our reporting units, which is a level of reporting at which goodwill is tested for impairment. To the extent we conclude the composition of our reporting units has changed, we will be required to allocate goodwill on
a relative fair value basis to the new reporting units and test the newly-allocated goodwill for impairment should triggering events occur. We may experience impairment of our long-lived assets and goodwill as a result of this reallocation.
Should the value of our long-lived assets and goodwill become impaired, we would incur additional charges which could have a
material adverse effect on our consolidated results of operations and could result in our incurring additional net operating losses in future periods. We cannot accurately predict the amount or timing of any impairment of assets. Any future
determination requiring the write-off of a significant portion of long-lived assets or goodwill, although not requiring any additional cash outlay, could have a material adverse effect on our results of operations and stock price.
We may not recognize the anticipated benefits of our proposed disposition of the Industrial Solutions business or any other divestitures we may
pursue in the future.
As described in Note 20 of the Notes to Consolidated Financial Statements herein, in
October 2013, our Board of Directors authorized commencement of a process for the divestiture of TFI, comprising our Industrial Solutions operating segment. There can be no assurance that we will be able to sell TFI. Additionally, we may
evaluate other potential divestiture opportunities with respect to portions of our business from time to time, and may determine to proceed with a divestiture opportunity if and when we believe such opportunity is consistent with our business
strategy and we would be able to realize value for our stockholders in so doing. Any divestiture or disposition, including the planned disposition of TFI, could expose us to significant risks, including, without limitation, fees for legal and
transaction-related services, diversion of management resources, transaction execution risks (including risks resulting from buyer financing and due diligence contingencies and other closing conditions), loss of key personnel and reduction in
revenue. Further, we may be required to retain or indemnify a buyer against certain liabilities and obligations in connection with any such divestiture, and we may also become subject to third-party claims arising out of such divestiture. In
addition, we may not achieve the expected price in a divestiture transaction, including the proposed sale of TFI, which could result in additional losses being recorded. If we do not realize the expected strategic, economic or other benefits of any
divestiture transaction, it could adversely affect our financial condition and results of operations. A divesture of TFI may be subject to various third party consents. There can be no assurances that we will obtain any necessary consents of
governmental authorities or other third parties, including consent of the lenders under our credit facility, that might be required in order for us to sell TFI or effectuate any other divesture. We anticipate that the expected sale of TFI in 2014
will take the form of a stock sale of TFI rather than a sale of TFIs assets which will likely result in a significant capital loss for tax purposes, due to our substantially higher tax basis in TFI stock than TFIs tax basis in its
assets. A significant portion of the goodwill impairment charge recorded in the three months ended September 30, 2013 did not result in a reduction of our tax basis in the stock of TFI. We will not be able to carry any recognized capital loss
resulting from a sale of TFI stock back to prior years as we did not generate capital gains nor pay any federal tax during such prior carryback years. We also do not currently expect to have significant capital gains in the five succeeding
carryforward tax years to offset the capital loss carryforward. Consequently, we expect that any deferred tax asset resulting from a capital loss generated from the sale of TFI stock will require a valuation allowance.
If we are unable to consummate the divestiture of TFI for any reason, our business could be adversely impacted and, in addition, we would
be subject to the risks associated with the continued operation of TFIs
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business, including (without limitation) operational, financial, legal, environmental and regulatory and compliance risks, any or all of which could be material to our business.
We depend on our senior management.
Our success is largely dependent on the skills, experience and efforts of our people and, in particular, the continued services of Mr. Johnsrud, our Chief Executive Officer and Vice Chairman. The
loss of the services of Mr. Johnsrud, or of other members of our senior management, could have a negative effect on our business, financial condition and results of operations and future growth.
We are engaged in litigation relating to China Water and Drinks Inc., our former China water bottling business which was disposed of in 2011, and a
negative outcome in any of these proceedings could materially adversely affect us.
As more fully described Note 16 of
the Notes to Consolidated Financial Statements herein, we and certain of our directors and officers are involved in class action litigation arising from or relating to our acquisition of China Water and Drinks, Inc., or China Water, in
October 2008. This litigation is causing us to incur substantial legal fees and expenses as well as requiring significant management attention. During the quarter ended September 30, 2013, we recorded a charge of $16.0 million to establish an
accrual related to the China Water class action litigation. Settlement discussions with the plaintiffs, through the mediator, continued during the period December 2013 through February 2014. On March 4, 2014, we reached an agreement in principle to
settle this matter by entering into a Stipulation of Settlement with the plaintiffs. Under the terms of the agreement, which must be approved by the court, we have agreed to a cash payment of $13.5 million, a portion of which will come from
remaining insurance proceeds, as well as the issuance of 0.8 million shares of our common stock. We have agreed to provide a floor value of $13.5 million on the equity portion of the settlement. Consequently, if the value of the shares is below
$13.5 million at the time of the final court approval of the Stipulation of Settlement, we will be required to contribute additional shares (or cash, at our option) to make the total value of the settlement equal to $27.0 million. The cash payment
is expected to be deposited into escrow prior to June 30, 2014 and the shares will be issued when the settlement proceeds are distributed to the claimants. The Stipulation of Settlement remains subject to court approval and will resolve all
claims asserted against us and individual defendants in the case. As a result of the pending settlement of this matter, we recorded an additional charge of $7.0 million in the quarter ended December 31, 2013 to effectively accrue for the
proposed settlement. We could incur additional charges in future periods if the market value of the 0.8 million shares exceeds $13.5 million upon issuance.
The litigation environment in which we operate poses a significant risk to our businesses.
We are involved in the ordinary course of business in a number of lawsuits involving employment, commercial, and environmental issues, and other claims for injuries and damages, among other matters. We
may experience negative outcomes in such lawsuits in the future. Any such negative outcomes could have a material adverse effect on our business, liquidity, financial condition and results of operations. We evaluate litigation claims and legal
proceedings to assess the likelihood of unfavorable outcomes and to estimate, if possible, the amount of potential losses. Based on these assessments and estimates, we establish reserves and disclose the relevant litigation claims or legal
proceedings, as appropriate. These assessments and estimates are based on the information available to management at the time and involve a significant amount of judgment. Actual outcomes or losses may differ materially from such assessments and
estimates. The settlement or resolution of such claims or proceedings may have a material adverse effect on our results of operations. In addition, judges and juries in certain jurisdictions in which we conduct business (including certain areas in
the State of Texas) have demonstrated a willingness to grant large verdicts, including punitive damages, to plaintiffs in personal injury, property damage and other tort cases. We use appropriate means to contest litigation threatened or filed
against us, but the litigation environment in these areas poses a significant business risk to us.
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A large verdict was rendered against our subsidiary Heckmann Water Resources (CVR), Inc. in late 2013,
and an adverse outcome in this case could adversely impact our business.
In December 2013, an adverse jury verdict was
rendered against our subsidiary Heckmann Water Resources (CVR), Inc. in Dimmitt County, Texas in a wrongful death case involving a vehicle accident. The jury awarded $281.6 million in damages, which award was subsequently reduced to $163.8 million
when the judgment was signed in January 2014. Our insurers have provided a surety bond of $25.0 million to stay enforcement of the judgment until the Texas appeals process is final. There will be no final resolution of the trial court judgment until
the appellate process is concluded or the case is otherwise resolved. We have agreed to indemnify our insurance carriers, subject to a complete reservation of rights, up to $9.0 million, for losses sustained in excess of the insurance coverage of
$16.0 million in connection with the surety bond. Heckmann Water Resources (CVR), Inc. has filed motions in the trial court seeking, among other things, a new trial. If the motions are denied, it will continue the legal process in the appellate
courts. The post-trial defense phase of this case could be expensive, complex and lengthy and its outcome is difficult to predict. It also may significantly divert the attention of our management and other key personnel. We may also be subject to
negative publicity due to this case. In the event that we are ultimately unsuccessful in our post-trial defense, we could be required to pay significant damages in excess of the amount covered by insurance of $16.0 million. In the event this outcome
occurred, our business, liquidity, financial condition and results of operations would be materially adversely affected. Although our subsidiary Heckmann Water Resources (CVR), Inc. is the defendant in this case, one set of Plaintiffs filed a
post-trial declaratory judgment action alleging that Nuverra Environmental Solutions, Inc. and Heckmann Water Resources Corp. are the alter egos of Heckmann Water Resources (CVR), Inc. and, therefore these entities are jointly and severally liable
for the judgment against Heckmann Water Resources (CVR), Inc. in the wrongful death action. Although we intend to vigorously defend against this declaratory judgment action, a negative outcome in this declaratory judgment action or in any other
aspect of this case could have a material adverse impact on other entities in our corporate structure and on our business as a whole. We currently estimate the potential loss for these cases to range between zero and the maximum judgment amount and
accrued interest. The trial court judgment or any revised result that may be achieved through an appeals process (which could take several years to complete) could result in multiple potential outcomes within this range. Considering the status of
the judicial process and based on currently available information, we have determined that this claim is not yet probable and have not established a reserve for this matter at this time. However, there can be no assurance that we will not be
required to establish significant reserves in connection with this matter in the future, and to the extent any such accrued liability is not fully offset by insurance recoveries it could have a material adverse effect on our business, liquidity,
financial condition and results of operations.
Litigation related to personal injury from the operation of our business may result in
significant liabilities and limit our profitability.
The hazards and risks associated with the transport, storage, and
handling and disposal of our customers waste (such as fires, spills, explosions and accidents) may expose us to personal injury claims, property damage claims and/or products liability claims from our customers or third parties. As protection
against such claims and operating hazards, we maintain insurance coverage against some, but not all, potential losses. However, we may sustain losses for uninsurable or uninsured risks, or in amounts in excess of existing insurance coverage. As more
fully described in Note 16 of the Notes to Consolidated Financial Statements herein, due to the unpredictable nature of personal injury litigation, it is not possible to predict the ultimate outcome of these claims and lawsuits, and we may be held
liable for significant personal injury or damage to property or third parties, or other losses, that are not fully covered by our insurance, which could have a material adverse effect on our business.
Significant capital expenditures are required to conduct our business.
The development of our business and services, excluding acquisition activities, requires substantial capital expenditures. During the year
ended December 31, 2013, we made capital expenditures of approximately $46.6 million primarily including (a) completion of our saltwater pipeline in the Haynesville shale area, (b) new
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disposal wells or upgrades to existing wells, including an expansion of our presence in the Utica shale area, (c) completion of construction of the initial cells of our oilfield waste
landfill in the Bakken shale area and (d) progress payments for a thermal desorption system to expand our solids treatment capabilities, also in the Bakken shale area. A significant portion of our transportation-related capital requirements are
financed through capital leases, which are not included in the capital expenditures figures cited previously. Such equipment additions under capital leases totaled approximately $5.8 million during 2013 and $20.8 million in 2012, as the Company
significantly expanded its fleet during 2012. We continue to focus on improving the utilization of our existing assets and optimizing the allocation of resources in the various shale areas in which we operate. Our capital expenditure program is
subject to market conditions, including customer activity levels, commodity prices, industry capacity and specific customer needs. We may also incur additional capital expenditures for acquisitions. Our planned capital expenditures for 2014, as well
as any acquisitions we choose to pursue, will likely be financed through a combination of cash on hand, cash flow from operations, borrowings under our revolving credit facility and capital leases, and, in the case of acquisitions, issuances of
equity. We may also issue additional debt securities to support growth initiatives. Future cash flows from operations are subject to a number of risks and variables, such as the level of drilling activity and oil and natural gas production of our
customers, prices of natural gas and oil, and the other risk factors discussed herein. Our ability to obtain capital from other sources, such as the capital markets, is dependent upon many of those same factors as well as the orderly functioning of
credit and capital markets. To the extent we fail to have adequate funds, we could be required to reduce our capital spending, or pursue other funding alternatives, which in turn could adversely affect our business and results of operations.
Increases in costs relating to our large fleet of trucks, including driver compensation or difficulty in attracting and retaining
qualified drivers as well as increases in fuel costs, could adversely affect our profitability.
We employed
approximately 1,900 truck drivers as of December 31, 2013. Maintaining a staff of qualified truck drivers is critical to the success of our operations. We have in the past experienced difficulty in attracting and retaining sufficient numbers of
qualified drivers in some of the markets in which we operate, which difficulty is due in part to our high standards for retention of drivers. In addition, due in part to current economic conditions, including the cost of fuel, insurance, and
tractors and the U.S. Department of Transportations regulatory requirements, the available pool of qualified truck drivers has been declining. A shortage of qualified drivers and intense competition for drivers from other companies may create
difficulties in some regions and may require us to pay more to attract and retain qualified drivers. If we are unable to continue to attract and retain a sufficient number of qualified drivers, we could have difficulty meeting customer demands, any
of which could materially and adversely affect our growth and profitability.
The compensation we offer our drivers is subject to market
conditions, and we may find it necessary to increase driver compensation and/or modify the benefits provided to our employees in future periods.
We and other companies in the oil and gas industry suffer from a high turnover rate of drivers. The high turnover rate requires us to continually recruit a substantial number of drivers in order to
operate existing equipment. If we are unable to continue to attract and retain a sufficient number of qualified drivers, we could be forced to, among other things, adjust our compensation packages, increase the number of our trucks without drivers,
or operate with fewer trucks and face difficulty meeting customer demands, any of which could adversely affect our growth and profitability. Additionally, in anticipation of or in response to geographical and market-related fluctuations in the
demand for our services, we strategically relocate our equipment and personnel from one area to another, which results in operating inefficiencies, increased labor, fuel and other operating costs and could adversely affect our growth and
profitability. As a result, our driver and employee training and orientation costs could be negatively impacted. We also utilize the services of independent contractor truck drivers to supplement our trucking capacity in the Bakken and Marcellus
Shale areas on an as-needed basis. There can be no assurance that we will be able to enter into these types of arrangements on favorable terms, or that there will be sufficient qualified independent contractors available to meet our needs, which
could have a material adverse impact on our business, financial condition and results of operations.
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Increases in oil, natural gas and diesel prices have a significant impact on our operating
expenses. The price and supply of oil and fuel is unpredictable and fluctuates based on events beyond our control, including geopolitical developments, supply and demand for oil, natural gas and LNG, actions by the Organization of Petroleum
Exporting Countries, or OPEC, and other oil and gas producers, war and unrest in oil producing countries, regional production patterns and environmental concerns.
In addition, the supply of critical infrastructure assets, in particular employee housing, in the Bakken Shale area has not kept pace with the rapid growth in the region caused by the boom in the energy
and environmental services industry. As a result, there is a shortage of fixed housing in the region, making it difficult for energy services operators and other businesses to attract quality, long-term personnel. Through an entity he controls, but
which is separate from the Company, Mr. Johnsrud owns fixed-housing rental units in the Bakken Shale area. However there is no formal arrangement with Mr. Johnsrud to ensure that our employees will be able to rent this housing. There can
be no assurance that there will be sufficient housing available for all of our employees in the Bakken Shale area, which could adversely affect our ability to provide services and our operating results.
We depend on certain key customers for a significant portion of our revenues. The loss of any of these key customers or the loss of any contracted
volumes could result in a decline in our business.
We rely on a limited number of customers for a significant portion
of our revenues. Our three largest customers represented 14%, 14% and 11%, respectively, of our total consolidated revenues for the year ended December 31, 2013 and in total equaled 31% of the Companys consolidated accounts receivable at
December 31, 2013. The loss of all, or even a portion of, the revenues from these customers, as a result of competition, market conditions or otherwise, could have a material adverse effect on our business, results of operations, financial
condition, and cash flows. For example, our 2013 results of operations were adversely affected by conditions which reduced drilling activities by key customers.
The fees charged to customers under our agreements with them may not escalate sufficiently to cover increases in costs and the agreements may be suspended in some circumstances, which would affect
our profitability.
Under our agreements with our customers, we may be unable to increase the fees that we charge our
customers at a rate sufficient to offset any increases in our costs. Additionally, some customers obligations under their agreements with us may be permanently or temporarily reduced upon the occurrence of certain events, some of which are
beyond our control, including
force majeure
events.
Force majeure
events may include (but are not limited to) events such as revolutions, wars, acts of enemies, embargoes, import or export restrictions, strikes, lockouts, fires,
storms, floods, acts of God, explosions, mechanical or physical failures of our equipment or facilities of our customers. If the escalation of fees is insufficient to cover increased costs or if any customer suspends or terminates its contracts with
us, our profitability could be materially and adversely affected.
We operate in competitive markets, and there can be no certainty that
we will maintain our current customers or attract new customers or that our operating margins will not be impacted by competition.
The industries in which our business operates are highly competitive. We compete with numerous local and regional companies of varying sizes and financial resources. Competition could intensify in the
future. Furthermore, numerous well-established companies are focusing significant resources on providing similar services to those that we provide that will compete with our services. We cannot assure you that we will be able to effectively compete
with these other companies or that competitive pressures, including possible downward pressure on the prices we charge for our products and services, will not arise. In the event that we cannot effectively compete on a continuing basis, or
competitive pressures arise, such inability to compete or competitive pressures could have a material adverse effect on our business, results of operations and financial condition.
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Our business depends on spending by the oil and natural gas industry in the United States, and this
spending and our business has been, and may continue to be, adversely affected by industry and financial market conditions that are beyond our control.
We depend on our customers willingness to make operating and capital expenditures to explore, develop and produce oil and natural gas in the United States. Declines in these expenditures could
result in project modification, delays or cancellations, general business disruptions, and delays in, or nonpayment of, amounts owed to us. Customers expectations for lower market prices for oil and natural gas, as well as the availability of
capital for operating and capital expenditures, may also cause our customers to curtail spending, thereby reducing demand for our services.
Industry conditions are influenced by numerous factors over which we have no control, including:
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the domestic and worldwide price and supply of natural gas, natural gas liquids and oil, including the natural gas inventories and oil reserves of the
United States;
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changes in the level of consumer demand;
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the price and availability of alternative fuels;
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the availability, proximity and capacity of pipelines, other transportation facilities and processing facilities;
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the level and effect of trading in commodity futures markets, including by commodity price speculators and others;
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the nature and extent of domestic and foreign governmental regulations and taxes;
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the ability of the members of OPEC to agree to and maintain oil price and production controls;
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political instability or armed conflict in oil and natural gas producing regions; and
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overall domestic and global economic and market conditions.
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The volatility of the oil and natural gas industry and the impact on exploration and production activity could adversely impact the level of drilling activity by some of our customers or in some of the
regions in which we operate. For example, natural gas spot prices fell significantly beginning in 2011 and the number of active drilling rigs operating in the Haynesville, Barnett and Marcellus Shale areas has declined with many of these rigs moving
to other oil- and liquids-rich shale areas such as the Utica, Eagle Ford, Bakken and Permian Basin. This transition in exploration and production activity has caused and may continue to cause a decline in the demand for our services in affected
regions where we operate and has adversely affected and may continue to affect the price of our services and the financial results of our operations. In addition, reduced discovery rates of new oil and natural gas reserves in our market areas also
may have a negative long-term impact on our business, even in an environment of stronger oil and natural gas prices, due to reduced fracking activity and reduced produced water from existing producing wells to the extent existing production is not
replaced and the number of producing wells for us to service declines.
Limitations on the availability of capital, or higher
costs of capital, for financing expenditures may cause E&P companies and other oil and natural gas producers to reduce their capital budgets. Any such cuts in spending could curtail drilling programs as well as discretionary spending on well
services, which could adversely affect the demand for our services, the rates we can charge and our utilization. Any of these conditions or events could adversely affect our operating results and cash flows.
Any interruption in our services due to pipeline ruptures or spills or necessary maintenance could impair our financial performance and negatively
affect our brand.
Our fixed water transport pipelines are susceptible to ruptures and spills, particularly during
start up and initial operation, and require ongoing inspection and maintenance. For example, in 2010 and 2011, we had breaks
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in our 50-mile underground pipeline network in the Haynesville Shale area that resulted in delays in transporting our customers water and resulted in significant repair and remediation
costs. We may experience further difficulties in maintaining the operation of our pipelines, which may cause downtime and delays. We also may be required to periodically shut down all or part of our pipeline for regulatory compliance and inspection
purposes. Any interruption in our services due to pipeline breakdowns or necessary maintenance, inspection or regulatory compliance could reduce sales revenues and earnings and result in remediation costs. Transportation interruptions at our
pipelines, even if only temporary, could severely harm our business and reputation.
Our operations are subject to risks inherent in the
oil and natural gas industry, some of which are beyond our control. These risks may not be fully covered under our insurance policies.
Our operations are subject to operational hazards, including accidents or equipment issues that can cause pollution and other damage to the environment. For example, produced water from our pipelines has
leaked into private property on several occasions. As required pursuant to applicable law, we remediated the environmental impact, including related to site investigation and soil, groundwater and surface water cleanup.
In addition, hazards inherent in the oil and natural gas industry, such as, but not limited to, accidents, blowouts, explosions,
pollution and other damage to the environment, fires and hydrocarbon spills, may delay or halt operations at extraction sites which we service. These conditions can cause:
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personal injury or loss of life;
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liabilities from pipeline breaks and accidents by our fleet of trucks and other equipment;
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damage to or destruction of property, equipment and the environment; and
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the suspension of operations.
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The occurrence of a significant event or a series of events that together are significant, or adverse claims in excess of the insurance coverage that we maintain or that are not covered by insurance,
could have a material adverse effect on our financial condition and results of operations. Litigation arising from a catastrophic occurrence at a location where our equipment and services are being used may result in our being named as a defendant
in lawsuits asserting large claims.
We maintain insurance coverage that we believe to be customary in the industry against
these hazards. We may not be able to maintain adequate insurance in the future at rates we consider reasonable. In addition, insurance may not be available to cover any or all of the risks to which we are subject, or, even if available, the coverage
provided by such insurance may be inadequate, or insurance premiums or other costs could make such insurance prohibitively expensive. It is likely that, in our insurance renewals, our premiums and deductibles will be higher, and certain insurance
coverage either will be unavailable or considerably more expensive than it has been in the recent past. In addition, our insurance is subject to coverage limits, and some policies exclude coverage for damages resulting from environmental
contamination.
Improvements in or new discoveries of alternative energy technologies or fracking methodologies could have a material
adverse effect on our financial condition and results of operations.
Because our business depends on the level of
activity in the oil and natural gas industry, any improvement in or new discoveries of alternative energy technologies (such as wind, solar, geothermal, fuel cells and biofuels) that increase the use of alternative forms of energy and reduce the
demand for oil and natural gas could have a material adverse impact on our business, financial condition and results of operations. In addition, technological changes could decrease the quantities of water required for fracking operations or
otherwise affect demand for our services.
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Seasonal weather conditions and natural disasters could severely disrupt normal operations and harm
our business.
Areas in which we operate are adversely affected by seasonal weather conditions, primarily in the winter
and spring. During periods of heavy snow, ice or rain, our customers may curtail their operations or we may be unable to move our trucks between locations or provide other services, thereby reducing demand for, or our ability to provide services and
generate revenues. For example, many municipalities impose weight restrictions on the paved roads that lead to our customers jobsites in the spring due to the muddy conditions caused by spring thaws, limiting our access and our ability to
provide service in these areas. In 2013 and the first quarter of 2014, inclement weather negatively impacted our operations in Pennsylvania and North Dakota . In September 2011 and October 2012, portions of Pennsylvania and other areas in the
eastern United States had record rainfall and flooding. In February 2011, portions of Texas had record snowfalls. During those periods, we and our customers had to significantly reduce or halt operations, resulting in a loss of revenue. In addition,
the regions in which we operate have in the past been, and may in the future be, affected by natural disasters such as hurricanes, windstorms, floods and tornadoes. In certain areas, our business may be dependent on our customers ability to
access sufficient water supplies to support their hydraulic fracturing operations. To the extent severe drought conditions or other factors prevent our customers from accessing adequate water supplies, our business could be negatively impacted.
Future natural disasters or inclement weather conditions could severely disrupt the normal operation of our business, or our customers business, and have a material adverse effect on our financial condition and results of operations.
Our operating margins and profitability may be negatively impacted by changes in fuel and energy costs, in part due to the fixed cost
structure of our business.
Our business is dependent on availability of fuel for operating our fleet of trucks.
Changes and volatility in the price of crude can adversely impact the prices for these products and therefore affect our operating results. The price and supply of fuel is unpredictable and fluctuates based on events beyond our control, including
geopolitical developments, supply and demand for oil and gas, actions by OPEC and other oil and gas producers, war and unrest in oil producing countries, regional production patterns, and environmental concerns.
Furthermore, our facilities, fleet and personnel subject us to fixed costs, which make our margins and earnings sensitive to changes in
revenues. In periods of declining demand, our fixed cost structure may limit our ability to cut costs, which may put us at a competitive disadvantage to firms with lower cost structures, or may result in reduced operating margins and/or operating
losses.
Our financial and operating performance may be affected by the inability to renew landfill operating permits, obtain new
landfills and expand existing ones.
We currently own one landfill and our ability to meet our financial and operating
objectives may depend, in part, on our ability to acquire, lease, or renew landfill operating permits, expand existing landfills and develop new landfill sites. It has become increasingly difficult and expensive to obtain required permits and
approvals to build, operate and expand solid waste management facilities, including landfills. Operating permits for landfills in states where we operate must generally be renewed every five to ten years, although some permits are required to be
renewed more frequently. These operating permits often must be renewed several times during the permitted life of a landfill. The permit and approval process is often time consuming, requires numerous hearings and compliance with zoning,
environmental and other requirements, is frequently challenged by special interest and other groups, and may result in the denial of a permit or renewal, the award of a permit or renewal for a shorter duration than we believed was otherwise required
by law, or burdensome terms and conditions being imposed on our operations. We may not be able to obtain new landfill sites or expand the permitted capacity of our landfills when necessary. Any of these circumstances could adversely affect our
operating results.
Our ability to utilize net operating loss carryforwards in the future may be subject to substantial limitations.
We believe that our ability to use our U.S. federal net operating loss carryforwards and other tax attributes in
future years may be limited. Internal Revenue Code Sections 382 and 383 provide annual limitations with
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respect to the ability of a corporation to utilize its net operating loss (as well as certain built-in losses) and tax credit carryforwards, respectively (Tax Attributes), against
future U.S. taxable income, if the corporation experiences an ownership change. In general terms, an ownership change may result from transactions increasing the ownership of certain stockholders in the stock of a corporation by more
than 50 percentage points over a three-year period. The company determined that an ownership change occurred during 2012, for purposes of the rules described above. Moreover, any future transaction or transactions and the timing of such transaction
or transactions could trigger additional ownership changes under Section 382. As a result of the ownership change, utilization of our Tax Attributes will be subject to an overall annual limitation determined in part by multiplying the
total adjusted aggregate market value of our common stock immediately preceding the ownership change by the applicable long-term tax-exempt rate, possibly subject to increase based on the built-in gain, if any, in our assets at the time of the
ownership change. Any unused annual limitation may be carried over to later years. While we do not expect the existing Section 382 limitation to result in federal Tax Attributes expiring unused, future U.S. taxable income may not be fully
offset by existing Tax Attributes in a given year if such income exceeds our annual limitation.
We are self-insured against many
potential liabilities, and our reserves may not be sufficient to cover future claims.
We maintain high deductible or
self-insured retention insurance policies for certain exposures including automobile, workers compensation and employee group health insurance. We carry policies for certain types of claims to provide excess coverage beyond the underlying
policies and per incident deductibles or self-insured retentions. Because many claims against us do not exceed the deductibles under our insurance policies, we are effectively self-insured for a substantial portion of our claims. Our insurance
accruals are based on claims filed and estimates of claims incurred but not reported. The insurance accruals are influenced by our past claims experience factors, which have a limited history, and by published industry development factors. The
estimates inherent in these accruals are determined using actuarial methods that are widely used and accepted in the insurance industry. If our insurance claims increase or if costs exceed our estimates of insurance liabilities, we could experience
a decline in profitability and liquidity, which would adversely affect our business, financial condition or results of operations. In addition, should there be a loss or adverse judgment or other decision in an area for which we are self-insured,
then our business, financial condition, results of operations and liquidity may be adversely affected.
We evaluate our
insurance accruals, and the underlying assumptions, regularly throughout the year and make adjustments as needed. While we believe that the recorded amounts are reasonable, there can be no assurance that changes to our estimates will not occur due
to limitations inherent in the estimation process. Changes in our assumptions and estimates could have an adverse impact on our financial condition, results of operations and liquidity.
Security breaches and other disruptions could compromise our information and expose us to liability, which would cause our business and reputation to suffer.
In the ordinary course of business, we collect and store sensitive data, including intellectual property, our proprietary business
information and that of our customers, suppliers and business partners, and personally identifiable information of our customers and employees, in our data centers and on our networks. The secure processing, maintenance and transmission of this
information is critical to our operations and business strategy. Despite our security measures, our information technology and infrastructure may be vulnerable to attacks by hackers or breached due to employee error, malfeasance or other
disruptions. Any such breach could compromise our networks and the information stored there could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or other loss of information could result in legal claims or proceedings,
liability under laws that protect the privacy of personal information, and regulatory penalties, disrupt our operations and the services we provide to customers, and damage our reputation, and cause a loss of confidence in our products and services,
which could adversely affect our business/operating margins, revenues and competitive position.
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A failure in our operational systems, or those of third parties, may adversely affect our business.
Our business is dependent upon our operational systems to process a large amount of data. If any of our financial,
operational, or other data processing systems fail or have other significant shortcomings, our financial results could be adversely affected. Our financial results could also be adversely affected if an employee causes our operational systems to
fail, either as a result of inadvertent error or by deliberately tampering with or manipulating our operational systems. In addition, dependence upon automated systems may further increase the risk that operational system flaws, employee tampering
or manipulation of those systems could result in losses that are difficult to detect. We are heavily reliant on technology for communications, financial reporting, treasury management and many other important aspects of our business. Any failure in
our operational systems could have a material adverse impact on our business. Third-party systems on which we rely could also suffer operational failures. Any of these occurrences could disrupt our business or otherwise have an adverse effect on our
financial condition and results of operations.
Risks Related to Our Indebtedness
Our substantial level of indebtedness could adversely affect our financial condition and prevent us from fulfilling our obligations under our
indebtedness.
As of December 31, 2013, we had approximately $555.2 million of indebtedness, net of premiums and
discounts, outstanding on a consolidated basis, of which approximately $155.9 million was secured, including $136.0 million outstanding under our senior secured revolving credit facility and $19.9 million of capital leases for new trucks acquired in
2012 and 2013 and other vehicle financings. In February 2014, our existing senior secured revolving credit facility was replaced with an asset-backed revolving credit facility, which provides a maximum credit amount of $200.0 million, which can be
increased to $225.0 million through an accordion feature. Borrowings under our credit facility effectively rank senior to our unsecured indebtedness, including our $400.0 million aggregate principal amount of 9.875% Senior Notes due 2018 (the
2018 Notes), to the extent of the value of the assets securing such debt. We had approximately $38.8 million of availability (net of approximately $4.4 million in outstanding letters of credit) under our credit facility as of
March 3, 2014. Our substantial level of indebtedness increases the risk that we may be unable to generate cash sufficient to pay amounts due in respect of our indebtedness. Our substantial level of indebtedness could have other important
consequences. For example, our level of indebtedness and the terms of our debt agreements may:
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make it more difficult for us to satisfy our financial obligations under our other indebtedness and our contractual and commercial commitments and
increase the risk that we may default on our debt obligations;
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prevent us from raising the funds necessary to repurchase the 2018 Notes tendered to us if there is a change of control, which would constitute a
default under the indenture governing the 2018 Notes;
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heighten our vulnerability to downturns in our business, our industry or in the general economy and restrict us from exploiting business opportunities
or making acquisitions;
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limit managements discretion in operating our business;
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require us to dedicate a substantial portion of our cash flow from operations to payments on our indebtedness, thereby reducing the availability of our
cash flow to fund working capital, capital expenditures, and other general corporate purposes;
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place us at a competitive disadvantage compared to our competitors that have less debt;
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limit our ability to borrow additional funds;
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constrain our ability to fund increased working capital needs in a rapid growth environment; and
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limit our flexibility in planning for, or reacting to, changes in our business, the industry in which we operate or the general economy.
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Each of these factors may have a material and adverse effect on our financial condition and
viability. Our ability to make payments with respect to the 2018 Notes and to satisfy our other debt obligations will depend on our future operating performance, which will be affected by prevailing economic conditions and financial, business and
other factors affecting us and our industry, many of which are beyond our control. In addition, the indenture governing the 2018 Notes and the credit facility documentation contain restrictive covenants that will affect our ability to engage in
activities that may be in our long-term best interests. Our failure to comply with those covenants could result in an event of default that, if not cured or waived, could result in the acceleration of all of our debt.
Borrowings under our credit facility bear interest at variable rates. If we were to borrow funds and these rates were to increase
significantly, our ability to borrow additional funds may be reduced and the risks related to our substantial indebtedness would intensify. While we may enter into agreements limiting our exposure to higher interest rates, any such agreements may
not offer complete protection for this risk.
Despite existing debt levels, we may still be able to incur substantially more debt, which
would increase the risks associated with our leverage.
Even with our existing debt levels, we and our subsidiaries may
be able to incur substantial amounts of additional debt in the future, some or all of which may be secured. As of March 3, 2014 we had approximately $38.8 million of borrowing availability (net of approximately $4.4 million in outstanding
letters of credit) under our credit facility. In addition, the indenture governing the 2018 Notes and the credit facility documentation allow us to issue additional debt, including additional notes, under certain circumstances, which may be
guaranteed by our subsidiaries. Although the terms of the credit facility and the indenture governing the 2018 Notes limit our ability to incur additional debt, these terms do not and will not prohibit us from incurring substantial amounts of
additional debt for specific purposes or under certain circumstances, some or all of which may be secured. If new debt is added to our and our subsidiaries current debt levels, the related risks that we and they now face could intensify and
could further exacerbate the risks associated with our leverage.
We may not be able to generate sufficient cash flow to meet our debt
service, lease payments and other obligations due to events beyond our control.
Our interest expense related to the
2018 Notes, the borrowings under our credit facility, and our other indebtedness was approximately $53.7 million in the year ended December 31, 2013. Our ability to generate cash flows from operations, to make scheduled payments on or refinance
our indebtedness and to fund working capital needs and planned capital expenditures will depend on our future financial performance and our ability to generate cash in the future. Our future financial performance will be affected by a range of
economic, financial, competitive, business and other factors that we cannot control, such as general economic, legislative, regulatory and financial conditions in our industry, the economy generally or other risks described in our reports filed with
the SEC. A significant reduction in operating cash flows resulting from changes in economic, legislative or regulatory conditions, increased competition or other events beyond our control could increase the need for additional or alternative sources
of liquidity and could have a material adverse effect on our business, financial condition, results of operations, prospects and our ability to service our debt and other obligations. If we are unable to service our indebtedness or to fund our other
liquidity needs, we may be forced to adopt an alternative strategy that may include actions such as reducing or delaying capital expenditures, selling assets, restructuring or refinancing our indebtedness, seeking additional capital, or any
combination of the foregoing. If we raise additional debt, it would increase our interest expense, leverage and our operating and financial costs. We cannot assure you that any of these alternative strategies could be affected on satisfactory terms,
if at all, or that they would yield sufficient funds to make required payments on our indebtedness or to fund our other liquidity needs. Reducing or delaying capital expenditures or selling assets could delay future cash flows. In addition, the
terms of existing or future debt agreements may restrict us from adopting any of these alternatives. We cannot assure you that our business will generate sufficient cash flows from operations or that future borrowings will be available in an amount
sufficient to enable us to pay our indebtedness or to fund our other liquidity needs.
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If for any reason we are unable to meet our debt service and repayment obligations, we would
be in default under the terms of the agreements governing our indebtedness, which would allow our creditors at that time to declare all outstanding indebtedness to be due and payable. This would likely in turn trigger cross-acceleration or
cross-default rights between our applicable debt agreements. Under these circumstances, our lenders could compel us to apply all of our available cash to repay our borrowings or they could prevent us from making payments on the 2018 Notes or our
other indebtedness. In addition, the lenders under our credit facility or other secured indebtedness could seek to foreclose on our assets that are their collateral. If the amounts outstanding under our indebtedness were to be accelerated, or were
the subject of foreclosure actions, we cannot assure you that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders.
Our credit facility and the indenture governing the 2018 Notes impose significant operating and financial restrictions on us and our subsidiaries that may prevent us from pursuing certain business
opportunities and restrict our ability to operate our business.
The credit facility and the indenture governing the
2018 Notes contain covenants that restrict our and our subsidiaries ability to take various actions, such as:
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transferring or selling assets;
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paying dividends or distributions, buying subordinated indebtedness or securities, making certain investments or making other restricted payments;
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incurring or guaranteeing additional indebtedness or issuing preferred stock;
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creating or incurring liens;
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incurring dividend or other payment restrictions affecting subsidiary guarantors;
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consummating a merger, consolidation or sale of all or substantially all our assets;
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entering into transactions with affiliates;
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engaging in business other than a business that is the same or similar, reasonably related, complementary or incidental to our business;
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making capital expenditures;
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entering into sale and leaseback transactions; and
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prepaying, redeeming or repurchasing debt prior to stated maturities.
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In addition, our credit facility requires, and any future credit facilities will likely require, us to comply with specified financial
ratios. A breach of any of the foregoing covenants under the indenture governing the Notes or the credit facility, as applicable, could result in a default. In addition, any debt agreements we enter into in the future may further limit our ability
to enter into certain types of transactions.
The maximum amount we can borrow under our credit facility is subject to
contractual and borrowing base limitations which could significantly and negatively impact our future access to capital required to operate our business. Borrowing base limitations are based upon eligible accounts receivable and equipment. If the
value of our accounts receivable or equipment decreases for any reason, or if some portion of our accounts receivable or equipment is deemed ineligible under the terms of our credit facility documentation, the amount we can borrow under the credit
facility would be reduced. These limitations could have a material adverse impact on our liquidity and financial condition. In addition, the administrative agent for our credit facility has the periodic right to perform an appraisal of the assets
comprising our borrowing base. If an appraisal results in a reduction of the borrowing base, then a portion of the outstanding indebtedness under the credit facility could become
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immediately due and payable. Any such repayment obligation could have a material adverse impact on our liquidity and financial condition.
We may also be prevented from taking advantage of business opportunities that arise because of the limitations imposed on us by such
restrictive covenants. These restrictions may also limit our ability to plan for or react to market conditions, meet capital needs or otherwise restrict our activities or business plans and adversely affect our ability to finance our operations,
enter into acquisitions, execute our business strategy, effectively compete with companies that are not similarly restricted or engage in other business activities that would be in our interest. In the future, we may also incur debt obligations that
might subject us to additional and different restrictive covenants that could affect our financial and operational flexibility. We cannot assure you that we will be granted waivers or amendments to the indenture governing the 2018 Notes, the credit
facility or such other debt obligations if for any reason we are unable to comply with our obligations thereunder or that we will be able to refinance our debt on acceptable terms, or at all, should we seek to do so.
The covenants described above are subject to important exceptions and qualifications. Our ability to comply with these covenants will
likely be affected by events beyond our control, and we cannot assure you that we will satisfy those requirements. A breach of any of these provisions could result in a default under such indenture, credit facility or other debt obligation, or any
future credit facilities we may enter into, which could allow all amounts outstanding thereunder to be declared immediately due and payable, subject to the terms and conditions of the documents governing such indebtedness. If we were unable to repay
the accelerated amounts, our secured lenders could proceed against the collateral granted to them to secure such indebtedness. This would likely in turn trigger cross-acceleration and cross-default rights under any other credit facilities and
indentures. If the amounts outstanding under the 2018 Notes or any other indebtedness outstanding at such time were to be accelerated or were the subject of foreclosure actions, we cannot assure you that our assets would be sufficient to repay in
full the money owed to the lenders or to our other debt holders.
Our borrowings under our credit facility expose us to interest rate
risk.
Our earnings are exposed to interest rate risk associated with borrowings under our credit facility. Our credit
facility carries a floating interest rate; therefore, as interest rates increase, so will our interest costs, which may have a material adverse effect on our results of operations and financial condition.
Our ability to make acquisitions may be adversely impacted by our outstanding indebtedness and by the price of our stock.
Our ability to make future business acquisitions, particularly those that would be financed solely or in part through cash from
operations, will be curtailed due to our obligations to make payments of principal and interest on our outstanding indebtedness. We may not have sufficient capital resources, now or in the future, and may be unable to raise sufficient additional
capital resources on terms satisfactory to us, if at all, in order to meet our capital requirements for such acquisitions. In addition, the terms of our indebtedness include covenants that directly restrict, or have the effect of restricting, our
ability to make certain acquisitions while this indebtedness remains outstanding. To the extent that the amount of our outstanding indebtedness has a negative impact on our stock price, using our common stock as consideration will be less attractive
for potential acquisition candidates. The future trading price of our common stock could limit our willingness to use our equity as consideration and the willingness of sellers to accept our shares and as a result could limit the size and scope of
our acquisition program. If we are unable to pursue strategic acquisitions that would enhance our business or operations, the potential growth of our business and revenues may be adversely affected.
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Risks Related to Our Common Stock
We may issue a substantial number of shares of our common stock in the future and stockholders may be adversely affected by the issuance of those
shares.
We may raise additional capital by issuing shares of common stock, which will increase the number of common
shares outstanding and may result in dilution in the equity interest of our current stockholders and may adversely affect the market price of our common stock. We have filed a shelf registration statement on Form S-3 with the SEC which allows us to
issue up to $400.0 million in debt, equity and hybrid securities. As of December 31, 2013, we had issued 1.8 million shares of common stock at total price of $80.1 million, under this registration statement and could issue up to an
additional $319.9 million of debt, equity or hybrid securities. In addition, we have issued shares of our common stock pursuant to private placement exemptions from Securities Act registration requirements, including 9.5 million shares issued
in connection with the Power Fuels merger, and may do so in connection with acquisitions, the settlement of litigation and other strategic transactions in the future. The issuance, and the resale or potential resale, of shares of our common stock in
connection with acquisitions or otherwise could adversely affect the market price of our common stock, and could be dilutive to our stockholders depending on the performance of the acquired business and other factors.
Our stock price may be volatile, which could result in substantial losses for investors in our securities.
The stock markets have experienced extreme volatility that has often been unrelated to the operating performance of particular companies.
These broad market fluctuations may adversely affect the trading price of our common stock.
The market price of our common
stock may also fluctuate significantly in response to the following factors, some of which are beyond our control:
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|
|
variations in our quarterly operating results;
|
|
|
|
changes in securities analysts estimates of our financial performance;
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|
|
|
inaccurate or negative comments about us on social networking websites or other media channels;
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|
|
|
changes in market valuations of similar companies;
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|
|
announcements by us or our competitors of significant contracts, acquisitions, strategic partnerships, joint ventures, capital commitments, new
products or product enhancements;
|
|
|
|
changes in the price of oil and natural gas;
|
|
|
|
loss of a major customer or failure to complete significant transactions; and
|
|
|
|
additions or departures of key personnel.
|
The trading price of our common stock on the New York Stock Exchange, or NYSE, since our initial public offering has ranged from a high of $107.40 on September 3, 2008 to a low of $13.10
on November 11, 2013. The last reported price of our common stock on the NYSE on March 3, 2014 was $16.34 per share.
We
currently do not intend to pay any dividends on our common stock.
We currently do not intend to pay any dividends on
our common stock, and restrictions and covenants in our debt agreements may prohibit us from paying dividends now or in the future. While we may declare dividends at some point in the future, subject to compliance with such restrictions and
covenants, we cannot assure you that you will ever receive cash dividends as a result of ownership of our common stock and any gains from investment in our common stock may only come from increases in our stock prices, if any.
28
We are subject to anti-takeover effects of certain charter and bylaw provisions and Delaware law, as
well as of our substantial insider ownership.
Provisions of our certificate of incorporation and bylaws, each as
amended and restated, and Delaware law may discourage, delay or prevent a merger or acquisition that stockholders may consider favorable, including transactions in which you might otherwise receive a premium for your shares. In addition, these
provisions may frustrate or prevent any attempts by our stockholders to replace or remove our management and board of directors. These provisions include:
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|
|
authorizing the issuance of blank check preferred stock without any need for action by stockholders;
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|
|
establishing a classified board of directors, so that only approximately one-third of our directors are elected each year;
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|
providing our board of directors the ability to set the number of directors and to fill vacancies on the board of directors occurring between
stockholder meetings;
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|
providing that directors may only be removed only for cause and only by the affirmative vote of the holders of at least a majority in
voting power of our issued and outstanding capital stock; and
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|
|
|
limiting the ability of our stockholders to call special meetings.
|
We are also subject to provisions of the Delaware corporation law that, in general, prohibit any business combination with a beneficial
owner of 15% or more of our common stock for three years following the date the beneficial owner acquired at least 15% of our stock, unless various conditions are met, such as approval of the transaction by our board of directors. Together, these
charter and statutory provisions could make the removal of management more difficult and may discourage transactions that otherwise could involve payment of a premium over prevailing market prices for our common stock.
The existence of the foregoing provisions and anti-takeover measures, as well as the significant amount of common stock beneficially
owned by our Chief Executive Officer and Vice Chairman, Mr. Johnsrud, could limit the price that investors might be willing to pay in the future for shares of our common stock. They could also deter potential acquirers of our company, thereby
reducing the likelihood that you could receive a premium for your common stock in an acquisition.
Risks Related to
Environmental and Other Governmental Regulation
We are subject to United States federal, state and local laws and regulations
relating to health, safety, transportation, and protection of natural resources and the environment. Under these laws and regulations, we may become liable for significant penalties, damages or costs of remediation. Any changes in laws and
regulations could increase our costs of doing business.
Our operations, and those of our customers, are subject to
United States federal, state and local laws and regulations relating to health, safety, transportation and protection of natural resources and the environment and worker safety, including those relating to waste management and transportation and
disposal of produced water and other materials. For example, we are subject to environmental regulation relating to disposal into injection wells, which can pose some risks of environmental liability, including leakage from the wells to surface or
subsurface soils, surface water or groundwater. Liability under these laws and regulations could result in cancellation of well operations, fines and penalties, expenditures for remediation, and liability for property damage and personal injuries.
Our business involves the use, handling, storage, and contracting for recycling or disposal of environmentally sensitive
materials. Accordingly, we are subject to regulation by federal, state, and local authorities establishing investigation and health and environmental quality standards, and liability related thereto, and providing penalties for violations of those
standards. We also are subject to laws, ordinances, and regulations governing investigation
29
and remediation of contamination at facilities we operate or to which we send hazardous or toxic substances or wastes for treatment, recycling, or disposal. In particular, CERCLA imposes joint,
strict, and several liability on owners or operators of facilities at, from, or to which a release of hazardous substances has occurred; parties that generated hazardous substances that were released at such facilities; and parties that transported
or arranged for the transportation of hazardous substances to such facilities. A majority of states have adopted statutes comparable to and, in some cases, more stringent than CERCLA. If we were to be found to be a responsible party under CERCLA or
a similar state statute, we could be held liable for all investigative and remedial costs associated with addressing such contamination. In addition, claims alleging personal injury or property damage may be brought against us as a result of alleged
exposure to hazardous substances resulting from our operations.
Failure to comply with these laws and regulations could
result in the assessment of significant administrative, civil or criminal penalties, imposition of cleanup and site restoration costs and liens, revocation of permits, and orders to limit or cease certain operations. In addition, certain
environmental laws impose strict and/or joint and several liability, which could cause us to become liable for the conduct of others or for consequences of our own actions that were in compliance with all applicable laws at the time of those
actions. For example, if a landfill or disposal operator mismanages our wastes in a way that creates an environmental hazard, we and all others who sent materials could become liable for cleanup costs, fines and other expenses many years after the
disposal or recycling was completed. Future events, such as the discovery of currently unknown matters, spills caused by future pipeline ruptures, changes in existing environmental laws and regulations or their interpretation, and more vigorous
enforcement policies by regulatory agencies, may give rise to additional expenditures or liabilities, which could impair our operations and adversely affect our business and results of operations.
Although we believe that we are in substantial compliance with all applicable laws and regulations, legal requirements are changing
frequently and are subject to interpretation. New laws, regulations and changing interpretations by regulatory authorities, together with uncertainty regarding adequate testing and sampling procedures, new pollution control technology and cost
benefit analysis based on market conditions are all factors that may increase our future capital expenditures to comply with environmental requirements. Accordingly, we are unable to predict the ultimate cost of future compliance with these
requirements or their effect on our operations.
Increased regulation of hydraulic fracturing, including regulation of the quantities,
sources and methods of water use and disposal, could result in reduction in drilling and completing new oil and natural gas wells or minimize water use or disposal, which could adversely impact the demand for our services.
Demand for our services depends, in large part, on the level of exploration and production of oil and gas and the oil and gas
industrys willingness to purchase our services. Most of our customer base uses hydraulic fracturing to drill new oil and gas wells. Hydraulic fracturing is a process that is used to release hydrocarbons, particularly natural gas, from certain
geological formations. The process involves the injection of water (typically mixed with significant quantities of sand and small quantities of chemical additives) under pressure into the formation to fracture the surrounding rock and stimulate
movement of hydrocarbons through the formation. The process is typically regulated by state oil and gas commissions and has been exempt (except when the fracturing fluids or propping agents contain diesel fuels) since 2005 from United States federal
regulation pursuant to the SDWA.
The EPA is conducting a comprehensive study of the potential environmental impacts of
hydraulic fracturing activities, and a committee of the United States House of Representatives is also conducting an investigation of hydraulic fracturing practices. The results of the EPA study and House investigation could lead to restrictions on
hydraulic fracturing. On February 11, 2014, the EPA released revised underground injection control (UIC) program permitting guidance for wells that use diesel fuels during hydraulic fracturing activities. EPA developed the guidance to clarify
how companies can comply with a law passed by Congress in 2005, which exempted hydraulic fracturing operations from the requirement to obtain a UIC permit, except in cases where diesel fuel is used as a fracturing fluid. In a February 5, 2014
memorandum, EPAs Inspector General (IG) announced plans to evaluate how EPA and the states have used their regulatory authority to address potential impacts of hydraulic fracturing on water resources. The IG reportedly will evaluate what
regulatory authority is
30
available to the EPA and states, identify potential threats to water resources from hydraulic fracturing, and evaluate the EPAs and states responses to them. In addition, the
EPA finalized regulations under the CAA in October 2012 regarding certain criteria and hazardous air pollutant emissions from hydraulic fracturing wells and, in October 2011, announced its intention to propose regulations by 2014 under the CWA to
regulate wastewater discharges from hydraulic fracturing and other gas production. Legislation has been introduced before Congress to provide for federal regulation of hydraulic fracturing, including, for example, requiring disclosure of chemicals
used in the fracturing process or seeking to repeal the exemption from the SWDA. If adopted, such legislation would add an additional level of regulation and necessary permitting at the federal level and could make it more difficult to complete
wells using hydraulic fracturing. Similar laws and regulations with respect to chemical disclosure also exist or are being considered by the United States Department of Interior and in several states, including certain states in which we operate,
that could restrict hydraulic fracturing. The Delaware River Basin Commission is also considering regulations which may impact hydrofracturing water practices in certain areas of Pennsylvania, New York, New Jersey and Delaware. Some
local governments have also sought to restrict drilling in certain areas.
Future United States federal, state or local laws
or regulations could significantly restrict, or increase costs associated with hydraulic fracturing and make it more difficult or costly for producers to conduct hydraulic fracturing operations, which could result in a decline in exploration and
production. New laws and regulations, and new enforcement policies by regulatory agencies, could also expressly restrict the quantities, sources and methods of water use and disposal in hydraulic fracturing and otherwise increase our costs and our
customers cost of compliance, which could minimize water use and disposal needs even if other limits on drilling and completing new wells were not imposed. Any decline in exploration and production or any restrictions on water use and disposal
could result in a decline in demand for our services and have a material adverse effect on our business, financial condition, results of operations and cash flows.
Delays or restrictions in obtaining permits by our customers for their operations or by us for our operations could impair our business.
In most states, our customers are required to obtain permits from one or more governmental agencies in order to perform drilling and
completion activities and we may be required to procure permits for construction and operation of our disposal wells and pipelines. Such permits are typically required by state agencies, but can also be required by federal and local governmental
agencies. The requirements for such permits vary depending on the location where our, or our customers, activities will be conducted. As with all governmental permitting processes, there is a degree of uncertainty as to whether a permit will
be granted, the time it will take for a permit to be issued, and the conditions which may be imposed in connection with the granting of the permit. Delays or restrictions in obtaining saltwater disposal well permits could adversely impact our
growth, which is dependent in part on new disposal capacity.
Our customers have been affected by moratoriums on the issuance
of permits that have been imposed upon drilling and completion activities in certain jurisdictions. For example, in December 2010, the State of New York imposed a moratorium on certain drilling and completion activities. In 2011, the state announced
plans to lift the moratorium, however, as of March 2014 the New York moratorium had not been lifted. A similar moratorium has been in place within the Delaware River Basin pending issuance of regulations by the Delaware River Basin Commission. Other
states, including Texas, Arkansas, Pennsylvania, Wyoming and Colorado, have enacted laws and regulations applicable to our business activities, including disclosure of information regarding the substances used in hydraulic fracturing. California is
presently considering similar requirements. The EPA published a rule on January 9, 2014 requiring oil and gas companies using hydraulic fracturing off the coast of California to disclose the chemicals they discharge into the ocean. Some of the
drilling and completion activities of our customers may take place on federal land, requiring leases from the federal government to conduct such drilling and completion activities. In some cases, federal agencies have cancelled oil and natural gas
leases on federal lands. Consequently, our operations in certain areas of the country may be interrupted or suspended for varying lengths of time, causing a loss of revenue and potentially having a materially adverse effect on our operations. Any
such changes could have a material adverse effect on our financial condition and results of operations.
31
We are subject to the trucking safety regulations, which are likely to be amended, and made stricter,
as part of the initiative known as Compliance, Safety, Accountability, or CSA. If our current USDOT safety rating of Satisfactory is downgraded in connection with this initiative, our business and results of our operations
may be adversely affected.
As part of the CSA initiative, the FMCSA is continuously revising its safety rating
methodology and implementation of the same. These revisions will likely link safety ratings more closely to roadside inspection and driver violation data gathered and analyzed from month to month under the FMCSAs new Safety Measurement System,
or SMS and may place increased scrutiny on carriers transporting significant quantities of hazardous material. This linkage could result in greater variability in safety ratings than the current system. Preliminary studies by
transportation consulting firms indicate that Satisfactory ratings (or any equivalent under a new SMS-based system) may become more difficult to achieve and maintain under such a system. If our operations lose their current
Satisfactory rating, which is the highest and best rating under this initiative, we may lose some of our customer contracts that require such a rating, adversely affecting our business prospects and results of operations.
Item 1B.
|
Unresolved Staff Comments
|
None.
We lease our corporate headquarters in Scottsdale, Arizona and we own or lease numerous facilities including administrative offices, sales
offices, truck yards, maintenance and warehouse facilities, a landfill facility, a water treatment facility and well disposal sites in 14 states. We also own or lease 56 saltwater disposal wells in Texas, Ohio, Mississippi, North Dakota and Montana
as of December 31, 2013. We believe that we have satisfactory title to the properties owned and used in our businesses, subject to liens for taxes not yet payable, liens incident to minor encumbrances, liens for credit arrangements (including
liens under our credit facility) and easements and restrictions that do not materially detract from the value of these properties, our interests in these properties, or the use of these properties in our businesses.
We believe all properties that we currently occupy are suitable for their intended uses. We believe that we have sufficient facilities to
conduct our operations. However, we continue to evaluate the purchase or lease of additional properties or the consolidation of our properties, as our business requires.
Item 3.
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Legal Proceedings
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We are party to legal proceedings and potential claims arising in the ordinary course of our business, including claims related to employment matters, contractual disputes, personal injuries and property
damage. In addition, various legal actions, claims and governmental inquiries and proceedings are pending or may be instituted or asserted in the future against us and our subsidiaries. See Litigation in Note 16 of the Notes to
Consolidated Financial Statements herein for a description of our legal proceedings.
Item 4.
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Mine Safety Disclosures
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N/A
32
PART II
Item 5.
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Market for Registrants Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
|
Market Information
The
Company is a Delaware corporation and was formerly named Heckmann Corporation. At the 2013 annual meeting of shareholders, the Companys shareholders approved an amendment to the Companys Certificate of Incorporation to change the
Companys name from Heckmann Corporation to Nuverra Environmental Solutions, Inc. The Companys shares began trading on the New York Stock Exchange under its new name and stock ticker symbol NES,
effective as of the market open on May 20, 2013.
On December 3, 2013, we filed a Certificate of Amendment to our
Restated Certificate of Incorporation in order to effect a one-for-ten reverse split of its common stock and our common stock began trading on the New York Stock Exchange (NYSE) on a split-adjusted basis on the same date. No
fractional shares were issued in connection with the reverse stock split. As a result of the reverse stock split, the number of authorized, issued and outstanding shares of our common stock was reduced to approximately 50.0 million,
27.4 million and 26.0 million, respectively, at December 31, 2013. Furthermore, proportional adjustments were made to stock options, warrants, and restricted stock units. The change in the number of shares resulting from the reverse
stock split has been applied retroactively to all shares and per share amounts presented in this Annual Report on Form 10-K.
The table below presents the high and low daily closing sales prices of the common stock, as reported by the New York Stock Exchange, for
each of the quarters in the years ended December 31, 2013 and 2012, respectively:
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For the Year Ending December 31, 2013
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|
High
|
|
|
Low
|
|
First Quarter
|
|
$
|
44.20
|
|
|
$
|
33.10
|
|
Second Quarter
|
|
$
|
42.70
|
|
|
$
|
28.50
|
|
Third Quarter
|
|
$
|
37.50
|
|
|
$
|
20.60
|
|
Fourth Quarter
|
|
$
|
25.10
|
|
|
$
|
13.10
|
|
|
|
|
For the Year Ending December 31, 2012
|
|
High
|
|
|
Low
|
|
First Quarter
|
|
$
|
68.70
|
|
|
$
|
43.10
|
|
Second Quarter
|
|
$
|
44.10
|
|
|
$
|
28.40
|
|
Third Quarter
|
|
$
|
51.40
|
|
|
$
|
26.00
|
|
Fourth Quarter
|
|
$
|
44.50
|
|
|
$
|
31.10
|
|
Holders
As of December 31, 2013, there were 48 holders of record of our common stock. The number of beneficial holders is substantially greater than the number of record holders because a significant portion
of our common stock is held of record in broker street names.
Dividends
We have not paid any dividends on our common stock to date. The payment of dividends in the future will be contingent upon our revenues
and earnings, if any, capital requirements and general financial condition. The payment of any dividends will be within the discretion of our Board of Directors and will be subject to other limitations as may be contained in our ABL Facility, the
indenture governing the 2018 Notes or other applicable agreements governing our indebtedness. It is the present intention of our Board of Directors to retain all earnings, if any, for use in our business operations and, accordingly, our board does
not anticipate declaring any dividends in the foreseeable future.
33
Sales of Unregistered Equity Securities
We did not make any sales of unregistered equity securities during year ended December 31, 2013, except as previously reported in our
current reports on Form 8-K filed with the SEC.
Repurchase of Equity Securities
During the year ended December 31, 2013, we did not repurchase any options or warrants for shares of our common stock nor did we
repurchase any shares of our common stock.
Recent Performance
The following performance graph and related information shall not be deemed filed with the SEC, nor shall such information be incorporated by reference into any future filing under the
Securities Act or Securities Exchange Act, except to the extent that we specifically incorporate it by reference into such filing.
Performance Graph
The
following graph compares the cumulative total shareholder return for our common stock from January 1, 2009, through December 31, 2013, with the comparable cumulative return of two indices, the S&P 500 Index and the Dow Jones Industrial
Average Index (DJIA).
The chart assumes $100 invested on January 1, 2009, in our common stock and $100 invested at that same
time in each of the two indices.
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|
|
|
|
|
|
|
|
|
|
Company / Index
|
|
January 1,
2009
|
|
|
December 31,
2009
|
|
|
December 31,
2010
|
|
|
December 31,
2011
|
|
|
December 31,
2012
|
|
|
December 31,
2013
|
|
NES
|
|
$
|
100.00
|
|
|
$
|
93.72
|
|
|
$
|
84.40
|
|
|
$
|
111.58
|
|
|
$
|
67.62
|
|
|
$
|
28.17
|
|
S&P 500 Index
|
|
|
100.00
|
|
|
|
122.57
|
|
|
|
141.03
|
|
|
|
144.01
|
|
|
|
167.06
|
|
|
|
221.16
|
|
DJIA Index
|
|
|
100.00
|
|
|
|
122.68
|
|
|
|
139.94
|
|
|
|
151.67
|
|
|
|
167.19
|
|
|
|
216.77
|
|
34
Securities Authorized for Issuance under Equity Compensation Plans
The following table provides information as of December 31, 2013, with respect to shares of our common stock that may be issued under
the Heckmann Corporation 2009 Equity Incentive Plan, which is our only existing equity compensation plan under which grants can be made.
Equity Compensation Plan Information
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|
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|
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|
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|
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|
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|
Plan Category
|
|
Number of securities to
be issued upon exercise of
outstanding
awards
or upon the vesting
of restricted stock
(a)
|
|
|
Weighted-average
exercise price of
outstanding awards
(b)
|
|
|
Number of securities
remaining available for
future issuance under
equity
compensation
plans (excluding
securities reflected in
column (a))
(c )
|
|
Equity compensation plans approved by stockholders (1)(2)
|
|
|
463,679
|
|
|
$
|
39.40
|
|
|
|
417,803
|
|
Equity compensation plans not approved by security holders
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
463,679
|
|
|
$
|
39.40
|
|
|
|
417,803
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
The number of securities to be issued upon exercise of outstanding awards is the sum of options to acquire 0.4 million shares of common stock and 0.2 million
shares of restricted stock awarded under the Heckmann Corporation 2009 Equity Incentive Plan less 0.1 million shares issued thereunder.
|
(2)
|
The weighted-average exercise price does not include shares of restricted stock.
|
35
Item 6.
|
Selected Financial Data
|
The following table presents selected consolidated financial information and other operational data for our business. You should read the following information in conjunction with Item 7 of this
Annual Report on Form 10-K entitled Managements Discussion and Analysis of Financial Condition and Results of Operations, and the consolidated financial statements and related notes included elsewhere in this Annual Report on
Form 10-K.
Income Statement Data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2013
|
|
|
2012 (2)
|
|
|
2011 (3)
|
|
|
2010 (6)
|
|
|
2009 (7)
|
|
|
|
($ in thousands, except per share data)
|
|
Revenue
|
|
$
|
525,816
|
|
|
$
|
256,671
|
|
|
$
|
156,837
|
|
|
$
|
15,208
|
|
|
$
|
3,820
|
|
Loss from operations (1)(4)
|
|
|
(149,659
|
)
|
|
|
(37,574
|
)
|
|
|
(5,412
|
)
|
|
|
(19,513
|
)
|
|
|
(7,474
|
)
|
Loss from continuing operations (1)(5)
|
|
|
(134,040
|
)
|
|
|
(6,597
|
)
|
|
|
(108
|
)
|
|
|
(10,300
|
)
|
|
|
(3,317
|
)
|
(Loss) income from discontinued operations (1)(8)(9)
|
|
|
(98,251
|
)
|
|
|
9,124
|
|
|
|
(22,898
|
)
|
|
|
(4,393
|
)
|
|
|
(392,078
|
)
|
(Loss) income attributable to common stockholders
|
|
|
(232,291
|
)
|
|
|
2,527
|
|
|
|
(23,006
|
)
|
|
|
(14,693
|
)
|
|
|
(395,395
|
)
|
Weighted average shares outstanding used in computing net (loss) income per basic and diluted common share
|
|
|
24,492
|
|
|
|
14,994
|
|
|
|
11,457
|
|
|
|
10,882
|
|
|
|
10,958
|
|
Basic and diluted loss per share from continuing operations
|
|
$
|
(5.47
|
)
|
|
$
|
(0.44
|
)
|
|
$
|
(0.01
|
)
|
|
$
|
(0.95
|
)
|
|
$
|
(0.30
|
)
|
Basic and diluted (loss) income per share from discontinued operations
|
|
$
|
(4.01
|
)
|
|
$
|
0.61
|
|
|
$
|
(2.00
|
)
|
|
$
|
(0.40
|
)
|
|
$
|
(35.78
|
)
|
Net (loss) income per basic and diluted share
|
|
$
|
(9.48
|
)
|
|
$
|
0.17
|
|
|
$
|
(2.01
|
)
|
|
$
|
(1.35
|
)
|
|
$
|
(36.08
|
)
|
(1)
|
During the fourth quarter of 2013, the Companys board of directors approved and committed to a plan to divest the Companys Thermo Fluids Inc. subsidiary,
which comprises its Industrial Solutions business segment. Subsequently, the sales process began and the Company considers TFI to be held for sale. As such, all prior periods have been restated to reflect TFI as discontinued operations. See
Assets Held for Sale and Discontinued Operations in Note 20 of the Notes to Consolidated Financial Statements herein for further information. Loss from operations and loss from continuing operations for the year ended December 31,
2013 includes a long-lived asset impairment charge of $111.9 million, approximately $24.6 million in litigation settlement charges and the write-off of $4.3 million of investments.
|
(2)
|
Loss from operations and loss from continuing operations for the year ended December 31, 2012 includes merger and acquisition costs of $7.7 million, impairment
charges of $2.4 million and $3.7 million related to write-downs of the carrying values of a customer intangible asset and saltwater disposal wells, respectively, and a $1.4 million charge to accrue for the estimated costs of remediation and testing
to comply with Louisiana Department of Environmental Quality requirements. 2012 results include amounts from the acquisitions of Keystone Vacuum, Inc. and related entities, Thermo Fluids Inc., Homer Enterprises, Inc., JB Transportation Services,
Inc. (All Phase), Appalachian Water Services, LLC and Badlands Power Fuels, LLC from their transaction dates of February 3, 2012, April 10, 2012, May 31, 2012, June 15, 2012, September 1, 2012
and November 30, 2012, respectively.
|
(3)
|
2011 results include amounts from the acquisitions of Bear Creek, LLC, Devonian Industries, Inc., Sand Hill Foundation, LLC, Excalibur Energy Services, Inc., and
Blackhawk, LLC and Consolidated Petroleum, Inc. from their acquisition dates of April 1, 2011, April 4, 2011, April 12, 2011, May 5, 2011 and June 14, 2011, respectively.
|
(4)
|
Loss from operations for the years ended December 31, 2011 and 2010 includes charges of $2.1 million and $11.8 million, respectively, for start-up and
commissioning costs associated with a pipeline in the Haynesville shale area.
|
(5)
|
In addition to the transactions described under item (1), loss from continuing operations for the year ended December 31, 2012 includes a $2.6
million charge for the write-off of unamortized deferred financing costs due to the repayment and replacement of our Old Credit Facility and an income tax benefit from the release of a $38.5 million valuation allowance associated with net operating
losses because of a determination that
|
36
|
the realization of the associated deferred tax assets is more likely than not based on future taxable income arising from the reversal of deferred tax liabilities that we acquired in the TFI
acquisition and the Power Fuels merger.
|
(6)
|
2010 results include amounts from the acquisition of Complete Vacuum and Rental, Inc. since November 30, 2010, the date of its acquisition.
|
(7)
|
2009 results include amounts from Heckmann Water Resources (HWR) since July 1, 2009, the date HWR acquired all of the limited liability company
interests of Charis Partners, LLC and all of the assets of Greer Exploration Corporation and Silversword Partnerships.
|
(8)
|
On September 30, 2011, we completed the disposition, through a sale and abandonment, of the China Water bottled water business. The business has, for all periods
presented herein, been reported as discontinued operations for financial reporting purposes.
|
(9)
|
2013 results include a $98.5 million goodwill impairment charge associated with our Industrial Solutions business segment. 2009 results include a goodwill impairment
charge of $357.5 million related to our China Water bottled water business. Both businesses are presented as discontinued operations for all periods presented herein.
|
Balance Sheet Data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
|
2009
|
|
|
|
($ in thousands)
|
|
Consolidated balance sheet data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents (1)
|
|
$
|
8,783
|
|
|
$
|
14,776
|
|
|
$
|
80,194
|
|
|
$
|
80,752
|
|
|
$
|
123,407
|
|
Total current assets
|
|
|
161,691
|
|
|
|
165,981
|
|
|
|
139,761
|
|
|
|
186,021
|
|
|
|
155,418
|
|
Property, plant and equipment, net (2)
|
|
|
498,541
|
|
|
|
579,022
|
|
|
|
270,054
|
|
|
|
85,696
|
|
|
|
32,857
|
|
Goodwill (2)
|
|
|
408,696
|
|
|
|
415,176
|
|
|
|
90,008
|
|
|
|
41,008
|
|
|
|
7,257
|
|
Total assets (2)(3)
|
|
|
1,410,763
|
|
|
|
1,644,339
|
|
|
|
539,681
|
|
|
|
355,671
|
|
|
|
308,448
|
|
Current maturities of long-term debt
|
|
|
5,464
|
|
|
|
4,699
|
|
|
|
11,914
|
|
|
|
11,221
|
|
|
|
|
|
Current liabilities
|
|
|
124,538
|
|
|
|
86,470
|
|
|
|
49,329
|
|
|
|
30,779
|
|
|
|
13,611
|
|
Long-term debt, less current maturities (4)
|
|
|
549,713
|
|
|
|
561,427
|
|
|
|
132,156
|
|
|
|
20,474
|
|
|
|
|
|
Total liabilities
|
|
|
766,394
|
|
|
|
796,578
|
|
|
|
197,871
|
|
|
|
72,680
|
|
|
|
20,265
|
|
Total equity of Nuverra Environmental Solutions, Inc.
|
|
|
644,369
|
|
|
|
847,761
|
|
|
|
341,810
|
|
|
|
301,621
|
|
|
|
310,981
|
|
(1)
|
The decrease to cash and cash equivalents in 2012 was due primarily to the use of cash to fund 2012 merger and acquisition activity.
|
(2)
|
The 2012 increases to property, plant and equipment, goodwill and total assets were due to the 2012 acquisition and merger transactions. 2013 results include an
impairment of long-lived assets of $111.9 million.
|
(3)
|
2013 also reflects a reduction in goodwill relating to an impairment of $98.5 at TFI which is included in assets held for sale.
|
(4)
|
In April 2012 and November 2012, we issued $250.0 million and $150.0 million, respectively, aggregate principal amount of 9.875% senior unsecured notes due 2018 to
partially finance the acquisition of TFI and the merger with Power Fuels.
|
37
Item 7.
|
Managements Discussion and Analysis of Financial Condition and Results of Operations
|
This Managements Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with our
Consolidated Financial Statements, and the Notes and Schedules related thereto, which are included in this Annual Report.
Company
Overview
Nuverra Environmental Solutions, Inc. is among the largest companies in the United States dedicated to providing
comprehensive, full-cycle environmental solutions to customers focused on the development and ongoing production of oil and natural gas from shale formations. Nuverra provides one-stop, total environmental solutions, including delivery, collection,
treatment, recycling, and disposal of water, wastewater, waste fluids, hydrocarbons, and restricted solids that are part of the drilling, completion, and ongoing production of shale oil and natural gas.
To meet its customers environmental needs, Nuverra utilizes a broad array of assets to provide a comprehensive environmental
solution. Our logistics assets include trucks and trailers, pipelines, temporary pipelines, temporary and permanent storage facilities, ancillary rental equipment, treatment facilities, and liquid and solid waste disposal sites. We continue to
expand our suite of environmentally compliant and sustainable solutions to customers who demand environmental compliance and accountability from their service providers.
Since the acquisition of TFI in April 2012, we have operated through two business segmentsShale Solutions and Industrial Solutions. During the fourth quarter of 2013, our board of directors approved
and committed to a plan to divest TFI, which comprises our Industrial Solutions business segment. As a result, we consider TFI to be held for sale and its assets and liabilities, results of operations and cash flows are presented as discontinued
operations in the accompanying consolidated financial statements for the years ended December 31, 2013 and 2012. See further discussion in the following paragraphs and in Note 20 of the Notes to Consolidated Financial Statements herein for
further information.
The Shale Solutions segment consists of our operations in shale basins where customer exploration and
production (E&P) activities are predominantly focused on shale oil and natural gas as follows:
|
|
|
Oil shale areas
: includes our operations in the Bakken, the Utica, the Eagle Ford, the Mississippian, and the Permian Basin shale areas. During
2013, approximately 71% of our revenues from continuing operations were derived from these shale areas, compared to 34% in 2012 and 10% in 2011.
|
|
|
|
Gas shale areas
: includes our operations in the Marcellus, the Haynesville, and the Barnett shale areas. During 2013, approximately 29% of our
revenues from continuing operations were derived from these shale areas, versus 66% in 2012 and 90% in 2011.
|
Nuverra supports its customers demand for diverse, comprehensive and regulatory compliant environmental solutions required for the
safe and efficient drilling, completion and production of oil and natural gas from shale formations. Current services, as well as prospective services in which Nuverra has made investments, include (i) fluid logistics via water procurement,
delivery, collection, storage, treatment, recycling and disposal, (ii) solid waste collection, treatment and disposal, (iii) permanent and portable pipeline facilities, water infrastructure services and equipment rental services, and
(iv) other ancillary services for E&P companies focused on the extraction of oil and natural gas resources from shale basins.
As part of its environmental solution for water and water-related services, Nuverra serves E&P customers seeking fresh water acquisition, temporary or permanent water transmission and storage,
transportation, treatment or disposal of fresh flowback and produced water in connection with shale oil and natural gas hydraulic fracturing operations. We also provide services for water pit excavations, well site preparation and well site
remediation. We own a 50-mile underground pipeline network in the Haynesville Shale area for the efficient delivery of fresh water and removal of produced water, a fleet of more than 1,100 trucks for delivery and collection, and approximately 5,700
storage tanks. We also own or lease 56 operating saltwater disposal wells in the Bakken, Marcellus/Utica, Haynesville, Eagle Ford, and Tuscaloosa shale areas.
38
As part of its environmental solution for water treatment, Nuverra has
a majority interest investment in Appalachian Water Services, LLC (AWS), which owns and operates a wastewater treatment facility in southwestern Pennsylvania specifically designed to treat and recycle water resulting from the hydraulic
fracturing process in the Marcellus Shale area. Additionally, in July 2013, Nuverra entered into an agreement with Halliburton to advance the treatment and recycling of produced water to be re-used in the hydraulic fracturing process. As part of the
agreement, Nuverra and Halliburton work together in the Bakken Shale area to offer the H2O Forward
SM
service to E&P companies. H2O Forward
SM
service allows customers to recycle waste streams of flowback and produced water for use in well completions, reducing the need for fresh water. For hydraulic fracturing operations conducted by
Halliburton using the H2O Forward
SM
system in the Bakken,
Nuverra provides logistics, transportation, storage, and overall fluid management services.
As part of our environmental
solution for solid waste, we own an oilfield solids disposal landfill in the Bakken Shale area. The oilfield solids disposal landfill is located on a 60-acre site with permitted capacity of more than 1.7 million cubic yards of airspace. The
Company believes that permitted capacity at this site could be expanded up to 5.8 million cubic yards of permitted airspace capacity in the future, subject to receipt of requisite regulatory approvals. In addition, we have begun construction of
a thermal treatment facility at the landfill site in North Dakota.
As part of its ongoing operations, Nuverra continually
assesses its asset mix and, as needs and demand require, will invest in additional equipment or make improvements to our existing assets.
Recent Developments
Following are the more significant issues impacting us since the filing of our Annual Report on Form 10-K for the year ended
December 31, 2012:
Impairment of Long-Lived Assets and Goodwill
Due to the existence of a number of potential impairment indicators at June 30, 2013, we performed a company-wide impairment review
of our long-lived assets and goodwill, which we completed during the three months ended September 30, 2013. Indicators of impairment, which triggered the need for such review, included adverse changes in the business climate in certain shale
basins including persistently low natural gas prices and shifts in customer end markets and resulting higher logistics costs in our Industrial Solutions operating segment, combined with lower-than-expected financial results. Additionally, the market
value of our equity traded for a period of time at a value that was less than the book value of our equity. In its Shale Solutions operating segment, long-lived assets were grouped at the shale basin level for purposes of assessing their
recoverability. Except for AWS and the Companys pipelines, we concluded the basin level is the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities. For those asset groups
with carrying values that exceed their undiscounted future cash flows, we recognized an impairment charge for the amount by which the carrying values of the asset group exceeded their respective fair values. Long-lived asset impairment was $111.9
million for the year ended December 31, 2013. The impairment charge recognized during 2013 consists of write-downs to the carrying values of our freshwater pipeline in the Haynesville Shale basin of $27.0 million and certain other long-lived assets
including customer relationship and disposal permit intangibles totaling $4.5 million and disposal wells and equipment of $80.4 million in the Haynesville, Eagle Ford, Tuscaloosa Marine and Barnett shale areas.
The goodwill impairment test has two steps. The first step of the goodwill impairment test, used to identify potential impairment,
compares the fair value of a reporting unit with its carrying amount including goodwill. During the three months ended September 30, 2013, we performed step one of the goodwill impairment test for each of our four reporting units: the Shale
Solutions reporting unit, the Industrial Solutions reporting unit, the Pipeline reporting unit and the AWS reporting unit. To measure the fair value of each reporting unit, we used a combination of the discounted cash flow method and the guideline
public company method. Based on the results of the step-one goodwill impairment review we concluded the fair values of the Shale Solutions, Pipeline and AWS reporting units exceeded their respective carrying amounts and accordingly, the second step
of the
39
impairment test was not necessary for these reporting units. Conversely, we concluded the fair value of the Industrial Solutions reporting unit was less than its carrying value thereby requiring
us to proceed to the second step of the two-step goodwill impairment test. The second step of the goodwill impairment test, used to measure the amount of the impairment loss, compares the implied fair value of reporting unit goodwill with its
carrying amount. The implied fair value of goodwill is determined in the same manner as the amount of goodwill recognized in a business combination. After allocating the fair value of Industrial Solutions to the assets and liabilities of the
reporting unit, we concluded the carrying value of reporting unit goodwill exceeded its implied fair value. Accordingly, we recognized a goodwill impairment charge of $98.5 million in 2013 which is recorded within loss from discontinued operations
in the accompanying Consolidated Statements of Operations.
We have $408.7 million in goodwill as of December 31, 2013 related
to our Shale Solutions reportable segment, which has been allocated to our Shale Solutions, Pipeline and AWS reporting units. As described in the preceding paragraphs, the results of our impairment test during the third quarter of 2013, which we
updated through September 30, 2013 (our annual testing date), indicated that the goodwill relating to each of these reporting units was not impaired at June 30, 2013 and September 30, 2013, since the estimated fair values of all
reporting units exceeded their carrying values. With respect to the Pipeline and AWS reporting units, the estimated fair values of the reporting units exceeded their carrying values by a substantial amount. However, while no impairment was indicated
as a result of our analysis and testing at June 30, 2013, September 30, 2013, or from our subsequent review at December 31, 2013, we determined that our Shale Solutions reporting unit, with goodwill of $390.7 million, had an estimated fair
value that exceeded its carrying value by less than 3.5 percent.
The fair values of each of the reporting units as well
as the related assets and liabilities utilized to assess the 2013 impairment were measured using Level 2 and Level 3 inputs as described in Note 11 of the Notes to Consolidated Financial Statements. We believe the assumptions used in
our discounted cash flow analysis are appropriate and result in reasonable estimates of the implied fair value of each reporting unit. However, these assumptions are subject to uncertainty and relatively small declines in the future performance or
cash flows of the Shale Solutions reporting unit or small changes in other key assumptions may result in the recognition of impairment charges, which could be significant. We believe the most significant assumption used in our analysis is the
expected improvement in the margins and overall profitability of our reporting units. In order to evaluate the sensitivity of the fair value calculations on the goodwill impairment test, a hypothetical decline of greater than 65 basis points in
the operating margin in our Shale Solutions reporting unit would result in an estimated carrying value in excess of its fair value, requiring us to proceed to the second step of the goodwill impairment test. Additionally, we may not meet our revenue
growth targets, our working capital needs and capital expenditures may be higher than forecast, changes in credit or equity markets may result in changes to our cost of capital and discount rate and general business conditions may result in changes
to the terminal value assumptions for our reporting units. One or more of these factors, among others, could result in additional impairment charges.
In evaluating the reasonableness of our fair value estimates, we consider (among other factors) the relationship between our book value, the market price of our common stock and the fair value of our
reporting units. At December 31, 2013, the closing market price of our common stock was $16.79 per share compared to our book value per share of $24.79 as of such date. Our assessment assumes this relationship is temporary; however, if our book
value per share continues to exceed our market price per share for an extended period of time, this would likely indicate the occurrence of events or changes that could cause us to revise our fair value estimates and perform a step-two goodwill
impairment analysis. While we believe that our estimates of fair value are reasonable, we will continue to monitor and evaluate this relationship in 2014.
In the fourth quarter of 2013, we announced a plan to realign our Shale Solutions business into three operating divisions: (1) the Northeast Division comprising the Marcellus and Utica Shale areas,
(2) the Southern Division comprising the Haynesville, Barnett, Eagle Ford, Mississippian Shale areas and Permian Basin and (3) the Rocky Mountain Division comprising the Bakken Shale area. The implementation of this organizational
40
realignment is ongoing and is expected to be completed in 2014. In connection with these planned organizational changes, we are evaluating whether the new operating divisions constitute separate
operating segments and if so, whether two or more of them can be aggregated into one or more reportable segments. As the organizational realignment progresses, we will continue to evaluate its potential impact on our reporting units, which is a
level of reporting at which goodwill is tested for impairment. To the extent we conclude the composition of our reporting units has changed, we will be required to allocate goodwill on a relative fair value basis to the new reporting units and test
the newly-allocated goodwill for impairment should triggering events occur. We may be required to record impairment of our goodwill and other intangible assets as a result of this reallocation.
Impairment charges recorded for the year ended December 31, 2013, by reportable segment, are summarized as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
Shale
Solutions
|
|
|
Industrial
Solutions
|
|
Impairment of property, plant and equipment
|
|
$
|
107,413
|
|
|
$
|
|
|
Impairment of intangible assets
|
|
|
4,487
|
|
|
|
|
|
Impairment of goodwill (1)
|
|
|
|
|
|
|
98,500
|
|
|
|
|
|
|
|
|
|
|
Total impairment
|
|
$
|
111,900
|
|
|
$
|
98,500
|
|
|
|
|
|
|
|
|
|
|
(1)
|
Goodwill impairment applicable to the Industrial Solutions segment is included as a part of loss from discontinued operations in our Consolidated Statements of
Operations.
|
Assets Held for Sale and Discontinued Operations
As discussed in the preceding paragraphs, our Board of Directors has approved and committed to a plan to divest TFI and, based on the
status of the sales process currently underway, we expect the sale will be completed in the second quarter of 2014. The results of operations and cash flows of TFI are presented as discontinued operations in our Consolidated Statements of Operations
and Consolidated Statements of Cash Flows for the years ended December 31, 2013 and 2012 (since its acquisition on April 10, 2012). Additionally, the assets and liabilities of TFI are presented separately as assets held for sale, and
liabilities of discontinued operations, in our Consolidated Balance Sheets as of December 31, 2013 and 2012. At December 31, 2013, the carrying value of the net assets of TFI was approximately $147.1 million, which we believe does not
exceed the amount expected to be realized from the sale. See Note 20 of Notes to Consolidated Financial Statements for additional information.
Financing Activities
As more fully described in Note 10 of the Notes to Consolidated Financial Statements and in Item 7. Managements Discussion and AnalysisLiquidity and Capital ResourcesRevolving
Credit Agreement in February 2014, we entered into a new asset-based revolving credit facility (ABL Facility) with Wells Fargo Bank as Administrative Agent and other lenders which amended and replaced our Amended Revolving Credit
Facility. Initially, the ABL Facility provides a maximum credit amount of $200.0 million, which can be increased to $225.0 million through a $25.0 million accordion feature. Initial borrowings under the ABL Facility were used to refinance amounts
outstanding under the Amended Revolving Credit Facility and fund certain related fees and expenses. The ABL Facility will be used to support ongoing working capital needs and other general corporate purposes, including growth initiatives and the
potential repurchase of a portion of the Companys currently outstanding 2018 Notes. The ABL Facility, which matures at the earlier of five years from the closing date or 90 days prior to the maturity of other material indebtedness including
the 2018 Notes, is secured by substantially all of our assets.
The terms of the ABL Facility limit the amount we can borrow to
the lesser of (a) $200.0 million or (b) 85% of the amount of our eligible accounts receivable plus the lower of (i) 95% of the net book value of our eligible rental equipment, tractors and trailers, and (ii) 85% times the
appraised net orderly liquidation value of our eligible rental
41
equipment, tractors and trailers, less any customary reserves. The borrowing base is evaluated monthly. The full $200.00 million facility is available to us based on the borrowing base as of the
closing date and subsequent levels of eligible receivables and equipment continue to support $200.0 million of availability under the facility. The ABL Facility includes a letter of credit sub-limit of $10.0 million and a swingline facility
sub-limit
equal to 10% of the total facility size for more immediate cash needs. As of March 3, 2014, borrowings under the ABL Facility totaled $156.8 million and outstanding letters of credit amounted to $4.4
million, leaving $38.8 million of unused borrowing capacity.
Interest will accrue on outstanding loans
under the ABL Facility at a floating rate based on, at our election, (i) the greater of (a) the prime lending rate as publicly announced by Wells Fargo or (b) the Federal Funds rate plus
1
/
2
% or (c) the one month LIBOR plus one percent plus an applicable margin percentage of 0.75% to 1.50% or (ii) the LIBOR rate plus the applicable margin of 1.75% to 2.50%. We are also required to
pay fees on the unused commitments of the lenders under the ABL Facility, fees for outstanding letters of credit and other customary fees.
Covenants under the Amended Revolving Credit Facility, as described in our Quarterly Report on
Form 10-Q
for the period ended September 30, 2013, were
effectively extinguished as of December 31, 2013 by the ABL Facility, and as a result any failure of the Company to comply with the covenants under the Amended Revolving Credit Facility as of December 31, 2013 would have had no effect. The
ABL Facility contains certain financial covenants that require us to maintain a senior leverage ratio and, upon the occurrence of certain specified conditions, a fixed charge coverage ratio as well as certain customary limitations on our ability to,
among other things, incur debt, grant liens, make acquisitions and other investments, make certain restricted payments such as dividends, dispose of assets or undergo a change in control. The senior leverage ratio is calculated as the ratio of
senior secured debt to adjusted EBITDA (as defined) and is limited to 3.0 to 1.0. Our $400.0 million of 2018 Notes are not secured and thus are excluded from the calculation of this ratio. The fixed charge coverage ratio, which only applies at such
time the total amount drawn under the credit facility exceeds 87.5 percent of the total facility amount, requires the ratio of adjusted EBITDA (as defined) less capital expenditures to fixed charges (as defined) to be at least 1.1 to 1.0.
Costs associated with the ABL Facility totaling approximately $3.5 million will be capitalized as deferred financing costs in
the three months ending March 31, 2014, and we expect to write-off unamortized deferred financing costs associated with our Amended Revolving Credit Facility of approximately $3.0 million in the same period.
Litigation
The following paragraphs should be read in conjunction with Legal Proceedings included in Item 3 of this Form 10-K and
Note 16 of the Notes to Consolidated Financial Statements.
During the year ended December 31, 2013, we settled the
2010 Derivative Action with a cash payment of $0.3 million by our insurance carrier and the issuance of 0.1 million shares of our common stock, resulting in a charge of $1.6 million in the accompanying Consolidated Statements of Operations.
On March 4, 2014, we reached an agreement in principle with the plaintiffs to settle the 2010 Class Action. Under the
terms of the agreement, which must be approved by the court, we have agreed to a cash payment of $13.5 million, a portion of which will come from remaining insurance proceeds, as well as the issuance of 0.8 million shares of our common stock. We
have agreed to provide a floor value of $13.5 million on the equity portion of the settlement such that the total value of the settlement is no less than $27.0 million, with any shortfall to be made up by the issuance of additional shares or cash,
at our option. The cash payment is expected to be deposited into escrow prior to June 30, 2014 and the shares will be issued when the settlement proceeds are distributed to the claimants. If approved, the settlement will resolve all claims
asserted against us and the individual defendants in the case. As a result of the pending settlement, we recorded a charge of $7.0 million in the quarter ended December 31, 2013, to effectively accrue for the proposed settlement. We could incur
additional charges in future periods if the market value of the 0.8 million shares exceeds $13.5 million upon issuance.
42
On December 5, 2013, a jury verdict was rendered against our subsidiary Heckmann Water
Resources (CVR), Inc. (CVR), in a wrongful death case resulting from a vehicle accident. The jury awarded $281.6 million in damages, which award was subsequently reduced to $163.8 million when the judgment was signed by the court on
January 7, 2014. CVR filed post-trial motions in the District Court of Dimmit County on February 6, 2014, seeking (among other things) to have the judgment overturned or a new trial ordered, and intends to continue to vigorously
defend this case through the Texas appellate court system. Our insurers have provided a surety bond of $25.0 million to stay enforcement of the judgment until the Texas appeals process is final. There will be no final resolution of the trial
court judgment until the appellate process is concluded or the case is otherwise resolved. We have agreed to indemnify our insurance carriers, subject to a complete reservation of rights, up to $9.0 million, for losses sustained in excess of the
insurance coverage of $16.0 million in connection with the surety bond. We currently estimate the potential loss for this matter to range between zero and the maximum judgment amount and accrued interest. The trial court judgment or any revised
result that may be achieved through an appeals process (which could take several years to complete) could result in multiple potential outcomes within this range. Considering the status of the judicial process and based on currently available
information, we have determined that this claim is not yet probable and have not established a reserve for this matter at this time. However, there can be no assurance that we will not be required to establish significant reserves in connection with
this matter in the future, and to the extent any such accrued liability is not fully offset by insurance recoveries it could have a material adverse effect on our business, liquidity, financial condition and results of operations.
In September 2013, two separate but substantially-similar putative class action lawsuits were commenced against us and certain of our
current and former officers and directors alleging that we and the individual defendants made certain material misstatements and/or omissions relating to our operations and financial condition which caused the price of our shares to fall. By order
dated October 29, 2013, the two putative class actions were consolidated. The lead plaintiffs have been ordered to file a consolidated complaint by March 17, 2014, and the defendants will thereafter have an opportunity to answer or move to
dismiss the claims asserted by the lead plaintiffs. In September and October 2013, three separate but substantially-similar shareholder derivative lawsuits were commenced against us and certain of our current and former officers and directors
alleging that that members of our board failed to prevent the issuance of certain misstatements and omissions and asserting claims for breach of fiduciary duty, waste of corporate assets and unjust enrichment. Defendants filed a motion to dismiss
these claims in mid-February. Also in October 2013, two identical shareholder derivative lawsuits were commenced us and certain of our current officers and directors alleging breach of fiduciary duty, waste of corporate assets and unjust enrichment.
By order dated January 28, 2014, these two actions were consolidated, and the plaintiffs have yet to file a consolidated complaint. We and the individual defendants intend to vigorously defend ourselves against the claims asserted in each of
these pending actions. While we continue to assess these claims, we believe they are without merit.
Trends Affecting Our Operating Results
Our results are driven by demand for our services, which are in turn affected by E&P trends in the shale areas
in which we operate, in particular the level of drilling activity (which impacts the amount of environmental products being managed) and active wells (which impacts the amount of produced water being managed). Activity in the oil and gas
drilling industry is also affected by market prices for those commodities, with persistent low natural gas prices and generally high oil prices driving reduced drilling and production in dry gas shale areas such as the Barnett,
Haynesville and Marcellus Shale areas where natural gas is the predominant natural resource, and the relocation of assets and increased activity in the liquids-rich or wet gas shale areas, such as the Utica, Eagle Ford, Mississippian and
Bakken Shale areas, where oil and natural gas liquids are the predominant natural resource. In addition, the low natural gas prices have in the past caused many natural gas producers to curtail capital budgets and these cuts in spending curtailed
drilling programs as well as discretionary spending on well services in certain shale areas, and accordingly reduced demand for our services in these areas. The industry-wide redeployment of assets from natural gas basins to oil-and liquids-rich
basins has resulted in downward pressure on pricing and utilization, particularly in Texas.
43
Our results are also driven by a number of other factors, including (i) our available
inventory of equipment, which we have built through acquisitions and capital expenditures over the last several years, (ii) transportation costs, which are affected by fuel costs, (iii) utilization rates for our equipment, which are also
affected by the level of our customers drilling and production activities, and our ability to relocate our equipment to areas in which oil and gas exploration and production activities are growing, (iv) availability of qualified drivers
(or alternatively, subcontractors) in the areas in which we operate, particularly in the Bakken and Marcellus/Utica shale areas, (v) labor costs, which have been generally increasing through the periods discussed due to tight labor market
conditions and increased government regulation, including the Affordable Care Act, (vi) depreciation and amortization, which have been increasing as we have expanded our asset base, (vii) developments in governmental regulations,
(viii) seasonality and weather events and (ix) our health, safety and environmental performance record.
Our
operating results are also affected by our acquisition activities, and the expenses we incur in connection with those activities, which can limit comparability of our results from period to period. We completed three acquisitions in the year ended
December 31, 2013, and six acquisitions during 2012, including Power Fuels and TFI, which were among our largest to date. We may complete other acquisitions in 2014 and beyond that will substantially change our future operating results from our
historical operating results. See Note 3 of the Notes to Consolidated Financial Statements for information regarding our recent acquisitions and certain pro forma financial information for the twelve months ended December 31, 2013 and 2012.
Such pro forma financial results were impacted by the following factors:
|
|
|
Lower operating results in the Bakken Shale reflect relatively lower pricing and activity levels in the 2013 period compared to 2012, disruption caused
by inclement weather in 2013 and increases in customer operating efficiencies, resulting in lower utilization of certain rental assets;
|
|
|
|
Revenues and margins in the Haynesville and Barnett Shale areas fell in 2013 and 2012 due to lower drilling and completion activity in these basins;
|
|
|
|
Revenues and margins in the Eagle Ford Shale basin have contracted in 2013 due in part to competitive pressures arising from our competitors
redeployment of assets from other basins, predominantly gas shale areas, and higher operating costs; and
|
|
|
|
Higher revenue in the Marcellus/Utica Shale areas in 2013 due to continued organic growth augmented by several tuck-in acquisitions in 2012 and 2013.
|
The following table summarizes our total revenues, loss from continuing operations before income taxes,
loss from continuing operations and EBITDA (defined below) for the years ended December 31, 2013, 2012 and 2011 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Revenuesfrom predominantly oil shale areas (a)
|
|
$
|
373,410
|
|
|
$
|
87,300
|
|
|
$
|
15,725
|
|
Revenuesfrom predominantly gas shale areas (b)
|
|
|
152,406
|
|
|
|
169,371
|
|
|
|
141,112
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenueShale Solutions
|
|
|
525,816
|
|
|
|
256,671
|
|
|
|
156,837
|
|
Loss from continuing operations before income taxes
|
|
|
(207,135
|
)
|
|
|
(69,357
|
)
|
|
|
(3,885
|
)
|
Loss from continuing operations
|
|
|
(134,040
|
)
|
|
|
(6,597
|
)
|
|
|
(108
|
)
|
EBITDA (c)
|
|
|
(54,196
|
)
|
|
|
4,891
|
|
|
|
25,639
|
|
(a)
|
Represents revenues associated with the Shale Solutions operating segment that are derived from predominantly oil-rich areas consisting of the Bakken, Utica, Eagle
Ford, Tuscaloosa Marine, Mississippian and Permian Basin shale areas.
|
(b)
|
Represents revenues associated with the Shale Solutions operating segment that are derived from predominantly gas-rich areas consisting of the Marcellus, Haynesville
and Barnett shale areas.
|
(c)
|
Defined as consolidated net income (loss) from continuing operations before net interest expense, income taxes and depreciation and amortization. EBITDA is not a
recognized measure under generally accepted accounting principles in the United States (GAAP). See the reconciliation between net loss and EBITDA and the reconciliation between net income (loss) from continuing operations and EBITDA
under Liquidity and Capital ResourcesEBITDA.
|
44
Results for the year ended December 31, 2013 were significantly impacted by the
inclusion of the
twelve-month
results for Power Fuels in 2013 versus one month in 2012, impairment charges of $111.9 million, charges for the settlement of shareholder litigation totaling $24.6 million, and
corporate rebranding and integration charges of $8.2 million.
For trends affecting our business and the markets in which we
operate see Recent Developments and Trends Affecting our Operating Results presented above and also Risk Factors in Part I, Item 1A of this Annual Report on Form 10-K.
Results of Operations
Revenues:
Our revenues are generated from two primary sources: (1) environmental solutions provided to E&P companies
operating in unconventional oil and natural gas resource areas and (2) equipment rental activities. Additional information about these revenue sources is as follows:
|
|
|
Environmental solutions revenue consists of fees charged to customers for the sale and transportation of fresh water and saltwater by trucks or through
temporary or permanent water transport pipelines owned by us to customer sites for use in drilling and hydraulic fracturing activities and from customer sites to remove and dispose of flowback and produced water originating from oil and gas wells.
Beginning in the third quarter of 2013, revenue also includes fees for the transportation and disposal of oilfield solid wastes following the Companys acquisition of a landfill in the Bakken Shale area; and
|
|
|
|
Rental revenue consists of fees charged to customers for use of equipment owned by us over the term of the rental as well as other fees charged to
customers for items such as delivery and pickup.
|
Cost of revenues:
Cost of revenues consists primarily of the following:
|
|
|
Wages and benefits for employees performing operational activities;
|
|
|
|
Fuel expense associated with transportation and logistics activities;
|
|
|
|
Costs to repair and maintain transportation and rental equipment and disposal wells; and
|
|
|
|
Depreciation of operating assets included in property, plant and equipment.
|
General and administrative expenses:
General and administrative expenses
consist primarily of the following:
|
|
|
Wages and benefits for employees performing administrative overhead roles;
|
|
|
|
Stock-based compensation;
|
|
|
|
Legal, audit and other professional fees;
|
|
|
|
Transaction and integration costs associated with business acquisitions and divestitures;
|
|
|
|
Certain insurance costs; and
|
|
|
|
Other costs, including provisions for the settlement of litigation.
|
45
Amortization of intangibles:
Amortization of intangible assets represents the allocation of costs for identifiable intangible assets originating from business acquisitions to future periods based on the assets useful lives
and/or their projected future cash flows. Intangible assets include customer relationships, customer contracts, disposal permits, vendor relationships and other.
Impairment of long-lived assets:
As discussed in Note 7 of the Notes to
the Consolidated Financial Statements, we recognized a charge of $111.9 million in the year ended December 31, 2013 for the write-down of the carrying values of certain intangible assets, disposal wells, vehicles and equipment and our
freshwater pipeline.
Interest expense, net:
Interest expense includes interest incurred on the outstanding balance of our Amended Revolving Credit Facility including fees on the unutilized portion thereof, interest incurred on our 2018 Notes as
well as other indebtedness. Additionally, interest expense includes accretion of contingent consideration obligations, the obligation to acquire non-controlling interest, asset retirement obligations, as well as amortization of deferred financing
costs. Such amounts are offset by interest earned on short-term investments.
Other income (expense):
Other income (expense) includes gains and losses from changes to contingent consideration estimates incurred in connection with business
combinations, losses attributable to declines in the value of escrowed assets associated with the indemnification arrangements pursuant to acquisitions, the impairment of cost-method investments and income from equity method investments.
Income tax benefit:
We
have significant deferred tax assets, consisting primarily of net operating losses (NOLs), which have a limited life. Although we have incurred losses in recent years, we have determined that the reversal of our deferred tax liabilities
will generate sufficient taxable income in future years to utilize our deferred tax assets prior to the expiration of our NOLs. However, if we were to generate additional deferred tax assets in the near future, our deferred tax liabilities may not
be sufficient to fully realize all of our deferred tax assets, and a valuation allowance will be required.
We anticipate that
the expected sale of TFI in 2014 will take the form of a stock sale of TFI rather than a sale of TFIs assets which will likely result in a significant capital loss for tax purposes, due to our substantially higher tax basis in TFI stock than
its carrying value. A significant portion of the goodwill impairment charge recorded in the three months ended September 30, 2013 did not result in a reduction of our tax basis in the stock of TFI. We will not be able to carry any recognized
capital loss resulting from a sale of TFI stock back to prior years as we did not generate capital gains nor pay any federal tax during such prior carryback years. We also do not currently expect to have significant capital gains in the five
succeeding carryforward tax years to offset the capital loss carryforward. Consequently, we expect that any deferred tax asset resulting from a capital loss generated from the sale of TFI stock will require a valuation allowance.
For trends affecting our business and the markets in which we operate see Trends Affecting Our Operating Results in the
preceding paragraphs and also Risk FactorsRisks Related to Our Business in Part I, Item 1A of this Annual Report on Form 10-K.
46
Results of Operations for the Year Ended December 31, 2013 Compared with Year Ended
December 31, 2012
The following table sets forth for each of the periods indicated our statements of operations
data and expresses revenue and expense data as a percentage of total revenues for the periods presented (dollars in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended
December 31,
|
|
|
Percent of Revenue
Years Ended
December 31,
|
|
|
Increase
(Decrease)
2013 versus 2012
|
|
|
|
2013
|
|
|
2012
|
|
|
2013
|
|
|
2012
|
|
|
Non-rental revenue
|
|
$
|
441,421
|
|
|
$
|
241,230
|
|
|
|
83.9
|
%
|
|
|
94.0
|
%
|
|
$
|
200,191
|
|
|
|
83.0
|
%
|
Rental revenue
|
|
|
84,395
|
|
|
|
15,441
|
|
|
|
16.1
|
%
|
|
|
6.0
|
%
|
|
|
68,954
|
|
|
|
446.6
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenue
|
|
|
525,816
|
|
|
|
256,671
|
|
|
|
100.0
|
%
|
|
|
100.0
|
%
|
|
|
269,145
|
|
|
|
104.9
|
%
|
Cost of revenues
|
|
|
(456,167
|
)
|
|
|
(237,962
|
)
|
|
|
-86.8
|
%
|
|
|
-92.7
|
%
|
|
|
218,205
|
|
|
|
91.7
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
69,649
|
|
|
|
18,709
|
|
|
|
13.2
|
%
|
|
|
7.3
|
%
|
|
|
50,940
|
|
|
|
272.3
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and administrative expenses
|
|
|
86,085
|
|
|
|
42,742
|
|
|
|
16.4
|
%
|
|
|
16.7
|
%
|
|
|
43,343
|
|
|
|
101.4
|
%
|
Amortization of intangible assets
|
|
|
20,424
|
|
|
|
7,511
|
|
|
|
3.9
|
%
|
|
|
2.9
|
%
|
|
|
12,913
|
|
|
|
171.9
|
%
|
Impairment of long-lived assets
|
|
|
111,900
|
|
|
|
6,030
|
|
|
|
21.3
|
%
|
|
|
2.3
|
%
|
|
|
105,870
|
|
|
|
1755.7
|
%
|
Other, net
|
|
|
899
|
|
|
|
|
|
|
|
0.2
|
%
|
|
|
0.0
|
%
|
|
|
899
|
|
|
|
100.0
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating expenses
|
|
|
219,308
|
|
|
|
56,283
|
|
|
|
41.7
|
%
|
|
|
21.9
|
%
|
|
|
163,025
|
|
|
|
289.7
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
(149,659
|
)
|
|
|
(37,574
|
)
|
|
|
-28.5
|
%
|
|
|
-14.6
|
%
|
|
|
112,085
|
|
|
|
298.3
|
%
|
Interest expense, net
|
|
|
(53,703
|
)
|
|
|
(26,607
|
)
|
|
|
-10.2
|
%
|
|
|
-10.4
|
%
|
|
|
27,096
|
|
|
|
101.8
|
%
|
Other (expense) income, net
|
|
|
(3,773
|
)
|
|
|
(2,538
|
)
|
|
|
-0.7
|
%
|
|
|
-1.0
|
%
|
|
|
1,235
|
|
|
|
48.7
|
%
|
Loss on extinguishment of debt
|
|
|
|
|
|
|
(2,638
|
)
|
|
|
0.0
|
%
|
|
|
-1.0
|
%
|
|
|
(2,638
|
)
|
|
|
-100.0
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations before income taxes
|
|
|
(207,135
|
)
|
|
|
(69,357
|
)
|
|
|
-39.4
|
%
|
|
|
-27.0
|
%
|
|
|
137,778
|
|
|
|
198.7
|
%
|
Income tax benefit
|
|
|
73,095
|
|
|
|
62,760
|
|
|
|
13.9
|
%
|
|
|
24.5
|
%
|
|
|
10,335
|
|
|
|
16.5
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations
|
|
|
(134,040
|
)
|
|
|
(6,597
|
)
|
|
|
-25.5
|
%
|
|
|
-2.6
|
%
|
|
|
127,443
|
|
|
|
1931.8
|
%
|
(Loss) income from discontinued operations, net of income taxes
|
|
|
(98,251
|
)
|
|
|
9,124
|
|
|
|
-18.7
|
%
|
|
|
3.6
|
%
|
|
|
(107,375
|
)
|
|
|
-1176.8
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
(232,291
|
)
|
|
$
|
2,527
|
|
|
|
-44.2
|
%
|
|
|
1.0
|
%
|
|
$
|
(234,818
|
)
|
|
|
-9292.4
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
Total revenue in the Shale Solutions business for the year ended December 31, 2013 amounted to $525.8 million, an increase of $269.1 million from 2012. The increase included the twelve-month
revenue contribution from Power Fuels in 2013 vs. only one month in 2012 following the November 30, 2012 Power Fuels merger, a difference of $278.8 million. Additionally, strong growth in the Marcellus and Utica shale areas was offset by
year-over-year revenue declines in the Haynesville, Barnett and Eagle Ford Shale areas. We continued to experience pricing pressure during the year due to competitive conditions across many of the shale areas in which we operate. Beginning in 2012
in some regions of our business, shifts in customer procurement practices, which effectively transfer more service efficiency risk to us, resulted in pricing and margin erosion. In terms of revenue mix, revenue from shale areas predominantly driven
by natural gas production declined on a year-over-year basis, while revenue derived from basins where the primary resource is oil increased markedly due to the addition of Power Fuels in the oil-rich Bakken Shale area.
Non-rental revenue consists of transportation, disposal, treatment, recycling and other ancillary revenues and, beginning in the third
quarter of 2013 following the acquisition of Ideal Oilfield Disposal, LLC in North Dakota, included $2.3 million of fees for the transportation and landfill disposal of oilfield solid wastes.
47
Non-rental revenue for the year ended December 31, 2013 was $441.4 million, up $200.2 million from $241.2 million in the preceding year. The increase is primarily attributable to Power
Fuels, which accounted for approximately $212.1 million of the year-over-year increase. Rental revenue for the year ended December 31, 2013 was $84.4 million, versus $15.4 million for 2012, with the increase being entirely attributable to
Power Fuels. Prior to the Power Fuels merger, our rental revenue consisted primarily of tank rentals, whereas Power Fuels has a more comprehensive rental equipment service offering.
Cost of Revenues
Cost of revenues was $456.2 million for the year ended
December 31, 2013, up $218.2 million from $238.0 million from the year ended December 31, 2012. Consistent with the increase in revenue, the increase in the overall cost of revenues was primarily attributable to the full-year impact
in 2013 of Power Fuels, which accounted for approximately $221.4 million of the year-over-year increase. The increase in cost of revenues included higher depreciation expense of $36.9 million, substantially all of which was attributable to
assets acquired in the Power Fuels transaction.
General and Administrative Expenses
General and administrative expenses increased to $86.1 million in the year ended December 31, 2013 from $42.7 million for the
comparable 2012 period. The higher costs in 2013 reflect a number of factors, including: (a) incremental general & administrative expenses amounting to $13.9 million related to the addition of Power Fuels; (b) charges totaling
$24.6 million for the settlement of the 2010 Derivative Action and 2010 Class Action litigation described in Note 16 of Notes to Consolidated Financial Statements; (c) approximately $8.2 million of integration and rebranding costs following the
Power Fuels merger in late 2012 and the Companys rebranding in early 2013; and (d) increased personnel costs associated with higher staffing levels.
Amortization of Intangible Assets
Amortization of intangible assets was
$20.4 million and $7.5 million for the years ended December 31, 2013 and 2012, respectively. The increase is due to the full-year impact in 2013 of the large increase in intangible assets acquired in connection with the acquisitions completed
in 2012, including Power Fuels. The largest components of newly acquired intangible assets were customer relationships valued at approximately $145.0 million of which $16.5 million was amortized to expense during 2013.
Impairment of Long-Lived Assets
Long-lived asset impairment was $111.9 million and $6.0 million for the years ended December 31, 2013 and 2012, respectively. The 2013 impairment charge represents a write-down of the carrying values
of certain intangible assets, disposal wells, motor vehicles, trailers, rental equipment and our freshwater pipeline in the Haynesville, Eagle Ford and Barnett Shale basins, primarily in the three-month period ended September 30, 2013. Due to
impairment indicators present at June 30, 2013, we commenced a company-wide impairment review of our long-lived assets during the third quarter of 2013. Long-lived assets were grouped at the shale basin level for purposes of assessing their
recoverability, which is the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities. For reporting units in which the carrying value of the long-lived group exceeded the undiscounted
future cash flows associated with the continued use and disposition of the asset group, we recorded an impairment charge for the amount by which the carrying values of the asset groups exceeded their respective fair values.
Other Operating Expenses
During 2013, we recorded a charge of approximately $1.4 million to restructure our operations in certain shale basins and improve overall
operating efficiencies. The charge included severance and termination benefits and other costs in connection with the substantial curtailment of our activities in the Tuscaloosa Marine Shale.
48
Loss from Operations
Loss from operations was $149.7 million for the year ended December 31, 2013, compared to $37.6 million for the year ended December 31, 2012 and was significantly impacted by the aforementioned
charges for impairment, legal settlements and rebranding and integration in 2013.
Loss on Extinguishment of Debt
Loss on extinguishment of debt was $2.6 million for the year ended December 31, 2012 and represents the write-off of unamortized debt
issuance costs related to the replacement of our previous credit facility with a new revolving credit facility during 2012.
Interest
Expense, net
Interest expense, net for the year ended December 31, 2013 was $53.7 million as compared to $26.6
million in the prior year. The increase of $27.1 million in interest expense during 2013 included $19.0 million of additional interest on the $250.0 million and $150.0 million tranches of the 2018 Notes issued in April 2012 and November 2012,
respectively, the proceeds of which were used to partially finance the acquisitions of TFI and Power Fuels. In addition, we amortized $4.5 million of deferred financing costs to interest expense during the year ended December 31, 2013, as
compared to $1.8 million in the previous year.
Other (Expense) Income, net
Other expense, net was $3.8 million for the year ended December 31, 2013 as compared to $2.5 million for the year ended
December 31, 2013, and consisted primarily of a $3.8 million write-down to our investment in UGSI. See Note 18 of Notes to Consolidated Financial Statements for additional information. In addition, we incurred an approximate $1.0 million loss
in 2013 in connection with a decline in the value of certain shares placed in escrow upon the closing of the TFI acquisition. Pursuant to the terms and conditions of the stock purchase agreement related to the TFI acquisition, the Company was
required to indemnify the sellers for a decline in the value of escrowed shares after the one-year anniversary of the TFI acquisition and upon liquidation of the escrowed shares.
Income (Loss) from Continuing Operations before Income Taxes
Loss from
continuing operations before income taxes amounted to $207.1 million for the year ended December 31, 2013, compared to $69.4 million for the year ended December 31, 2012, due to the items previously described. On a segment basis, the
pre-tax loss in Shale Solutions was $100.1 million for the year ended December 31, 2013 compared to $23.3 million for the year ended December 31, 2012, reflecting the $111.9 million impairment charge in 2013. During the year
ended December 31, 2013, the pre-tax loss incurred by the Corporate group was $107.0 million, up from $46.1 million in 2012. The primary factors impacting Corporate pre-tax loss are $19.0 million of additional interest expense
associated with the 2018 Notes, a $24.6 million charge associated with the 2010 Derivative and Class Action litigation described previously, $8.2 million of rebranding and integration-related costs and higher salaries and benefit costs
attributable to headcount transfers and increases.
Income Tax Benefit
Our income tax benefit for the year ended December 31, 2013 was $73.1 million, resulting in an effective tax rate of 35.3%. Our
income tax benefit for the year ended December 31, 2012 was $62.8 million, an effective rate of 90.4%. Our effective income tax benefit rate for the year ended December 31, 2012 differed from the federal statutory rate of 35.0% primarily
due to reductions in previously-established valuation allowances due to acquired sources of taxable income in the form of deferred tax liabilities resulting from the acquisitions in 2012.
49
In 2013, we established a valuation allowance of $1.6 million to offset deferred tax assets
associated with the book write-down of certain investments that would generate capital losses if sold at book value. Additionally, we maintain a valuation allowance of $4.5 million to offset deferred tax assets associated with certain state net
operating losses that we do not believe will be realized prior to their expiration.
Income (Loss) from Discontinued Operations
Income (loss) from discontinued operations in the years ended December 31, 2013 and 2012 represents the financial
results of TFI, which comprises our Industrial Solutions business segment. Such income or loss, which is presented net of income taxes, was a loss of approximately $98.3 million for the year ended December 31, 2013 and income for the period
ended December 31, 2012 of $9.2 million (since the acquisition of TFI on April 10, 2012). The 2013 loss includes a goodwill impairment charge of $98.5 million in the quarter ended September 30, 2013 and $12.3 million of depreciation
and amortization expense. See Note 20 of the Notes to Consolidated Financial Statements herein for additional information.
Results of
Operations for the Year Ended December 31, 2012 Compared with Year Ended December 31, 2011
The following
table sets forth for each of the periods indicated our statements of operations data and expresses revenue and expense data as a percentage of total revenues for the periods presented (dollars in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended
December 31,
|
|
|
Percent of Revenue
Years Ended
December 31,
|
|
|
Increase
(Decrease)
2012 versus 2011
|
|
|
|
2012
|
|
|
2011
|
|
|
2012
|
|
|
2011
|
|
|
Non-rental revenue
|
|
$
|
241,230
|
|
|
$
|
144,291
|
|
|
|
94.0
|
%
|
|
|
92.0
|
%
|
|
$
|
96,939
|
|
|
|
67.2
|
%
|
Rental revenue
|
|
|
15,441
|
|
|
|
12,546
|
|
|
|
6.0
|
%
|
|
|
8.0
|
%
|
|
|
2,895
|
|
|
|
23.1
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenue
|
|
|
256,671
|
|
|
|
156,837
|
|
|
|
100.0
|
%
|
|
|
100.0
|
%
|
|
|
99,834
|
|
|
|
63.7
|
%
|
Cost of revenues
|
|
|
(237,962
|
)
|
|
|
(123,509
|
)
|
|
|
-92.7
|
%
|
|
|
-78.7
|
%
|
|
|
114,453
|
|
|
|
92.7
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
18,709
|
|
|
|
33,328
|
|
|
|
7.3
|
%
|
|
|
21.3
|
%
|
|
|
(14,619
|
)
|
|
|
-43.9
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and administrative expenses
|
|
|
42,742
|
|
|
|
32,783
|
|
|
|
16.7
|
%
|
|
|
20.9
|
%
|
|
|
9,959
|
|
|
|
30.4
|
%
|
Amortization of intangible assets
|
|
|
7,511
|
|
|
|
3,868
|
|
|
|
2.9
|
%
|
|
|
2.5
|
%
|
|
|
3,643
|
|
|
|
94.2
|
%
|
Impairment of long-lived assets
|
|
|
6,030
|
|
|
|
|
|
|
|
2.3
|
%
|
|
|
0.0
|
%
|
|
|
6,030
|
|
|
|
100.0
|
%
|
Other, net
|
|
|
|
|
|
|
2,089
|
|
|
|
0.0
|
%
|
|
|
1.3
|
%
|
|
|
(2,089
|
)
|
|
|
-100.0
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating expenses
|
|
|
56,283
|
|
|
|
38,740
|
|
|
|
21.9
|
%
|
|
|
24.7
|
%
|
|
|
17,543
|
|
|
|
45.3
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
(37,574
|
)
|
|
|
(5,412
|
)
|
|
|
-14.6
|
%
|
|
|
-3.5
|
%
|
|
|
32,162
|
|
|
|
594.3
|
%
|
Interest expense, net
|
|
|
(26,607
|
)
|
|
|
(4,243
|
)
|
|
|
-10.4
|
%
|
|
|
-2.7
|
%
|
|
|
22,364
|
|
|
|
527.1
|
%
|
Other (expense) income, net
|
|
|
(2,538
|
)
|
|
|
5,770
|
|
|
|
-1.0
|
%
|
|
|
3.7
|
%
|
|
|
(8,308
|
)
|
|
|
-144.0
|
%
|
Loss on extinguishment of debt
|
|
|
(2,638
|
)
|
|
|
|
|
|
|
-1.0
|
%
|
|
|
0.0
|
%
|
|
|
2,638
|
|
|
|
100.0
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations before income taxes
|
|
|
(69,357
|
)
|
|
|
(3,885
|
)
|
|
|
-27.0
|
%
|
|
|
-2.5
|
%
|
|
|
65,472
|
|
|
|
1685.3
|
%
|
Income tax benefit
|
|
|
62,760
|
|
|
|
3,777
|
|
|
|
24.5
|
%
|
|
|
2.4
|
%
|
|
|
58,983
|
|
|
|
1561.6
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations
|
|
|
(6,597
|
)
|
|
|
(108
|
)
|
|
|
-2.6
|
%
|
|
|
-0.1
|
%
|
|
|
6,489
|
|
|
|
6008.3
|
%
|
Income (loss) from discontinued operations, net of income taxes
|
|
|
9,124
|
|
|
|
(22,898
|
)
|
|
|
3.6
|
%
|
|
|
-14.6
|
%
|
|
|
32,022
|
|
|
|
139.8
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
2,527
|
|
|
$
|
(23,006
|
)
|
|
|
1.0
|
%
|
|
|
-14.7
|
%
|
|
$
|
25,533
|
|
|
|
111.0
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
50
Revenue
Shale Solutions revenue for the year ended December 31, 2012 was $256.7 million, up significantly from $156.8 million in 2011. The one-month contribution of Power Fuels in 2012 accounted for $25.3
million of the increase, with the remainder attributable to a combination of other acquisitions completed during 2012 and 2011 and organic growth, which accounted for approximately $41.6 million and $33.0 million of the remaining increase,
respectively. The organic growth was driven primarily by new investments and asset redeployments primarily in the Eagle Ford and Marcellus shale areas, and included revenues from a contract with a major customer that commenced in late
2011. In addition, 2012 also includes increased revenue from our produced water pipeline in the Haynesville shale area (up approximately 80% in 2012 versus 2011), portions of which were under construction and out of service during the
period from February 2011 through September 2011. Revenue growth in 2012 was negatively affected by somewhat weaker pricing in certain shale areas due to business mix issues and competitive pressures.
Non-rental revenue for the year ended December 31, 2012 was $241.2 million, up $96.9 million from $144.3 million for the year ended
December 31, 2011. The increase was driven by acquisition activity during 2012, including the one month contribution from Power Fuels contribution of $20.5 million, as well as the
full-year
impact of the
five acquisitions that closed during the three months ended June 30, 2011. Rental revenue for the year ended December 31, 2012 was $15.4 million, up $2.9 million from $12.5 million for the year ended December 31, 2011. The increase
was attributable entirely to rental revenue from Power Fuels.
Cost of Revenues
Cost of revenues for the year ended December 31, 2012 was $238.0 million, up $114.5 million from $123.5 million for the year
ended December 31, 2011. Consistent with the increase in revenue, the increase in cost of revenues was attributable primarily to the Power Fuels merger in 2012 and secondarily to the full year impact of the five acquisitions that closed during
the three months ended June 30, 2011. Power Fuels transactions accounted for approximately $18.9 million of the year-over-year increase in cost of revenues. Excluding the impact of the Power Fuels transaction, depreciation expense increased
$14.9 million in 2012, which was attributable to 2011 capital purchases of $150.9 million and equipment acquired in connection with 2011 acquisitions, which totaled approximately $48.5 million. Gross profit decreased $14.6 million or 44% from
$33.3 million for the year ended December 31, 2011. Excluding the impact on cost of revenues from the acquisition and merger related transactions, the increase in cost of revenues and the accompanying decline in gross margin were due to in
part to costs incurred to redeploy assets from the Haynesville Shale area in response to diminished natural gas drilling activity. These costs were accompanied by additional training costs to onboard new drivers in the Eagle Ford Shale area to
support growth in that basin. In addition, the Company also incurred costs for increased staffing in order to support the Companys growth and integration of the recently acquired businesses including the five acquisitions that closed during
the year ended December 31, 2011.
General and Administrative Expenses
General and administrative expenses for the year ended December 31, 2012 totaled $42.7 million, compared to $32.8 million for the
year ended December 31, 2011. Operating expenses for 2012 includes transaction costs associated with 2012 acquisition activity and the Power Fuels merger of $7.7 million, stock-based compensation expense of $3.6 million and provision for
doubtful accounts of $6.1 million. The corresponding 2011 expenses for transaction costs, stock-based compensation and the provision for doubtful accounts were $0.9 million, $2.4 million, and $2.2 million, respectively.
Amortization of Intangible Assets
Amortization of intangible assets was $7.5 million and $3.9 million for the year ended December 31, 2012 and 2011, respectively. The increase is due to the large increase in intangible assets
resulting from the acquisitions that were completed during 2012 and 2011.
51
Impairment of Long-Lived Assets
Impairment of long-lived assets was $6.0 million for the year ended December 31, 2012 and represents primarily the write-off of the
carrying values of several disposal wells in the Haynesville shale area, and the write-down of a customer relationship intangible. We reviewed the recoverability of the disposal wells carrying values because of various technical problems
encountered, which ultimately limit the usability of the wells. The impairment charge considered declines in drilling activity in the Haynesville market due to relatively lower natural gas prices.
Other Operating Expenses
Other operating expenses include pipeline start-up and commissioning expenses in the year ended December 31, 2011 relate to start-up
costs for our underground pipeline in the Haynesville Shale area.
Loss from Operations
Loss from operations was $37.6 million and $5.4 million for the years ended December 31, 2012 and 2011, respectively. The increased
loss includes the impact of the $6.8 million increase to transaction costs, the impairment charges totaling $6.0 million and the $18.7 million and $3.6 million increases in depreciation and amortization of intangible assets, respectively, mentioned
above.
Loss on Extinguishment of Debt
Loss on extinguishment of debt was $2.6 million for the year ended December 31, 2012 and represents the write-off of the unamortized balance of debt issuance costs related to our old credit facility
which was replaced by a new revolving credit facility.
Interest (Expense) Income, net
Interest expense, net was $26.6 million for the year ended December 31, 2012 as compared to $4.2 million for the year ended
December 31, 2011. The increase was due to an increase in average debt outstanding during 2012 and higher average interest rates, driven primarily by the 2018 Notes. In addition, interest income was lower in the 2012 versus 2011 year to date
period due to lower investment balances during 2012 compared to the same period of 2011, and increased borrowings under our Amended Revolving Credit Facility throughout 2012.
Other (Expense) Income, net
Other expense, net for the year ended
December 31, 2012 totaled approximately $2.5 million and consists primarily of a $1.7 million loss on the disposition of assets used in the Shale Solutions segment. Other expense, net for the year ended December 31, 2011 totaled
approximately $5.8 million, consisting primarily of net reductions to liabilities for contingent consideration which were adjusted through earnings. Such changes result from reassessment of the performance-based earnouts related to (a) our
acquisition of the Excalibur Energy Services, Inc. in 2011, and (b) the acquisition of Complete Vacuum and Rental, Inc. in 2010, and (c) the acquisition of Charis Partners LLC, in July 2009. During the year ended December 31, 2012, we
recorded income from an equity method investment. During the year ended December 31, 2011 we recorded a loss of approximately $0.5 million related to our joint venture with Energy Transfer Partners, L.P. which was terminated on July 8,
2011.
Income Tax Benefit
The income tax benefit for the year ended December 31, 2012 was approximately $62.8 million resulting in an effective income tax rate of 90.4%, compared to an income tax benefit for the year ended
December 31, 2011
52
of approximately $3.8 million resulting in an effective income tax rate of 97.2%. The primary factor affecting the effective income tax rate in 2012 as compared the federal taxable rate of 35.0%
is the release of a valuation allowance after we determined that the realization of certain deferred tax assets was more likely than not based on future taxable income arising from the reversal of deferred tax liabilities that we acquired in 2012.
The primary factors affecting the effective tax rate in 2011 were the loss on the sale and abandonment of China Water, which was offset in part by a valuation allowance. These items resulted in a net increase to the effective tax rate for the year
ended December 31, 2011.
Loss from Continuing Operations
Loss from continuing operations was $6.6 million for the year ended December 31, 2012 compared to a loss from continuing operations of $0.1 million for the year ended December 31, 2011,
primarily as a result of the items referred to above.
Loss from Discontinued Operations
As described previously, during the fourth quarter of 2013 we began a process to divest TFI, which comprises our Industrial Solutions
business segment. As a result, the Company considers TFI to be held for sale and as such, the results of all prior periods have been restated to reflect TFI as discontinued operations since its acquisition in April 2012. Our income from discontinued
operations for the year ended December 31, 2012 was approximately $9.1 million. For the year ended December 31, 2011, loss from discontinued operations was approximately $22.9 million and was entirely attributable to our September 30,
2011 sale and abandonment of the China Water business. See Note 20 of the Notes in the accompanying notes to Consolidated Financial Statements herein for additional information.
Liquidity and Capital Resources
Cash Flows and Liquidity
Our primary source of capital is from cash generated by our operations with additional sources of capital from borrowings available under
our revolving credit facility as well as debt and equity accessed through the capital markets. Our level of historical acquisition activity was highly capital intensive and required significant investments in order to expand our presence in existing
shale basins, access new markets and to expand the breadth and scope of services we provide. Additionally, we have historically issued equity in connection with much of our external growth.
The following table summarizes our sources and uses of cash from continuing operations for the years ended December 31, 2013, 2012
and 2011 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
Net cash provided by (used in):
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Operating activities
|
|
$
|
66,668
|
|
|
$
|
25,078
|
|
|
$
|
(9,279
|
)
|
Investing activities
|
|
|
(52,788
|
)
|
|
|
(388,540
|
)
|
|
|
(142,326
|
)
|
Financing activities
|
|
|
(19,873
|
)
|
|
|
298,044
|
|
|
|
151,047
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net decrease in cash and cash equivalents
|
|
$
|
(5,993
|
)
|
|
$
|
(65,418
|
)
|
|
$
|
(558
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2013, we had unrestricted cash and cash equivalents of $8.8 million, a decrease
of $6.0 million from December 31, 2012. Generally, we manage our liquidity by using any excess cash, after considering our working capital and capital expenditures needs, to reduce the outstanding balance of our revolving credit facility.
53
Operating Activities
Net cash provided by operating activities was $66.7 million
for the year ended December 31, 2013. The net loss from continuing operations, after adjustments for non-cash items, provided cash of $26.0 million in 2013. Changes in operating assets and liabilities provided an additional $40.7 million
primarily related to the decrease in accounts receivable and the increase in accrued liabilities. The non-cash items and other adjustments included $99.2 million of depreciation and amortization, a charge totaling $111.9 million for the impairment
of certain tangible and intangible assets as well as a $68.6 million deferred income tax benefit.
Net cash provided by
operating activities was $25.1 million for the year ended December 31, 2012 and resulted from non-cash items and other adjustments of $13.2 million offset by an increase in net operating liabilities of $18.5 million and loss from continuing
operations of $6.6 million. The non-cash items and other adjustments included $47.6 million of depreciation and amortization as well as a $56.7 million deferred income tax benefit that resulted in part from $38.5 million release of valuation
allowance.
Net cash used in operating activities was $9.3 million for the year ended December 31, 2011. Net cash used in
operating activities consisted of non-cash items and other adjustments of $19.9 million offset by an increase in net operating assets of $29.1 million and a loss from continuing operations of $0.1 million. The increase in operating activities
included an overall increase in accounts receivable of $31.2 million, due in part to slower customer payments in the fourth quarter.
Investing Activities
Net cash used in investing activities was $52.8 million for the year ended December 31, 2013, as compared to $388.5 million for the year ended December 31, 2012.
The higher investment activity in 2012 was primarily attributable to payments in connection with the Power Fuels merger and the TFI acquisition, which totaled $127.3 million and $229.6 million, respectively. Excluding acquisitions, cash required to
support capital spending in 2013 was marginally higher than in 2012.
Net cash used in investing activities was $142.3 million
for the year ended December 31, 2011, which included cash paid for acquisitions of $88.3 million and capital expenditures of $150.9 million to support the organic growth of the business. Such amounts were partially offset by net cash activity
from investment sales and purchases of $96.9 million.
Financing Activities
Net cash used in financing activities
was $19.9 million for the year ended December 31, 2013 compared to cash provided by financing activities of $298.0 million for the year ended December 31, 2012. Net cash provided by financing activities included proceeds from the 2018
Notes and common stock issuance in 2012 to support the TFI and Power Fuels acquisitions. Additionally, financing activities in 2012 included a reduction of term debt, notes payable and capital leases totaling $155.0 million. Net borrowings under our
revolving credit facility in 2012 amounted to $6.8 million. Additionally, we made payments of $26.2 million for financing costs associated with the 2018 Notes and bank credit facilities. Net cash used in financing activities for the year end
December 31, 2013, also included $5.4 million of payments under capital leases and notes payable, $1.9 million of contingent consideration payments and $1.6 million in other disbursements.
Net cash provided by financing activities was $298.0 million for the year ended December 31, 2012 compared to $151.0 million for the
year ended December 31, 2011. As noted previously, the year-over-year net increase in net cash provided by financing activities was attributable to the larger funding needs to support the TFI and Power Fuels acquisitions in 2012. The $147.0
million increase in cash provided by financing activities consisted of $399.0 million of proceeds, net of original issue discounts, received in connection with the issuance of the 2018 Notes, $147.0 million of net proceeds drawn from our Amended
Revolving Credit Facility and $74.4 million of cash proceeds received in connection with an equity offering of our common shares. Cash provided by financing activities was offset by a $140.2 million repayment of our old credit facility, a
$150.4 million repayment of debt acquired in connection with the Power Fuels merger and $26.2 million of deferred financing fees associated with the 2018 Notes and the Amended Revolving Credit Facility.
54
Capital Expenditures
Cash required for capital expenditures (related to continuing operations) for the year ended December 31, 2013, excluding acquisitions, totaled $46.6 million compared to $43.6 million in 2012.
Capital expenditures in 2013 primarily included (a) completion of the Companys saltwater pipeline in the Haynesville shale area, (b) new disposal wells or upgrades to existing wells, including an expansion of our presence in the
Utica shale area, (c) completion of construction of the initial phase of the Companys oilfield waste landfill in the Bakken shale area and (d) cash outlays for a thermal desorption system to expand the Companys solids treatment
capabilities, also in the Bakken shale area. Historically, a significant portion of our transportation-related capital requirements are financed through capital leases, which are not included in the capital expenditures figures cited previously.
Such equipment additions under capital leases totaled approximately $5.8 million during 2013 and $20.8 million in 2012, as the Company significantly expanded its transportation fleet during 2012. We continue to focus on improving the utilization of
our existing assets and optimizing the allocation of resources in the various shale areas in which we operate. Our capital expenditure program is subject to market conditions, including customer activity levels, commodity prices, industry capacity
and specific customer needs. We may also incur additional capital expenditures for acquisitions. Our planned capital expenditures for 2014, as well as any acquisitions we choose to pursue, will likely be financed through a combination of cash flow
from operations, borrowings under our revolving credit facility and, in the case of acquisitions, issuances of equity. We may also issue additional debt securities to support growth initiatives.
Indebtedness
We are
highly leveraged and a substantial portion of our liquidity needs arise from debt service requirements and from funding our costs of operations and capital expenditures, including acquisitions. As of December 31, 2013, we had $555.9 million of
indebtedness outstanding, consisting of $136.0 million under the Amended Revolving Credit Facility, $400.0 million of 2018 Notes and $19.9 million of capital leases and installment notes payable for vehicle financings.
Revolving Credit Agreement
In February 2014, we entered into a new asset-based revolving credit facility (ABL Facility) with Wells Fargo Bank as Administrative Agent and other lenders which amended and replaced our
Amended Revolving Credit Facility. Initially, the ABL Facility provides a maximum credit amount of $200.0 million, which can be increased to $225.0 million through a $25.0 million accordion feature. Initial borrowings under the ABL Facility were
used to refinance amounts outstanding under the Amended Revolving Credit Facility and fund certain related fees and expenses. The ABL Facility will be used to support ongoing working capital needs and other general corporate purposes, including
growth initiatives and the potential repurchase of a portion of the Companys currently outstanding 2018 Notes. The ABL Facility, which matures at the earlier of five years from the closing date or 90 days prior to the maturity of other
material indebtedness including the 2018 Notes, is secured by substantially all of our assets.
The terms of the ABL Facility
limit the amount we can borrow to the lesser of (a) $200.0 million or (b) 85% of the amount of our eligible accounts receivable plus the lower of (i) 95% of the net book value of our eligible rental equipment, tractors and trailers,
and (ii) 85% times the appraised net orderly liquidation value of our eligible rental equipment, tractors and trailers, less any customary reserves. The borrowing base is evaluated monthly. The full $200.00 million facility is available to us
based on the borrowing base as of the closing date and current levels of eligible receivables and equipment continue to support $200.0 million of availability under the facility. The ABL Facility includes a letter of credit sub-limit of $10.0
million and a swingline facility
sub-limit
equal to 10% of the total facility size for more immediate cash needs. As of March 3, 2014, borrowings under the ABL Facility totaled $156.8 million and
outstanding letters of credit amounted to $4.4 million, leaving $38.8 million of unused borrowing capacity.
Interest will
accrue on outstanding loans under the ABL Facility at a floating rate based on, at our election, (i) the greater of (a) the prime lending rate as publicly announced by Wells Fargo or (b) the Federal Funds rate
55
plus
1
/
2
% or (c) the one month LIBOR plus one percent plus an applicable margin percentage of 0.75% to 1.50% or (ii) the
LIBOR rate plus the applicable margin of 1.75% to 2.50%. We are also required to pay fees on the unused commitments of the lenders under the ABL Facility, fees for outstanding letters of credit and other customary fees.
Covenants under the Amended Revolving Credit Facility, as described in our Quarterly Report on Form
10-Q
for the period ended September 30, 2013, were effectively extinguished as of December 31, 2013 by the ABL Facility, and as a result any failure of the Company to comply with the covenants under the
Amended Revolving Credit Facility as of December 31, 2013 would have had no effect. The ABL Facility contains certain financial covenants that require us to maintain a senior leverage ratio and, upon the occurrence of certain specified conditions, a
fixed charge coverage ratio as well as certain customary limitations on our ability to, among other things, incur debt, grant liens, make acquisitions and other investments, make certain restricted payments such as dividends, dispose of assets or
undergo a change in control. The senior leverage ratio is calculated as the ratio of senior secured debt to adjusted EBITDA (as defined) and is limited to 3.0 to 1.0. Our $400.0 million of 2018 Notes are not secured and thus are excluded from the
calculation of this ratio. The fixed charge coverage ratio, which only applies at such time the total amount drawn under the credit facility exceeds 87.5 percent of the total facility amount, requires the ratio of adjusted EBITDA (as defined) less
capital expenditures to fixed charges (as defined) to be at least 1.1 to 1.0.
Costs associated with the ABL Facility totaling
approximately $3.5 million will be capitalized as deferred financing costs in the three months ending March 31, 2014, and we expect to write-off unamortized deferred financing costs associated with our Amended Revolving Credit Facility of
approximately $3.0 million in the same period.
Planned Sale of TFI
As described previously, we are currently actively engaged in a process for the sale of TFI, and expect such sale to be completed during
the second quarter of 2014. Based on currently available information, the carrying value of TFI at December 31, 2013 does not exceed the net proceeds expected to be received from its divestiture. Further, we anticipate using all of the net
proceeds from the sale to reduce outstanding indebtedness under the ABL Facility and for other general corporate purposes. See Note 20 of the Notes to Consolidated Financial Statements for additional information.
Contractual Obligations
The following table details our contractual cash obligations as of December 31, 2013 (in thousands). Obligations for contingent
consideration related to acquisitions that are payable in shares of our common stock are excluded from the table below. See Note 11 of the Notes to Consolidated Financial Statements for additional information.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments due by Period
|
|
|
|
Total
|
|
|
Less than
1 Year
|
|
|
1-3 Years
|
|
|
3-5 Years
|
|
|
More than
5 Years
|
|
Debt obligations including capital leases (1)
|
|
$
|
555,946
|
|
|
$
|
5,437
|
|
|
$
|
9,217
|
|
|
$
|
541,292
|
|
|
$
|
|
|
Interest on debt and capital leases (2)
|
|
|
195,425
|
|
|
|
46,391
|
|
|
|
92,283
|
|
|
|
56,751
|
|
|
|
|
|
Operating leases (3)
|
|
|
20,710
|
|
|
|
4,444
|
|
|
|
7,669
|
|
|
|
5,610
|
|
|
|
2,987
|
|
Capital expenditures (4)
|
|
|
7,115
|
|
|
|
7,115
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchase of remaining interest in AWS (5)
|
|
|
11,000
|
|
|
|
|
|
|
|
11,000
|
|
|
|
|
|
|
|
|
|
Settlement of 2010 Class Action litigation (6)
|
|
|
13,500
|
|
|
|
13,500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset retirement obligation (7)
|
|
|
3,993
|
|
|
|
|
|
|
|
533
|
|
|
|
200
|
|
|
|
3,260
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
807,689
|
|
|
$
|
76,887
|
|
|
$
|
120,702
|
|
|
$
|
603,853
|
|
|
$
|
6,247
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
Principal payments are reflected when contractually required. As discussed previously, covenants under the Amended Revolving Credit Facility were
effectively extinguished as of December 31, 2013 by the ABL
|
56
|
Facility, and as a result the Companys technical non-compliance with certain of such covenants as of December 31, 2013 had no effect. Payments do not include estimates for future changes to
the balance outstanding under our Amended Revolving Credit Facility as of December 31, 2013.
|
(2)
|
Estimated interest on debt for all periods presented is calculated using interest rates available as of December 31, 2013 and includes fees for the unused portion
of our Amended Revolving Credit Facility. In February 2014, the Amended Revolving Credit Facility was replaced with a $200 million ABL Facility. See Note 10 of the Notes to Consolidated Financial Statements for additional information.
|
(3)
|
Represents operating leases primarily for facilities, vehicles and rental equipment.
|
(4)
|
Represents remaining amounts due for the purchase of thermal desorption equipment for the expansion of solids treatment capabilities at our North Dakota landfill site
(Note 15).
|
(5)
|
Represents the future payment to purchase the remaining 49% interest in AWS. This differs from the carrying value of the obligation, which is based on the present value
of the obligation at the reporting date and was $10.1 million at December 31, 2013. The Company was required to record this obligation due to the Companys call option to purchase, and the noncontrolling interest holders put option
to sell, the remaining interest in AWS (Note 11).
|
(6)
|
Represents cash portion of the pending settlement of 2010 Class Action litigation. Of the total settlement amount of $27.0 million, $13.5 million will be satisfied
through the issuance of 0.8 million shares of the Companys common stock. If the value of the shares falls below $13.5 million at the time of their issuance, we are required to make up the shortfall with additional shares or cash, at our
option. (Note 16).
|
(7)
|
Represents estimated future costs related to the closure and/or remediation of the Companys disposal wells and landfill.
|
EBITDA
As a supplement
to the financial statements in this Annual Report on Form 10-K, which are prepared in accordance with GAAP, we also present EBITDA. EBITDA is consolidated net income (loss) from continuing operations before net interest expense, income taxes and
depreciation and amortization. We present EBITDA because we believe this information is useful to financial statement users in evaluating our financial performance. We also use EBITDA to evaluate our financial performance, make business decisions,
including developing budgets, managing expenditures, forecasting future periods, and evaluating capital structure impacts of various strategic scenarios. EBITDA is not a measure of performance calculated in accordance with GAAP and there are
material limitations to its usefulness on a stand-alone basis. EBITDA does not include reductions for cash payments for our obligations to service our debt, fund our working capital and pay our income taxes. In addition, certain items excluded from
EBTIDA such as interest, income taxes, depreciation and amortization are significant components in understanding and assessing our financial performance. All companies do not calculate EBITDA in the same manner and our presentation may not be
comparable to those presented by other companies. Financial statement users should use EBITDA in addition to, and not as an alternative to, net (loss) income as defined under and calculated in accordance with GAAP.
The table below provides reconciliation between net loss, as determined in accordance with GAAP, and EBITDA (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Loss from continuing operations
|
|
$
|
(134,040
|
)
|
|
$
|
(6,597
|
)
|
|
$
|
(108
|
)
|
Depreciation of property, plant and equipment
|
|
|
78,812
|
|
|
|
40,130
|
|
|
|
21,413
|
|
Amortization of intangible assets
|
|
|
20,424
|
|
|
|
7,511
|
|
|
|
3,868
|
|
Interest expense, net
|
|
|
53,703
|
|
|
|
26,607
|
|
|
|
4,243
|
|
Income tax benefit
|
|
|
(73,095
|
)
|
|
|
(62,760
|
)
|
|
|
(3,777
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$
|
(54,196
|
)
|
|
$
|
4,891
|
|
|
$
|
25,639
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA for the year ended December 31, 2013 was adversely impacted by charges for impairments of
property, plant and equipment, intangible assets of $111.9 million and the write-down of investments of $4.3 million. Exclusive of these non-cash charges, EBITDA would have approximated $62.0 million.
57
Critical Accounting Policies and Estimates
Our discussion and analysis of financial condition and results of operations are based upon our audited consolidated financial statements,
which have been prepared in accordance with GAAP. The preparation of these financial statements requires management to make estimates and judgments that affect the reported amounts in the consolidated financial statements and accompanying notes.
Actual results, however, may materially differ from our calculated estimates.
We believe the following critical accounting
policies affect the more significant judgments and estimates used in the preparation of our financial statements and changes in these judgments and estimates may impact future results of operations and financial condition. For additional discussion
of our accounting policies see Note 2 of the Notes to Consolidated Financial Statements included in this Annual Report on Form 10-K.
Allowance for Doubtful Accounts
Accounts receivable are recognized and carried at the original invoice amount less an allowance for doubtful accounts. We provide an allowance for doubtful accounts to reflect the expected
uncollectability of trade receivables for both billed and unbilled receivables on our rental and non-rental revenues. We perform ongoing credit evaluations of prospective and existing customers and adjust credit limits based upon payment history and
the customers current credit worthiness, as determined by a review of their current credit information. In addition, we continuously monitor collections and payments from customers and maintain a provision for estimated credit losses based
upon historical experience and any specific customer collection issues that have been identified. Inherent in the assessment of the allowance for doubtful accounts are certain judgments and estimates including, among others, the customers
willingness or ability to pay, the Companys compliance with customer invoicing requirements, the effect of general economic conditions and the ongoing relationship with the customer. Additionally, if the financial condition of a specific
customer or our general customer base were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required. Accounts receivable are presented net of allowances for doubtful accounts of
approximately $5.5 million and $6.1 million at December 31, 2013 and 2012, respectively.
Accounting for Business
Combinations
We allocate the purchase price of acquisitions to the assets acquired and liabilities assumed based on their
estimated fair value at the date of acquisition. Any purchase price in excess of the net fair value of the assets acquired and liabilities assumed is allocated to goodwill. The fair value of certain of our assets and liabilities is determined by
(1) using estimates of replacement costs for tangible fixed assets and (2) using discounted cash flow valuation methods for estimating identifiable intangibles such as customer contracts and customer relationship intangibles (Income
Approach). We believe the assumptions used in our discounted cash flow analyses are appropriate and result in reasonable estimates of the fair value of each acquisition. We further believe the most significant assumptions used in our analyses are
the anticipated margins and overall profitability. However, we may not meet our revenue and profitability targets, working capital needs and capital expenditures may be higher than forecast, changes in credit or equity markets may result in changes
to our discount rate and general business conditions may result in changes to our terminal value assumptions used in the estimate of fair value. The purchase price allocation requires subjective estimates that, if incorrectly estimated, could be
material to our consolidated financial statements including the amount of depreciation and amortization expense recognized. The determination of the final purchase price allocation could extend over several quarters resulting in the use of
preliminary estimates that are subject to adjustment until finalized. The income approach used to value identifiable intangible assets utilizes forward-looking assumptions and projections, but considers factors unique to our businesses and related
long-range plans that may not be comparable to other companies and that are not yet publicly available. The determination of fair value under the income approach requires significant judgment on our part. Our judgment is required in developing
assumptions about future revenue growth, projected capital expenditures, changes in working capital, general and administrative expenses, attrition rates,
58
and the weighted average cost of capital. The estimated future cash flows and projected capital expenditures used under the income approach are based on our business plans and forecasts, which
consider historical results adjusted for future expectations. Future expectations include assumptions related to including economic trends, market conditions and other factors which are beyond managements control.
Contingent Consideration
Contingent consideration primarily consists of earn-out obligations in connection with business combinations that are payable by us to the
former owners of an acquiree as part of the exchange for control of the acquiree if specified future events occur or conditions are met. Contingent consideration is recorded at the acquisition date fair value, which is measured at the present value
of the consideration expected to be transferred. The fair value of contingent consideration is remeasured at the end of each reporting period with the change in fair value recognized as other income (expense) in the Consolidated Statements of
Operations. Estimates of the fair value of contingent consideration are impacted by changes to cash flow projections, growth rates, discount rates and probabilities of achieving future milestones. Contingent consideration obligations were $15.4
million at December 31, 2013, of which approximately $13.1 million and $2.3 million were classified as current and
long-term,
respectively, in our Consolidated Balance Sheets.
Impairment of Long-Lived Assets and Intangible Assets with Finite Useful Lives
We review long-lived assets including intangible assets with finite useful lives for impairment whenever events or changes in
circumstances indicate the carrying value of a long-lived asset (or asset group) may not be recoverable. If an impairment indicator is present, we evaluate recoverability by comparing the estimated future cash flows of the category classes, on an
undiscounted basis, to their carrying values. The category class represents the lowest level for which identifiable cash flows are largely independent of the cash flows of other groups of assets and liabilities. If the undiscounted cash flows exceed
the carrying value, the asset group is recoverable and no impairment is present. If the undiscounted cash flows are less than the carrying value, the impairment is measured as the difference between the carrying value and the fair value of the
long-lived asset (or asset group). Our determination that an event or change in circumstance has occurred potentially indicating the carrying amount of an asset (or asset group) may not be recoverable generally includes but is not limited to one or
more of the following: (1) a deterioration in an assets financial performance compared to historical results, (2) a shortfall in an assets financial performance compared to forecasted results, (3) changes affecting the
utility and estimated future demands for the asset, (4) a significant decrease in the market price of an asset, and (5) a current expectation that a long-lived asset will be sold or disposed of significantly before the end of its
previously estimated useful life and a significant adverse change in the extent or manner in which a long-lived asset (asset group) is being used or in its physical condition.
During the year ended December 31, 2013, long-lived asset impairment expense was $111.9 million. The impairment charge recognized consisted of write-downs to the carrying values of certain of the
Companys disposal wells, motor vehicles, trailers, rental equipment and its freshwater pipeline; including customer relationship and disposal permit intangibles, associated with the Haynesville, Eagle Ford and Barnett Shale basins. During the
year ended December 31, 2012, we recognized a $3.7 million impairment loss on three saltwater disposal wells primarily in the Haynesville shale area. We tested the disposal wells for recoverability after the wells developed technical problems
which required us to suspend their use unusable. Additionally, we also recognized a $2.4 million impairment loss related to the write-down of a customer relationship intangible associated with a portion of a prior business acquisition. The
impairment review and associated write-down was triggered by managements updated assessment of the reduced growth prospects of the business and the related impact on its expected financial performance. We could recognize future impairments to
the extent adverse events or changes in circumstances result in conditions in which long-lived assets are not recoverable. See Note 7 of the Notes to Consolidated Financial Statements for additional information.
59
Goodwill
Goodwill represents the excess of the purchase price over the fair value of the net assets of businesses acquired. Goodwill is not amortized. Instead, goodwill is required to be tested for impairment
annually and between annual tests if events or circumstances lead to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The goodwill impairment test involves a two-step process;
however, if after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, then performing the two-step impairment test is
unnecessary. In evaluating whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, an entity shall assess all relevant events and circumstances indicating whether it is more likely than not the
fair value of a reporting unit is less than its carrying value, which include but are not limited to one or more of the following: (1) macroeconomic conditions such as a deterioration in general economic conditions, limitations on accessing
capital or other developments in equity and capital markets, (2) industry and market conditions such as a deterioration in the environment in which an entity operates, an increased competitive environment, a change in the market for an entity,
(3) cost factors such as increases in raw materials or labor, (4) overall financial performance such as negative or declining cash flows or a decline in actual revenue or earnings compared with projected results or relevant prior periods,
(5) entity specific events such as changes in management, key personnel, strategy, or customers, (6) events affecting a reporting unit such as a change in the composition or carrying amount of its net assets, or a more-likely-than not
expectation of selling or disposing all, or a portion, or a reporting unit and (7) a sustained decrease in share price.
In the event a determination is made that it is more likely than not that the fair value of a reporting unit is less than its carrying
value, the first step of the two-step process must be performed. The first step of the test, used to identify potential impairment, compares the estimated fair value of a reporting unit with its carrying amount, including goodwill. If the fair value
of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired and the second step of the impairment test is unnecessary. If the carrying amount of a reporting unit exceeds its fair value, the second
step of the impairment test must be performed to measure the amount of the impairment loss, if any. The second step of the goodwill impairment test compares the implied fair value of reporting unit goodwill with the carrying amount of that goodwill.
The implied fair value of goodwill is determined in the same manner as goodwill recognized in a business combination. If the carrying amount of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is
recognized in an amount equal to that excess.
An entity has the option to bypass the qualitative assessment for any reporting
unit in any period and proceed directly to performing the first step of the two-step goodwill impairment test. We performed an assessment of qualitative factors at June 30, 2013 and concluded that certain impairment indicators were present.
These impairment indicators included adverse changes in the business climate of certain Shale basins including persistently low natural gas prices and shifts in customer end markets and resulting higher logistics costs in our Industrial Solutions
operating segment combined with lower-than-expected financial results, and the fact that the market value of our equity traded for a period of time at a value that was less than book value of our equity. We completed our impairment review of
long-lived
assets and goodwill during the quarter ended September 30, 2013, resulting in impairment charges of $111.9 million and $98.5 million in its Shale Solutions and Industrial Solutions segments,
respectively for the year ended December 31, 2013. See Notes 6 and 7 of the Notes to Consolidated Financial Statements for additional information.
We have $408.7 million in goodwill as of December 31, 2013 related to our Shale Solutions reportable segment, which has been allocated to the Shale Solutions, Pipeline and AWS reporting units. As
described in the preceding paragraphs, the results of our impairment test during the third quarter of 2013, which we updated through September 30, 2013 (our annual testing date), indicated that the goodwill relating to these reporting units was
not impaired at June 30, 2013 and September 30, 2013, since the estimated fair values of all reporting units exceeded their carrying values. With respect to the Pipeline and AWS reporting units, the estimated fair values of the reporting units
exceeded their carrying values by a substantial amount. However, while no impairment was
60
indicated as a result of our analysis and testing at June 30, 2013, September 30, 2013, or from our subsequent review at December 31, 2013, we determined that our Shale Solutions reporting unit,
with goodwill of $390.7 million, had an estimated fair value that exceeded its carrying value by less than 3.5 percent.
The
fair values of each of the reporting units as well as the related assets and liabilities utilized to assess the 2013 impairment were measured using Level 2 and Level 3 inputs as described in Note 11 of the Notes to Consolidated Financial
Statements. We believe the assumptions used in our discounted cash flow analysis are appropriate and result in reasonable estimates of the implied fair value of each reporting unit. However, these assumptions are subject to uncertainty and
relatively small declines in the future performance or cash flows of the Shale Solutions reporting unit or small changes in other key assumptions may result in the recognition of impairment charges, which could be significant. We believe the most
significant assumption used in our analysis is the expected improvement in the margins and overall profitability of our reporting units. In order to evaluate the sensitivity of the fair value calculations on the goodwill impairment test, a
hypothetical decline of greater than 65 basis points in the operating margin in our Shale Solutions reporting unit would result in an estimated carrying value in excess of its fair value, requiring us to proceed to the second step of the goodwill
impairment test. Additionally, we may not meet our revenue growth targets, working capital needs and capital expenditures may be higher than forecast, changes in credit or equity markets may result in changes to our cost of capital and discount rate
and general business conditions may result in changes to our terminal value assumptions for our reporting units. One or more of these factors, among others, could result in additional impairment charges.
In evaluating the reasonableness of our fair value estimates, we consider (among other factors) the relationship between our book value,
the market price of our common stock and the fair value of our reporting units. At December 31, 2013, the closing market price of our common stock was $16.79 per share compared to our book value per share of $24.79 as of such date. Our assessment
assumes this relationship is temporary; however, if our book value per share continues to exceed our market price per share for an extended period of time, this would likely indicate the occurrence of events or changes that could cause us to revise
our fair value estimates and perform a step-two goodwill impairment analysis. While we believe that our estimates of fair value are reasonable, we will continue to monitor and evaluate this relationship in 2014.
In the fourth quarter of 2013, we announced a plan to realign our Shale Solutions business into three operating divisions: (1) the
Northeast Division comprising the Marcellus and Utica Shale areas (2) the Southern Division comprising the Haynesville, Barnett, Eagle Ford, Tuscaloosa Marine and Mississippian Shale areas and Permian Basin and (3) the Rocky Mountain
Division comprising the Bakken Shale area. The implementation of this organizational realignment is ongoing and is expected to be completed in 2014. In connection with these planned organizational changes, we are evaluating whether the new operating
divisions constitute separate operating segments and if so, whether two or more of them can be aggregated into one or more reportable segments. As the organizational realignment progresses, we will continue to evaluate its potential impact on our
reporting units, which is a level of reporting at which goodwill is tested for impairment. To the extent we conclude the composition of our reporting units has changed, we will be required to allocate goodwill on a relative fair value basis to the
new reporting units and test the newly-allocated goodwill for impairment should triggering events occur. We may be required to record impairment of our goodwill and other intangible assets as a result of this reallocation.
Income Taxes and Valuation of Deferred Tax Assets
We are subject to federal income taxes and state income taxes in those jurisdictions in which we operate. We exercise judgment with regard to income taxes in interpreting whether expenses are deductible
in accordance with federal income tax and state income tax codes, estimating annual effective federal and state income tax rates and assessing whether deferred tax assets are, more likely than not, expected to be realized. The accuracy of these
judgments impacts the amount of income tax expense we recognize each period.
With regard to the valuation of deferred tax
assets, we record valuation allowances to reduce net deferred tax assets to the amount considered more likely than not to be realized. All available evidence is considered to determine whether, based on the weight of that evidence, a valuation
allowance for deferred tax assets is needed.
61
Future realization of the tax benefit of an existing deductible temporary difference or carryforward ultimately depends on the existence of sufficient taxable income of the appropriate character
(for example ordinary income or capital gain) within the carryback or carryforward periods available under the tax law.
Future reversals of existing taxable temporary differences are one source of taxable income that is used in this analysis. As a result,
deferred tax liabilities in excess of deferred tax assets generally will provide support for recognition of deferred tax assets. However, most of our deferred tax assets are associated with net operating loss (NOL) carryforwards, which statutorily
expire after a specified number of years; therefore, we compare the estimated timing of these taxable timing difference reversals with the scheduled expiration of our NOL carryforwards, considering any limitations on use of NOL carryforwards, and
record a valuation allowance against deferred tax assets that would expire unused.
As a matter of law, we are subject to
examination by federal and state taxing authorities. We have estimated and provided for income taxes in accordance with settlements reached with the Internal Revenue Service in prior audits. Although we believe that the amounts reflected in our tax
returns substantially comply with the applicable federal and state tax regulations, both the IRS and the various state taxing authorities can take positions contrary to our position based on their interpretation of the law. A tax position that is
challenged by a taxing authority could result in an adjustment to our income tax liabilities and related tax provision.
We
measure and record tax contingency accruals in accordance with accounting principles generally accepted in the United States (GAAP) which prescribes a threshold for the financial statement recognition and measurement of a tax position
taken or expected to be taken in a return. Only positions meeting the more likely than not recognition threshold at the effective date may be recognized or continue to be recognized. A tax position is measured at the largest amount that
is greater than 50 percent likely of being realized upon ultimate settlement.
Revenue Recognition
We recognize revenues in accordance with Accounting Standards Codification 605
(ASC 605 Revenue Recognition)
and Staff
Accounting Bulletin No 104, and accordingly all of the following criteria must be met for revenues to be recognized: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed
and determinable and collectability is reasonably assured. The majority of our revenue results from contracts with direct customers and revenues are generated upon performance of contracted services.
Services provided to our customers primarily include the transportation of fresh water and saltwater by Company-owned trucks or through a
temporary or permanent water transport pipeline. Revenues are also generated through fees from our disposal wells and rental of tanks and other equipment. Certain customers, limited to those under contract with us to utilize the pipeline, have an
obligation to dispose of a minimum quantity (number of barrels) of saltwater over the contract period. Transportation and disposal rates are generally based on a fixed fee per barrel of disposal water or, in certain circumstances; transportation is
based on an hourly rate. Revenue is recognized based on the number of barrels transported or disposed or at hourly rates for transportation. Rates for other services are based on negotiated rates with our customers and revenue is recognized when the
services have been performed.
Our Shale Solutions segment derives the majority of its revenue from the transportation of
fresh and saltwater by Company-owned trucks or through a temporary or permanent water transport pipeline to customer sites for use in drilling and hydraulic fracturing activities and from customer sites to remove and dispose of backflow and produced
water originating from oil and gas wells. Revenues are also generated through fees charged for use of our disposal wells and from the rental of tanks and other equipment. Certain customers, limited to those under contract with us to utilize the
pipeline, have an obligation to dispose of a minimum quantity (number of barrels) of saltwater over the contract period. Transportation and disposal rates are generally based on a fixed fee per barrel of disposal water or, in certain circumstances;
transportation is based on an hourly
62
rate. Revenue is recognized based on the number of barrels transported or disposed or at hourly rates for transportation. Rates for other services are based on negotiated rates with our customers
and revenue is recognized when the services have been performed.
Our discontinued Industrial Solutions segment derives the
majority of its revenue from the sale of used motor oil and antifreeze after it is refined by one of its processing facilities. Revenue is recognized upon shipment or delivery, dependent on contracted terms, of salable fuel oil or upon recovery
service provided in the receipt of waste oil and antifreeze per specific customer contract terms. Transportation costs charged to customers are included in revenue.
Insurance Liabilities
We maintain high deductible or self-insured
retention insurance policies for certain exposures including automobile, workers compensation and employee group health insurance. We carry policies for certain types of claims to provide excess coverage beyond the underlying policies and
per incident deductibles or self-insured retentions. Our insurance accruals are based on claims filed and estimates of claims incurred but not reported and are developed by our management with assistance from our third-party actuary and
third-party claims administrator. The insurance accruals are influenced by our past claims experience factors, which have a limited history, and by published industry development factors. The estimates inherent in these accruals are
determined using actuarial methods that are widely used and accepted in the insurance industry.
We evaluate the accrual, and
the underlying assumptions, regularly throughout the year and make adjustments as needed. The ultimate cost of these claims may be substantially greater than or less than the established accrual. While we believe that the recorded amounts are
reasonable, there can be no assurance that changes to our estimates will not occur due to limitations inherent in the estimation process. Changes in our assumptions and estimates could potentially have a negative impact on our earnings.
Environmental and Legal Contingencies
We have established liabilities for environmental and legal contingencies. We record a loss contingency for these matters when it is probable that a liability has been incurred and the amount of the loss
can be reasonably estimated. In determining the liability, we consider a number of factors including, but not limited to, the jurisdiction of the claim, related claims, insurance coverage when insurance covers the type of claim and our historic
outcomes in similar matters, if applicable. A significant amount of judgment and the use of estimates are required to quantify our ultimate exposure in these matters. The determination of liabilities for these contingencies is reviewed periodically
to ensure that we have accrued the proper level of expense. The liability balances are adjusted to account for changes in circumstances for ongoing issues, including the effect of any applicable insurance coverage for these matters. While we believe
that the amount accrued to-date is adequate, future changes in circumstances could impact these determinations.
We record
obligations to retire tangible, long-lived assets on our balance sheet as liabilities, which are recorded at a discount when we incur the liability. A certain amount of judgment is involved in estimating the future cash flows of such obligations, as
well as the timing of these cash flows. If our assumptions and estimates on the amount or timing of the future cash flows change, it could potentially have a negative impact on our earnings.
Estimates of Depreciable Lives
We have significant tangible capital assets
on our balance sheet which are used to generate revenues in our business operations, including heavy-duty trucks and trailers, pipelines, disposal wells, rental equipment and a landfill, as further described in Note 2 Summary of Significant
Accounting Policies. We review the residual values and useful lives of revenue earning equipment periodically. These reviews consider a variety of factors including future market conditions, competition and the expected lives of such assets
given our expected level of
63
expenditures necessary to maintain these assets in good condition. As a result, future depreciation expense rates are subject to change based upon a change in these factors. While we believe that
the carrying values and estimated revenues to be earned from these assets are appropriate, there can be no assurance that adverse changes in these assumptions and estimates will not occur, resulting in a negative impact on our earnings.
We recognize landfill depreciation expense using the units-of-consumption method based on estimated remaining airspace. Periodically, we
engage independent engineers to survey the estimate of the remaining disposal capacity for the landfill. These estimates include the waste compaction, depth of the excavation and the density of waste deposited. These assumptions and estimates, as
well as future events including regulatory action, may change the depreciable life of the landfill, resulting in a negative impact on our earnings.
Recent Accounting Pronouncements
In February 2013, the FASB issued ASU
No. 2013-02,
Reporting of Amounts Reclassified out of Accumulated Other Comprehensive Income
(ASU 2013-02). The amendments in this update do not change the current requirements for reporting net income or other comprehensive
income in financial statements. However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the
face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified is required under GAAP
to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures
required under GAAP that provide additional detail about those amounts. The amendments in this update are effective prospectively for reporting periods beginning after December 15, 2012, which for us is the reporting period starting
January 1, 2013. The adoption of ASU 2013-02 did not have a material impact on our consolidated financial statements. As permitted under ASU 2013-02, the Company has presented reclassification adjustments from each component of accumulated
other comprehensive income within a single note to the financial statements. There were no reclassification adjustments from any components of accumulated other comprehensive income during the year ended December 31, 2013. There was a less than
$0.1 million reclassification adjustment out of the unrealized losses from available-for-sale securities component of accumulated other comprehensive income during the year ended December 31, 2012.
In July 2012, the FASB issued ASU No. 2012-02,
Testing Indefinite-Lived Intangible Assets for Impairment
(ASU
2012-02). The amendments in this update provide an entity the option to first assess qualitative factors to determine whether the existence of events and circumstances indicates that it is more likely than not that the indefinite-lived
intangible asset is impaired. If, after assessing the totality of events and circumstances, an entity concludes that it is not more likely than not that the indefinite lived intangible asset is impaired, then the entity is not required to take
further action. However, if an entity concludes otherwise, then it is required to determine the fair value of the indefinite-lived intangible asset and perform the quantitative impairment test by comparing the fair value with the carrying amount in
accordance with Accounting Standards Codification subtopic 350-30,
General Intangibles other than Goodwill
. An entity also has the option to bypass the qualitative assessment for any indefinite-lived intangible asset in any period and proceed
directly to performing the quantitative impairment test. An entity will be able to resume performing the qualitative assessment in any subsequent period. The amendments in this update are effective for annual and interim impairment tests performed
for fiscal years beginning after September 15, 2012, which for us are the annual and interim periods starting January 1, 2013. As of December 31, 2013 and 2012, we did not have any intangible assets with indefinite lives.
In September 2011, the FASB issued ASU No. 2011-08,
Testing Goodwill for Impairment
(ASU 2011-08). The amendments
in this update provide an entity the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less
than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of the reporting unit is less than its carrying
64
amount, then performing the two-step impairment test is unnecessary. However, if an entity concludes otherwise, then it is required to perform the first step of the two-step impairment test by
calculating the fair value of the reporting unit and comparing the fair value with the carrying amount of the reporting unit. The amendment does not change the requirement to perform the second step of the interim goodwill impairment test to measure
the amount of an impairment loss, if any, if the carrying amount of a reporting unit exceeds its fair value. Under the amendments in this update, an entity has the option to bypass the qualitative assessment for any reporting unit in any period and
proceed directly to performing the first step of the two-step goodwill impairment test. An entity may resume performing the qualitative assessment in any subsequent period. The amendments in this update were effective for annual and interim goodwill
impairment tests performed for fiscal years beginning after December 15, 2011, which for us were the annual and interim periods starting January 1, 2012. During the second quarter of 2013, we experienced a number of potential
impairment indicators. As a result of these impairment indicators, we performed a company-wide impairment review of its long-lived assets and goodwill which it completed during the third quarter of 2013. In connection with the impairment review, we
recorded a goodwill impairment charge of $98.5 million for our Industrial Solutions reporting unit in the three months ended September 30, 2013. Such amount is included in loss from discontinued operations in our consolidated statements of
operations for the year ended December 31, 2013. See Note 20 of the Notes to Consolidated Financial Statements for additional information.
Item 7A.
|
Quantitative and Qualitative Disclosures about Market Risk
|
Inflation
Inflationary factors, such as increases in our cost structure,
could impair our operating results. Although we do not believe that inflation has had a material impact on our financial position or results of operations to date, a high rate of inflation in the future may have an adverse effect on our ability to
maintain current levels of gross margin and selling, general and administrative expenses as a percentage of sales revenue if the selling prices of our products do not increase with these increased costs.
Commodity Risk
We are
subject to market risk exposures arising from declines in oil and natural gas drilling activity in unconventional areas, which is primarily a function of the market price for oil and natural gas. Various factors beyond our control affect the market
prices for oil and natural gas, including but not limited to the level of consumer demand, governmental regulation, the price and availability of alternative fuels, political instability in foreign markets, weather-related factors and the overall
economic environment. Market prices for oil and natural gas have been volatile and unpredictable for several years, and we expect this volatility to continue in the future. Prolonged declines in the market price of oil and/or natural gas could
contribute to declines in drilling activity and accordingly would reduce demand for our services. We attempt to manage this risk by strategically aligning our assets with those areas where we believe demand is highest and market conditions for our
services are most favorable.
Interest Rates
As of December 31, 2013 the outstanding principal balance on our revolving credit facility was $136.0 million with variable rates of interest based generally on London inter-bank offered rate
(LIBOR) plus a margin of between 2.50% and 3.75% based on a ratio of the Companys total debt to EBITDA (as defined in the Revolving Credit Facility), or an alternate interest rate equal to the higher of the Federal Funds Rate as
published by the Federal Reserve Bank of New York plus 0.50%, the prime commercial lending rate of the administrative agent under the Credit Agreement, and monthly LIBOR plus 1.00%, plus a margin of between 1.50% and 2.75% based on the
Companys total debt to EBITDA (as defined in the Revolving Credit Facility). We have assessed our exposure to changes in interest rates on variable rate debt by analyzing the sensitivity to our earnings assuming various changes in market
interest rates. Assuming a hypothetical increase of 1% to the
65
interest rates on the average outstanding balance of our variable rate debt portfolio during the year ended December 31, 2013 our net interest expense for the twelve months ended
December 31, 2013 would have increased by an estimated $1.4 million, respectively.
As of December 31, 2013 the
carrying value and the fair value of our 2018 Notes was $400.0 million and $404.0 million, respectively. The fair value of our 2018 Notes is affected, among other things, by changes to market interest rates. Should we decide to retire our 2018 Notes
early, a change in interest rates could affect our future repurchase price. We have assessed our exposure to changes in interest rates by analyzing the sensitivity to the fair value of our 2018 Notes assuming various changes in market interest
rates. Assuming a hypothetical increase to market interest rates of 1%, we estimate the fair value of our 2018 Notes would decrease by approximately $13.6 million. Assuming a hypothetical decrease to market interest rates of 1%, we estimate the fair
value of our 2018 Notes would increase by approximately $14.2 million.
Item 8.
|
Financial Statements and Supplementary Data
|
The financial statements and supplementary data required by Regulation S-X are included in Item 15. Exhibits, Financial Statement Schedules contained in Part IV, Item 15 of
this Annual Report on Form 10-K.
Item 9.
|
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
|
None
Item 9A.
|
Controls and Procedures
|
Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in company reports filed or submitted under the Securities
Exchange Act of 1934, as amended (the Exchange Act) is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission, and that such information is
accumulated and communicated to management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
Evaluation of Disclosure Controls and Procedures
An evaluation of the
effectiveness of our disclosure controls and procedures was performed under the supervision of, and with the participation of, management, including our Chief Executive Officer and Chief Financial Officer, as of the end of the period covered by this
Annual Report on Form 10-K. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective.
Managements Annual Report on Internal Control over Financial Reporting
The Companys management is responsible for establishing and maintaining adequate internal control over financial reporting as
defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. The Companys internal control system is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of the
consolidated financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America.
The Companys internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly
reflect the transactions and dispositions of the assets of the Company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of consolidated financial statements in accordance with generally
accepted
66
accounting principles, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and (3) provide
reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Companys assets that could have a material effect on the consolidated financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections
of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Management assessed the effectiveness of the Companys internal control over financial reporting as of December 31, 2013. In
making its assessment of internal control over financial reporting, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in
Internal ControlIntegrated Framework
(1992).
Based on this assessment, management concluded that our internal control over financial reporting was effective as of December 31, 2013.
Our independent registered public accounting firm, KPMG LLP, has issued an audit report on the effectiveness of our internal control over financial reporting. This report has been included on page 68 of
this Annual Report on Form 10-K.
Changes in Internal Control over Financial Reporting
An evaluation of our internal controls over financial reporting was performed under the supervision of, and with the participation of,
management, including our Chief Executive Officer and Chief Financial Officer, to determine whether any changes have occurred during the quarter ended December 31, 2013 that have materially affected, or are reasonably likely to materially
affect, our internal control over financial reporting. During the fourth quarter ended December 31, 2013, the Company completed its process of aligning the processes and controls following the acquisition of Thermo Fluids Inc. in April 2012 and
Badlands Power Fuels, LLC. in November 2012, into its existing control environment.
67
Report of Independent Registered Public Accounting Firm
The Board of Directors and Stockholders
Nuverra Environmental Solutions, Inc.:
We have
audited Nuverra Environmental Solutions, Inc.s internal control over financial reporting as of December 31, 2013, based on criteria established in
Internal ControlIntegrated Framework
(1992) issued by the Committee of
Sponsoring Organizations of the Treadway Commission (COSO). Nuverra Environmental Solutions, Inc.s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of
internal control over financial reporting, included in the accompanying Item 9A (a),
Managements Annual Report on Internal Control Over Financial Reporting
. Our responsibility is to express an opinion on Nuverra Environmental
Solutions, Inc.s internal control over financial reporting 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 effective internal control over financial reporting was maintained in all
material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control
based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
A companys internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A companys internal control over financial reporting includes those policies and procedures that
(1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as
necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors
of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the companys assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of
any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
In our opinion, Nuverra Environmental Solutions, Inc. maintained, in all material respects, effective internal control over financial reporting as of
December 31, 2013, based on criteria established in Internal ControlIntegrated Framework (1992) issued by COSO.
We also have
audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Nuverra Environmental Solutions, Inc. and subsidiaries as of December 31, 2013 and 2012, and the
related consolidated statements of operations, comprehensive income, stockholders equity, and cash flows for each of the years in the three-year period ended December 31, 2013, and our report dated March 10, 2014 expressed an
unqualified opinion on those consolidated financial statements.
/s/ KPMG LLP
Phoenix, Arizona
March 10, 2014
68
Item 9B.
|
Other Information
|
On March 7, 2014, we filed with the New York Stock Exchange (NYSE) the Annual CEO Certification regarding our compliance with the NYSEs corporate governance listing standards as
required by Section 303A(12)(a) of the NYSE Listed Company Manual. In addition, we have filed as exhibits to this Annual Report on Form 10-K for the year ended December 31, 2013, the applicable certifications of its Chief Executive
Officer and its Chief Financial Officer required under Rule 13a-14(a) of the Securities Exchange Act of 1934, as amended, regarding the quality of our public disclosures.
69
NUVERRA ENVIRONMENTAL SOLUTIONS, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) Organization and Nature of Business Operations
Description of Business
Nuverra Environmental Solutions, Inc., a
Delaware Corporation, together with its subsidiaries (collectively, the Company, we, us or our) is an environmental solutions company providing full-cycle environmental solutions to our customers in
energy and industrial end-markets. The Company focuses on the delivery, collection, treatment, recycling, and disposal of restricted solids, water, waste water, used motor oil, spent antifreeze, waste fluids and hydrocarbons.
Since the acquisition of Thermo Fluids Inc. (TFI) on April 10, 2012, the Company has operated through two business
segments: Shale Solutions (formerly referred to as Fluids Management) and Industrial Solutions (formerly referred to as Recycling).
Shale Solutions provides comprehensive environmental solutions for unconventional oil and gas exploration and production including the delivery, collection, treatment, recycling, and disposal
of restricted environmental products used in the development of unconventional oil and natural gas fields. Shale Solutions currently operates in select shale areas in the United States including the predominantly oil-rich shale areas consisting of
the Bakken, Utica, Eagle Ford, Mississippian Lime and Permian Shale areas and the predominantly gas-rich Haynesville, Marcellus and Barnett Shale areas. Shale Solutions serves customers seeking fresh water acquisition, temporary water transmission
and storage, transportation, treatment, recycling or disposal of complex water flows, such as flowback and produced brine water, and solids such as drill cuttings, and management of other environmental products in connection with shale oil and gas
hydraulic fracturing operations. In addition, Shale Solutions rents equipment to customers, including providing for delivery and pickup.
Industrial Solutions provides route-based environmental services and waste recycling solutions that focus on the collection and recycling of used motor oil (UMO) and is the largest seller of
reprocessed fuel oil (RFO) from recovered UMO in the Western United States. Industrial Solutions also provides environmental services including the recycling of spent anti-freeze and oil filters.
As more fully described in Note 20, during the fourth quarter of 2013, the Company and its board of directors approved and committed to a
plan to divest TFI, which comprises its Industrial Solutions business segment. Additionally, in the fourth quarter of 2013, the Company announced a strategic organizational plan to realign its Shale Solutions business into three operating divisions:
(1) the Northeast Division comprising the Marcellus and Utica Shale areas (2) the Southern Division comprising the Haynesville, Barnett, Eagle Ford, Mississippian Shale areas and Permian Basin and (3) the Rocky Mountain Division
comprising the Bakken Shale area. The implementation of this organizational change is ongoing and is expected to be completed during 2014.
(2) Summary of Significant Accounting Policies
Basis of Presentation
The accompanying audited consolidated
financial statements of the Company have been prepared by management in accordance with the instructions to Form 10-K of the United States Securities and Exchange Commission (the SEC). These statements include all normal
recurring adjustments considered necessary by management to present a fair statement of the consolidated balance sheets, results of operations, and cash flows.
F-10
The business comprising the Companys Industrial Solutions segment is presented as
discontinued operations in the Companys consolidated financial statements for the years ended December 31, 2013 and 2012 (since its acquisition on April 10, 2012). The business comprising the Companys former Bottled Water
segment is presented as discontinued operations in the Companys consolidated financial statements for the year ended December 31, 2011. See Note 20 for additional information. Unless stated otherwise, any reference to balance sheet,
income statement and cash flow items in these consolidated financial statement notes refers to results from continuing operations.
All dollar amounts in the footnote tabular presentations are in thousands, except per share amounts and unless otherwise noted.
Principles of Consolidation
The consolidated financial statements
include the accounts of the Company and its subsidiaries. All intercompany accounts, transactions and profits are eliminated in consolidation.
Use of Estimates
The Companys consolidated financial
statements have been prepared in conformity with generally accepted accounting principles in the United States (GAAP). The preparation of the financial statements requires management to make estimates and judgments that affect the
reported amounts of assets and liabilities and the disclosure of contingencies at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting period. Estimates have been prepared on the
basis of the most current and best available information, however actual results could differ from those estimates.
Reclassifications
Certain reclassifications have been made to prior period amounts in the consolidated statements of financial position,
operations and cash flows in order to conform to the current years presentation, including recasting our Industrial Solutions business as held-for-sale and discontinued operations. Certain similar line items in the consolidated statements of
operations and cash flows have been combined to present a more concise and easier to follow presentation.
Cash Equivalents
The Company considers all highly liquid investments with original maturities of three months or less when purchased to
be cash equivalents. The Company maintains bank accounts in the United States. A majority of funds considered cash equivalents are invested in institutional money market funds. The Company has not experienced any historical losses in such accounts
and believes that the risk of any loss is minimal.
Restricted Cash
In connection with the Power Fuels merger (Note 3) assets received in exchange for the merger consideration excluded accounts receivable
greater than ninety days as of November 30, 2012. Subsequent collections on these accounts receivable by the Company are required to be remitted to the former owner of Power Fuels (Note 18). At December 31, 2013 and 2012, such unremitted
collections totaled $0.1 million and $3.5 million, respectively. Such amounts are classified as restricted cash and the corresponding liability due to the former owner is classified as a component of accrued liabilities in the accompanying
consolidated balance sheets.
F-11
Accounts Receivable
Accounts receivable are recognized and carried at original billed and unbilled amounts less allowances for estimated uncollectible amounts and estimates for potential credits. Unbilled accounts receivable
result from revenue earned for services rendered where customer billing is still in progress at the balance sheet date. Such amounts totaled approximately $21.2 million at December 31, 2013. Inherent in the assessment of these allowances are
certain judgments and estimates including, among others, the customers willingness or ability to pay, the Companys compliance with customer invoicing requirements, the effect of general economic conditions and the ongoing relationship
with the customer. Accounts with outstanding balances longer than the payment terms are considered past due. The Company writes off trade receivables when it determines that they have become uncollectible. Bad debt expense is reflected as a
component of general and administrative expenses in the consolidated statements of operations.
The following table summarizes
activity in the allowance for doubtful accounts:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Beginning balance at January 1,
|
|
$
|
6,128
|
|
|
$
|
2,636
|
|
|
$
|
1,232
|
|
Bad debt expense
|
|
|
3,275
|
|
|
|
6,517
|
|
|
|
2,206
|
|
Write-offs, net
|
|
|
(3,875
|
)
|
|
|
(3,025
|
)
|
|
|
(802
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ending balance at December 31,
|
|
$
|
5,528
|
|
|
$
|
6,128
|
|
|
$
|
2,636
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value of Financial Instruments
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market
participants at the measurement date. The carrying amounts of the Companys cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term nature of these instruments. The carrying value of the
Companys contingent consideration is adjusted to fair value at the end of each reporting period using a probability-weighted discounted cash flow model. See Note 11 for disclosures on the fair value of the Companys contingent
consideration at December 31, 2013 and 2012.
The Companys 2018 Notes are carried at cost. Their estimated fair
values are based on quoted market prices. The fair value of the Companys Amended Revolving Credit Facility and other debt obligations including capital leases, secured by various properties and equipment, bears interest at rates commensurate
with market rates and therefore their respective carrying values approximate fair value. See Note 10 for disclosures on the fair value of the Companys debt instruments at December 31, 2013.
Property and Equipment
Property and equipment is recorded at cost. Depreciation is recorded using the straight-line method over the estimated useful lives of the related assets ranging from three to thirty nine years. The
Companys landfill is depreciated using the units-of-consumption method based on estimated remaining airspace. Leasehold improvements are depreciated over the life of the lease or the life of the asset, whichever is shorter. The range of useful
lives for the components of property, plant and equipment are as follows:
|
|
|
|
|
Buildings
|
|
|
15-39 years
|
|
Building improvements
|
|
|
5-20 years
|
|
Pipelines
|
|
|
10-30 years
|
|
Disposal wells
|
|
|
3-10 years
|
|
Machinery and equipment
|
|
|
3-15 years
|
|
Equipment under capital leases
|
|
|
4-6 years
|
|
Motor vehicles and trailers
|
|
|
3-11 years
|
|
Rental equipment
|
|
|
5-15 years
|
|
Office equipment
|
|
|
3-7 years
|
|
F-12
Expenditures for betterments that increase productivity and/or extend the useful life of an
asset are capitalized. Maintenance and repair costs are charged to expense as incurred. Upon disposal, the related cost and accumulated depreciation of the assets are removed from their respective accounts, and any gains or losses are included in
cost of revenues in the consolidated statements of operations. Depreciation expense was $78.8 million, $40.1 million, and $21.4 million for the years ended December 31, 2013, 2012 and 2011, respectively, and is characterized primarily as a
component of cost of revenues in the consolidated statements of operations.
Goodwill
Goodwill represents the excess of the purchase price over the fair value of the net assets of businesses acquired. The Company has made
acquisitions over the years that have resulted in the recognition and accumulation of significant goodwill. The carrying values of goodwill at December 31, 2013 and 2012 were $408.7 million and $415.2 million, respectively (Note 6).
Goodwill is tested for impairment annually at September 30
th
and more frequently if events or circumstances lead to a
determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The goodwill impairment test involves a two-step process; however, if, after assessing the totality of events or circumstances,
an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, then performing the two-step impairment test is unnecessary.
In the event a determination is made that it is more likely than not that the fair value of a reporting unit is less than its carrying
value, the first step of the two-step process must be performed. The first step of the test, used to identify potential impairment, compares the estimated fair value of a reporting unit with its carrying amount, including goodwill. If the fair value
of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired and the second step of the impairment test is unnecessary. If the carrying amount of a reporting unit exceeds its fair value, the second
step of the impairment test must be performed to measure the amount of the impairment loss, if any. The second step of the goodwill impairment test compares the implied fair value of reporting unit goodwill with the carrying amount of that goodwill.
The implied fair value of goodwill is determined in the same manner as goodwill recognized in a business combination. If the carrying amount of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is
recognized in an amount equal to that excess.
Due to the existence of a number of potential impairment indicators at
June 30, 2013, the Company performed a company-wide impairment review of its long-lived assets and goodwill which it completed during the third quarter of 2013. In connection with the impairment review, the Company recorded a goodwill
impairment charge of $98.5 million for its Industrial Solutions reporting unit in the three months ended September 30, 2013 (Note 7). Such amount is included in loss from discontinued operations in the Companys consolidated statements of
operations for the year ended December 31, 2013 (Note 20).
Debt Issuance Costs
The Company capitalizes costs associated with the issuance of debt and amortizes them as additional interest expense over the lives of the
respective debt instrument on a straight-line basis, which approximates the effective interest method. The unamortized balance of deferred financing costs was $20.8 million and $24.4 million at December 31, 2013 and 2012, respectively, and is
included in other long-term assets in the consolidated balance sheets. Upon the prepayment of related debt, the Company accelerates the recognition of the unamortized cost, which is characterized as loss on extinguishment of debt in the consolidated
statements of operations. During the year ended December 31, 2012 the Company wrote-off the unamortized balance of issuance costs related to its Old Credit Facility in connection with the repayment of the Old Credit Facility and the issuance of
the New Credit Facility (Note 10).
F-13
Impairment of Long-Lived Assets and Intangible Assets with Finite Useful Lives
Long-lived assets including intangible assets with finite useful lives are evaluated for impairment whenever events or changes in
circumstances indicate the carrying value of a long-lived asset (or asset group) may not be recoverable. If an impairment indicator is present, the Company evaluates recoverability by comparing the estimated future cash flows of the category
classes, on an undiscounted basis, to their carrying values. The category class represents the lowest level for which identifiable cash flows are largely independent of the cash flows of other groups of assets and liabilities. If the undiscounted
cash flows exceed the carrying value, the asset group is recoverable and no impairment is present. If the undiscounted cash flows are less than the carrying value, the impairment is measured as the difference between the carrying value and the fair
value of the long-lived asset (or asset group).
Due to the existence of a number of potential impairment indicators at
June 30, 2013, the Company performed a company-wide impairment review of its long-lived assets and goodwill which it completed during the third quarter of 2013. The Company recorded long-lived asset impairment charges of $111.9 million and
$6.0 million for the years ended December 31, 2013 and 2012, respectively (Note 7).
Asset Retirement
Obligations
The Company records the fair value of estimated asset retirement obligations (AROs) associated with
tangible long-lived assets in the period incurred. Retirement obligations associated with long-lived assets are those for which there is an obligation for closures and/or site remediation at the end of the assets useful lives. These
obligations, which are initially estimated based on discounted cash flow estimates, are accreted to full value over time through charges to interest expense (Note 15). In addition, asset retirement costs are capitalized as part of the related
assets carrying value and are depreciated on a straight line basis for disposal wells and using a units-of-consumption basis for landfill costs over the assets respective useful lives.
Revenue Recognition
The Company recognizes revenues in accordance with Accounting Standards Codification 605
(ASC 605 Revenue Recognition)
and Staff Accounting Bulletin No 104, and accordingly all of the
following criteria must be met for revenues to be recognized: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed and determinable and collectability is reasonably
assured. Revenues are generated upon the performance of contracted services under formal and informal contracts with direct customers.
The Companys Shale Solutions segment derives a significant portion of its revenue from the transportation of fresh and saltwater by Company-owned trucks or through temporary or permanent water
transport pipelines to customer sites for use in drilling and hydraulic fracturing activities and from customer sites to remove and dispose of flowback and produced water originating from oil and gas wells. Revenue also includes fees charged for
disposal of oilfield wastes in the Companys landfill, disposal of fluids in the Companys disposal wells and from the rental of tanks and other equipment. Certain customers are under contract with the Company to utilize its saltwater
pipeline and have an obligation to dispose of a minimum quantity (number of barrels) of saltwater over the contract period. Transportation and disposal rates are generally based on a fixed fee per barrel of disposal water or, in certain
circumstances transportation is based on an hourly rate. Revenue is recognized based on the number of barrels transported or disposed of or at hourly rates for transportation services, depending on the customer contract. Rates for other services are
based on negotiated rates with the Companys customers and revenue is recognized when the services have been performed.
The Companys discontinued Industrial Solutions segment derives the majority of its revenue from the sale of used motor oil and
antifreeze after it is refined by one of its processing facilities. Revenue is recognized upon shipment or delivery, dependent on contracted terms, of salable fuel oil or upon recovery service provided in the
F-14
receipt of waste oil and antifreeze per specific customer contract terms. Transportation costs charged to customers are included in revenue.
The Company presents its revenues net of any sales taxes collected by the Company from its customers that are required to be remitted to
governmental taxing authorities.
Cost of Revenues
Cost of revenues consists primarily of wages and benefits for employees performing operational activities; fuel expense associated with transportation and logistics activities; costs to repair and
maintain transportation and rental equipment and disposal wells and; depreciation of operating assets included in property, plant and equipment (including rental assets).
Concentration of Customer Risk
Three of the Companys
customers comprised 40% and 39% of the Companys consolidated revenues for the years ended December 31, 2013 and 2012, respectively, and 31% and 34% of the Companys consolidated accounts receivable at December 31, 2013 and 2012,
respectively, consisted of amounts due from three customers. One of the Companys customers comprised 25% of the Companys consolidated revenues and 29% of the Companys consolidated accounts receivable for the year ended
December 31, 2011.
Income Taxes
Income taxes are accounted for using the asset and liability method. Under this method, deferred income tax assets and liabilities are recognized for the expected future tax consequences attributable to
temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases including temporary differences related to assets acquired in business combinations (see Note 3). Deferred tax
assets are also recognized for net operating loss, capital loss and tax credit carryforwards. Deferred income tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the related
temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A valuation allowance is provided for
those deferred tax assets for which realization of the related benefits is not more likely than not.
The Company measures and
records tax contingency accruals in accordance with GAAP which prescribes a threshold for the financial statement recognition and measurement of a tax position taken or expected to be taken in a return. Only positions meeting the more likely
than not recognition threshold may be recognized or continue to be recognized. A tax position is measured at the largest amount that is greater than 50 percent likely of being realized upon ultimate settlement. The Companys policy is to
recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax expense.
Reverse Stock Split
On December 3, 2013, the Company filed a Certificate of Amendment to its Restated Certificate of Incorporation in
order to effect a one-for-ten reverse split of its common stock and its common stock began trading on the New York Stock Exchange (NYSE) on a split-adjusted basis on the same date. No fractional shares were issued in connection with the
reverse stock split. As a result of the reverse stock split, the number of authorized, issued and outstanding shares of its common stock was reduced to approximately 50.0 million, 27.4 million and 26.0 million, respectively, at
December 31, 2013. Furthermore, proportional adjustments were made to stock options, warrants, and restricted stock units. The change in the number of shares resulting from the reverse stock split has been applied retroactively to all shares
and per share amounts presented in the consolidated financial statements and accompanying notes.
F-15
Share-Based Compensation
Share-based compensation for all share-based payment awards granted is based on the grant-date fair value. Generally, awards of stock
options granted to employees vest in equal increments over a three-year service period from the date of grant and awards of restricted stock vest over a two or three year service period from the date of grant. The grant date fair value of the award
is recognized to expense on a straight-line basis over the service period for the entire award, that is, over the requisite service period of the last separately vesting portion of the award. As of December 31, 2013 there was approximately $2.5
million of unrecognized compensation cost related to unvested stock options, which are expected to vest over a weighted average period of approximately of 0.8 years. As of December 31, 2013 there was approximately $1.6 million of unrecognized
compensation cost related to unvested shares of restricted stock, which are expected to vest over a weighted average period of approximately 1.3 years. As of December 31, 2013 there was approximately $1.4 million of unrecognized compensation
cost related to unvested restricted stock units. See Note 13 for additional information.
Recent Accounting Pronouncements
In February 2013, the Financial Accounting Standards Board (the FASB) issued Accounting Standards Update
(ASU) No. 2013-02,
Reporting of Amounts Reclassified out of Accumulated Other Comprehensive Income
(ASU 2013-02). The amendments in this update do not change the current requirements for reporting net income or
other comprehensive income in financial statements. However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to
present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified
is required under GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to
other disclosures required under GAAP that provide additional detail about those amounts. The amendments in this update are effective prospectively for reporting periods beginning after December 15, 2012, which for the Company is the reporting
period starting January 1, 2013. The adoption of ASU 2013-02 did not have a material impact on the Companys consolidated financial statements. As permitted under ASU 2013-02, the Company has elected to present reclassification
adjustments from each component of accumulated other comprehensive income within a single note to the financial statements. There were no reclassification adjustments from any components of accumulated other comprehensive income during the year
ended December 31, 2013. There was a less than $0.1 million reclassification adjustment out of the unrealized losses from available-for-sale securities component of accumulated other comprehensive income during the year ended December 31,
2012.
In July 2012, the FASB issued ASU No. 2012-02,
Testing Indefinite-Lived Intangible Assets for Impairment
(ASU 2012-02). The amendments in this update provide an entity the option to first assess qualitative factors to determine whether the existence of events and circumstances indicates that it is more likely than not that the
indefinite-lived intangible asset is impaired. If, after assessing the totality of events and circumstances, an entity concludes that it is not more likely than not that the indefinite lived intangible asset is impaired, then the entity is not
required to take further action. However, if an entity concludes otherwise, then it is required to determine the fair value of the indefinite-lived intangible asset and perform the quantitative impairment test by comparing the fair value with the
carrying amount in accordance with Accounting Standards Codification subtopic 350-30,
General Intangibles other than Goodwill
. An entity also has the option to bypass the qualitative assessment for any indefinite-lived intangible asset in any
period and proceed directly to performing the quantitative impairment test. An entity will be able to resume performing the qualitative assessment in any subsequent period. The amendments in this update are effective for annual and interim
impairment tests performed for fiscal years beginning after September 15, 2012, which for the Company were the annual and interim periods starting January 1, 2013. As of December 31, 2013 and 2012, the Company did not have any
intangible assets with indefinite lives.
F-16
In September 2011, the FASB issued ASU No. 2011-08,
Testing Goodwill for
Impairment
(ASU 2011-08).
The amendments in this update provide an entity the option to first assess qualitative factors to determine whether the existence of events or circumstances leads
to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the
fair value of the reporting unit is less than its carrying amount, then performing the two-step impairment test is unnecessary. However, if an entity concludes otherwise, then it is required to perform the first step of the two-step impairment test
by calculating the fair value of the reporting unit and comparing the fair value with the carrying amount of the reporting unit. The amendment does not change the requirement to perform the second step of the interim goodwill impairment test to
measure the amount of an impairment loss, if any, if the carrying amount of a reporting unit exceeds its fair value. Under the amendments in this update, an entity has the option to bypass the qualitative assessment for any reporting unit in any
period and proceed directly to performing the first step of the two-step goodwill impairment test. An entity may resume performing the qualitative assessment in any subsequent period. The amendments in this update were effective for annual and
interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011, which for the Company were the annual and interim periods starting January 1, 2012. During the second quarter of 2013, the Company experienced
a number of potential impairment indicators. As a result of these impairment indicators, the Company performed a company-wide impairment review of its long-lived assets and goodwill which it completed during the third quarter of 2013. In connection
with the impairment review, the Company recorded a goodwill impairment charge of $98.5 million for its Industrial Solutions reporting unit in the three months ended September 30, 2013 (Note 7). Such amount is included in loss from discontinued
operations in the Companys consolidated statements of operations for the year ended December 31, 2013 (Note 20).
(3)
Acquisitions
2013 Acquisitions
During the year ended December 31, 2013, the Company completed three acquisitions in its Shale Solutions business, including two in the Marcellus/Utica Shale and one in the Bakken Shale. In the
Bakken Shale, in July 2013, the Company acquired Ideal Oilfield Disposal, LLC (Ideal), a greenfield oilfield waste disposal landfill site located in North Dakota. Total consideration was $24.6 million including stock valued at $6.7
million, cash of $9.8 million, and contingent consideration of approximately $8.1 million. The acquisition included land, certain land improvements and a disposal permit. See Note 11 for additional information regarding the contingent consideration
related to Ideal. The Company has also agreed to pay the former owners of Ideal certain additional amounts based on future revenues of the landfill, which was determined to be appropriately expensed as revenue is incurred. Such amounts totaled $0.2
million in the year ended December 31, 2013.
The aggregate purchase price of the 2013 acquired businesses was
approximately $42.9 million consisting of approximately 0.7 million shares of the Companys common stock with an estimated fair value of approximately $24.3 million, cash consideration of approximately $10.5 million and contingent
consideration of approximately $8.1 million. The results of operations of the three acquisitions were not material to our consolidated results of operations during the year ended December 31, 2013.
F-17
The final allocations of the combined aggregate purchase prices of the three acquisitions
are summarized as follows:
|
|
|
|
|
Accounts receivable
|
|
$
|
753
|
|
Other current assets
|
|
|
13
|
|
Property, plant and equipment, including landfill of $24.0 million
|
|
|
41,942
|
|
Customer relationships
|
|
|
400
|
|
Goodwill
|
|
|
341
|
|
Accounts payable and accrued liabilities
|
|
|
(189
|
)
|
Other long-term liabilities
|
|
|
(302
|
)
|
|
|
|
|
|
Total
|
|
$
|
42,958
|
|
|
|
|
|
|
The goodwill relates to the pool of customer-qualified drivers acquired in connection with one of the
Marcellus/Utica acquisitions.
2012 Acquisitions
The Company has included the information below regarding acquisitions completed in the year ended December 31, 2012. The Companys acquisition of TFI and a subsequent small acquisition by TFI during
2012 is presented as discontinued operations (Note 20).
Power Fuels Merger
On November 30, 2012, the Company completed a merger (the Power Fuels Merger) with Badlands Power Fuels, LLC
(collectively with its subsidiaries, Power Fuels) of which the Companys Chief Executive Officer and Vice Chairman, Mark D. Johnsrud, was the sole member. Prior to the merger, Power Fuels was a privately-held North Dakota-based
environmental solutions company providing delivery and disposal of environmental products, fluids transportation and handling, water sales, and equipment rental services for unconventional oil and gas exploration and production customers. As a
result of the Power Fuels Merger on November 30, 2012, Power Fuels and its subsidiaries became wholly-owned subsidiaries of the Company.
The aggregate purchase price was approximately $498.8 million (net of settlement of the working capital adjustment of $2.1 million) and was comprised of the following:
|
|
|
9.5 million unregistered shares of the Companys common stock, with a fair value of approximately $371.5 million, of which 1.0 million
shares were placed into escrow for up to three years to pay certain potential indemnity claims; and
|
|
|
|
$127.3 million in cash including adjustments for targeted versus actual debt and working capital.
|
The Power Fuels Merger has been accounted for as a business combination under the acquisition method of accounting. During the year ended
December 31, 2013, the Company amended its original purchase price allocation to reflect settlement of the working capital adjustment and finalized appraisals and assessments of the tangible and intangible assets acquired and liabilities
assumed, including related tax effects. Such adjustments resulted in a decrease in recorded goodwill of $8.7 million, primarily due to an increase in the final values assigned to property, plant and equipment and the settlement of the working
capital adjustment.
F-18
The final allocation of the purchase price is summarized as follows:
|
|
|
|
|
Cash
|
|
$
|
2,111
|
|
Accounts receivable
|
|
|
57,484
|
|
Inventory
|
|
|
3,443
|
|
Other assets
|
|
|
3,271
|
|
Property, plant and equipment
|
|
|
287,818
|
|
Customer relationships
|
|
|
145,000
|
|
Goodwill
|
|
|
304,031
|
|
Accounts payable and accrued liabilities
|
|
|
(24,291
|
)
|
Debt
|
|
|
(150,367
|
)
|
Deferred income tax liabilities, net
|
|
|
(129,711
|
)
|
|
|
|
|
|
Total
|
|
$
|
498,789
|
|
|
|
|
|
|
The purchase price allocation requires subjective estimates that, if incorrect, could be material to the
Companys consolidated financial statements including the amount of depreciation and amortization expense. The most important estimates for measurement of tangible fixed assets are (a) the cost to replace the asset with a new asset and
(b) the economic useful life of the asset after giving effect to its age, quality and condition. The most important estimates for measurement of intangible assets are (a) discount rates and (b) timing and amount of cash flows
including estimates regarding customer renewals and cancellations. The goodwill recognized was attributable to the premium associated with the immediate entry into the Bakken Shale area where Power Fuels had an established workforce and operations.
Other 2012 Acquisitions
During the year ended December 31, 2012, the Company completed three other acquisitions in its Shale Solutions business (one in each of the first, second and third quarters of 2012). The aggregate
purchase price of the acquired businesses was approximately $36.1 million consisting of 0.8 million shares of the Companys common stock with an estimated fair value of approximately $30.5 million, cash consideration of approximately
$0.4 million and approximately $5.2 million of contingent consideration.
In conjunction with the acquisition
completed in Shale Solutions in the third quarter of 2012, the Company acquired a 51% interest in Appalachian Water Services, LLC (AWS) which owns and operates a water treatment and recycling facility in southwestern Pennsylvania, and
has a call option to buy the remaining 49% at a fixed price at a stated future date, and the noncontrolling interest holder has a put option to sell the remaining 49% percent to the Company under those same terms. As such, the fixed price of the
call option is equal to the fixed price of the put option. In accordance with ASC 480,
Distinguishing Liabilities from Equity
, the option contracts are viewed on a combined basis with the noncontrolling interest and accounted for
as the Companys financing of the purchase of the noncontrolling interest. Accordingly, $10.1 and $9.0 million, representing the present value of the option, was classified as other long-term obligations in the accompanying Consolidated Balance
Sheets at December 31, 2013 and 2012, respectively, with the financing accreted, as interest expense, to the strike price of the option over the period until settlement.
F-19
The allocations of the combined aggregate purchase prices at the respective 2012 acquisition
dates are summarized as follows (in thousands):
|
|
|
|
|
Accounts receivable
|
|
$
|
2,653
|
|
Equipment
|
|
|
21,108
|
|
Customer relationships
|
|
|
9,270
|
|
Goodwill
|
|
|
12,452
|
|
Other long-term obligations
|
|
|
(8,768
|
)
|
Other liabilities
|
|
|
(613
|
)
|
|
|
|
|
|
Total
|
|
$
|
36,102
|
|
|
|
|
|
|
Pro forma Financial Information Reflecting 2012-2013 Acquisitions
The following unaudited pro forma results of operations for the years ended December 31, 2013 and 2012, respectively, assume that all
of the 2012 and 2013 acquisitions, excluding the acquisition of TFI which is presented as discontinued operations, were completed at the beginning of the periods presented. The pro forma results include adjustments to reflect additional amortization
of intangibles and depreciation of assets associated with the acquired and merged businesses and additional interest expense for debt issued to consummate these transactions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011*
|
|
Revenue
|
|
$
|
529,398
|
|
|
$
|
622,853
|
|
|
$
|
454,164
|
|
Net (loss) income
|
|
$
|
(133,693
|
)
|
|
$
|
26,515
|
|
|
$
|
22,529
|
|
Net (loss) income per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
(5.43
|
)
|
|
$
|
1.11
|
|
|
$
|
1.09
|
|
Diluted
|
|
$
|
(5.43
|
)
|
|
$
|
1.00
|
|
|
$
|
1.02
|
|
*
|
The 2011 pro forma financial information above includes the 2012 and 2011 acquisitions as if they had occurred as of January 1, 2011.
|
The pro forma financial information presented above is not necessarily indicative of either the results of operations that would have
occurred had the acquisitions been effective as of January 1 of the respective years or of future operations of the Company.
(4)
Earnings Per Share
As further described in Note 2, the Company effected a one-for-ten split of its common stock on
December 3, 2013. As a result of the reverse stock split, the change in the number of shares has been applied retroactively to all shares and per share amounts presented in our consolidated financial statements and accompanying notes for the
years ended December 31, 2013, 2012 and 2011.
Basic and diluted loss per common share from continuing operations, income
(loss) per common share from discontinued operations and net income (loss) per common share have been computed using the weighted average number of shares of common stock outstanding during the period. Basic earnings per share (EPS)
excludes dilution and is computed by dividing net income (loss) applicable to common stockholders by the weighted average number of common shares outstanding for the period. Diluted EPS is based upon the weighted average number of common shares
outstanding during the period plus the additional weighted average common equivalent shares during the period. Common equivalent shares result from the assumed exercise of outstanding warrants, restricted stock and stock options, the proceeds of
which are then assumed to have been used to repurchase outstanding shares of common stock. Inherently, stock warrants are deemed to be anti-dilutive when the average market price of the common stock during the period is less than the exercise prices
of the stock warrants.
F-20
Pursuant to Accounting Standards Codification 260-10-45-18, an entity that reports a
discontinued operation in a period shall use income (loss) from continuing operations, adjusted for preferred dividends, as the control number in determining whether potential common equivalent shares are dilutive or antidilutive. That is, the same
number of potential common equivalent shares used in computing the diluted per-share amount for income (loss) from continuing operations shall be used in computing all other reported diluted per-share amounts even if those amounts would be
antidilutive to their respective basic per-share amounts. For the years ended December 31, 2013, 2012, and 2011, no shares of common stock underlying stock options, restricted stock, or other common stock equivalents were included in the
computation of diluted EPS from continuing operations because the inclusion of such shares would be antidilutive based on the net losses from continuing operations reported for those periods. Accordingly, for the years ended December 31, 2013,
2012, and 2011, no shares of common stock underlying stock options, restricted stock, or other common stock equivalents were included in the computations of diluted EPS from income (loss) from discontinued operations or diluted EPS from net income
(loss) per common share, because such shares were excluded from the computation of diluted EPS from continuing operations for those periods based on the guidance referenced above.
For the purpose of the computation of EPS, shares issued in connection with acquisitions that are contingently returnable are classified
as issued but are not included in the basic weighted average number of shares outstanding until all applicable conditions are satisfied such that the shares are no longer contingently returnable. As of December 31, 2013, 2012, and 2011,
respectively, excluded from the computation of basic EPS are approximately 1.0 million, 1.3 million, and 0.1 million, respectively of contingently returnable shares that are subject to sellers indemnification obligations and
were being held in escrow as of such dates.
The following table presents the calculation of basic and diluted net income
(loss) per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations
|
|
$
|
(134,040
|
)
|
|
$
|
(6,597
|
)
|
|
$
|
(108
|
)
|
Income (loss) from discontinued operations
|
|
|
(98,251
|
)
|
|
|
9,124
|
|
|
|
(22,898
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to common stockholders
|
|
$
|
(232,291
|
)
|
|
$
|
2,527
|
|
|
$
|
(23,006
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average sharesbasic
|
|
|
24,492
|
|
|
|
14,994
|
|
|
|
11,457
|
|
Common stock equivalents
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average sharesdiluted
|
|
|
24,492
|
|
|
|
14,994
|
|
|
|
11,457
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss per common share from continuing operationsbasic and diluted
|
|
$
|
(5.47
|
)
|
|
$
|
(0.44
|
)
|
|
$
|
(0.01
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) per common share from discontinued operationsbasic and diluted
|
|
$
|
(4.01
|
)
|
|
$
|
0.61
|
|
|
$
|
(2.00
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income (loss) per common sharebasic and diluted
|
|
$
|
(9.48
|
)
|
|
$
|
0.17
|
|
|
$
|
(2.01
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Antidilutive stock-based awards and warrants excluded
|
|
|
272
|
|
|
|
1,166
|
|
|
|
3,596
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a)
|
All per-share amounts and shares outstanding for all periods reflect the Companys one-for-ten reverse stock split, which was effective December 3, 2013.
|
(b)
|
For the years ended December 31, 2013, 2012 and 2011 no common equivalent shares were included in the computation of diluted EPS because the inclusion of such
shares would be antidilutive based on reported losses.
|
(c)
|
Antidilutive common stock equivalents include contingently issuable shares and a call option in connection with business acquisitions, litigation and stock-based
awards. The decrease in antidilutive shares in 2012 is due primarily to the expiration of certain warrants in November 2011.
|
F-21
(5) Property, Plant and Equipment, net
Property, plant and equipment consists of the following:
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Land
|
|
$
|
10,640
|
|
|
$
|
8,469
|
|
Buildings and improvements
|
|
|
40,465
|
|
|
|
32,699
|
|
Pipelines
|
|
|
74,817
|
|
|
|
76,667
|
|
Disposal wells
|
|
|
71,860
|
|
|
|
79,344
|
|
Landfill
|
|
|
27,828
|
|
|
|
|
|
Machinery and equipment
|
|
|
39,011
|
|
|
|
94,982
|
|
Equipment under capital leases
|
|
|
18,475
|
|
|
|
20,771
|
|
Motor vehicles and trailers
|
|
|
159,992
|
|
|
|
148,555
|
|
Rental equipment
|
|
|
167,912
|
|
|
|
137,084
|
|
Office equipment
|
|
|
4,976
|
|
|
|
4,214
|
|
|
|
|
|
|
|
|
|
|
|
|
|
615,976
|
|
|
|
602,785
|
|
Less accumulated depreciation
|
|
|
(137,318
|
)
|
|
|
(61,242
|
)
|
Construction in process
|
|
|
19,883
|
|
|
|
37,479
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
$
|
498,541
|
|
|
$
|
579,022
|
|
|
|
|
|
|
|
|
|
|
During the year ended December 31, 2013, the Company recorded impairment of property, plant and
equipment of $107.4 million (Note 7). Depreciation expense for the years ended December 31, 2013, 2012 and 2011 was $78.8 million, $40.1 million and $21.4 million, respectively.
(6) Goodwill and Intangible Assets
Goodwill
Changes in the carrying amount of goodwill were as follows:
|
|
|
|
|
Balance at December 31, 2011
|
|
$
|
90,008
|
|
AdditionsPower Fuels merger
|
|
|
312,715
|
|
AdditionsOther acquisitions
|
|
|
12,453
|
|
|
|
|
|
|
Balance at December 31, 2012
|
|
|
415,176
|
|
Additions2013 acquisitions
|
|
|
341
|
|
Acquisition adjustments, net
|
|
|
(6,821
|
)
|
|
|
|
|
|
Balance at December 31, 2013
|
|
$
|
408,696
|
|
|
|
|
|
|
During 2013, the Company recorded net adjustments to goodwill for the settlement of the working capital
adjustment for Power Fuels and the finalization of tangible asset valuations for Power Fuels.
F-22
Intangible Assets
Intangible assets consist of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2013
|
|
|
December 31, 2012
|
|
|
|
Gross
Carrying
Amount
|
|
|
Accumulated
Amortization
|
|
|
Net
|
|
|
Remaining
Useful Life
|
|
|
Gross
Carrying
Amount
|
|
|
Accumulated
Amortization
|
|
|
Net
|
|
|
Remaining
Useful Life
|
|
Customer relationships
|
|
$
|
163,106
|
|
|
$
|
(28,127
|
)
|
|
$
|
134,979
|
|
|
|
13.6
|
|
|
$
|
166,426
|
|
|
$
|
(8,945
|
)
|
|
$
|
157,481
|
|
|
|
14.3
|
|
Disposal permits
|
|
|
1,819
|
|
|
|
(682
|
)
|
|
|
1,137
|
|
|
|
7.2
|
|
|
|
2,588
|
|
|
|
(472
|
)
|
|
|
2,116
|
|
|
|
8.2
|
|
Customer contracts
|
|
|
17,352
|
|
|
|
(4,105
|
)
|
|
|
13,247
|
|
|
|
13.0
|
|
|
|
17,352
|
|
|
|
(3,073
|
)
|
|
|
14,279
|
|
|
|
14.0
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
182,277
|
|
|
$
|
(32,914
|
)
|
|
$
|
149,363
|
|
|
|
13.4
|
|
|
$
|
186,366
|
|
|
$
|
(12,490
|
)
|
|
$
|
173,876
|
|
|
|
14.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The remaining weighted average useful lives shown are calculated based on the net book value and
remaining amortization period of each respective intangible asset. During the years ended December 31, 2013 and 2012, the Company recorded impairment charges of $4.5 million and $2.4 million, respectively, for the write-down of certain
intangible assets (Note 7).
Amortization expense was $20.4 million, $7.5 million and $3.9 million for the years ended
December 31, 2013, 2012 and 2011, respectively. As of December 31, 2013, future amortization expense of intangible assets is estimated to be:
|
|
|
|
|
2014
|
|
$
|
16,681
|
|
2015
|
|
|
15,643
|
|
2016
|
|
|
13,930
|
|
2017
|
|
|
13,310
|
|
2018
|
|
|
12,889
|
|
Thereafter
|
|
|
76,910
|
|
|
|
|
|
|
Total
|
|
$
|
149,363
|
|
|
|
|
|
|
(7) Impairment of Long-Lived Assets and Goodwill
Due to the existence of a number of potential impairment indicators at June 30, 2013, the Company performed a company-wide impairment
review of its long-lived assets and goodwill, which it completed during the three months ended September 30, 2013. Indicators of impairment, which triggered the need for such review, included adverse changes in the business climate in certain
shale basins including persistently low natural gas prices and shifts in customer end markets and resulting higher logistics costs in the Companys Industrial Solutions operating segment, combined with lower-than-expected financial results.
Additionally, the market value of the equity of the Company traded for a period of time at a value that was less than the book value of the equity of the Company. In its Shale Solutions operating segment, long-lived assets were grouped at the shale
basin level for purposes of assessing their recoverability. Except for AWS and the Companys pipelines, the Company concluded the basin level is the lowest level for which identifiable cash flows are largely independent of the cash flows of
other assets and liabilities. For those asset groups with carrying values that exceed their undiscounted future cash flows, the Company recognized an impairment charge for the amount by which the carrying values of the asset group exceeded their
respective fair values. Long-lived asset impairment was $111.9 million for the year ended December 31, 2013. The impairment charge recognized during 2013 consists of write-downs to the carrying values of the Companys freshwater pipeline
in the Haynesville Share basin of $27.0 million and certain other long-lived assets including customer relationship and disposal permit intangibles totaling $4.5 million and disposal wells and equipment of $80.4 million in the Haynesville, Eagle
Ford, Tuscaloosa Marine and Barnett Shale basins.
F-23
Impairment charges recorded for the year ended December 31, 2013 and 2012 related to
continuing operations consist of the following:
|
|
|
|
|
|
|
|
|
|
|
2013
|
|
|
2012
|
|
Impairment of property, plant and equipment
|
|
$
|
107,413
|
|
|
$
|
3,658
|
|
Impairment of intangible assets
|
|
|
4,487
|
|
|
|
2,372
|
|
|
|
|
|
|
|
|
|
|
Total impairment
|
|
$
|
111,900
|
|
|
$
|
6,030
|
|
|
|
|
|
|
|
|
|
|
During the year ended December 31, 2012, the Company recognized a $3.7 million impairment charge on
three saltwater disposal wells primarily in the Haynesville shale area after the wells developed technical problems which required the Company to suspend their use. During the year ended December 31, 2012, the Company also recognized a $2.4
million impairment charge related to the write-down of a customer relationship intangible associated with a portion of a prior business acquisition.
The goodwill impairment test has two steps. The first step of the goodwill impairment test, used to identify potential impairment, compares the fair value of a reporting unit with its carrying amount
including goodwill. During the quarter ended September 30, 2013, the Company performed step one of the goodwill impairment test for each of its four reporting units: the Shale Solutions reporting unit, the Industrial Solutions reporting unit,
the Pipeline reporting unit and the AWS reporting unit. To measure the fair value of each reporting unit, the Company used a combination of the discounted cash flow method and the guideline public company method. Based on the results of the step-one
goodwill impairment review the Company concluded the fair values of the Shale Solutions, Pipeline and AWS reporting units exceeded their respective carrying amounts and accordingly, the second step of the impairment test was not necessary for these
reporting units. Conversely, the Company concluded the fair value of the Industrial Solutions reporting unit was less than its carrying value thereby requiring the Company to proceed to the second step of the two-step goodwill impairment test. The
second step of the goodwill impairment test, used to measure the amount of the impairment loss, compares the implied fair value of reporting unit goodwill with its carrying amount. The implied fair value of goodwill is determined in the same manner
as the amount of goodwill recognized in a business combination. After allocating the fair value of Industrial Solutions to the assets and liabilities of the reporting unit, the Company concluded the carrying value of reporting unit goodwill exceeded
its implied fair value. Accordingly, the Company recognized a goodwill impairment charge of $98.5 million in 2013 which is recorded within loss from discontinued operations in the accompanying Consolidated Statement of Operations (Note 20).
The Company has $408.7 million in goodwill as of December 31, 2013 related to its Shale Solutions reportable segment,
which has been allocated to its Shale Solutions, Pipeline and AWS reporting units. As described in the preceding paragraphs, the results of the Companys impairment test during the third quarter of 2013, which we updated through
September 30, 2013 (our annual testing date), indicated that the goodwill relating to these reporting units was not impaired at June 30, 2013 and September 30, 2013, since the estimated fair values of all reporting units exceeded
their carrying values. With respect to the Pipeline and AWS reporting units, the estimated fair values of the reporting units exceeded their carrying values by a substantial amount. However, while no impairment was indicated as a result of our
analysis and testing at June 30, 2013, September 30, 2013 or from our subsequent review at December 31, 2013, we determined that the Companys Shale Solutions reporting unit, with goodwill of $390.7 million, had an estimated fair
value that exceeded its carrying value by less than 3.5 percent.
The fair values of each of the reporting units as well
as the related assets and liabilities utilized to assess the 2013 impairment were measured using Level 2 and Level 3 inputs as described in Note 11. The Company believes the assumptions used in its discounted cash flow analysis are
appropriate and result in reasonable estimates of the implied fair value of each reporting unit. However, these assumptions are subject to uncertainty and relatively small declines in the future performance or cash flows of the Shale Solutions
reporting unit or
F-24
small changes in other key assumptions may result in the recognition of impairment charges, which could be significant. The Company believes the most significant assumption used in its analysis
is the expected improvement in the margins and overall profitability of its reporting units. In order to evaluate the sensitivity of the fair value calculations on the goodwill impairment test, a hypothetical decline of greater than 65 basis points
in the operating margin in its Shale Solutions reporting unit would result in an estimated carrying value in excess of its fair value, requiring the Company to proceed to the second step of the goodwill impairment test. Additionally, the Company may
not meet its revenue growth targets, working capital needs and capital expenditures may be higher than forecast, changes in credit or equity markets may result in changes to the Companys cost of capital and discount rate and general business
conditions may result in changes to the Companys terminal value assumptions for its reporting units. One or more of these factors, among others, could result in additional impairment charges.
In evaluating the reasonableness of the Companys fair value estimates, the Company considers (among other factors) the relationship
between its book value, the market price of its common stock and the fair value of its reporting units. At December 31, 2013, the closing market price of the Companys common stock was $16.79 per share compared to its book value per share
of $24.79 as of such date. The Companys assessment assumes this relationship is temporary; however, if the Companys book value per share continues to exceed its market price per share for an extended period of time, this would likely
indicate the occurrence of events or changes that could cause the Company to revise its fair value estimates and perform a step-two goodwill impairment analysis. While the Company believes that its estimates of fair value are reasonable, the Company
will continue to monitor and evaluate this relationship in 2014.
In the fourth quarter of 2013, the Company announced a plan
to realign its Shale Solutions business into three operating divisions: (1) the Northeast Division comprising the Marcellus and Utica Shale areas (2) the Southern Division comprising the Haynesville, Barnett, Eagle Ford and Mississippian
Shale areas and Permian Basin and (3) the Rocky Mountain Division comprising the Bakken Shale area. The implementation of this organizational realignment is ongoing and is expected to be completed in 2014. In connection with these planned
organizational changes, the Company is evaluating whether the new operating divisions constitute separate operating segments and if so, whether two or more of them can be aggregated into one or more reportable segments. As the organizational
realignment progresses, the Company will continue to evaluate its potential impact on its reporting units, which is a level of reporting at which goodwill is tested for impairment. To the extent the Company concludes the composition of its reporting
units has changed, the Company will be required to allocate goodwill on a relative fair value basis to the new reporting units and test the newly-allocated goodwill for impairment should triggering events occur. The Company may be required to record
impairment of its goodwill and other intangible assets as a result of this reallocation.
(8) Accrued Liabilities
Accrued liabilities consist of the following:
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Accrued payroll and benefits
|
|
$
|
9,380
|
|
|
$
|
6,434
|
|
Accrued insurance
|
|
|
2,881
|
|
|
|
3,548
|
|
Accrued legal and environmental
|
|
|
33,707
|
|
|
|
8,537
|
|
Accrued taxes
|
|
|
1,239
|
|
|
|
1,497
|
|
Accrued interest
|
|
|
8,294
|
|
|
|
8,991
|
|
Amounts payable to related party (Note 18)
|
|
|
110
|
|
|
|
3,536
|
|
Accrued operating costs and other
|
|
|
7,820
|
|
|
|
14,003
|
|
|
|
|
|
|
|
|
|
|
Total accrued liabilities
|
|
$
|
63,431
|
|
|
$
|
46,546
|
|
|
|
|
|
|
|
|
|
|
F-25
Accrued legal and environmental at December 31, 2013 includes $27.0 million in
connection with the pending settlement of the 2010 Class Action litigation. Of such amount, $13.5 million is expected to be settled through the issuance of the Companys common stock upon final approval of the settlement by the court (Note 16).
(9) Restructuring and Exit Costs
In June 2013, the Company initiated a plan to restructure its business in certain shale basins and reduce costs. In doing so, the Company recorded a charge of approximately $1.4 million for the year ended
December 31, 2013 which is included in other operating expenses in the accompanying consolidated statements of operations. Approximately $0.5 million of the total charge was recorded in the Shale Solutions operating segment while the remainder
was recognized at the corporate level. The total remaining liability expected to be incurred in connection with the shale basin restructuring activities is approximately $0.6 million and is included as accrued liabilities in the consolidated balance
sheets as of December 31, 2013. A reconciliation of the beginning and ending liability balances associated with the restructuring and exit activities during the year ended December 31, 2013 is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employee
Termination
Costs (a)
|
|
|
Lease Exit
Costs (b)
|
|
|
Other Exit
Costs (c)
|
|
|
Total
|
|
Restructuring and exit costs accrued at December 31, 2012
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
Restructuring and exit-related costs
|
|
|
944
|
|
|
|
211
|
|
|
|
298
|
|
|
|
1,453
|
|
Cash payments
|
|
|
(557
|
)
|
|
|
(83
|
)
|
|
|
(115
|
)
|
|
|
(755
|
)
|
Adjustments
|
|
|
(80
|
)
|
|
|
|
|
|
|
|
|
|
|
(80
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Restructuring and exit costs accrued at December 31, 2013
|
|
$
|
307
|
|
|
$
|
128
|
|
|
$
|
183
|
|
|
$
|
618
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a)
|
Employee termination costs consist primarily of severance and related costs.
|
(b)
|
Lease exit costs consist primarily of costs that will continue to be incurred under non-cancellable operating leases for their remaining term without benefit to the
Company.
|
(c)
|
Other exit costs include costs related to the movement of vehicles and equipment in connection with the significant curtailment of activity in the Tuscaloosa Marine
Shale area.
|
(10) Debt
Debt consists of the following at:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2013
|
|
|
December 31, 2012
|
|
|
|
Interest Rate
|
|
|
Maturity Date
|
|
|
Unamortized
Deferred
Financing
Costs
|
|
|
Debt
|
|
|
Debt
|
|
Amended Revolving Credit Facility (a)
|
|
|
4.61
|
%
|
|
|
Nov. 2017
|
|
|
$
|
6,115
|
|
|
$
|
135,990
|
|
|
$
|
146,990
|
|
2018 Notes (b)
|
|
|
9.875
|
%
|
|
|
Apr. 2018
|
|
|
|
14,691
|
|
|
|
400,000
|
|
|
|
400,000
|
|
Vehicle Financings (c)
|
|
|
3.30
|
%
|
|
|
Various
|
|
|
|
|
|
|
|
19,956
|
|
|
|
20,047
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total debt
|
|
|
|
|
|
|
|
|
|
$
|
20,806
|
|
|
|
555,946
|
|
|
|
567,037
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Original issue discount (d)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,084
|
)
|
|
|
(1,277
|
)
|
Original issue premium (d)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
315
|
|
|
|
366
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total debt, net
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
555,177
|
|
|
|
566,126
|
|
Less: current portion
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(5,464
|
)
|
|
|
(4,699
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
549,713
|
|
|
$
|
561,427
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a)
|
The interest rate presented represents the interest rate on the $325.0 million senior secured revolving credit facility (the Revolving Credit Facility) at
December 31, 2013.
|
F-26
(b)
|
The interest rate presented represents the coupon rate on the Companys outstanding $400 million aggregate principal amounts of 9.875% Senior Notes due 2018 (the
2018 Notes), excluding the effect of deferred financing costs, original issue discounts and original issue premiums. Including the effect of these items, the effective interest rate on the 2018 Notes is approximately 11.0%.
|
(c)
|
Vehicle financings consist of installment notes payable and capital lease arrangements related to fleet purchases with a weighted-average annual interest rate of
approximately 3.30%, which mature in varying installments between 2014 and 2017. Installment notes payable and capital lease obligations were $1.1 million and $18.8 million, respectively, at December 31, 2013 and $2.1 million and $17.9 million,
respectively, at December 31, 2012.
|
(d)
|
The issuance discount represents the unamortized difference between the $250.0 million aggregate principal amount of the 2018 Notes issued in April 2012 and the
proceeds received upon issuance (excluding interest and fees). The issuance premium represents the unamortized difference between the proceeds received in connection with the November 2012 issuance of the 2018 Notes (excluding interest and fees) and
the $150.0 million aggregate principal amount thereunder.
|
The required principal payments for all borrowings
for each of the five years following the balance sheet date are as follows:
|
|
|
|
|
2014
|
|
$
|
5,437
|
|
2015
|
|
|
4,940
|
|
2016
|
|
|
4,277
|
|
2017
|
|
|
140,090
|
|
2018
|
|
|
401,202
|
|
Thereafter
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
555,946
|
|
|
|
|
|
|
As of December 31, 2013 the estimated fair value of the Companys debt was as follows:
|
|
|
|
|
|
|
Fair Value
|
|
Revolving Credit Facility
|
|
$
|
135,990
|
|
2018 Notes
|
|
|
404,000
|
|
Vehicle Financings
|
|
|
19,956
|
|
|
|
|
|
|
Total
|
|
$
|
559,946
|
|
|
|
|
|
|
The estimated fair value of the Companys 2018 Notes is based on quoted market prices as of
December 31, 2013. The Companys Revolving Credit Facility and other debt obligations, including capital leases, bear interest at rates commensurate with market rates and therefore their respective carrying values approximate fair value.
On April 10, 2012, the Company completed a private placement offering of $250.0 million aggregate principal amount of
9.875% senior unsecured notes due April 2018 (the Notes). Net proceeds from the issuance of the Notes, after deducting underwriters fees and offering expenses, totaled $240.8 million and were used to repay the outstanding principal
balances of the Companys old credit facility and to partially finance the acquisition of TFI. In connection with the repayment of the old credit facility, the Company wrote-off approximately $2.6 million of unamortized deferred financing
costs, which is characterized as loss on extinguishment of debt in the accompanying consolidated statement of operations for the year ended December 31, 2012.
On November 5, 2012, the Company completed a private placement offering of $150.0 million aggregate principal amount of 9.875% senior unsecured notes due April 2018 (the Additional Notes
and with the Notes, are collectively referred to as the 2018 Notes ). Net proceeds from the issuance of the Additional Notes, after deducting underwriters fees and offering expenses, totaled approximately $147.0 million and were
used to partially finance the merger with Power Fuels.
F-27
The 2018 Notes are redeemable, at the Companys option, in whole or in part, at any
time and from time to time on and after April 15, 2015 at the applicable redemption price set forth below, if redeemed during the 12-month period commencing on April 15 of the years set forth below:
|
|
|
|
|
Redemption Period
|
|
Price
|
|
2015
|
|
|
104.938
|
%
|
2016
|
|
|
102.469
|
%
|
2017 and thereafter
|
|
|
100.000
|
%
|
In addition, at any time on or prior to April 15, 2015, the Company may on any one or more occasions
redeem up to 35% of the original aggregate principal amount of the 2018 Notes, with funds in an equal aggregate amount up to the aggregate proceeds of certain equity offerings of the Company, at a redemption price of 109.875%. The indentures
governing the 2018 Notes also contain restrictive covenants that, among other things, limit the Companys ability to transfer or sell assets; pay dividends or make certain distributions, buy subordinated indebtedness or securities, make certain
investments or make other restricted payments; incur or guarantee additional indebtedness or issue preferred stock; create or incur liens securing indebtedness; incur dividend or other payment restrictions affecting subsidiary guarantors; consummate
a merger, consolidation or sale of all or substantially all of our assets; enter into transactions with affiliates; engage in business other than a business that is the same or similar, reasonably related, complementary or incidental to our current
business and/or that of our subsidiaries; and make certain acquisitions or investments. The Company was compliant with these covenants at December 31, 2013.
Concurrent with the April 10, 2012 repayment and termination of its previous credit facility, the Company
entered into a new $150.0 million senior revolving credit agreement (the Revolving Credit Facility) with Wells Fargo Bank as Administrative Agent and the lenders party thereto. The Revolving Credit Facility contained an uncommitted
accordion feature, which allowed the Company to increase borrowings by up to an additional $100.0 million. On November 30, 2012, the Company amended this senior revolving credit agreement (the Amended Revolving Credit
Facility) to increase the commitment from $150.0 million to $325.0 million and extend the maturity from April 10, 2017 to November 30, 2017. Together with the $100.0 million uncommitted accordion feature under the
agreement (which was not affected by the amendment), the Amended Revolving Credit Facility provided for total maximum potential borrowings of $425.0 million. Interest on the Amended Revolving Credit Facility accrued based generally on London
inter-bank offered rate (LIBOR) plus a margin of between 2.50% and 3.75% based on a ratio of the Companys total debt to EBITDA, or an alternate interest rate equal to the higher of the Federal Funds Rate as published by the Federal
Reserve Bank of New York plus
1
/
2
of 1.00%, the prime commercial lending rate of the administrative agent
under the Credit Agreement, and monthly LIBOR plus 1.00%, plus a margin of between 1.50% and 2.75% based on the Companys total debt to EBITDA. As of December 31, 2012, the Company had $177.0 million available for borrowing under the
Amended Revolving Credit Facility. A portion of the Amended Revolving Credit Facility was available for the issuance of letters of credit up to $20.0 million in the aggregate and swingline loans, which are three day loans that can be drawn on the
same day as requested for an amount not to exceed $30.0 million. The Company was required to pay fees on the unused commitments of the lenders under the Amended Revolving Credit Facility, a letter of credit fee on the outstanding stated amount of
letters of credit plus facing fees for the letter of credit issuing banks and any other customary fees.
In September 2013,
the Company executed an amendment to the an Amended Revolving Credit Facility (the Amendment) to increase the permissible maximum total debt leverage ratio for the periods ending September 30, 2013, December 31,
2013, March 31, 2014 and June 30, 2014. The pricing of the Amended Revolving Credit Facility was unchanged by the Amendment. In connection with the Amendment, the Company incurred lender and third party fees of approximately $0.6
million.
In February 2014, the Company entered into a new asset-based revolving credit facility (ABL Facility)
with Wells Fargo Bank as Administrative Agent and other lenders which amended and replaced its Amended
F-28
Revolving Credit Facility. Initially, the ABL Facility provides a maximum credit amount of $200.0 million, which can be increased to $225.0 million through a $25.0 million accordion feature.
Initial borrowings under the ABL Facility were used to refinance amounts outstanding under the Amended Revolving Credit Facility and fund certain related fees and expenses. The ABL Facility will be used to support ongoing working capital needs and
other general corporate purposes, including growth initiatives and the potential repurchase of a portion of the Companys currently outstanding 2018 Notes. The ABL Facility, which matures at the earlier of five years from the closing date or 90
days prior to the maturity of other material indebtedness including the 2018 Notes, is secured by substantially all of the Companys assets.
The terms of the ABL Facility limit the amount the Company can borrow to the lesser of (a) $200.0 million or (b) 85% of the amount of the Companys eligible accounts receivable plus
the lower of (i) 95% of the net book value of the Companys eligible rental equipment, tractors and trailers, and (ii) 85% times the appraised net orderly liquidation value of the Companys eligible rental equipment, tractors and
trailers, less any customary reserves. The borrowing base is evaluated monthly. The full $200.00 million facility is available to the Company based on the borrowing base as of the closing date and subsequent levels of eligible receivables and
equipment continue to support $200.0 million of availability under the facility. The ABL Facility includes a letter of credit sub-limit of $10.0 million and a swingline facility sub-limit equal to 10% of the total facility size for more
immediate cash needs.
Interest will accrue on outstanding loans under the ABL Facility at a floating
rate based on, at the Companys election, (i) the greater of (a) the prime lending rate as publicly announced by Wells Fargo or (b) the Federal Funds rate plus
1
/
2
% or (c) the one month LIBOR plus one percent plus an applicable margin percentage of 0.75% to 1.50% or (ii) the LIBOR rate plus the applicable margin of 1.75% to 2.50%. The Company is also
required to pay fees on the unused commitments of the lenders under the ABL Facility, fees for outstanding letters of credit and other customary fees.
Covenants under the Amended Revolving Credit Facility, as described in our Quarterly Report on Form 10-Q for the period ended September 30, 2013, were effectively extinguished as of December 31,
2013 by the ABL Facility, and as a result any failure of the Company to comply with the covenants under the Amended Revolving Credit Facility as of December 31, 2013 would have had no effect. The ABL Facility contains certain financial
covenants that require the Company to maintain a senior leverage ratio and, upon the occurrence of certain specified conditions, a fixed charge coverage ratio as well as certain customary limitations on the Companys ability to, among other
things, incur debt, grant liens, make acquisitions and other investments, make certain restricted payments such as dividends, dispose of assets or undergo a change in control. The senior leverage ratio is calculated as the ratio of senior secured
debt to adjusted EBITDA (as defined), and is limited to 3.0 to 1.0. The Companys $400.0 million of 2018 Notes are not secured and thus are excluded from the calculation of this ratio. The fixed charge coverage ratio, which only applies at such
time the total amount drawn under the credit facility exceeds 87.5 percent of the total facility amount, requires the ratio of adjusted EBITDA (as defined) less capital expenditures to fixed charges (as defined) to be at least 1.1 to 1.0.
Costs associated with the ABL Facility totaling approximately $3.5 million will be capitalized as deferred financing costs in
the three months ending March 31, 2014, and the Company expects to write-off unamortized deferred financing costs associated with its Amended Revolving Credit Facility of approximately $3.0 million in the same period.
(11) Fair Value
Measurements
Fair value is an exit price, representing the amount that would be received to sell an asset or paid to transfer a
liability in an orderly transaction between market participants. As such, fair value is a market-based
measurement that should be determined
based on assumptions that market participants would use in pricing an asset or liability. GAAP establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value as follows:
|
|
|
Level 1Observable inputs such as quoted prices in active markets that are accessible at the measurement date for identical assets or liabilities;
|
F-29
|
|
|
Level 2Inputs, other than the quoted prices in active markets, that are observable either directly or indirectly; and
|
|
|
|
Level 3Unobservable inputs in which there is little or no market data, which require the reporting entity to develop its own assumptions.
|
Assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012
and the fair value hierarchy of the valuation techniques the Company utilized to determine such fair value are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value
|
|
|
Quoted Prices in
Active
Markets
for Identical
Assets
(Level 1)
|
|
Significant
Other
Observable
Inputs
(Level 2)
|
|
Significant
Unobservable
Inputs (Level 3)
|
|
December 31, 2013
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets-cost method investments
|
|
$
|
3,382
|
|
|
|
|
|
|
$
|
3,382
|
|
|
|
|
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Contingent consideration
|
|
|
15,457
|
|
|
|
|
|
|
|
15,457
|
|
Obligation for AWS call/put option
|
|
|
10,104
|
|
|
|
|
|
|
|
10,104
|
|
|
|
|
|
|
December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets-cost method investments
|
|
$
|
7,682
|
|
|
|
|
|
|
$
|
7,682
|
|
|
|
|
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Contingent consideration
|
|
|
10,431
|
|
|
|
|
|
|
|
10,431
|
|
Obligation for AWS call/put option
|
|
|
9,021
|
|
|
|
|
|
|
|
9,021
|
|
Contingent Consideration
The Company and its subsidiaries are liable for certain contingent consideration payments in connection with various acquisitions, as described below. The fair value of the contingent consideration
obligations was determined using a probability-weighted income approach at the acquisition date and is revalued at each reporting date or more frequently if circumstances dictate based on changes in the discount periods and rates, changes in the
timing and amount of the revenue estimates and changes in probability assumptions with respect to the likelihood of achieving the obligations. Contingent consideration is reported as current portion of contingent consideration and long-term
contingent consideration in the Companys consolidated balance sheets. Changes to the fair value of contingent consideration are recorded as other income (expense), net in the Companys consolidated statements of operations. Accretion
expense related to the increase in the net present value of the contingent liabilities is included in interest expense for the period. The fair value measurement is based on significant inputs not observable in the market, which are referred to as
Level 3 inputs.
Changes to contingent consideration obligations during the years ended December 31, 2013 and 2012 were
as follows:
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Balance at beginning of period
|
|
$
|
10,431
|
|
|
$
|
13,597
|
|
Additions related to acquisitions
|
|
|
8,141
|
|
|
|
5,445
|
|
Accretion
|
|
|
293
|
|
|
|
1,365
|
|
Cash payments
|
|
|
(1,884
|
)
|
|
|
(1,000
|
)
|
Issuances of stock
|
|
|
(47
|
)
|
|
|
(6,000
|
)
|
Changes in fair value of contingent consideration, net
|
|
|
(1,477
|
)
|
|
|
(2,976
|
)
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
15,457
|
|
|
|
10,431
|
|
Less: current portion
|
|
|
(13,113
|
)
|
|
|
(1,568
|
)
|
|
|
|
|
|
|
|
|
|
Total long-term contingent consideration
|
|
$
|
2,344
|
|
|
$
|
8,863
|
|
|
|
|
|
|
|
|
|
|
F-30
Acquisitions with remaining contingent consideration obligations are as follows:
Appalachian Water Services, LLC
The seller of the membership interests in Appalachian Water Services, LLC (AWS)
is entitled to receive additional consideration equal to $1.5 million, payable entirely in shares of the Companys common stock, in the event that EBITDA, as defined in the membership interest purchase agreement, for any consecutive twelve
months from September 1, 2012 to and ending on August 31, 2014, is equal to or greater than $4.0 million.
Keystone Vacuum, Inc.
In addition to the initial purchase price, the Company is obligated to make additional payments to the
sellers of Keystone Vacuum, Inc. (KVI), which the Company acquired on February 3, 2012, for each of the fiscal years ended January 31, 2013 through 2016, in which KVIs adjusted EBITDA (as defined) is greater than
applicable adjusted EBITDA targets. Any additional amounts payable are payable in shares of the Companys common stock or cash at the Companys discretion and any such additional payments are capped at an aggregate value of $7.5 million.
During July 2013, the Company issued less than 0.1 million shares of our common stock and made a cash payment of approximately $0.9 million in satisfaction of contingent consideration obligation for the contract period ended January 31,
2013.
Complete Vacuum and Rentals, Inc.
In addition to the initial purchase price, the Company is obligated to
make additional payments to the former shareholders of Complete Vacuum and Rentals, Inc. (CVRI), which the Company acquired on November 30, 2010. Under the terms of a February 2014 settlement agreement and release, which resolved
certain previous disputes regarding additional consideration due by the Company and indemnification obligations of the former shareholders of CVRI, the Company agreed to issue shares to the former shareholders of CVRI with a value totaling $4.0
million. Additionally, the Company may issue additional shares with a value of up to $2.0 million based on the Companys financial performance in 2014 and 2015, as defined.
Ideal Oilfield Disposal, LLC
In addition to the initial purchase price, the Company is obligated to pay the former owners of
Ideal up to a maximum amount of $8.5 million upon the issuance of a second special waste disposal permit issued to expand its current landfill, depending on permitted capacity. The additional amount is payable in cash or in shares of the
Companys common stock at the Companys discretion and is due at such time the former owners deliver to the Company all permits, certificates and other documents necessary to operate the portion of the landfill associated with the
additional capacity. The Company has also agreed to pay the former owners of Ideal certain additional amounts based on future revenues of the landfill, which was determined to be appropriately expensed as revenue is incurred.
Financing Obligation to Acquire Non-Controlling Interest
:
The fair value of the financing obligation to acquire non-controlling interest represents the present value of the Companys right
to acquire the remaining 49% interest in AWS from the noncontrolling interest holder at a fixed price of $11.0 million payable in shares of the Companys common stock. The noncontrolling interest holder has a put option to sell the remaining
49% to the Company under the same terms. In accordance with ASC 480,
Distinguishing Liabilities from Equity
, the instrument is accounted for as a financing of the Companys purchase of the minority interest. Changes to the
financing obligation to acquire the non-controlling interest during the year ended December 31, 2013 were as follows:
|
|
|
|
|
Balance at December 31, 2012
|
|
$
|
9,021
|
|
Accretion
|
|
|
1,083
|
|
|
|
|
|
|
Balance at December 31, 2013
|
|
$
|
10,104
|
|
|
|
|
|
|
In addition to the Companys assets and liabilities that are measured at fair value on a recurring
basis, the Company is required, by GAAP, to measure certain assets and liabilities at fair value on a nonrecurring basis after initial recognition. Generally, assets, liabilities and reporting units are measured at fair value on a nonrecurring basis
as a result of impairment reviews and any resulting impairment charges (Note 7). In
F-31
connection with its 2013 impairment review of long-lived assets described in Note 7, the Company measured the fair value of its asset groups for those asset groups deemed not recoverable, based
on level 3 inputs consisting of the discounted future cash flows associated with the use and eventual disposition of the asset group. In connection with its 2013 goodwill impairment review described in Note 7, the Company measured the fair value of
its reporting units using a combination of the discounted cash flow method and the guideline public company method. The discounted cash flow method is based on level 3 inputs consisting primarily of the Companys
five-year
forecast and utilizes forward-looking assumptions and projections as well as factors impacting long-range plans such as pricing, discount rates, commodity prices, etc. The guideline public company
method is based on level 2 inputs and considers potentially comparable companies and transactions within the industries where the Companys reporting units participate, and applies their trading multiples to the Companys reporting units.
This approach utilizes data from actual marketplace transactions, but reliance on its results is limited by difficultly in identifying entities that are specifically comparable to the Companys reporting units, considering their diversity,
relative sizes and levels of complexity.
Cost method investments are measured at fair value on a nonrecurring basis when
deemed necessary, using observable inputs such as trading prices of the stock as well as using discounted cash flows, incorporating adjusted available market discount rate information and the Companys estimates for liquidity risk. In the third
quarter of 2013, the Company recorded a $4.3 million charge related to the write-down of cost method investments.
(12) Equity
2013 Common Stock Issuances
|
|
|
On June 17, 2013, the Company issued approximately 0.5 million unregistered shares of common stock in a private placement pursuant to
Section 4(a)(2) under the Securities Act in connection with an acquisition in the Utica Shale basin (Note 3).
|
|
|
|
On July 9, 2013, the Company issued approximately 0.2 million unregistered shares of common stock in a private placement pursuant to
Section 4(a)(2) under the Securities Act in connection with the acquisition of Ideal Oilfield Disposal, LLC (Note 3).
|
|
|
|
On July 18, 2013, the Company issued approximately 0.1 million shares of common stock in connection with the settlement of the 2010
Derivative Action (Note 16).
|
2012 Common Stock Offerings and Issuances
|
|
|
On February 3, 2012, the Company issued approximately 0.2 million shares of common stock pursuant to the Companys Registration
Statement on Form S-4 in connection with an acquisition by Shale Solutions.
|
|
|
|
On March 30, 2012, the Company sold approximately 1.8 million shares of common stock at a reverse split-adjusted price of $44 per share in an
underwritten public offering pursuant to the Companys Registration Statement on Form S-3. The $74.4 million in net proceeds from the share issuance was used to finance a portion of the cash purchase price of TFI.
|
|
|
|
On April 10, 2012, the Company issued approximately 0.4 million shares of common stock in connection with the TFI acquisition in a private
placement pursuant to Section 4(a)(2) under the Securities Act.
|
|
|
|
On May 3, 2012, the Company issued approximately 0.2 million shares of common stock pursuant to the Companys Form S-4 in
connection with an acquisition by Shale Solutions.
|
|
|
|
On September 4, 2012, the Company issued approximately 0.3 million shares of common stock pursuant to the Companys Registration
Statement on Form S-4 in connection with an acquisition of 51% of the sellers equity by Shale Solutions.
|
|
|
|
On September 12, 2012, the Company issued approximately 0.2 million shares of common stock in connection with a partial payment under an
earn-out obligation (Note 11).
|
F-32
|
|
|
On November 30, 2012, the Company issued 9.5 million unregistered shares of common stock in connection with the Power Fuels acquisition in a
private placement pursuant to Section 4(a)(2) under the Securities Act (Note 3).
|
Preferred Stock
The Company is authorized to issue 1.0 million shares of preferred stock with such designations, voting and other
rights and preferences as may be determined from time to time by the Board of Directors. At December 31, 2013, 2012 or 2011, no shares of preferred stock were outstanding.
Reverse Stock Split
As more fully described in Note 2, the Company
affected a one-for-ten reverse split of its common stock on December 3, 2013.
(13) Share-based Compensation
Stock Options
The
Company measures the cost of employee services received in exchange for awards of stock options based on the fair value of those awards at the date of grant. Awards of stock options generally vest in equal increments over a three-year service period
from the date of grant. The fair value of stock options on the date of grant is amortized to compensation expense on a straight-line basis over the requisite service period for the entire award, that is, over the requisite service period of the last
separately vesting portion of the award. The exercise price for stock options is equal to the market price of the Companys common stock on the date of grant. The maximum contractual term of stock options is 10 years. The Company estimates the
fair value of stock options using a Black-Scholes option-pricing model.
The assumptions used to estimate the fair value of
stock awards granted in the years ended December 31, 2013, 2012 and 2011 are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Volatility
|
|
|
44.4
|
%
|
|
|
40.1
|
%
|
|
|
34.6
|
%
|
Expected term (years)
|
|
|
8
|
|
|
|
10
|
|
|
|
10
|
|
Risk free interest rate
|
|
|
2.0
|
%
|
|
|
2.1
|
%
|
|
|
2.7
|
%
|
Expected dividend yield
|
|
|
0
|
%
|
|
|
0
|
%
|
|
|
0
|
%
|
The expected term of stock options represents the period of time that the stock options granted are
expected to be outstanding taking into consideration the contractual term of the options and termination history and option exercise behaviors of the Companys employees. The expected volatility is based on the historical price volatility of
the Companys common stock. The risk-free interest rate represents the U.S. Treasury bill rate for the expected term of the related stock options. The dividend yield represents the Companys anticipated cash dividend over the expected term
of the stock options.
Compensation cost for stock options recognized in operating results is included in general and
administrative expense in the consolidated statements of operations and was $1.7 million, $2.0 million and $1.4 million for the years ended December 31, 2013, 2012 and 2011, respectively. For the year ended December 31, 2013, compensation
costs for stock options was reduced by $0.2 million for forfeitures resulting from terminations. In addition, approximately $0.5 million of stock-based compensation cost for stock options was included in the results from discontinued operations for
the year ended December 31, 2011. This cost includes expense associated with the vesting of 0.3 million stock options previously granted to employees of China Water,
F-33
which were accelerated upon closing of the Share Purchase Agreement (Note 20). The income tax expense associated with stock option activity recognized in the consolidated statements of operations
was $0.1 million for the year ended December 31, 2013. The income tax benefit associated with stock option activity recognized in the consolidated statements of operations was $0.9 million for the year ended December 31, 2012. There was no
income tax benefit recognized in the consolidated statement of operations for the year ended December 31, 2011 as all deferred tax assets were fully reserved by a valuation allowance.
A summary of stock option activity during 2013 is presented below:
|
|
|
|
|
|
|
|
|
|
|
|
|
Options
|
|
Shares
|
|
|
Weighted-Average
Exercise Price
|
|
|
Weighted-Average
Remaining
Contractual
Term
(Years)
|
|
Outstanding December 31, 2012
|
|
|
399
|
|
|
$
|
41.80
|
|
|
|
|
|
Granted
|
|
|
74
|
|
|
|
32.10
|
|
|
|
|
|
Exercised
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited, canceled, or expired
|
|
|
(157
|
)
|
|
|
42.10
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding December 31, 2013
|
|
|
316
|
|
|
$
|
39.40
|
|
|
|
6.5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercisable at December 31, 2013
|
|
|
184
|
|
|
$
|
42.30
|
|
|
|
2.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2013, there was approximately $2.5 million of unrecognized compensation expense
for employee stock options, which is expected to be recognized over a weighted-average period of approximately 0.8 years.
Restricted Stock
The Company measures the cost of employee services received in exchange for awards of restricted stock based on the market value of the
Companys common shares at the date of grant. Shares of restricted common stock generally vest over a two or three year service period from the date of grant. The fair value of the restricted stock is amortized on a straight-line basis over the
requisite service period for the entire award, that is, over the requisite service period of the last separately vesting portion of the award.
Compensation cost for shares of restricted common stock recognized in operating results is included in general and administrative expense in the consolidated statements of operations and was $1.4 million,
$1.6 million and $1.0 million, for the years ended December 31, 2013, 2012 and 2011, respectively. For the year ended December 31, 2013, compensation costs for shares of restricted common stock was reduced by $0.2 million for forfeitures
resulting from terminations. The income tax expense (benefit) associated with restricted stock activity recognized in the consolidated statements of operations was $0.2 million and ($0.7 million) for the years ended December 31, 2013 and 2012,
respectively. There was no income tax benefit recognized in the consolidated statement of operations for the year ended December 31, 2011 as all deferred tax assets were fully reserved by a valuation allowance.
A summary of non-vested restricted common stock activity is presented below:
|
|
|
|
|
|
|
|
|
Non-Vested Restricted Stock
|
|
Shares
|
|
|
Weighted-Average
Grant-Date
Fair Value
|
|
Non-vested at December 31, 2012
|
|
|
87
|
|
|
$
|
51.30
|
|
Granted
|
|
|
41
|
|
|
|
15.82
|
|
Vested
|
|
|
(25
|
)
|
|
|
52.87
|
|
Forfeited
|
|
|
(10
|
)
|
|
|
47.43
|
|
|
|
|
|
|
|
|
|
|
Non-vested at December 31, 2013
|
|
|
93
|
|
|
$
|
35.64
|
|
|
|
|
|
|
|
|
|
|
F-34
As of December 31, 2013, there was approximately $1.6 million of unrecognized
compensation expense for restricted common stock, which is expected to be recognized over a weighted-average period of approximately 1.3 years. The total fair value of shares vested during the years ended December 31, 2013, 2012 and 2011
was approximately $0.4 million, $0.4 million and $1.3 million, respectively.
Restricted Stock Units
The Company measures the cost of employee services received in exchange for awards of restricted stock units based on the market value of
the Companys common shares at the date of grant. Restricted common stock units generally vest over a two or three year service period from the date of grant. The fair value of the restricted stock units is amortized on a straight-line basis
over the requisite service period for the entire award, that is, over the requisite service period of the last separately vesting portion of the award.
Compensation cost for restricted common stock units recognized in operating results is included in general and administrative expense in the consolidated statements of operations and was approximately
$0.6 million for the year ended December 31, 2013. There was no compensation cost recognized in the consolidated statements of operations for restricted common stock units for the years ended December 31, 2012 and 2011 as no restricted
common stock units were granted in those years. The income tax benefit associated with restricted common stock unit activity recognized in the consolidated statements of operations was $0.2 million for the year ended December 31, 2103. There
was no income tax benefit recognized in the consolidated statements of operations for the years ended December 31, 2012 and 2011 as restricted common stock units were not granted until fiscal 2013.
A summary of non-vested restricted common stock activity is presented below:
|
|
|
|
|
|
|
|
|
Non-Vested Restricted Stock Units
|
|
Shares
|
|
|
Weighted-Average
Grant-Date
Fair Value
|
|
Non-vested at December 31, 2012
|
|
|
|
|
|
$
|
|
|
Granted
|
|
|
62
|
|
|
|
34.40
|
|
Vested
|
|
|
|
|
|
|
|
|
Forfeited
|
|
|
(6
|
)
|
|
|
36.30
|
|
|
|
|
|
|
|
|
|
|
Non-vested at December 31, 2013
|
|
|
56
|
|
|
$
|
35.64
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2013, there was approximately $1.4 million of unrecognized compensation
expense for restricted common stock units, which is expected to be recognized over a weighted-average period of approximately 1.3 years. No restricted stock units were vested at December 31, 2013 as restricted stock units were not granted
prior to 2013, and the first units are not expected to vest until 2014.
Employee Stock Purchase Plan
Effective September 1, 2013, the Company established a noncompensatory employee stock purchase plan (ESPP) which permits
all regular full-time employees and employees who work part time over 20 hours per week to purchase shares of the Companys common stock at a five percent discount. Annual employee contributions are limited to twenty-five thousand dollars, are
voluntary and made through a bi-weekly payroll deduction.
F-35
(14) Income Taxes
The components of income tax expense (benefit) are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
Current income tax expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$
|
(3,443
|
)
|
|
$
|
(6,845
|
)
|
|
$
|
|
|
State
|
|
|
(1,053
|
)
|
|
|
763
|
|
|
|
500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current
|
|
|
(4,496
|
)
|
|
|
(6,082
|
)
|
|
|
500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income tax benefit:
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
(64,292
|
)
|
|
|
(51,557
|
)
|
|
|
(4,277
|
)
|
State
|
|
|
(4,307
|
)
|
|
|
(5,121
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Deferred
|
|
|
(68,599
|
)
|
|
|
(56,678
|
)
|
|
|
(4,277
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income tax benefit attributable to continuing operations
|
|
$
|
(73,095
|
)
|
|
$
|
(62,760
|
)
|
|
$
|
(3,777
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
A reconciliation of the income tax benefit and the amount computed by applying the statutory federal
income tax rate of 35% to loss from continuing operations before income taxes is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
|
2011
|
|
U.S. federal income tax benefit at statutory rate
|
|
|
35.0
|
%
|
|
|
35.0
|
%
|
|
|
35.0
|
%
|
State and local income taxes, net of federal benefit
|
|
|
4.1
|
%
|
|
|
4.3
|
%
|
|
|
(8.4
|
%)
|
Compensation
|
|
|
(0.3
|
%)
|
|
|
(0.4
|
%)
|
|
|
(3.7
|
%)
|
Transaction costs
|
|
|
0.0
|
%
|
|
|
(2.4
|
%)
|
|
|
(10.2
|
%)
|
Change in fair value of contingent consideration
|
|
|
0.1
|
%
|
|
|
(1.2
|
%)
|
|
|
6.7
|
%
|
Loss on disposal of China Water
|
|
|
0.0
|
%
|
|
|
0.0
|
%
|
|
|
976.9
|
%
|
Change in valuation allowance
|
|
|
(2.1
|
%)
|
|
|
55.4
|
%
|
|
|
(909.5
|
%)
|
Other
|
|
|
(1.5
|
%)
|
|
|
(0.3
|
%)
|
|
|
10.4
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Benefit for income taxes
|
|
|
35.3
|
%
|
|
|
90.4
|
%
|
|
|
97.2
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
On May 3, 2013, North Dakota enacted SB 2156, which lowered the top corporate income tax rate from
5.15% to 4.53%, effective for tax years beginning after December 31, 2012. This rate reduction resulted in a reduction to the Companys overall deferred tax liability of $1.1 million, and was recorded as an income tax benefit in the
quarter ended June 30, 2013. During 2013, the Company also recorded $3.0 million of adjustments from prior periods to deferred tax assets and liabilities associated with fixed assets, certain acquired intangible assets and net operating loss
carryforwards.
F-36
Significant components of the Companys deferred tax assets and liabilities as of
December 31, 2013 and 2012 are as follows:
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Deferred tax assets:
|
|
|
|
|
|
|
|
|
Reserves
|
|
$
|
11,783
|
|
|
$
|
3,451
|
|
Net operating losses
|
|
|
106,763
|
|
|
|
85,123
|
|
Equity based compensation
|
|
|
1,806
|
|
|
|
1,434
|
|
Other
|
|
|
5,114
|
|
|
|
4,221
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
125,466
|
|
|
|
94,229
|
|
Less: Valuation allowance
|
|
|
(6,076
|
)
|
|
|
(1,657
|
)
|
|
|
|
|
|
|
|
|
|
Total deferred tax assets
|
|
|
119,390
|
|
|
|
92,572
|
|
|
|
|
|
|
|
|
|
|
Deferred tax liabilities:
|
|
|
|
|
|
|
|
|
Fixed assets and intangibles
|
|
|
(130,032
|
)
|
|
|
(167,210
|
)
|
Deferred financing costs
|
|
|
(2,041
|
)
|
|
|
(2,023
|
)
|
Other
|
|
|
(227
|
)
|
|
|
(51
|
)
|
|
|
|
|
|
|
|
|
|
Total deferred tax liabilities
|
|
|
(132,300
|
)
|
|
|
(169,284
|
)
|
|
|
|
|
|
|
|
|
|
Net deferred tax liability
|
|
$
|
(12,910
|
)
|
|
$
|
(76,712
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Current deferred tax assets, net:
|
|
|
|
|
|
|
|
|
Deferred tax assets
|
|
$
|
31,754
|
|
|
$
|
11,949
|
|
Deferred tax liabilities
|
|
|
(219
|
)
|
|
|
(45
|
)
|
Valuation allowance
|
|
|
(1,463
|
)
|
|
|
(220
|
)
|
|
|
|
|
|
|
|
|
|
Total current deferred tax assets, net
|
|
|
30,072
|
|
|
|
11,684
|
|
|
|
|
|
|
|
|
|
|
Long-term deferred tax liabilities, net:
|
|
|
|
|
|
|
|
|
Deferred tax assets
|
|
|
93,712
|
|
|
|
82,281
|
|
Deferred tax liabilities
|
|
|
(132,081
|
)
|
|
|
(169,240
|
)
|
Valuation allowance
|
|
|
(4,613
|
)
|
|
|
(1,437
|
)
|
|
|
|
|
|
|
|
|
|
Total long-term deferred tax liabilities, net
|
|
|
(42,982
|
)
|
|
|
(88,396
|
)
|
|
|
|
|
|
|
|
|
|
Net deferred tax liability
|
|
$
|
(12,910
|
)
|
|
$
|
(76,712
|
)
|
|
|
|
|
|
|
|
|
|
As of December 31, 2013, the Company had net operating loss (NOL) carryforwards for
federal income tax purposes of approximately $282.9 million, which expire in 2030-2033, and state NOL carryforwards of approximately $158.4 million, which expire in 2017 through 2033.
As required by GAAP, management assesses the recoverability of the Companys deferred tax assets on a regular basis and records a
valuation allowance for any such assets where recoverability is determined to be not more likely than not. The Companys evaluation of its valuation allowance resulted in a release of $38.5 million of valuation allowance in 2012. The Company
determined that realization of these deferred tax assets is more likely than not based on future taxable income arising from the reversal of deferred tax liabilities acquired in connection with the Power Fuels Merger described in Note 3 and the TFI
acquisition described in Note 20. The Company has recorded a valuation allowance of $6.1 million as of December 31, 2013 for certain state net operating loss carryforwards that management does not believe are more likely than not to be realized
and for the write-down of the Companys investment in UGSI, which would result in a capital loss that would more likely than not be unrealizable prior to its expiration.
F-37
A reconciliation of the Companys valuation allowance on deferred tax assets for the
years ended December 31, 2013 and 2012 is as follows:
|
|
|
|
|
|
|
|
|
|
|
2013
|
|
|
2012
|
|
Beginning balance at January 1,
|
|
$
|
1,657
|
|
|
$
|
40,188
|
|
Additions to valuation allowance
|
|
|
4,419
|
|
|
|
|
|
Valuation allowance release, net
|
|
|
|
|
|
|
(38,531
|
)
|
|
|
|
|
|
|
|
|
|
Ending balance at December 31,
|
|
$
|
6,076
|
|
|
$
|
1,657
|
|
|
|
|
|
|
|
|
|
|
Pursuant to United States Internal Revenue Code Section 382, if the Company underwent an ownership
change, the NOL carryforward limitations would impose an annual limit on the amount of the taxable income that may be offset by the Companys NOL generated prior to the ownership change. The Company has determined that an ownership change
occurred on November 30, 2012 as a result of the stock consideration transferred in the Power Fuels Merger. The Company does not expect any limitation under Section 382 to result in federal NOLs expiring unused. If a subsequent
ownership change were to occur, the Company may be unable to use a significant portion of its NOL to offset future taxable income.
As of December 31, 2013, the Company had unrecognized tax benefits attributable to discontinued operations totaling approximately $0.3 million which would favorably impact the Companys
effective tax rate if subsequently recognized. As of December 31, 2012, and 2011, the Company had no unrecognized tax benefits recorded.
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
|
|
|
|
|
|
|
Year Ended
December 31,
2013
|
|
Unrecognized tax benefits balance at beginning of year
|
|
$
|
|
|
Additions for tax positions taken in prior periods
|
|
|
306
|
|
Reductions for lapses of statute of limitations
|
|
|
(23
|
)
|
|
|
|
|
|
Unrecognized tax benefits balance at end of year
|
|
$
|
283
|
|
|
|
|
|
|
The Company recognizes potential accrued interest and penalties related to unrecognized tax benefits as a
component of income tax expense. Accrued interest and penalties as of December 31, 2013 was approximately $0.1 million and no interest and penalties were accrued as of December 31, 2012 and 2011. To the extent interest and penalties are
not assessed with respect to uncertain tax positions, amounts accrued will be reduced and reflected as a reduction of the overall income tax provision.
The Company anticipates a reduction of $0.1 million in the total amount of unrecognized tax benefits during the next twelve months as a result of the lapsing of the statute of limitations related to a
state tax position.
The Company and its subsidiaries are subject to the following significant taxing jurisdictions: U.S.
Federal, Pennsylvania, Louisiana, North Dakota, Texas, West Virginia, Arizona, and Oregon. The Company has had NOLs in various years for federal purposes and for many states. The statute of limitations for a particular tax year for examination by
the Internal Revenue Service is generally three years subsequent to the filing of the associated tax return. However, the Internal Revenue Service can adjust NOL carryovers up to three years subsequent to the last year in which the loss carryover is
finally used. Accordingly, there are multiple years open to examination. The statute of limitations is generally three to four years for many of the states where the Company operates.
During 2013, the Internal Revenue Service completed its examination of the Companys Federal income tax returns for the years ended
December 31, 2008 through 2010 with no changes. The Company is currently not under income tax examination in any other tax jurisdictions.
F-38
(15) Commitments and Contingencies
Environmental Liabilities
We are subject to the environmental
protection and health and safety laws and related rules and regulations of the United States and of the individual states, municipalities and other local jurisdictions where we operate. The Companys Shale Solutions business is subject to
rules and regulations promulgated by the Texas Railroad Commission, the Texas Commission on Environmental Quality, the Louisiana Department of Natural Resources, the Louisiana Department of Environmental Quality, the Ohio Department of Natural
Resources, the Pennsylvania Department of Environmental Protection, the North Dakota Department of Health, the North Dakota Industrial Commission, Oil and Gas Division, and the North Dakota State Water Commission and, in Montana, the rules and
regulations of the Montana Department of Environmental Quality and the Montana Board of Oil and Gas, among others. These laws, rules and regulations address environmental, health and safety and related concerns, including water quality and employee
safety. We have installed safety, monitoring and environmental protection equipment such as pressure sensors and relief valves, and have established reporting and responsibility protocols for environmental protection and reporting to such
relevant local environmental protection departments as required by law.
The Companys Industrial Solutions business
involves the use, handling, storage and contracting for recycling or disposal of environmentally sensitive materials, such as waste motor oil and filters, solvents, transmission fluid, antifreeze, lubricants and degreasing agents. Accordingly,
the Companys Industrial Solutions business is subject to regulation by various federal, state, and local authorities with respect to health, safety and environmental quality and standards. The Industrial Solutions business is also subject
to laws, ordinances, and regulations governing the investigation and remediation of contamination at facilities we operate or to which we send hazardous substances for treatment, recycling or disposal. In particular, the United States
Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, imposes joint, strict, and several liability on owners or operators of facilities at, from, or to which a release of hazardous substances has occurred,
parties that generated hazardous substances that were released at such facilities and parties that transported or arranged for the transportation of hazardous substances to such facilities. A majority of states have adopted statutes comparable
to, and in some cases more stringent than, CERCLA.
Management believes the Company is in material compliance with all
applicable environmental protection laws and regulations in the United States and the states in which the Company operates. The Company believes that there are no unrecorded liabilities in connection with the Companys compliance with
environmental laws and regulations. The consolidated balance sheet at December 31, 2013 included accruals totaling $1.5 million for various environmental matters, including the estimated cost to comply with a Louisiana Department of
Environmental Quality requirement that the Company perform testing and monitoring at certain locations to confirm that prior spills were remediated in accordance with applicable requirements.
Leases
Included in property and equipment in the accompanying
consolidated balance sheets are the following assets held under capital leases at December 31, 2013:
|
|
|
|
|
Leased equipment
|
|
$
|
18,475
|
|
Less accumulated depreciation
|
|
|
(5,843
|
)
|
|
|
|
|
|
Leased equipment
|
|
$
|
12,632
|
|
|
|
|
|
|
Capital lease obligations consist primarily of vehicle leases with periods expiring at various dates
through 2017 at variable interest rates and fixed interest rates, which were approximately 3.30% at December 31, 2013. Capital lease obligations amounted to $18.8 million and $17.9 million at December 31, 2013 and 2012, respectively.
F-39
Future minimum lease payments, by year and in the aggregate, for capital leases are as
follows at:
|
|
|
|
|
|
|
December 31,
|
|
2014
|
|
$
|
5,228
|
|
2015
|
|
|
5,082
|
|
2016
|
|
|
4,580
|
|
2017
|
|
|
4,201
|
|
2018
|
|
|
1,188
|
|
Thereafter
|
|
|
|
|
|
|
|
|
|
Total minimum lease payments
|
|
|
20,279
|
|
Less amount representing executor costs
|
|
|
(266
|
)
|
|
|
|
|
|
Net minimum lease payments
|
|
|
20,013
|
|
Less amount representing interest (3.30% at December 31, 2013)
|
|
|
(1,195
|
)
|
|
|
|
|
|
Present value of net minimum lease payments
|
|
$
|
18,818
|
|
|
|
|
|
|
The Company also rents transportation equipment, real estate and certain office equipment under operating
leases. Certain real estate leases require the Company to pay maintenance, insurance, taxes and certain other expenses in addition to the stated rentals. Lease expense under operating leases and rental contracts amounted to $7.5 million, $7.8
million and $0.6 million for the years ended December 31, 2013, 2012 and 2011, respectively.
Future minimum lease
payments, by year and in the aggregate, for noncancelable operating leases with initial or remaining terms of one year or more are as follows at:
|
|
|
|
|
|
|
December 31,
|
|
2014
|
|
$
|
4,444
|
|
2015
|
|
|
4,000
|
|
2016
|
|
|
3,669
|
|
2017
|
|
|
3,373
|
|
2018
|
|
|
2,237
|
|
Thereafter
|
|
|
2,987
|
|
|
|
|
|
|
Total minimum lease payments
|
|
$
|
20,710
|
|
|
|
|
|
|
Asset Retirement Obligations
At December 31, 2013, the Company had approximately $2.8 million of asset retirement obligations related to its disposal wells and landfill which are recorded in Other long-term
liabilities in the accompanying consolidated balance sheet.
Surety Bonds and Letters of Credits
At December 31, 2013, the Company had surety bonds outstanding of approximately $5.2 million primarily to support financial assurance
obligations related to its landfill and disposal wells. Additionally, the Company has agreed to indemnify its insurance carriers, subject to a complete reservation of rights, up to 9.0 million, for losses sustained in excess of the insurance
coverage of $16.0 million in connection with the surety bond in connection with the Texas Jury Verdict (Note 16). At December 31, 2013, the Company had outstanding irrevocable letters of credit totaling $3.1 million to support various
agreements, leases and insurance policies.
F-40
Capital Expenditures Commitment
The Company has entered into an agreement to purchase approximately $13.0 million of thermal desorption equipment for expansion of its
solids treatment capabilities at its landfill site in North Dakota. As of December 31, 2013, approximately $7.1 million of purchases remained under this agreement.
(16) Legal and Insurance Matters
There are various lawsuits, claims,
investigations and proceedings that have been brought or asserted against the Company, which arise in the ordinary course of business, including actions with respect to securities and shareholder class actions, personal injury, vehicular and
industrial accidents, commercial contracts, legal and regulatory compliance, securities disclosure, labor and employment, employee benefits and environmental matters, the more significant of which are summarized below. The Company records a
provision for these matters when it is both probable that a liability has been incurred and the amount of the loss can be reasonably estimated. Any provisions are reviewed at least quarterly and are adjusted to reflect the impact and status of
settlements, rulings, advice of counsel and other information and events pertinent to a particular matter.
The Company
believes that it has valid defenses with respect to legal matters pending against it. Based on its experience, the Company also believes that the damage amounts claimed in the lawsuits disclosed below are not necessarily a meaningful indicator of
the Companys potential liability. Litigation is inherently unpredictable, however, and it is possible that the Companys results of operations or cash flow could be materially affected in any particular period by the resolution of one or
more of the legal matters pending against it.
Texas Jury Verdict
On June 4, 2012, a lawsuit was commenced in the District Court of Dimmit County, Texas, alleging wrongful death in a case involving a
vehicle accident. The accident occurred in May 2012 and involved our subsidiary Heckmann Water Resources (CVR), Inc.(CVR) truck and one other vehicle. The case is captioned
Jose Luis Aguilar, Individually; Eudelia Aguilar,
Individually; Vanessa Arce, Individually; Eudelia Aguilar and Vanessa Arce, as Personal Representatives of the Estate of Carlos Aguilar; Clarissa Aguilar, as Next Friend of Carlos Aguilar, Jr., Alyssa Nicole Aguilar, Andrew Aguilar, Marcus Aguilar,
and Kaylee Aguilar; and Elsa Quinones as Next Friend of Karime and Carla Aguilar, Plaintiffs vs. Heckmann Water Resources (CVR), Inc. and Ruben Osorio Gonzalez, Defendants.
On December 5, 2013, a jury verdict was rendered against CVR in the
amount of $281.6 million, which award was subsequently reduced to $163.8 million when the judgment was signed by the court on January 7, 2014. CVR filed post-trial motions on February 6, 2014, seeking (among other things) to have the
judgment overturned or a new trial ordered, and intends to continue to vigorously defend this case through the Texas appellate court system. CVRs insurers have provided a surety bond of $25.0 million to stay enforcement of the
judgment until the Texas appeals process is final. There will be no final resolution of the trial court judgment until the appellate process is concluded or the case is otherwise resolved. We have agreed to indemnify our insurance carriers, subject
to a complete reservation of rights, up to $9.0 million, for losses sustained in excess of the insurance coverage of $16.0 million in connection with the surety bond.
On January 29, 2014, a lawsuit was commenced in the District Court of Dimmit County, Texas captioned
Clarissa Aguilar, as Next Friend of Carlos Aguilar, Jr., Alyssa Nicole Aguilar, Andrew Aguilar,
Marcus Aguilar, and Kaylee Aguilar v. Zurich American Insurance Company, Heckmann Water Resources (CVR), Inc., Heckmann Water Resources Corp., and Nuverra Environmental Solutions, Inc. f/k/a Heckmann Corp.,
Cause
No. 14-01-12176-DCV. Plaintiff seeks a declaratory judgment that Nuverra Environmental Solutions, Inc. and Heckmann Water Resources Corp. are the alter egos of CVR, and therefore these entities are jointly and severally liable for the
judgment against CVR in the wrongful death action. Plaintiff also seeks a declaratory judgment that Zurich American Insurance Company, as CVRs insurer, breached certain obligations when they failed to settle the wrongful death action
within insurance policy limits, and is therefore liable for the judgment entered against CVR. The Company, Heckmann Water Resources Corp., and CVR intend to vigorously defend themselves against the claims asserted in this action.
F-41
The Company currently estimates the potential loss for these cases to range between zero and
the maximum judgment amount and accrued interest. The trial court judgment or any revised result that may be achieved through an appeals process (which could take several years to complete) could result in multiple potential outcomes within this
range. Considering the status of the judicial process and based on currently available information, the Company has determined that this claim is not yet probable and has not established a reserve for this matter at this time. However, there can be
no assurance that the Company will not be required to establish significant reserves in connection with this matter in the future, and to the extent any such accrued liability is not fully offset by insurance recoveries it could have a material
adverse effect on the Companys business, liquidity, financial condition and results of operations.
Shareholder Litigation
2010 Derivative Action.
In November 2010, a stockholder filed a derivative complaint, purportedly on
behalf of the Company, against various officers and directors (the 2010 Derivative Action). The 2010 Derivative Action alleged claims for breach of fiduciary duty, waste of corporate assets, and unjust enrichment in connection with
the acquisition of China Water. On April 1, 2013, the Company and plaintiffs entered into a Stipulation of Settlement which was granted final approval by the Superior Court of California on June 24, 2013. Under the Stipulation of
Settlement, the Company agreed to make certain corporate governance changes, pay the plaintiffs attorneys $0.3 million in cash (which was paid by the Companys insurance carriers) and issue 0.1 million shares of the Companys
common stock to the plaintiffs attorneys. In connection with the settlement, the Company recognized an expense of $1.6 million in the year ended December 31, 2013.
2010 Class Action.
On May 21, 2010, Richard P. Gielata, an individual purporting to act on behalf of stockholders, served a class action lawsuit filed May 6, 2010 against the Company and
various directors and officers in the United States District Court for the District of Delaware captioned
In re Heckmann Corporation Securities Class Action
(Case No. 1:10-cv-00378-JJF-MPT) (the 2010 Class Action). On
October 8, 2010, the court-appointed lead plaintiff filed an Amended Class Action Complaint which adds China Water as a defendant. The 2010 Class Action alleges violations of federal securities laws in connection with the acquisition of
China Water. The Company responded by filing a motion to transfer the 2010 Class Action to California and a motion to dismiss the case. On October 19, 2012, plaintiff filed a motion to certify a class and appoint class representatives and class
counsel. On January 18, 2013, the Company filed its opposition and a motion to exclude the declaration of plaintiffs class certification expert. On February 19, 2013, plaintiff filed a reply brief. A hearing on plaintiffs
motion to certify a class and appoint class representatives and class counsel has not been scheduled. Depositions were taken by the parties during the three months ended September 30, 2013. During this time a
mediator was also appointed
for the
case and settlement discussions occurred. Management was subsequently apprised of the status of the case by counsel and based on these developments and an assessment of its remaining insurance coverage, the Company recorded a charge
of $16.0 million in the quarter ended September 30, 2013 to establish an accrual in connection with this matter.
Settlement discussions with the plaintiffs continued through the mediator during the period December 2013 through February 2014. On March
4, 2014, the Company reached an agreement in principle to settle this matter by entering into a Stipulation of Settlement with the plaintiffs. Under the terms of the agreement, which must be approved by the court, the Company has agreed to a cash
payment of $13.5 million, a portion of which will come from remaining insurance proceeds, as well as the issuance of 0.8 million shares of its common stock. The Company has agreed to provide a floor value of $13.5 million on the equity portion of
the settlement. Consequently, if the value of the shares is below $13.5 million at the time of the final court approval of the Stipulation of Settlement, the Company will be required to contribute additional shares (or cash, at its option) such that
the total value of the settlement is equal to $27.0 million. The cash payment is expected to be deposited into escrow prior to June 30, 2014 and the shares will be issued when the settlement proceeds are distributed to the claimants. The
Stipulation of Settlement remains subject to court approval and will resolve all claims asserted against the Company and individual defendants in the case. As a result of the pending settlement of this matter, the Company recorded an additional
charge of $7.0 million in the quarter ended December 31, 2013, to effectively accrue for the proposed settlement (Note 8). The Company could incur additional charges in future periods if the market value of the 0.8 million shares exceeds $13.5
million upon issuance.
F-42
2013 Shareholder Class Actions.
On September 3, 2013, and September 26, 2013,
respectively, two separate but substantially-similar putative class action lawsuits were commenced in the United States District Court for the District of Arizona. Plaintiffs in each action asserted claims against the Company and certain of its
officers and directors for violations of (i) Section 10(b) of the Exchange Act of 1934 (the Exchange Act), and Rule 10b-5 promulgated thereunder, and (ii) Section 20(a) of the Exchange Act. Plaintiffs in each action alleged that the
Company and the individual defendants made certain material misstatements and/or omissions relating to the Companys operations and financial condition which caused the price of the Companys shares to fall.
By order dated October 29, 2013, the two putative class actions were consolidated. The consolidated action is captioned
In re Nuverra
Environmental Solutions Securities Litigation
, No. 13-CIV-01800-PHX-JWS, and is pending before Judge John D. Sedwick in the District of Arizona. Pursuant to provisions of the Private Securities Litigation Reform Act of 1995, Judge Sedwick
appointed a Lead Plaintiff group in the consolidated action on January 15, 2014. Lead Plaintiffs have been ordered to file a consolidated complaint by March 17, 2014. Defendants will thereafter have an opportunity to answer or move to dismiss the
claims asserted by the Lead Plaintiffs. The Company and the individual defendants intend to vigorously defend themselves against the claims asserted in this consolidated action.
2013 Shareholder Derivative Actions.
On September 20, 2013, October 4, 2013, and October 7, 2013, respectively, three separate but
substantially-similar shareholder derivative lawsuits were commenced in the United States District Court for the District of Arizona. By order dated October 29, 2013, these actions were consolidated. The consolidated action is captioned as
In re
Nuverra Environmental Solutions, Inc. Derivative Shareholder Litigation
, No. CV-13-01933-PHX-NVW, and is pending before Judge Neil V. Wake in the District of Arizona. Plaintiffs filed a consolidated complaint on December 31, 2013. Plaintiffs
allege that members of the Companys board failed to prevent the issuance of certain misstatements and omissions and assert claims for breach of fiduciary duty, waste of corporate assets and unjust enrichment. Defendants intend to vigorously
defend themselves against the claims asserted and expect to file a motion to dismiss the claims in mid-February.
On October
7, 2013, two identical shareholder derivative lawsuits were commenced in the Superior Court for the State of Arizona in and for the County of Maricopa against ten of the Companys current officers and/or directors. Plaintiffs in each action
asserted claims for (i) breach of fiduciary duty, (ii) waste of corporate assets and (iii) unjust enrichment. By order dated January 28, 2014, these two actions were consolidated. The consolidated action is captioned
In re: Nuverra Derivative
Shareholder Litigation
, No. CV2013-013425, and is pending before Judge John Rea in the Superior Court for the State of Arizona in and for the County of Maricopa. Plaintiffs have yet to file a consolidated complaint. The Company and the
individual defendants intend to vigorously defend themselves against the claims asserted in this consolidated action.
The
Company does not expect that the outcome of other claims and legal actions not discussed above will have a material adverse effect on its consolidated financial position, results of operations or cash flows.
(17) Employee Benefit Plans
The Company sponsors a defined contribution 401(k) plan that is subject to the provisions of the Employee Retirement Income Security Act of 1974 (ERISA). Effective September 1, 2013,
the Company established a defined contribution plan (the 401k Plan) covering substantially all employees who have met certain eligibility requirements except those employees working less than 25 hours per week. Employees may participate
in the 401k Plan on the first day of the first month following 60 days of employment. The Company provides a quarterly match in shares of Company common stock equal to 100% of each participants annual contribution up to 3% of each
participants annual compensation and 50% of participants annual contribution up to an additional 2% of each participants annual compensation.
Company contributions to the plans were $1.9 million and $0.3 million for the year the years ended December 31, 2013 and 2012, respectively.
F-43
(18) Related Party Transactions
Richard J. Heckmann, the Executive Chairman of the Companys board of directors, and Mark D. Johnsrud, the Companys Chief
Executive Officer and Vice Chairman of the Companys board of directors, are members of an entity that owns an aircraft used periodically by the Company for business-related travel. Reimbursements paid to the entity in exchange for use of the
aircraft were $0.4 million, $1.2 million and $0.9 million for the years ended December 31, 2013, 2012 and 2011, respectively. Amounts payable to the entity were less than $0.1 million at December 31, 2013.
Mr. Johnsrud is the sole member of an entity that owns apartment buildings in North Dakota which are rented to certain of the
Companys employees at rates that are equal to or below market rates. Rent payments are collected from the employees by the Company through payroll deductions and remitted to the entity.
In connection with the Power Fuels Merger, assets received in exchange for the merger consideration excluded accounts receivable
outstanding for more than ninety days as of November 30, 2012. Subsequent collections on these accounts receivable, which are recorded by the Company as restricted cash with an offsetting liability, are required to be periodically remitted to
Mr. Johnsrud. Pursuant to the terms of this agreement, during the year ended December 31, 2013, the Company paid Mr. Johnsrud $3.6 million for such collections, net of a working capital adjustment of approximately $2.1 million.
Amounts payable to Mr. Johnsrud at December 31, 2013 for accounts receivable collections totaled approximately $0.1 million.
The Company periodically purchases fresh water for resale to customers from a sole proprietorship owned by Mr. Johnsrud. Purchases made by the Company during the year ended December 31, 2013
amounted to $0.7 million. Purchases made by Power Fuels prior to its merger with the Company totaled approximately $2.2 million during the year ended December 31, 2012. No amounts were due to the sole proprietorship at December 31, 2013.
Mr. Johnsrud is the sole member of an entity that owns land in North Dakota on which five of the Companys
saltwater disposal wells are situated. The Company has agreed to pay the entity a per-barrel royalty fee in exchange for the use of the land, which is consistent with rates charged by non-affiliated third parties under similar arrangements.
Royalties paid by the Company were approximately $0.1 million in each of the years ended December 31, 2013 and 2012, respectively. Royalties payable to the entity were less than $0.1 million at December 31, 2013 and 2012.
During 2009, the Company acquired an approximate 7% investment in Underground Solutions, Inc. (UGSI) a supplier of water
infrastructure pipeline products, whose chief executive officer, Andrew D. Seidel, is a member of the Companys board of directors. The Companys total investment in UGSI was $7.2 million. During the quarter ended September 30, 2013,
management performed an evaluation of various alternatives for this non-strategic investment, including its potential liquidation. As a result, the Company recorded a $3.8 million charge for the write-down of this investment to its estimated
net realizable value. The Companys interest in UGSI is accounted for as a cost method investment in the Companys consolidated balance sheet as of December 31, 2013 and December 31, 2012, and is included in the Corporate/Other
group for purposes of reportable segments (Note 19). The $3.8 million write-down was classified as a component of other expense, net in the consolidated statement of operations for the year ended December 31, 2013.
(19) Segments
The
Company evaluates business segment performance based on income (loss) before income taxes exclusive of corporate general and administrative costs and interest expense, which are not allocated to the segments. Following an assessment of various
alternatives regarding its Industrial Solutions business in the third quarter of 2013 and a decision to focus exclusively on its Shale Solutions business, the Companys board of directors approved and committed to a plan to divest TFI, which
comprises its Industrial Solutions operating and
F-44
reportable segment, in the fourth quarter of 2013. As a result, the Company considers TFI to be held for sale (Note 20). As such, the Companys reportable segment shown below represents the
segment performance of the Companys Shale Solutions business. Corporate/Other includes certain corporate costs and losses from discontinued operations, as well as assets held for sale and certain other corporate assets. The Companys
reportable segments at December 31, 2013 represent those used by the Companys chief operating decision maker to evaluate performance and allocate resources and are consistent with its reportable segments at December 31, 2012. See
Note 1 for information on the types of services from which the Shale Solutions segment derives its revenues.
The financial
information for the Companys reportable segments is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shale
Solutions
|
|
|
Corporate/
Other
|
|
|
Total
|
|
Year ended December 31, 2013
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
525,816
|
|
|
$
|
|
|
|
$
|
525,816
|
|
Depreciation and amortization
|
|
|
98,799
|
|
|
|
437
|
|
|
|
99,236
|
|
Loss from continuing operations before income taxes
|
|
|
(100,088
|
)
|
|
|
(107,047
|
)
|
|
|
(207,135
|
)
|
Additions to fixed assets
|
|
|
97,991
|
|
|
|
1,599
|
|
|
|
99,590
|
|
Goodwill
|
|
|
408,696
|
|
|
|
|
|
|
|
408,696
|
|
Total assets excluding those applicable to discontinued operations (a)
|
|
|
1,154,014
|
|
|
|
67,999
|
|
|
|
1,222,013
|
|
Total assets held for sale (b)
|
|
|
|
|
|
|
188,750
|
|
|
|
188,750
|
|
Year ended December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
|
256,671
|
|
|
|
|
|
|
|
256,671
|
|
Depreciation and amortization
|
|
|
47,641
|
|
|
|
|
|
|
|
47,641
|
|
Loss from continuing operations before income taxes
|
|
|
(23,257
|
)
|
|
|
(46,100
|
)
|
|
|
(69,357
|
)
|
Additions to fixed assets
|
|
|
60,900
|
|
|
|
|
|
|
|
60,900
|
|
Goodwill
|
|
|
415,176
|
|
|
|
|
|
|
|
415,176
|
|
Total assets excluding those applicable to discontinued operations (a)
|
|
|
1,299,730
|
|
|
|
47,700
|
|
|
|
1,347,430
|
|
Total assets held for sale (b)
|
|
|
|
|
|
|
296,909
|
|
|
|
296,909
|
|
Year ended December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
|
156,837
|
|
|
|
|
|
|
|
156,837
|
|
Depreciation and amortization
|
|
|
25,281
|
|
|
|
|
|
|
|
25,281
|
|
Income (loss) from continuing operations before income taxes
|
|
|
10,415
|
|
|
|
(14,300
|
)
|
|
|
(3,885
|
)
|
Additions to fixed assets
|
|
|
156,800
|
|
|
|
|
|
|
|
156,800
|
|
Goodwill
|
|
|
90,008
|
|
|
|
|
|
|
|
90,008
|
|
Total assets
|
|
|
447,381
|
|
|
|
92,300
|
|
|
|
539,681
|
|
(a)
|
Total assets exclude intercompany receivables eliminated in consolidation.
|
(b)
|
Represents the carrying value of the assets of discontinued operations (Note 20).
|
Revenues from three customers of the Shale Solutions segment each exceeded 11% of the segments total revenue and collectively
represented approximately 40% of the segments total revenue for the year ended December 2013. Accounts receivables from three customers of the Shale Solutions segment each exceeded 7% of the segments total accounts receivable and
collectively represented approximately 31% of the segments total accounts receivable as of December 31, 2013.
In
the fourth quarter of 2013, the Company announced a plan to realign its Shale Solutions business into three operating divisions: (1) the Northeast Division comprising the Marcellus and Utica Shale areas (2) the Southern Division comprising
the Haynesville, Barnett, Eagle Ford, Mississippian Shale areas and Permian Basin and (3) the Rocky Mountain Division comprising the Bakken Shale area. The implementation of this organizational realignment is ongoing and is expected to be
completed in 2014. In connection with these planned organizational changes, the Company is evaluating whether the new operating divisions constitute separate operating segments and if so, whether two or more of them can be aggregated into one or
more reportable
F-45
segments. As the organizational realignment progresses, the Company will continue to evaluate its potential impact on its reporting units, which is a level of reporting at which goodwill is
tested for impairment. A reporting unit is defined as an operating segment or one level below an operating segment. To the extent the Company concludes the composition of its reporting units have changed, the Company will be required to allocate
goodwill on a relative fair value basis to the new reporting units and test the newly allocated goodwill for impairment should triggering events occur.
(20) Assets Held for Sale and Discontinued Operations
Thermo Fluids Inc. (TFI)
On April 10, 2012, the Company completed the acquisition of all the issued and outstanding shares of TFI
Holdings, Inc. and its wholly-owned subsidiary, Thermo Fluids Inc. (collectively, TFI), a route-based environmental services and waste recycling solutions provider that focuses on the collection and recycling of UMO and the sale of RFO
from recovered UMO.
The aggregate purchase price of $246.0 million was comprised of approximately $230.2 million in cash, and
0.4 million shares of the Companys common stock with a fair value of approximately $15.8 million, which shares were issued in a private placement and were held in escrow in respect of potential indemnification obligations of the sellers of
TFI. In connection with the settlement of these indemnification obligations, the aggregate purchase price increased $0.6 million during the three months ended March 31, 2013. The escrow was settled and the shares remaining in escrow were
released to the sellers of TFI in April 2013.
The acquisition of TFI was accounted for as a business combination under the
acquisition method of accounting. The allocation of the aggregate purchase price, which was revised in the three months ended March 31, 2013 to reflect the final valuation, is summarized as follows:
|
|
|
|
|
Accounts receivable
|
|
$
|
13,808
|
|
Inventory
|
|
|
3,456
|
|
Other assets
|
|
|
1,431
|
|
Property, plant and equipment
|
|
|
23,685
|
|
Customer relationships
|
|
|
93,200
|
|
Vendor relationships
|
|
|
16,300
|
|
Other intangibles
|
|
|
1,400
|
|
Goodwill
|
|
|
145,031
|
|
Accounts payable and accrued liabilities
|
|
|
(13,045
|
)
|
Deferred income tax liabilities, net
|
|
|
(39,261
|
)
|
|
|
|
|
|
Total
|
|
$
|
246,005
|
|
|
|
|
|
|
The goodwill recognized was attributable to TFIs assembled workforce and premium associated with
the opportunity to further diversify the Companys operations and service offerings.
In 2012 TFI completed an
acquisition for a total aggregate purchase price of the acquired business of approximately $2.8 million consisting of cash consideration and contingent consideration of approximately $2.1 million and $0.7 million, respectively.
Following an assessment of various alternatives regarding its Industrial Solutions business in the third quarter of 2013 and
a decision to focus exclusively on its Shale Solutions business, the Companys board of directors approved and committed to a plan to divest TFI, which comprises its Industrial Solutions operating and reportable segment, in the fourth quarter
of 2013. Based on currently available information, the Company expects the sale of TFI to be completed in the second quarter of 2014 and believes the carrying value of TFI at
F-46
December 31, 2013 does not exceed its net realizable value. The results of operations of TFI are presented as discontinued operations in the Companys Consolidated Statements of
Operations for the years ended December 31, 2013 and 2012 (since its acquisition on April 10, 2012). The assets and liabilities related to TFI are presented separately as assets held for sale and liabilities of discontinued operations in
the Companys Consolidated Balance Sheets at December 31, 2013 and 2012.
The following table details selected
financial information of discontinued operations related to TFI since its acquisition on April 10, 2012:
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Revenue
|
|
$
|
116,263
|
|
|
$
|
95,312
|
|
|
|
|
|
|
|
|
|
|
Pretax (loss) income from operations
|
|
|
(98,237
|
)
|
|
|
13,279
|
|
Income tax expense
|
|
|
(14
|
)
|
|
|
(4,155
|
)
|
|
|
|
|
|
|
|
|
|
(Loss) income from discontinued operations
|
|
$
|
(98,251
|
)
|
|
$
|
9,124
|
|
|
|
|
|
|
|
|
|
|
The pretax loss from operations for the year ended December 31, 2013 includes a goodwill impairment
charge of $98.5 million (Note 7).
The carrying value of the assets and liabilities of TFI that are classified as held for
sale in the accompanying Consolidated Balance Sheets at December 31, 2013 and 2012 are as follows:
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2013
|
|
|
2012
|
|
Assets:
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
429
|
|
|
$
|
1,435
|
|
Accounts receivable, net
|
|
|
15,620
|
|
|
|
13,901
|
|
Inventories, net
|
|
|
2,328
|
|
|
|
1,938
|
|
Prepaid expenses and other receivables
|
|
|
2,475
|
|
|
|
1,971
|
|
Other current assets
|
|
|
594
|
|
|
|
1,079
|
|
|
|
|
|
|
|
|
|
|
Total current assets held for sale
|
|
|
21,446
|
|
|
|
20,324
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
26,369
|
|
|
|
25,848
|
|
Intangible assets, net
|
|
|
92,935
|
|
|
|
110,822
|
|
Goodwill
|
|
|
48,000
|
|
|
|
139,915
|
|
|
|
|
|
|
|
|
|
|
Total long-term assets held for sale
|
|
|
167,304
|
|
|
|
276,585
|
|
|
|
|
|
|
|
|
|
|
Total assets held for sale
|
|
$
|
188,750
|
|
|
$
|
296,909
|
|
|
|
|
|
|
|
|
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
6,625
|
|
|
$
|
6,137
|
|
Accrued expenses
|
|
|
2,676
|
|
|
|
3,719
|
|
Current portion of contingent consideration
|
|
|
|
|
|
|
400
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities of discontinued operations
|
|
|
9,301
|
|
|
|
10,256
|
|
|
|
|
|
|
|
|
|
|
Long-term liabilities of discontinued operationsdeferred income taxes
|
|
|
32,389
|
|
|
|
40,596
|
|
|
|
|
|
|
|
|
|
|
Total liabilities of discontinued operations
|
|
$
|
41,690
|
|
|
$
|
50,852
|
|
|
|
|
|
|
|
|
|
|
Net assets held for sale
|
|
$
|
147,060
|
|
|
$
|
246,057
|
|
|
|
|
|
|
|
|
|
|
F-47
China Water
On September 30, 2011, the Company, through its wholly-owned subsidiary, China Water, entered into a Share Purchase Agreement by and among Pacific Water & Drinks (HK) Group Limited (f/k/a
Sino Bloom Investments Limited), a Hong Kong company (Buyer), China Water, as Seller, and China Water Drinks (H.K.) Holdings Limited, a Hong Kong company (Target), pursuant to which China Water agreed to sell 100% of the
equity interests in Target to Buyer in exchange for shares in Buyer equal to ten percent of the Buyers outstanding equity. Upon completion of the sale, the Company abandoned the remaining non-U.S. legal entities that were part of its original
acquisition of China Water.
Selected financial information of the discontinued operations of China Water for the year ended
December 31, 2011 is as follows:
|
|
|
|
|
Revenue
|
|
$
|
20,560
|
|
|
|
|
|
|
Pretax loss from operations
|
|
|
(4,881
|
)
|
Income tax expense
|
|
|
(100
|
)
|
|
|
|
|
|
Loss from operations
|
|
|
(4,981
|
)
|
Loss from disposal, net
|
|
|
(17,917
|
)
|
|
|
|
|
|
Loss from discontinued operations
|
|
$
|
(22,898
|
)
|
|
|
|
|
|
(21) Selected Unaudited Quarterly Financial Data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
|
March 31,
|
|
|
June 30,
|
|
|
September 30,
|
|
|
December 31,
|
|
2013
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
130,647
|
|
|
$
|
134,977
|
|
|
$
|
131,804
|
|
|
$
|
128,388
|
|
Gross profit
|
|
|
17,007
|
|
|
|
18,106
|
|
|
|
14,664
|
|
|
|
19,872
|
|
Loss from continuing operations (2)(3)
|
|
|
(4,005
|
)
|
|
|
(21,665
|
)
|
|
|
(97,998
|
)
|
|
|
(10,372
|
)
|
Loss (income) from discontinued operations (2)(3)
|
|
|
(8,627
|
)
|
|
|
8,816
|
|
|
|
(95,740
|
)
|
|
|
(2,700
|
)
|
Net loss attributable to common stockholders (2)(3)
|
|
|
(12,632
|
)
|
|
|
(12,849
|
)
|
|
|
(193,738
|
)
|
|
|
(13,072
|
)
|
Loss per common share from continuing operations (4):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted
|
|
|
(0.17
|
)
|
|
|
(0.89
|
)
|
|
|
(3.94
|
)
|
|
|
(0.42
|
)
|
Income (loss) per common share from discontinued operations (4):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted
|
|
|
(0.36
|
)
|
|
|
0.36
|
|
|
|
(3.85
|
)
|
|
|
(0.11
|
)
|
Net loss per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic and diluted
|
|
|
(0.53
|
)
|
|
|
(0.53
|
)
|
|
|
(7.80
|
)
|
|
|
(0.53
|
)
|
(1)
|
Totals may not equal corresponding amounts on the Consolidated Statements of Operations due to rounding.
|
(2)
|
During the fourth quarter of 2013, the following unusual or non-recurring items were recorded:
|
|
(a)
|
The Company recorded an additional charge of $7.0 million related to the pending settlement of its 2010 class action litigation.
|
|
(b)
|
The Company reduced its self-insurance liabilities by $3.3 million based on actuarial valuations performed in the period.
|
|
(c)
|
The Company recorded a reduction to depreciation expense of $3.2 million following the completion of its assessment of the useful lives of the tangible assets acquired
in the Power Fuels acquisition.
|
F-48
(3)
|
During the third quarter of 2013, the Company recorded the following unusual or non-recurring items:
|
|
(a)
|
The Company recorded a charge for goodwill impairment related to its Industrial Solutions business of $98.5 million.
|
|
(b)
|
The Company recorded a charge of $107.4 million to write-down the carrying values of certain long-lived assets in its Shale Solutions business.
|
|
(c)
|
The Company recorded a charge of $16.0 million related to the 2010 class action litigation.
|
|
(d)
|
The Company wrote off $4.3 million of cost-method investments, primarily related to its minority ownership in a pipeline products supplier.
|
(4)
|
During the second quarter of 2013, the Company recorded charges for restructuring portions of its business in the amount of $1.5 million and the impairment of certain
related assets totaling $3.5 million, along with a reduction of $0.8 million to amounts previously accrued for the settlement of the 2010 Derivative Action.
|
(5)
|
During the first quarter of 2013, the Company recorded a $2.4 million charge related to settlement of its 2010 Derivative Action litigation.
|
(6)
|
Per-share amounts for all periods reflect the one-for-ten reverse stock split, which was effective December 3, 2013 (Note 4).
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
|
March 31,
|
|
|
June 30,
|
|
|
September 30,
|
|
|
December 31,
|
|
2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
54,959
|
|
|
$
|
58,749
|
|
|
$
|
59,220
|
|
|
$
|
83,743
|
|
Gross profit
|
|
|
6,986
|
|
|
|
4,326
|
|
|
|
5,981
|
|
|
|
1,416
|
|
Income (loss) from continuing operations (2)(3)
|
|
|
(3,863
|
)
|
|
|
5,414
|
|
|
|
(14,159
|
)
|
|
|
6,011
|
|
Income (loss) from discontinued operations (2)(3)
|
|
|
|
|
|
|
5,329
|
|
|
|
4,814
|
|
|
|
(1,019
|
)
|
Net Income (loss) attributable to common stockholders (2)(3)
|
|
|
(3,863
|
)
|
|
|
10,743
|
|
|
|
(9,345
|
)
|
|
|
4,992
|
|
Income (loss) per common share from continuing operations (4):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
(0.31
|
)
|
|
|
0.37
|
|
|
|
(0.96
|
)
|
|
|
0.33
|
|
Diluted
|
|
|
(0.31
|
)
|
|
|
0.36
|
|
|
|
(0.96
|
)
|
|
|
0.30
|
|
Income (loss) per common share from discontinued operations (4):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
0.37
|
|
|
|
0.33
|
|
|
|
(0.06
|
)
|
Diluted
|
|
|
|
|
|
|
0.35
|
|
|
|
0.31
|
|
|
|
(0.06
|
)
|
Net (loss) income per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
(0.31
|
)
|
|
|
0.74
|
|
|
|
(0.63
|
)
|
|
|
0.28
|
|
Diluted
|
|
|
(0.31
|
)
|
|
|
0.71
|
|
|
|
(0.65
|
)
|
|
|
0.25
|
|
(1)
|
Totals may not equal corresponding amounts on the Consolidated Statements of Operations due to rounding.
|
(2)
|
During the fourth quarter of 2012, the following recorded the following unusual or non-recurring items:
|
|
(a)
|
The Company released $17.8 million of deferred tax asset valuation allowance associated with NOLs because of a determination that the realization of the
associated tax benefits is more likely that not based on future taxable income arising from the reversal of deferred tax liabilities that the Company acquired in connection with the Power Fuels merger.
|
|
(b)
|
The Company recognized an impairment of long-lived assets of $3.7 million for the write-down of the carrying values of three saltwater disposal wells.
|
|
(c)
|
The Company recognized an impairment of intangible assets of $2.4 million for the write-down of a customer relationship intangible associated with a portion of a prior
business acquisition.
|
|
(d)
|
The Company recorded a $1.4 million environmental accrual for the estimated costs necessary to comply with Louisiana Department of Environmental Quality requirements.
|
(3)
|
During the second quarter of 2012, the Company released $20.7 million of valuation allowance associated with NOLs because of a determination that the
realization of the associated deferred tax assets is more likely than not based on future taxable income arising from the reversal of deferred tax liabilities that the Company acquired in connection with the TFI acquisition.
|
(4)
|
Per-share amounts for all periods reflect Nuverras 1-for-10 reverse stock split, which was effective December 3, 2013 (Note 4).
|
F-49
Diluted net income (loss) per common share for each of the quarters presented above is based
on the respective weighted average number of common shares outstanding for each quarter and the sum of the quarters may not necessarily be equal to the full year diluted net loss per common share amounts.
(22) Subsidiary Guarantors
The obligations of Nuverra Environmental Solutions, Inc. under the 2018 Notes are jointly and severally, fully and unconditionally guaranteed by certain of the Companys subsidiaries. The following
tables present consolidating financial information for Nuverra Environmental Solutions, Inc. (Parent), certain 100% wholly-owned subsidiaries (the Guarantor Subsidiaries) and Appalachian Water Services, LLC, a 51% owned
subsidiary (the Non-Guarantor Subsidiary), as of December 31, 2013 and December 31, 2012 and for the years ended December 31, 2013, 2012 and 2011. These condensed consolidating financial statements have been prepared from
the Companys financial information on the same basis of accounting as the Companys consolidated financial statements. The principal elimination entries relate to investments in subsidiaries and intercompany balances and transactions.
F-50
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING BALANCE SHEET
DECEMBER 31, 2013
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
3,839
|
|
|
$
|
3,201
|
|
|
$
|
1,743
|
|
|
$
|
|
|
|
$
|
8,783
|
|
Restricted cash
|
|
|
|
|
|
|
110
|
|
|
|
|
|
|
|
|
|
|
|
110
|
|
Accounts receivablenet
|
|
|
|
|
|
|
86,256
|
|
|
|
830
|
|
|
|
|
|
|
|
87,086
|
|
Other current assets
|
|
|
33,809
|
|
|
|
10,371
|
|
|
|
86
|
|
|
|
|
|
|
|
44,266
|
|
Current assets held for sale
|
|
|
|
|
|
|
21,446
|
|
|
|
|
|
|
|
|
|
|
|
21,446
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
37,648
|
|
|
|
121,384
|
|
|
|
2,659
|
|
|
|
|
|
|
|
161,691
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
2,396
|
|
|
|
485,586
|
|
|
|
10,559
|
|
|
|
|
|
|
|
498,541
|
|
Equity investments
|
|
|
742,342
|
|
|
|
650
|
|
|
|
|
|
|
|
(738,960
|
)
|
|
|
4,032
|
|
Intangible assets, net
|
|
|
|
|
|
|
148,063
|
|
|
|
1,300
|
|
|
|
|
|
|
|
149,363
|
|
Goodwill
|
|
|
|
|
|
|
398,024
|
|
|
|
10,672
|
|
|
|
|
|
|
|
408,696
|
|
Other
|
|
|
410,774
|
|
|
|
120,786
|
|
|
|
|
|
|
|
(510,424
|
)
|
|
|
21,136
|
|
Long-term assets held for sale
|
|
|
|
|
|
|
167,304
|
|
|
|
|
|
|
|
|
|
|
|
167,304
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$
|
1,193,160
|
|
|
$
|
1,441,797
|
|
|
$
|
25,190
|
|
|
$
|
(1,249,384
|
)
|
|
$
|
1,410,763
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
3,784
|
|
|
$
|
27,850
|
|
|
$
|
1,595
|
|
|
$
|
|
|
|
$
|
33,229
|
|
Accrued expenses
|
|
|
43,274
|
|
|
|
19,941
|
|
|
|
216
|
|
|
|
|
|
|
|
63,431
|
|
Current portion of contigent consideration
|
|
|
|
|
|
|
13,113
|
|
|
|
|
|
|
|
|
|
|
|
13,113
|
|
Current portion of long-term debt
|
|
|
|
|
|
|
5,464
|
|
|
|
|
|
|
|
|
|
|
|
5,464
|
|
Current liabilities of discontinued operations
|
|
|
|
|
|
|
9,301
|
|
|
|
|
|
|
|
|
|
|
|
9,301
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
47,058
|
|
|
|
75,669
|
|
|
|
1,811
|
|
|
|
|
|
|
|
124,538
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
(34,275
|
)
|
|
|
77,257
|
|
|
|
|
|
|
|
|
|
|
|
42,982
|
|
Long-term debt, less current portion
|
|
|
535,221
|
|
|
|
14,492
|
|
|
|
|
|
|
|
|
|
|
|
549,713
|
|
Long-term contingent consideration
|
|
|
|
|
|
|
2,344
|
|
|
|
|
|
|
|
|
|
|
|
2,344
|
|
Other long-term liabilities
|
|
|
787
|
|
|
|
513,961
|
|
|
|
10,104
|
|
|
|
(510,424
|
)
|
|
|
14,428
|
|
Long-term liabilities of discontinued operations
|
|
|
|
|
|
|
32,389
|
|
|
|
|
|
|
|
|
|
|
|
32,389
|
|
Total shareholders equity
|
|
|
644,369
|
|
|
|
725,685
|
|
|
|
13,275
|
|
|
|
(738,960)
|
|
|
|
644,369
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND EQUITY
|
|
$
|
1,193,160
|
|
|
$
|
1,441,797
|
|
|
$
|
25,190
|
|
|
$
|
(1,249,384
|
)
|
|
$
|
1,410,763
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-51
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING BALANCE SHEET
DECEMBER 31, 2012
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
5,819
|
|
|
$
|
8,101
|
|
|
$
|
856
|
|
|
$
|
|
|
|
$
|
14,776
|
|
Restricted cash
|
|
|
|
|
|
|
3,536
|
|
|
|
|
|
|
|
|
|
|
|
3,536
|
|
Accounts receivablenet
|
|
|
|
|
|
|
102,867
|
|
|
|
760
|
|
|
|
|
|
|
|
103,627
|
|
Other current assets
|
|
|
10,509
|
|
|
|
13,117
|
|
|
|
2
|
|
|
|
|
|
|
|
23,628
|
|
Current assets held for sale
|
|
|
|
|
|
|
20,324
|
|
|
|
|
|
|
|
|
|
|
|
20,324
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
16,328
|
|
|
|
147,945
|
|
|
|
1,618
|
|
|
|
|
|
|
|
165,891
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
44
|
|
|
|
569,445
|
|
|
|
9,533
|
|
|
|
|
|
|
|
579,022
|
|
Equity investments
|
|
|
901,411
|
|
|
|
597
|
|
|
|
|
|
|
|
(893,729
|
)
|
|
|
8,279
|
|
Intangible assets, net
|
|
|
|
|
|
|
172,426
|
|
|
|
1,450
|
|
|
|
|
|
|
|
173,876
|
|
Goodwill
|
|
|
|
|
|
|
404,732
|
|
|
|
10,444
|
|
|
|
|
|
|
|
415,176
|
|
Other
|
|
|
475,829
|
|
|
|
149,045
|
|
|
|
|
|
|
|
(599,364
|
)
|
|
|
25,510
|
|
Long-term assets held for sale
|
|
|
|
|
|
|
276,585
|
|
|
|
|
|
|
|
|
|
|
|
276,585
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$
|
1,393,612
|
|
|
$
|
1,720,775
|
|
|
$
|
23,045
|
|
|
$
|
(1,493,093
|
)
|
|
$
|
1,644,339
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
757
|
|
|
$
|
22,429
|
|
|
$
|
215
|
|
|
$
|
|
|
|
$
|
23,401
|
|
Accrued expenses
|
|
|
17,833
|
|
|
|
28,651
|
|
|
|
62
|
|
|
|
|
|
|
|
46,546
|
|
Current portion of contingent consideration
|
|
|
|
|
|
|
1,568
|
|
|
|
|
|
|
|
|
|
|
|
1,568
|
|
Current portion of long-term debt
|
|
|
|
|
|
|
4,699
|
|
|
|
|
|
|
|
|
|
|
|
4,699
|
|
Current liabilities of discontinued operations
|
|
|
|
|
|
|
10,256
|
|
|
|
|
|
|
|
|
|
|
|
10,256
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
18,590
|
|
|
|
67,603
|
|
|
|
277
|
|
|
|
|
|
|
|
86,470
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
(46,161
|
)
|
|
|
134,557
|
|
|
|
|
|
|
|
|
|
|
|
88,396
|
|
Long-term debt, less current portion
|
|
|
546,079
|
|
|
|
15,348
|
|
|
|
|
|
|
|
|
|
|
|
561,427
|
|
Long-term contingent consideration
|
|
|
|
|
|
|
7,363
|
|
|
|
1,500
|
|
|
|
|
|
|
|
8,863
|
|
Other long-term liabilities
|
|
|
27,343
|
|
|
|
573,826
|
|
|
|
9,021
|
|
|
|
(599,364
|
)
|
|
|
10,826
|
|
Long-term liabilities of discontinued operations
|
|
|
|
|
|
|
40,596
|
|
|
|
|
|
|
|
|
|
|
|
40,596
|
|
Total shareholders equity
|
|
|
847,761
|
|
|
|
881,482
|
|
|
|
12,247
|
|
|
|
(893,729
|
)
|
|
|
847,761
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND EQUITY
|
|
$
|
1,393,612
|
|
|
$
|
1,720,775
|
|
|
$
|
23,045
|
|
|
$
|
(1,493,093
|
)
|
|
$
|
1,644,339
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-52
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 2013, 2012 AND 2011
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2013
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Revenue
|
|
$
|
|
|
|
$
|
520,922
|
|
|
$
|
4,894
|
|
|
$
|
|
|
|
$
|
525,816
|
|
Cost of revenues
|
|
|
|
|
|
|
(453,609
|
)
|
|
|
(2,558
|
)
|
|
|
|
|
|
|
(456,167
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
|
|
|
|
67,313
|
|
|
|
2,336
|
|
|
|
|
|
|
|
69,649
|
|
Selling, general and administrative expenses
|
|
|
50,437
|
|
|
|
56,746
|
|
|
|
225
|
|
|
|
|
|
|
|
107,408
|
|
Long-lived asset impairment
|
|
|
|
|
|
|
111,900
|
|
|
|
|
|
|
|
|
|
|
|
111,900
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from operations
|
|
|
(50,437
|
)
|
|
|
(101,333
|
)
|
|
|
2,111
|
|
|
|
|
|
|
|
(149,659
|
)
|
Interest expense, net
|
|
|
(51,318
|
)
|
|
|
(1,303
|
)
|
|
|
(1,082
|
)
|
|
|
|
|
|
|
(53,703
|
)
|
Loss on extinguishment of debt
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from equity investment
|
|
|
(161,203
|
)
|
|
|
54
|
|
|
|
|
|
|
|
161,203
|
|
|
|
54
|
|
Other (loss) income
|
|
|
(5,292
|
)
|
|
|
(35
|
)
|
|
|
1,500
|
|
|
|
|
|
|
|
(3,827
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations before income taxes
|
|
|
(268,250
|
)
|
|
|
(102,617
|
)
|
|
|
2,529
|
|
|
|
161,203
|
|
|
|
(207,135
|
)
|
Income tax benefit (expense)
|
|
|
35,959
|
|
|
|
37,136
|
|
|
|
|
|
|
|
|
|
|
|
73,095
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) gain from continuing operations
|
|
|
(232,291
|
)
|
|
|
(65,481
|
)
|
|
|
2,529
|
|
|
|
161,203
|
|
|
|
(134,040
|
)
|
Loss from discontinued operations, net of income taxes
|
|
|
|
|
|
|
(98,251
|
)
|
|
|
|
|
|
|
|
|
|
|
(98,251
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
(232,291
|
)
|
|
$
|
(163,732
|
)
|
|
$
|
2,529
|
|
|
$
|
161,203
|
|
|
$
|
(232,291
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-53
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 2013, 2012 AND 2011
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2012
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Revenue
|
|
$
|
|
|
|
$
|
255,263
|
|
|
$
|
1,408
|
|
|
$
|
|
|
|
$
|
256,671
|
|
Cost of revenues
|
|
|
|
|
|
|
(237,048
|
)
|
|
|
(914
|
)
|
|
|
|
|
|
|
(237,962
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
|
|
|
|
18,215
|
|
|
|
494
|
|
|
|
|
|
|
|
18,709
|
|
Selling, general and administrative expenses
|
|
|
17,362
|
|
|
|
32,807
|
|
|
|
84
|
|
|
|
|
|
|
|
50,253
|
|
Long-lived asset impairment
|
|
|
|
|
|
|
6,030
|
|
|
|
|
|
|
|
|
|
|
|
6,030
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from operations
|
|
|
(17,362
|
)
|
|
|
(20,622
|
)
|
|
|
410
|
|
|
|
|
|
|
|
(37,574
|
)
|
Interest expense, net
|
|
|
(25,200
|
)
|
|
|
(1,155
|
)
|
|
|
(252
|
)
|
|
|
|
|
|
|
(26,607
|
)
|
Loss on extinguishment of debt
|
|
|
(2,638
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,638
|
)
|
(Loss) income from equity investment
|
|
|
(5,701
|
)
|
|
|
12
|
|
|
|
|
|
|
|
5,701
|
|
|
|
12
|
|
Other (loss) income
|
|
|
(920
|
)
|
|
|
(1,630
|
)
|
|
|
|
|
|
|
|
|
|
|
(2,550
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from continuing operations before income taxes
|
|
|
(51,821
|
)
|
|
|
(23,395
|
)
|
|
|
158
|
|
|
|
5,701
|
|
|
|
(69,357
|
)
|
Income tax benefit (expense)
|
|
|
54,348
|
|
|
|
8,412
|
|
|
|
|
|
|
|
|
|
|
|
62,760
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from continuing operations
|
|
|
2,527
|
|
|
|
(14,983
|
)
|
|
|
158
|
|
|
|
5,701
|
|
|
|
(6,597
|
)
|
Income from discontinued operations, net of income taxes
|
|
|
|
|
|
|
9,124
|
|
|
|
|
|
|
|
|
|
|
|
9,124
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
2,527
|
|
|
$
|
(5,859
|
)
|
|
$
|
158
|
|
|
$
|
5,701
|
|
|
$
|
2,527
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-54
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 2013, 2012 AND 2011
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2011
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Revenue
|
|
$
|
|
|
|
$
|
156,837
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
156,837
|
|
Cost of revenues
|
|
|
|
|
|
|
(123,509
|
)
|
|
|
|
|
|
|
|
|
|
|
(123,509
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
|
|
|
|
33,328
|
|
|
|
|
|
|
|
|
|
|
|
33,328
|
|
Selling, general and administrative expenses
|
|
|
11,061
|
|
|
|
25,590
|
|
|
|
|
|
|
|
|
|
|
|
36,651
|
|
Pipeline start-up and commissioning
|
|
|
|
|
|
|
2,089
|
|
|
|
|
|
|
|
|
|
|
|
2,089
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) gain from operations
|
|
|
(11,061
|
)
|
|
|
5,649
|
|
|
|
|
|
|
|
|
|
|
|
(5,412
|
)
|
Interest expense, net
|
|
|
(2,437
|
)
|
|
|
(1,806
|
)
|
|
|
|
|
|
|
|
|
|
|
(4,243
|
)
|
Gain (loss) from equity investment
|
|
|
(13,416
|
)
|
|
|
(462
|
)
|
|
|
|
|
|
|
13,416
|
|
|
|
(462
|
)
|
Other income
|
|
|
131
|
|
|
|
6,101
|
|
|
|
|
|
|
|
|
|
|
|
6,232
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from continuing operations before income taxes
|
|
|
(26,783
|
)
|
|
|
9,482
|
|
|
|
|
|
|
|
13,416
|
|
|
|
(3,885
|
)
|
Income tax benefit
|
|
|
3,777
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,777
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) income from continuing operations
|
|
|
(23,006
|
)
|
|
|
9,482
|
|
|
|
|
|
|
|
13,416
|
|
|
|
(108
|
)
|
Loss from discontinued operations, net of income taxes
|
|
|
|
|
|
|
|
|
|
|
(22,898
|
)
|
|
|
|
|
|
|
(22,898
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
(23,006
|
)
|
|
$
|
9,482
|
|
|
$
|
(22,898
|
)
|
|
$
|
13,416
|
|
|
$
|
(23,006
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-55
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
YEARS ENDED DECEMBER 31, 2013, 2012 AND 2011
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2013
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Net income (loss) attributable to common stockholders
|
|
$
|
(232,291
|
)
|
|
$
|
(163,732
|
)
|
|
$
|
2,529
|
|
|
$
|
161,203
|
|
|
$
|
(232,291
|
)
|
Total other comprehensive income (loss), net of tax
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income (loss), net of tax
|
|
$
|
(232,291
|
)
|
|
$
|
(163,732
|
)
|
|
$
|
2,529
|
|
|
$
|
161,203
|
|
|
$
|
(232,291
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to common stockholders
|
|
$
|
2,527
|
|
|
$
|
(5,859
|
)
|
|
$
|
158
|
|
|
$
|
5,701
|
|
|
$
|
2,527
|
|
Add back: income attributable to noncontrolling interest
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
2,527
|
|
|
|
(5,859
|
)
|
|
|
158
|
|
|
|
5,701
|
|
|
|
2,527
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other comprehensive loss, net of tax:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reclassification of net gains from sales of available for sale securities included in earnings
|
|
|
(8
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(8
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other comprehensive loss, net of tax
|
|
|
(8
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(8
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income (loss), net of tax
|
|
$
|
2,519
|
|
|
$
|
(5,859
|
)
|
|
$
|
158
|
|
|
$
|
5,701
|
|
|
$
|
2,519
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
(23,006
|
)
|
|
$
|
9,482
|
|
|
$
|
(22,898
|
)
|
|
$
|
13,416
|
|
|
$
|
(23,006
|
)
|
Add back: income attributable to noncontrolling interest
|
|
|
(1,456
|
)
|
|
|
|
|
|
|
(1,456
|
)
|
|
|
1,456
|
|
|
|
(1,456
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
(24,462
|
)
|
|
|
9,482
|
|
|
|
(24,354
|
)
|
|
|
14,872
|
|
|
|
(24,462
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other comprehensive loss, net of tax:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency translation gain (loss)
|
|
|
21
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
21
|
|
Reclassification of net gains from sales of available for sale securities included in earnings
|
|
|
(112
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(112
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other comprehensive loss, net of tax
|
|
|
(91
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(91
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive (loss) income, net of tax
|
|
$
|
(24,553
|
)
|
|
$
|
9,482
|
|
|
$
|
(24,354
|
)
|
|
$
|
14,872
|
|
|
$
|
(24,553
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-56
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENT OF CASH FLOWS
YEAR ENDED DECEMBER 31, 2013
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Net cash provided by operating activities from continuing operations
|
|
$
|
20,693
|
|
|
$
|
43,458
|
|
|
$
|
2,517
|
|
|
$
|
|
|
|
$
|
66,668
|
|
Net cash provided by operating activities from discontinued operations
|
|
|
|
|
|
|
3,589
|
|
|
|
|
|
|
|
|
|
|
|
3,589
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
20,693
|
|
|
|
47,047
|
|
|
|
2,517
|
|
|
|
|
|
|
|
70,257
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for acquisitions, net of cash acquired
|
|
|
(10,570
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(10,570
|
)
|
Proceeds from the sale of property and equipment
|
|
|
|
|
|
|
2,308
|
|
|
|
|
|
|
|
|
|
|
|
2,308
|
|
Purchase of property, plant and equipment
|
|
|
(1,597
|
)
|
|
|
(43,366
|
)
|
|
|
(1,630
|
)
|
|
|
|
|
|
|
(46,593
|
)
|
Other investing activities
|
|
|
2,067
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,067
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities from continuing operations
|
|
|
(10,100
|
)
|
|
|
(41,058
|
)
|
|
|
(1,630
|
)
|
|
|
|
|
|
|
(52,788
|
)
|
Net cash used in investing activities from discontinuing operations
|
|
|
|
|
|
|
(4,195
|
)
|
|
|
|
|
|
|
|
|
|
|
(4,195
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(10,100
|
)
|
|
|
(45,253
|
)
|
|
|
(1,630
|
)
|
|
|
|
|
|
|
(56,983
|
)
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from revolving credit facility
|
|
|
98,501
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
98,501
|
|
Payments on revolving credit facility
|
|
|
(109,501
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(109,501
|
)
|
Payments for deferred financing costs
|
|
|
(855
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(855
|
)
|
Payments on notes payable and capital leases
|
|
|
|
|
|
|
(5,416
|
)
|
|
|
|
|
|
|
|
|
|
|
(5,416
|
)
|
Payments of contingent consideration
|
|
|
|
|
|
|
(1,884
|
)
|
|
|
|
|
|
|
|
|
|
|
(1,884
|
)
|
Other financing activities
|
|
|
(718
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(718
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities from continuing operations
|
|
|
(12,573
|
)
|
|
|
(7,300
|
)
|
|
|
|
|
|
|
|
|
|
|
(19,873
|
)
|
Net cash used in financing activities from discontinued operations
|
|
|
|
|
|
|
(400
|
)
|
|
|
|
|
|
|
|
|
|
|
(400
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities
|
|
|
(12,573
|
)
|
|
|
(7,700
|
)
|
|
|
|
|
|
|
|
|
|
|
(20,273
|
)
|
Net (decrease) increase in cash
|
|
|
(1,980
|
)
|
|
|
(5,906
|
)
|
|
|
887
|
|
|
|
|
|
|
|
(6,999
|
)
|
Cash and cash equivalentsbeginning of period
|
|
|
5,819
|
|
|
|
9,536
|
|
|
|
856
|
|
|
|
|
|
|
|
16,211
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalentsend of period
|
|
|
3,839
|
|
|
|
3,630
|
|
|
|
1,743
|
|
|
|
|
|
|
|
9,212
|
|
Less: cash and cash equivalents of discontinued operations at year end
|
|
|
|
|
|
|
(429
|
)
|
|
|
|
|
|
|
|
|
|
|
(429
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents of continuing operations at year end
|
|
$
|
3,839
|
|
|
$
|
3,201
|
|
|
$
|
1,743
|
|
|
$
|
|
|
|
$
|
8,783
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-57
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENT OF CASH FLOWS
YEAR ENDED DECEMBER 31, 2012
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Net cash (used in) provided by operating activities from continuing operations
|
|
$
|
(23,119
|
)
|
|
$
|
47,301
|
|
|
$
|
896
|
|
|
$
|
|
|
|
$
|
25,078
|
|
Net cash provided by operating activities from discontinued operations
|
|
|
|
|
|
|
5,593
|
|
|
|
|
|
|
|
|
|
|
|
5,593
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash (used in) provided by operating activities
|
|
|
(23,119
|
)
|
|
|
52,894
|
|
|
|
896
|
|
|
|
|
|
|
|
30,671
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for acquisitions, net of cash acquired
|
|
|
(359,456
|
)
|
|
|
2,110
|
|
|
|
|
|
|
|
|
|
|
|
(357,346
|
)
|
Proceeds from the sale of property and equipment
|
|
|
|
|
|
|
7,235
|
|
|
|
|
|
|
|
|
|
|
|
7,235
|
|
Purchase of property, plant and equipment
|
|
|
(41
|
)
|
|
|
(43,466
|
)
|
|
|
(9
|
)
|
|
|
|
|
|
|
(43,516
|
)
|
Proceeds from available for sale securities
|
|
|
5,169
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,169
|
|
Other investing activities
|
|
|
|
|
|
|
(51
|
)
|
|
|
(31
|
)
|
|
|
|
|
|
|
(82
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities from continuing operations
|
|
|
(354,328
|
)
|
|
|
(34,172
|
)
|
|
|
(40
|
)
|
|
|
|
|
|
|
(388,540
|
)
|
Net cash used in investing activities from discontinuing operations
|
|
|
|
|
|
|
(4,158
|
)
|
|
|
|
|
|
|
|
|
|
|
(4,158
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(354,328
|
)
|
|
|
(38,330
|
)
|
|
|
(40
|
)
|
|
|
|
|
|
|
(392,698
|
)
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from revolving credit facility
|
|
|
193,490
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
193,490
|
|
Payments on revolving credit facility
|
|
|
(186,674
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(186,674
|
)
|
Proceeds from other debt
|
|
|
398,980
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
398,980
|
|
Payments on other debt
|
|
|
(150,367
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(150,367
|
)
|
Proceeds from equity offering
|
|
|
76,048
|
|
|
|
(1,600
|
)
|
|
|
|
|
|
|
|
|
|
|
74,448
|
|
Payments for deferred financing costs
|
|
|
(26,170
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(26,170
|
)
|
Payments on notes payable and capital leases
|
|
|
|
|
|
|
(4,605
|
)
|
|
|
|
|
|
|
|
|
|
|
(4,605
|
)
|
Payments of contingent consideration
|
|
|
(1,000
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,000
|
)
|
Other financing activities
|
|
|
(569
|
)
|
|
|
511
|
|
|
|
|
|
|
|
|
|
|
|
(58
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities from continuing operations
|
|
|
303,738
|
|
|
|
(5,694
|
)
|
|
|
|
|
|
|
|
|
|
|
298,044
|
|
Net cash provided by (used in) financing activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities
|
|
|
303,738
|
|
|
|
(5,694
|
)
|
|
|
|
|
|
|
|
|
|
|
298,044
|
|
Net (decrease) increase in cash
|
|
|
(73,709
|
)
|
|
|
8,870
|
|
|
|
856
|
|
|
|
|
|
|
|
(63,983
|
)
|
Cash and cash equivalentsbeginning of period
|
|
|
79,528
|
|
|
|
666
|
|
|
|
|
|
|
|
|
|
|
|
80,194
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalentsend of period
|
|
|
5,819
|
|
|
|
9,536
|
|
|
|
856
|
|
|
|
|
|
|
|
16,211
|
|
Less: cash and cash equivalents of discontinued operations at year end
|
|
|
|
|
|
|
(1,435
|
)
|
|
|
|
|
|
|
|
|
|
|
(1,435
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents of continuing operations at year end
|
|
$
|
5,819
|
|
|
$
|
8,101
|
|
|
$
|
856
|
|
|
$
|
|
|
|
$
|
14,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-58
NUVERRA ENVIRONMENTAL SOLUTIONS, INC. AND SUBSIDIARIES
CONSOLIDATING STATEMENT OF CASH FLOWS
YEAR ENDED DECEMBER 31, 2011
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Parent
|
|
|
Guarantor
Subsidiaries
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Net cash (used in) provided by operating activities from continuing operations
|
|
$
|
(158,684
|
)
|
|
$
|
149,405
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
(9,279
|
)
|
Net cash used in operating activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(4,683
|
)
|
|
|
|
|
|
|
(4,683
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash (used in) provided by operating activities
|
|
|
(158,684
|
)
|
|
|
149,405
|
|
|
|
(4,683
|
)
|
|
|
|
|
|
|
(13,962
|
)
|
Cash flows from investing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for acquisitions, net of cash acquired
|
|
|
(88,544
|
)
|
|
|
210
|
|
|
|
|
|
|
|
|
|
|
|
(88,334
|
)
|
Purchase of property, plant and equipment
|
|
|
(299
|
)
|
|
|
(150,622
|
)
|
|
|
|
|
|
|
|
|
|
|
(150,921
|
)
|
Purchases of available for sale securities
|
|
|
(34,947
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(34,947
|
)
|
Proceeds from available for sale securities
|
|
|
120,062
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
120,062
|
|
Proceeds from the sale of certificates of deposits
|
|
|
11,830
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
11,830
|
|
Other investing activities
|
|
|
(16
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(16
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) investing activities from continuing operations
|
|
|
8,086
|
|
|
|
(150,412
|
)
|
|
|
|
|
|
|
|
|
|
|
(142,326
|
)
|
Net cash used in investing activities from discontinuing operations
|
|
|
|
|
|
|
|
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) investing activities
|
|
|
8,086
|
|
|
|
(150,412
|
)
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
(148,103
|
)
|
Cash flows from financing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from revolving credit facility
|
|
|
72,799
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
72,799
|
|
Proceeds from other debt
|
|
|
109,885
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
109,885
|
|
Payments on other debt
|
|
|
(73,914
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(73,914
|
)
|
Cash proceeds from the exercise of warrants
|
|
|
47,912
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
47,912
|
|
Payments for deferred financing costs
|
|
|
(2,764
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,764
|
)
|
Cash paid to purchase treasury stock
|
|
|
(4,414
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,414
|
)
|
Other financing activities
|
|
|
1,488
|
|
|
|
55
|
|
|
|
|
|
|
|
|
|
|
|
1,543
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities from continuing operations
|
|
|
150,992
|
|
|
|
55
|
|
|
|
|
|
|
|
|
|
|
|
151,047
|
|
Net cash provided by financing activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
150,992
|
|
|
|
55
|
|
|
|
|
|
|
|
|
|
|
|
151,047
|
|
Net increase (decrease) increase in cash
|
|
|
394
|
|
|
|
(952
|
)
|
|
|
(10,460
|
)
|
|
|
|
|
|
|
(11,018
|
)
|
Cash and cash equivalentsbeginning of period
|
|
|
79,134
|
|
|
|
1,618
|
|
|
|
10,460
|
|
|
|
|
|
|
|
91,212
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalentsend of period
|
|
$
|
79,528
|
|
|
$
|
666
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
80,194
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-59
(23) Subsequent Events
As more fully described in Note 10, in February 2014, the Company entered into a new asset-backed revolving credit facility to replace its existing revolving credit facility.
As more fully described in Note 16, in March 2014, the Company reached an agreement in principle to settle the 2010 Class Action
litigation.
In March 2014, the Company entered into a Stock Purchase Agreement with respect to the sale of 100% of the common
stock of its wholly-owned subsidiary Thermo Fluids Inc. to VeroLube, Inc. (VeroLube) in exchange for $165.0 million in cash and $10.0 million in VeroLube stock. Closing of the transaction is subject to customary closing conditions,
including regulatory approvals, confirmatory environmental due diligence and a buyer financing contingency. Subject to the satisfaction of closing conditions, the sale is expected to close in the second quarter of 2014.
F-60