ensv20171231

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

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act: ☐ Yes ☑ No

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act: ☐ Yes ☑ No

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).☑ Yes ☐ No

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

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

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Securities Exchange Act of 1934). Yes ☐ No ☑

The aggregate market value of the common stock held by non-affiliates of the Registrant was approximately $47.2 million based upon the closing sale price of the Registrants Common Stock of $1.16 as of June 29, 2018, the last trading day of the registrants most recently completed second fiscal quarter. This determination of affiliate status is not necessarily a conclusive determination for other purposes.

As of March 15, 2019, there were 54,369,829 shares of the Enservco Corporation’s common stock outstanding.

This annual report on Form 10-K contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). In some cases, you can identify forward-looking statements by terms such as “may,” “anticipate,” “should,” “could,” “project,” “intend,” “estimate,” “expect,” “believe,” “predict,” “budget,” “goal,” “plan,” “forecast,” “target” and other similar expressions.

All statements, other than statements of historical facts, contained in this annual report are forward-looking statements. Although we believe that the expectations reflected in the forward-looking statements are reasonable, many factors could cause our actual results to differ materially from what is expressed in or indicated by the forward-looking statements. Forward-looking statements are subject to known and unknown risks and uncertainties, including, among others, the risks set forth in the section of this annual report entitled “Risk Factors” and elsewhere throughout this annual report, as well as the following factors:

All forward-looking statements, express or implied, contained in this annual report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements to reflect events or circumstances after the date of this annual report.

Enservco Corporation (“Enservco”) and its wholly-owned subsidiaries (collectively referred to as the “Company”, “we” or “us”) provides various services to the domestic onshore oil and natural gas industry. These services include frac water heating, hot oiling and acidizing (well enhancement services) and water transfer services. The Company owns and operates a fleet of more than 450 specialized trucks, trailers, frac tanks and other well-site related equipment and serves customers in several major domestic oil and gas fields including the DJ Basin/Niobrara area in Colorado, the Bakken area in North Dakota, the Marcellus and Utica Shale area in Pennsylvania and Ohio, the Jonah Field, Green River and Powder River Basins in Wyoming, the Eagle Ford Shale in Texas, and the Stack and Scoop plays in the Anadarko Basin in Oklahoma.

Enservco was originally incorporated as Aspen Exploration Corporation under Delaware law on February 28, 1980 for the primary purpose of acquiring, exploring and developing oil and natural gas and other mineral properties. During the first half of 2009, Aspen disposed of its oil and natural gas producing assets and as a result was no longer engaged in active business operations. On June 24, 2010, Aspen entered into an Agreement and Plan of Merger and Reorganization with Dillco Fluid Service, Inc. (“Dillco”) which set forth the terms by which Dillco became a wholly owned subsidiary of Aspen on July 27, 2010. On December 30, 2010, Aspen changed its name to “Enservco Corporation.”

The Company’s executive (or corporate) offices are located at 999 18th Street, Suite 1925N, Denver, CO 80202. Our telephone number is (303) 333-3678, and our facsimile number is (720) 974-3417. Our website is www.enservco.com.

The below table provides an overview of the Company’s current subsidiaries and their activities.

On October 26, 2018, the Company entered into a Membership Interest Purchase Agreement (the “Agreement”) with Adler Hot Oil Holdings, LLC, a Delaware limited liability company (the “Seller”), pursuant to which the Company acquired all of the outstanding membership interests of Adler Hot Oil Service, LLC, a Delaware limited liability company (“Adler”) for a gross aggregate purchase price of $12.5 million, subject to customary purchase price adjustments (the “Transaction”). Certain former members of Adler are also parties to the Agreement. Adler is a provider of frac water heating and hot oiling services, whose assets consist primarily of vehicles and equipment, with a complementary base of customers in several oil and gas producing basins where the Company operates.

Enservco primarily conducts its business operations through its principal operating subsidiaries (Heat Waves, HWWM, and Adler), which provide oil field services to the domestic onshore oil and natural gas industry. These services include frac water heating, hot oiling, pressure testing, acidizing, water transfer, bacteria and scale treatment, freshwater and saltwater hauling, fluid disposal, frac tank rental, well site construction and other general oil field services. As described in the table above, certain assets utilized by Heat Waves, HWWM, and Adler in their business operations are owned by other subsidiary entities. The Company currently operates in the following geographic regions:

Historically, the Company focused its growth strategy on strategic acquisitions of operating companies and expansion of services through capital investment consisting of the acquisition and fabrication of property and equipment. That strategy also included expanding into new geographical territories as well as expanding the services it provides. These strategies are exemplified by these activities:

During 2018, relatively stable commodity prices and rig activity in North America resulted in modest increases in production and completion activities by our customers, which led to generally stronger demand for our services. While demand and pricing for the services we provide remain below levels we experienced before the industry downturn that began in the last half of 2014, we believe current activity levels will support continued modest improvement in both metrics. The Company has reacted to increases in demand by allocating resources to our most active customers and basins, as we focus on increasing utilization levels and optimizing the deployment of our equipment and workforce, and maintaining a high service quality and safety record. The recent market recovery has also allowed us to compete on the basis of the quality and breadth of our service offerings, as our customers focus on optimization in production. As of March 15, 2019, we had approximately $35.2 million outstanding and $1.6 million available under our revolving credit facility. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for further information.

As noted above, Enservco conducts its business operations and holds assets primarily through its subsidiary entities. The following describes the operations and assets of Enservco’s operating subsidiaries.

Heat Waves. Heat Waves provides a range of well stimulation/maintenance services to a diverse group of independent and major oil and natural gas companies. The primary services provided are intended to:

These services consist of frac water heating, hot oiling and acidizing. Heat Waves also provides some water hauling and well site construction services. Heat Waves’ operations are currently in the major oil and natural gas areas in Colorado, Montana, North Dakota, Ohio, Oklahoma, Pennsylvania, Texas, West Virginia, and Wyoming.

HWWM. HWWM provides water transfer services and equipment rental to customers in the oil and natural gas industry. Water transfer entails using high and low volume pumps, lay flat hose, aluminum pipe and manifolds to move fresh and/or recycled water from a water source such as a well, pond, lake, river, stream, or water storage facility to frac tanks at drilling locations to be used in connection with well completion activities.

Adler. Adler provides frac water heating, hot oiling, and ancillary services to major oil and natural gas companies in Colorado, North Dakota, Ohio, and Pennsylvania. Adler was established as a Delaware Limited Liability Company on September 25, 2013.

The following map shows the primary areas in which the Company currently operates.

Enservco, through its operating subsidiaries, provides a range of services to owners and operators of oil and natural gas wells in the following business segments.

The Company’s well enhancement services consist of frac water heating, acidizing, hot oiling services, and pressure testing. These services are provided primarily by Heat Waves and Adler which, as of December 31, 2018 utilized a fleet of 246 custom designed trucks and other related equipment. Heat Waves’ operations are currently in northwestern Oklahoma, Texas panhandle, Wyoming (Niobrara), Colorado (D-J Basin), southwestern Pennsylvania/northwestern West Virginia (Marcellus Shale), eastern Ohio (Utica Shale), western North Dakota and eastern Montana (Bakken formation), and southern Texas (Eagle Ford Shale). Well enhancement services accounted for approximately 91% and 94% of the Company’s total revenues for fiscal years ended December 31, 2018 and 2017, respectively.

Frac Water Heating – Frac Water Heating is the process of heating water used in connection with the fracturing process of completing a well. Fracturing services are intended to enhance the production from crude oil and natural gas wells through the creation of conductive flowpaths to enable the hydrocarbons to reach the wellbore where the natural flow has been restricted by underground formations. The fracturing process consists of pumping a fluid slurry, which largely consists of fresh water and a proppant into a well at sufficient pressure to fracture (i.e. create conductive flowpaths) the formation. To ensure these solutions are properly mixed and can flow freely, during certain parts of the year the water frequently needs to be heated to a sufficient temperature as determined by the well owner/operator. As of December 31, 2018, Heat Waves and Adler owned and operated a fleet of 80 frac heaters designed to heat large amounts of water.

Acidizing - Acidizing entails pumping large volumes of specially formulated acids and/or chemicals into a well to dissolve materials blocking the flow of the crude oil or natural gas. The acid is pumped into the well under pressure. Acidizing is most often used to increase permeability throughout the formation, clean up formation damage near the wellbore caused by drilling, and to remove buildup of materials restricting the flow of crude oil and gas through perforations in the well casing. For most customers, Heat Waves supplies the acid solution and also pumps that solution into a given well. As of December 31, 2018, Heat Waves owned and operated a fleet of 7 acidizing units, each of which consist of a specially designed acid pump truck and an acid transport trailer.

Hot Oil Services – Hot oil services involve the circulation of a heated fluid, typically oil, to dissolve, melt, or dislodge paraffin or other hydrocarbon deposits from the tubing of a producing well. Paraffin deposits build up over time from normal production operations, although the rate at which this paraffin builds up depends on the chemical character of the crude oil or natural gas being produced. These services are performed by circulating and heating oil from a well through a hot oil truck and then pumping it down the casing and back up the tubing to remove the deposits. As of December 31, 2018, Heat Waves and Adler owned and operated a fleet of 73 Hot Oiling units. Based on customer needs and seasonal conditions, these vehicles are deployed among the service regions as necessary in seeking to maximize their productive time.

Hot oil servicing also includes the heating of oil storage tanks. The heating of storage tanks is done (i) to eliminate frozen water and other soluble waste in the tank for which the operator’s revenue is reduced at the refinery; and (ii) because heated oil flows more efficiently from the tanks to transports taking oil to the refineries in colder weather.

Pressure Testing – Pressure testing consists of pumping fluids into new or existing wells or other components of the well system such as flow lines to detect leaks. Hot oil trucks and pressure trucks are used to perform this service.

Water Transfer Services – Water transfer entails using high and low volume pumps, lay flat hose, aluminum pipe and manifolds to move fresh and/or recycled water from a water source such as a pond, lake, river, stream, or storage facility to frac tanks at drilling locations to be used in connection with fracking activities. Water transfer differs from water hauling in that water transfer is typically used in connection with well completion activities and involves moving water via pumps, hoses and pipes whereas water hauling involves moving water via bobtail trucks or water transports for either service or completion work. Water transfer services accounted for approximately 9% and 6% of the Company’s total revenues for fiscal 2018 and 2017, respectively.

The Company owns various equipment and other assets to provide its services and products. Substantially all of the equipment and personal property assets owned by these entities are subject to security interests from the company's Loan and Security Agreement with its bank lender.

Historically, as supply and demand require, the Company has leased additional trucks and equipment from time to time. These leases are generally for periods of less than one year, and therefore are treated as operating leases for accounting purposes, and the rent expense associated with these leases is reported ratably over the term of the lease.

We face intense competition in our operations. Competition is influenced by factors such as price, capacity, the quality/safety-record/availability of equipment and work crews, and the reputation and experience of the service provider. The Company believes that an important competitive factor in establishing and maintaining long-term customer relationships is having an experienced, skilled, and well-trained work force that is responsive to our customers’ needs. Although we believe customers consider all of these factors, price is often the primary factor in determining which service provider is awarded work.

The demand for our services fluctuates primarily in relation to the domestic commodity price (or anticipated price) of oil and natural gas which, in turn, is largely driven by the domestic and worldwide supply of, and demand for, oil and natural gas, political events, as well as speculation within the financial markets. Demand and prices are often volatile and difficult to predict and depend on events that are not within our control. Generally, as supply of oil and natural gas decreases and demand increases, service and maintenance requirements increase as oil and natural gas producers drill new wells and attempt to maximize the productivity of their existing wells to take advantage of the higher priced environment. Conversely, as the supply of commodities increase and demand and crude oil and natural gas prices fall, oil and gas producers drill fewer wells and scale back or suspend service and maintenance work.

The Company’s competition primarily consists of small and large regional or local contractors. The Company attempts to differentiate itself from its competition in large part through its range, availability, and quality of services it has the capability to provide. The Company invests a significant amount of capital into purchasing, developing, and maintaining a fleet of trucks and other equipment that are critical to the services it provides. Further, the Company concentrates on providing services to a diverse group of major and independent oil and natural gas companies in a number of geographical areas. We believe we have been successful using this business model and believe it will enable us to grow our business in the event the oil and gas industry has continuing need for the type of service we provide.

The Company serves numerous major and independent oil and natural gas companies that are active in our core areas of operations.

As of December 31, 2018, no single customer comprised more than 10% of the Company’s accounts receivable balance. Revenues from one customer represented approximately 10% of total revenues for the year ended December 31, 2018.

While the Company believes its equipment could be redeployed in the current market environment if it lost any material customers, such loss could have an adverse effect on the Company’s business until the equipment is redeployed. We believe that the market for the Company’s services is sufficiently diversified that it is not dependent on any single customer or a few major customers. Further, the Company believes that if our customers shift production from any of the geographies in which we operate, we could effectively re-deploy our equipment into other geographies.

A significant portion of the Company’s operations is impacted by seasonal factors, particularly with regard to its frac water heating and hot oiling services. In 2018, approximately 70% of revenue was earned during the first and fourth fiscal quarters. In regard to frac water heating, because customers rely on Heat Waves to heat large amounts of water for use in fracturing formations, demand for this service is much greater in the colder months. Similarly, hot oiling services are in higher demand during the colder months when they are needed for maintenance of existing wells and to heat oil storage tanks.

Acidizing and pressure testing are performed throughout the year with higher revenues typically during non-winter months.

We believe water transfer services are not seasonal. However, our water transfer services depend upon the level of drilling, well completion, and production activities.

The Company purchases a wide variety of raw materials, parts, and components that are made by other manufacturers and suppliers for our use. The Company is not dependent on any single source of supply for those parts, supplies or materials. However, there are a limited number of vendors for propane and certain acids and chemicals. The Company utilizes a limited number of suppliers and service providers available to fabricate and/or construct the trucks and equipment used in its hot oiling, frac water heating, and acid related services.

Patents, Trademarks, Licenses, Franchises, Concessions, Royalty Agreements or Labor Contracts

As is the situation with all companies in the frac water heating service business, we rely on certain procedures and practices in performing our services. In 2016, we were issued our first patent relating to an aspect of the frac water heating process. We have other patent applications pending regarding other procedures used in our process of heating frac water. Further, Adler has been issued three United States patents and one Canadian patent and has two United States patents pending related to aspects of the frac water heating process. We are aware that one unrelated company has been awarded four patents related, in part, to a process for heating of frac water. For a further discussion of this, see Item 3 – Litigation, below.

The Company and its subsidiaries are subject to a variety of government regulations ranging from environmental to Occupational Safety and Health Act ("OSHA") to the Department of Transportation. Our operations are also subject to stringent federal, state and local laws regulating the discharge of materials into the environment or otherwise relating to health and safety or the protection of the environment. These federal, state, and local laws and regulations relating to protection of the environment, wildlife protection, historic preservation, and health and safety are extensive and changing. The trend in environmental legislation and regulation is generally toward stricter standards, and we expect that this trend will continue as governmental agencies issue and amend existing regulations. Failure to comply with these laws and regulations as they currently exist or may be amended in the future may result in the assessment of substantial administrative, civil and criminal penalties, as well as the issuance of injunctions limiting or prohibiting activities. Adherence with these regulatory requirements increases our cost of doing business and consequently affects our profitability. The Company does not believe that it is in material violation of any regulations that would have a significant negative impact on the Company’s operations.

Through the routine course of providing services, the Company handles and stores bulk quantities of hazardous materials. If leaks or spills of hazardous materials handled, transported or stored by us occur, the Company may be responsible under applicable environmental laws for costs of remediating any damage to the surface or sub-surface (including aquifers).

The Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”), also known as “Superfund,” and comparable state statutes impose strict, joint and several liability on owners and operators of sites and on persons who disposed of or arranged for the disposal of “hazardous substances” found at such sites. It is not uncommon for the government to file claims requiring cleanup actions, demands for reimbursement for government-incurred cleanup costs, or natural resource damages, or for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances released into the environment. The Federal Resource Conservation and Recovery Act, or RCRA, and comparable state statutes govern the disposal of “solid waste” and “hazardous waste” and authorize the imposition of substantial fines and penalties for noncompliance, as well as requirements for corrective actions. Although CERCLA currently excludes petroleum from its definition of “hazardous substance,” state laws affecting our operations may impose clean-up liability relating to petroleum and petroleum-related products. In addition, although RCRA classifies certain oil field wastes as “non-hazardous,” such exploration and production wastes could be reclassified as hazardous wastes thereby making such wastes subject to more stringent handling and disposal requirements. CERCLA, RCRA and comparable state statutes can impose liability for clean-up of sites and disposal of substances found on drilling and production sites long after operations on such sites have been completed. Other statutes relating to the storage and handling of pollutants include the Oil Pollution Act of 1990, or OPA, which requires certain owners and operators of facilities that store or otherwise handle oil to prepare and implement spill response plans relating to the potential discharge of oil into surface waters. The OPA contains numerous requirements relating to prevention of, reporting of, and response to oil spills into waters of the United States. State laws mandate oil cleanup programs with respect to contaminated soil. A failure to comply with OPA’s requirements or inadequate cooperation during a spill response action may subject a responsible party to civil or criminal enforcement actions.

In the course of the Company’s operations, it does not typically generate materials that are considered “hazardous substances.” One exception, however, would be spills that occur prior to well treatment materials being circulated down hole. For example, if the Company spills acid on a roadway as a result of a vehicle accident in the course of providing well enhancement/stimulation services, or if a tank with acid leaks prior to down hole circulation, the spilled material may be considered a “hazardous substance.” In this respect, the Company may occasionally be considered to “generate” materials that are regulated as 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.

The Clean Water Act (the “CWA”), and comparable state statutes, impose restrictions and controls on the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the United States. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the Environmental Protection Agency (the “EPA”) or an analogous state agency. The CWA regulates storm water run-off from oil and natural gas facilities and requires a storm water discharge permit for certain activities. Such a permit requires the regulated facility to monitor and sample storm water run-off from its operations. The CWA and regulations implemented thereunder also prohibit discharges of dredged and fill material in wetlands and other waters of the United States unless authorized by an appropriately issued permit. The CWA and comparable state statutes provide for civil, criminal and administrative penalties for unauthorized discharges of oil and other pollutants and impose liability on parties responsible for those discharges for the costs of cleaning up any environmental damage caused by the release and for natural resource damages resulting from the release.

The Safe Drinking Water Act (the “SDWA”), and the Underground Injection Control (“UIC”) program promulgated thereunder, regulate the drilling and operation of subsurface injection wells, such as the disposal wells owned and operated by the Company. The EPA directly administers the UIC program in some states and in others the responsibility for the program has been delegated to the state. The program requires that a permit be obtained before drilling a disposal well. Violation of these regulations and/or contamination of groundwater by oil and natural gas drilling, production, and related operations may result in fines, penalties, and remediation costs, among other sanctions and liabilities under the SWDA and state laws. In addition, third party claims may be filed by landowners and other parties claiming damages for alternative water supplies, property damages, and bodily injury.

Regulations in the states in which the Company owns and operates water injection wells (Oklahoma) require us to obtain a permit to operate each of our disposal wells. The applicable regulatory agency may suspend or modify one of our permits if the Company’s well operations are likely to result in pollution of freshwater, substantial violation of permit conditions or applicable rules, or if the well leaks into the environment.

The Federal Energy Policy Act of 2005 amended the SDWA to exclude hydraulic fracturing from the definition of “underground injection” under certain circumstances. However, the repeal of this exclusion has been advocated by certain advocacy organizations and others in the public. The EPA at the request of Congress conducted a national study examining the potential impacts of hydraulic fracturing on drinking water resources and issued a final assessment report in December 2016, which concluded that hydraulic fracturing activities can impact drinking water resources under some circumstances and identifies factors that influence these impacts.

We incur, and expect to continue to incur, capital and operating costs to comply with the environmental laws and regulations described herein. The technical requirements of these laws and regulations are becoming increasingly complex, stringent and expensive to implement.

If new federal or state laws or regulations that significantly restrict hydraulic fracturing are adopted, such legal requirements could result in delays, eliminate certain drilling and injection activities, make it more difficult or costly for our customers to perform fracturing and increase their and our costs of compliance and doing business. It is also possible that drilling and injection operations utilizing our services could adversely affect the environment, which could result in a requirement to perform investigations or clean-ups or in the incurrence of other unexpected material costs or liabilities.

Significant studies and research have been devoted to climate change and global warming, and climate change has developed into a major political issue in the United States and globally. Certain research suggests that greenhouse gas emissions contribute to climate change and pose a threat to the environment. Recent scientific research and political debate has focused in part on carbon dioxide and methane incidental to oil and natural gas exploration and production. Many state governments have enacted legislation directed at controlling greenhouse gas emissions, and future state and federal legislation and regulation could impose additional restrictions or requirements in connection with our operations and favor use of alternative energy sources, which could increase operating costs and decrease demand for oil products. As such, our business could be materially adversely affected by domestic and international legislation targeted at controlling climate change.

We are also subject to a number of federal and state laws and regulations, including OSHA, and comparable state laws, whose purpose is to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of the federal Superfund Amendment and Reauthorization Act and comparable state statutes require that information be maintained concerning hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens.

Because our trucks travel over public highways to get to customers’ wells, the Company is subject to the regulations of the Department of Transportation. These regulations are very comprehensive and cover a wide variety of subjects from the maintenance and operation of vehicles to driver qualifications to safety. Violations of these regulations can result in penalties ranging from monetary fines to a restriction on the use of the vehicles. Under regulations effective July 1, 2010, an uncured violation of regulations could result in a shutdown of all of the vehicles of Heat Waves, Adler, or HWWM. The Company does not believe it is in violation of Department of Transportation regulations at this time that would result in a shutdown of vehicles.

Some states and certain municipalities have regulated, or are considering regulating hydraulic fracturing (“fracking”) which, if accomplished, could impact certain of our operations. While the Company does not believe that existing regulations and contemplated actions to limit or prohibit fracking have impacted its activities to date, there can be no assurance that these actions, if taken on a wider scale, may not adversely impact the Company’s business operations and revenues.

As of February 28, 2019, the Company employed 231 full time employees. Of these employees, 149 are employed by Heat Waves, 29 by Adler, 36 by HWWM, and 17 are employed by Enservco. From time to time, the Company may hire contractors to perform work.

We maintain a website at http://www.enservco.com. The information contained on, or accessible through, our website is not part of this Annual Report on Form 10-K. Our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to reports filed or furnished pursuant to the Exchange Act, are available on our website, free of charge, as soon as reasonably practicable after we electronically file such reports with, or furnish those reports to, the SEC.

In addition, we maintain our corporate governance documents on our website, including our:

An investment in our common stock may be considered speculative and involves a high degree of risk, including among other items the risk factors described below. These risk factors are intended to generally describe certain risks that could materially affect the Company and its current business operations and activities.

You should carefully consider the risks described below and elsewhere herein in connection with any decision whether to acquire, hold or sell the Company’s securities. The following list identifies and briefly summarizes certain risk but should not be viewed as complete or comprehensive. If any of the contingencies discussed in the following paragraphs or other materially adverse events actually occur, the business, financial condition and results of operations could be materially and adversely affected. In such case, the trading price of our common stock could decline, and you could lose all or a significant part of your investment.

While our growth strategy includes seeking acquisitions of other oilfield services companies, we may not be successful in identifying, making and integrating business or asset acquisitions, if any, in the future.

We anticipate that a component of our growth strategy may be to make geographically focused acquisitions of businesses or assets aimed to strengthen our presence and expand services offered in selected regional markets. Pursuit of this strategy may be restricted by the on-going volatility and uncertainty within the credit markets which may significantly limit the availability of funds for such acquisitions. Our ability to use shares of our common stock in an acquisition transaction may be adversely affected by the volatility in the price of our common stock.

In addition to restricted funding availability, the success of this strategy will depend on our ability to identify suitable acquisition candidates and to negotiate acceptable financial and other terms. There is no assurance that we will be able to do so. The success of an acquisition also depends on our ability to perform adequate due diligence before the acquisition and on our ability to integrate the acquisition after it is completed. While the we intend to commit significant resources to ensure that it conducts comprehensive due diligence, there can be no assurance that all potential risks and liabilities will be identified in connection with an acquisition. Similarly, while we expect to commit substantial resources, including management time and effort, to integrating acquired businesses into ours, there is no assurance that we will be successful in integrating these businesses. In particular, it is important that we be able to retain both key personnel of the acquired business and its customer base. A loss of either key personnel or customers could negatively impact the future operating results of any acquired business.

Our businesses, particularly our frac heating and hot oil services, are impacted by weather conditions and temperatures. Unseasonably warm weather during winter months reduces demand for the heating services and results in higher operating costs, as a percentage of revenue, due to the need to retain equipment operators during these low demand periods. Management makes concerted efforts to reduce costs during these low demand periods by utilizing operators in other business segments, reducing hours, and some instances utilizing seasonal layoffs.

Further, during the winter months, our customers may delay operations or we may not be able to operate or move our equipment between locations during periods of heavy snow, ice or rain, and during the spring some areas impose transportation restrictions due to muddy conditions caused by spring thaws.

We may be unable to implement price increases or maintain existing prices on our core services.

We periodically seek to increase the prices of our services to offset rising costs and to generate increased revenues. We operate in a very competitive industry and, as a result, we are not always successful in raising or maintaining our existing prices. Additionally, during periods of increased market demand, a significant amount of new equipment may enter the market, which would also put pressure on the pricing of our services. Even when we are able to increase our prices, we may not be able to do so at a rate that is sufficient to offset rising costs. Also, we may not be able to successfully increase prices without adversely affecting our activity levels. The inability to maintain our prices or to increase the prices of our services to offset rising costs increase could have a material adverse effect on our business, financial position and results of operations.

We operate in a capital-intensive industry. We may not be able to finance future growth of our operations or future acquisitions.

Our business activities require substantial capital expenditures. If our cash flow from operating activities and borrowings under our existing credit facility were not sufficient to fund our capital expenditure budget, we would be required to reduce these expenditures or to fund these expenditures through new debt or equity issuances.

Our ability to raise new debt or equity capital or to refinance or restructure our debt at any given time depends, among other things, on the condition of the capital markets and our financial condition at such time. Also, the terms of existing or future debt or equity instruments could further restrict our business operations. The inability to finance future growth could materially and adversely affect our business, financial condition and results of operations.

Increased labor costs or the unavailability of skilled workers could hurt our operations.

Companies in our industry, including us, are dependent upon the available labor pool of skilled workers. We compete with other oilfield services businesses and other employers to attract and retain qualified personnel with the technical skills and experience required to provide our customers with the highest quality service. We are also subject to the Fair Labor Standards Act, which governs such matters as minimum wage, overtime and other working conditions, and which can increase our labor costs or subject us to liabilities to our employees. A shortage of skilled workers or other general inflationary pressures or changes in applicable laws and regulations could make it more difficult for us to attract and retain skilled personnel and could require us to enhance our wage and benefits packages. Labor costs may increase in the future or we may not be able to reduce wages when demand and pricing falls, and such changes could have a material adverse effect on our business, financial condition and results of operations.

Historically, we have experienced a high employee turnover rate. Any difficulty we experience replacing or adding workers could adversely affect our business.

We believe that the high turnover rate in our industry is attributable to the nature of oilfield services work, which is physically demanding and performed outdoors, and to the seasonality of certain of our segments. As a result, workers may choose to pursue employment in areas that offer a more desirable work environment at wage rates that are competitive with ours. The potential inability or lack of desire by workers to commute to our facilities and job sites, as well as the competition for workers from competitors or other industries, are factors that could negatively affect our ability to attract and retain skilled workers. We may not be able to recruit, train and retain an adequate number of workers to replace departing workers. The inability to maintain an adequate workforce could have a material adverse effect on our business, financial condition and results of operations.

On December 22, 2017, legislation referred to as the Tax Act was signed into law. The Tax Act is generally effective for taxable years beginning after December 31, 2017. The Tax Act includes significant amendments to the Internal Revenue Code, including amendments that significantly change the taxation of business entities, including the deductibility of interest. Some of the amendments could adversely affect our business and financial condition, including by limiting our ability to realize tax benefits from our NOLs, however we expect that, ultimately, the reduction of the federal corporate tax rate from 35% to 21% should be beneficial to us.

Our business depends on domestic (United States) spending by the crude oil and natural gas industry which has suffered significant price volatility since July 2014, and such volatility may continue; our business has been, and may in the future be, adversely affected by industry and financial market conditions that are beyond our control.

We depend on our customers’ ability and willingness to make operating and capital expenditures to explore, develop and produce crude oil and natural gas in the United States. Customers’ expectations for future crude oil and natural gas prices, as well as the availability of capital for operating and capital expenditures, may cause them to curtail spending, thereby reducing demand for our services and equipment. Major declines in oil and natural gas prices since July 2014 (when prices were at approximately $100 per barrel) have resulted in substantial declines in capital spending and drilling programs across the industry. As a result of the declines in oil and natural gas prices, many exploration and production companies substantially reduced drilling programs at times and required service providers to make pricing concessions. Over the two years ended December 31, 2017, we offered pricing concessions to a number of customers. Typically, these concessions have been made with the intent to maintain existing service volumes and/or develop additional business.

Industry conditions and specifically the market price for crude oil and natural gas are influenced by numerous domestic and global factors over which we have no control, such as the supply of and demand for oil and natural gas, domestic and worldwide economic conditions, weather conditions, political instability in oil and natural gas producing countries and perceived economic conditions. The volatility of the oil and natural gas industry and the consequent impact on commodity prices as well as exploration and production activity could adversely impact the level of drilling and activity by many of our customers. Where declining prices lead to reduced exploration and development activities in our market areas, the reduction in exploration and development activities also may have a negative long-term impact on our business. Several month periods of low oil and natural gas prices may result in increased pressure from our customers to make additional pricing concessions in the future and may impact our borrowing arrangements with our principal bank. There can be no assurance that the prices we charge to our customers will return to former levels experienced in 2014.

There has also been significant political pressures for the United States economy to reduce its dependence on crude oil and natural gas due to the perceived impacts on climate change. Furthermore, there have been significant political and regulatory efforts to reduce or eliminate hydraulic fracturing operations in certain of our service areas, particularly in Colorado. The Colorado legislature is considering a bill that in our view would significantly restrict oil and gas drilling in Colorado, thereby negatively affecting our revenues. These activities may make oil and gas investment and production less attractive.

Higher oil and gas prices do not necessarily result in increased drilling activity because our customers’ expectation of future prices also drives demand for production maintenance and completion services. Oil and gas prices, as well as demand for our services, also depend upon other factors that are beyond our control, including the following:

On going volatility and uncertainty in the domestic and global economic and political environments have caused the oilfield services industry to experience demand volatility. While our management is generally optimistic for the continuing development of the onshore North American oil and gas industry, there are a number of political and economic pressures negatively impacting the economics of continuing production from some existing wells, future drilling operations, and the willingness of banks and investors to provide capital to participants in the oil and gas industry. We believe that these cuts in spending will continue to curtail drilling programs as well as discretionary spending on well services, and will continue to result in a reduction in the demand for our services, the rates we can charge, and equipment utilization. In addition, certain of our customers could become unable to pay their suppliers, including us. Any of these conditions or events could adversely affect our operating results.

Our success depends on key members of our management, the loss of any executive or key personnel could disrupt our business operations.

We depend to a large extent on the services of certain of our executive officers. The loss of the services of Ian Dickinson, Kevin Kersting or Dustin Bradford, could disrupt our operations. Although we have entered or intend to enter into employment agreements with Messrs. Dickinson, Kersting and Bradford, that contain, among other things non-compete and confidentiality provisions, we may not be able to enforce the non-compete and/or confidentiality provisions in the employment agreements.

We depend on several significant customers, and a loss of one or more significant customers could adversely affect our results of operations.

Our top five customers accounted for approximately 36% and 43% of our total annual revenues for 2018 and 2017, respectively. The loss of any one of these customers or a sustained decrease in demand by any of such customers could result in a substantial loss of revenues and could have a material adverse effect on our results of operations.

While we believe our equipment could be redeployed in the current market environment if we lost any material customers, such loss could have an adverse effect on our business until the equipment is redeployed. We believe that the market for our services is sufficiently diversified that it is not dependent on any single customer or a few major customers.

Demand for the majority of our services is substantially dependent on the levels of expenditures by the domestic oil and natural gas industry. We have no influence over our customers’ capital expenditures. On-going economic volatility could have a material adverse effect on our financial condition, results of operations and cash flows.

Over the last several years, oil prices have experienced significant swings. Significant and sustained price declines have historically caused many of our customers to reduce or delay their oil and natural gas exploration and production spending, which consequently resulted in decreased demand for our services, and exerted downward pressure on the prices we charged for our services and products.

Also, an environment of increasing oil and natural gas prices can lead to increasing costs of exploring for and producing oil and natural gas. Though the addition of frac stimulation into the domestic oil and gas industry has somewhat reduced the overall costs of producing oil and natural gas, the price of drill rigs, pipe, other equipment, fluids, and oil field services and the cost to companies like us of providing those services, has generally increased along with increases in oil and natural gas prices. The reduction in cash flows experienced by our customers during periods of lower oil and natural gas prices and the increase of the costs of exploring for and producing oil and natural gas as noted above could have significant adverse effects on the financial condition of some of our customers. This could result in project modifications, delays or cancellations, general business disruptions, and delay in, or nonpayment of, amounts that are owed to us, which could have a material adverse effect on our financial condition, results of operations and cash flows.

Environmental compliance costs and liabilities could reduce our earnings and cash available for operations.

We are subject to increasingly stringent laws and regulations relating to environmental protection and the importation and use of hazardous materials, including laws and regulations governing air emissions, water discharges and waste management. Government authorities have the power to enforce compliance with their regulations, and violations are subject to fines, injunctions or both. We incur, and expect to continue to incur, capital and operating costs to comply with environmental laws and regulations. The technical requirements of these laws and regulations are becoming increasingly complex, stringent and expensive to implement. These laws may provide for “strict liability” for damages to natural resources or threats to public health and safety. Strict liability can render a party liable for damages without regard to negligence or fault on the part of the party. Some environmental laws provide for joint and several strict liability for remediation of spills and releases of hazardous substances.

We use hazardous substances and transport hazardous wastes in our operations. Accordingly, we could become subject to potentially material liabilities relating to the investigation and cleanup of contaminated properties, and to claims alleging personal injury or property damage as the result of exposures to, or releases of, hazardous substances. In addition, stricter enforcement of existing laws and regulations, new laws and regulations, the discovery of previously unknown contamination or the imposition of new or increased requirements could require us to incur costs and penalties, or become the basis of new or increased liabilities that could reduce its earnings and cash available for operations. We believe we are currently in compliance with environmental laws and regulations.

Intense competition within the well services industry may adversely affect our ability to market our services.

The well services industry is intensely competitive. It includes numerous small companies capable of competing effectively in our markets on a local basis, as well as several large companies that possess substantially greater financial and other resources than us. Our larger competitors have greater resources that allow those competitors to compete more effectively than us. Our small competitors may be able to react to market conditions more quickly. The amount of equipment available may exceed demand at some point in time, which could result in active price competition.

We could be impacted by unfavorable results of legal proceedings, such as being found to have infringed on intellectual property rights.

As is the situation with other companies in the frac water heating service business, we rely on certain procedures and practices in performing our services. In 2016, we were issued our first patent relating to an aspect of the frac water heating process and in 2017, a second patent was issued. We have other patent applications pending regarding other procedures used in our process of heating frac water. We are aware that one unrelated company (the “Patent Owner”) has been awarded four patents related, in part, to a process for heating of frac water. The Patent Owner is currently in litigation with two different groups of energy companies that are seeking to invalidate the first patent. A North Dakota court has issued a summary judgment that the first patent owned by the Patent Owner is invalid. The same Court also found that this first patent is unenforceable due to inequitable conduct by the Patent Owner and/or the inventor. The Patent Owner has filed an appeal with the U.S. Court of Appeals for the Federal Circuit to appeal this judgment and other adverse judgments and orders by the North Dakota court. As of March 15, 2019, the U.S. Court of Appeals for the Federal Circuit has dismissed this case in its entirety without any finding of wrongdoing by Enservco or Heat Waves.

In October 2014, we were served with a complaint that alleges that Enservco and Heat Waves, in offering and selling frac water heating services, infringed and induced others to infringe two patents owned by the Patent Owner including the first patent ruled invalid and unenforceable by the North Dakota Court. The complaint seeks various remedies including injunctive relief and unspecified damages and relates to only a portion of Heat Waves’ frac water heating services. Heat Waves has answered the complaint, denied the Patent Owner’s allegations of infringement and asserted counterclaims asking the Court to find, among other things, that it does not infringe either patent and that both patents are invalid. The Patent Owner has replied to and denied those counterclaims. In July 2015, a Colorado Court granted a joint request by Enservco, Heat Waves and the Patent Owner to stay the case. On March 15, 2019, the U.S. Court of Appeals for the Federal Circuit has dismissed this case in its entirety without any finding of wrongdoing by Enservco or Heat Waves. (See Item 3 – Litigation, for more information about this matter.)

Our operations are subject to inherent risks, some of which are beyond our control. These risks may be self-insured, or may not be fully covered under our insurance policies, but to the extent not covered, are self-insured by us.

Our operations are subject to hazards inherent in the oil and natural gas industry, such as, but not limited to, accidents, blowouts, explosions, fires and oil spills. These conditions can cause:

The occurrence of a significant event or adverse claim in excess of the insurance coverage that we maintain or that is not covered by insurance could have a material adverse effect on our financial condition and results of operations. In addition, claims for loss of oil and natural gas production and damage to formations can occur in the well services industry. Litigation arising from a catastrophic occurrence at a location where our equipment and services are being used may result in us 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. In addition, in June 2015, we became self-insured under our Employee Group Medical Plan for the first $50,000 per individual participant. However, we do not have insurance against all foreseeable risks, either because insurance is not available or because of the high premium costs. The occurrence of an event not fully insured against, or the failure of an insurer to meet its insurance obligations, could result in substantial losses to us. In addition, we may not be able to maintain adequate insurance in the future at reasonable rates. Insurance may not be available to cover any or all of the risks to which we are subject, or, even if available, it may be inadequate, or insurance premiums or other costs could rise significantly in the future so as to 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.

Failure to successfully integrate the operations of Adler could materially increase our costs with a resulting negative effect on our results of operations.

Our recent acquisition of Adler Hot Oil Service, LLC will require an integration of its operations into our operations. While we are optimistic about the integration of Adler, we may experience unforeseen delays and operational issues in seeking to complete the integration. These unforeseen circumstances could include employee turnover, significant management time devoted to the integration, loss of Adler customers, as well as discovery of unanticipated liabilities. Any of these factors could have a material adverse effect on our operations, revenues and liquidity. In addition, we have financed a significant portion of the Adler acquisition through payment of a note to the Seller. Payment of the notes will have a significant negative effect on our liquidity.

Compliance with climate change legislation or initiatives could negatively impact our business.

The U.S. Congress has considered legislation to mandate reductions of greenhouse gas emissions and certain states have already implemented, or may be in the process of implementing, similar legislation. Additionally, the U.S. Supreme Court has held in its decisions that carbon dioxide can be regulated as an “air pollutant” under the Clean Air Act, which could result in future regulations even if the U.S. Congress does not adopt new legislation regarding emissions. At this time, it is not possible to predict how legislation or new federal or state government mandates regarding the emission of greenhouse gases could impact our business; however, any such future laws or regulations could require us or our customers to devote potentially material amounts of capital or other resources in order to comply with such regulations. These expenditures could have a material adverse impact on our financial condition, results of operations, or cash flows.

Anti-fracking initiatives and revisions of applicable state regulations could adversely impact our business.

Some states (including Colorado) and certain municipalities have regulated, or are considering regulating fracking which, if accomplished, could impact certain of our operations. While we do not believe that these regulations and contemplated actions to limit or prohibit fracking have impacted its activities to date, there can be no assurance that these actions, if taken on a wider scale, may not adversely impact our business operations and revenues.

Our ability to use our net operating loss carry forwards may be subject to limitation and may result in increased future tax liability.

Sections 382 and 383 of the Internal Revenue Code of 1986, as amended, or the Code, contain rules that limit the ability of a corporation that undergoes an “ownership change” to utilize its net operating loss carry forwards (“NOLs”) and certain built-in losses recognized in years after the ownership change. An “ownership change” is generally defined as any change in ownership of more than 50% of a corporation’s stock over a rolling three-year period by stockholders that own (directly or indirectly) 5% or more of the stock of the corporation, or arising from a new issuance of stock by the corporation. If an ownership change occurs, Section 382 generally imposes an annual limitation on the use of pre-ownership change net operating losses, or NOLs, credits and certain other tax attributes to offset taxable income earned after the ownership change. The annual limitation is equal to the product of the applicable long-term tax-exempt rate and the value of the corporation’s stock immediately before the ownership change. This annual limitation may be adjusted to reflect any unused annual limitation for prior years and certain recognized built-in gains for the year. In addition, Section 383 generally limits the amount of tax liability in any post-ownership change year that can be reduced by pre-ownership change tax credit carryforwards. If we were to experience an "ownership change," this could result in increased U.S. federal income tax liability for us if we generate taxable income after the ownership change. Limitations on the use of NOLs and other tax attributes could also increase our state tax liabilities. The use of our tax attributes will also be limited to the extent that we do not generate positive taxable income in future tax periods. As a result of these limitations, we may be unable to offset future taxable income, if any, with NOLs before such NOLs expire. Accordingly, these limitations may increase our federal and state income tax liabilities.

As of December 31, 2018, we had U.S. federal NOLs of approximately $23.5 million and state NOLs of approximately $27.7 million.

In addition to restricted funding availability, the success of this strategy will depend on our ability to identify suitable acquisition candidates and to negotiate acceptable financial and other terms. There is no assurance that we will be able to do so. The success of an acquisition also depends on our ability to perform adequate due diligence before the acquisition and on our ability to integrate the acquisition after it is completed. While the Company intends to commit significant resources to ensure that it conducts comprehensive due diligence, there can be no assurance that all potential risks and liabilities will be identified in connection with an acquisition. Similarly, while we expect to commit substantial resources, including management time and effort, to integrating acquired businesses into ours, there is no assurance that we will be successful in integrating these businesses. In particular, it is important that the Company be able to retain both key personnel of the acquired business and its customer base. A loss of either key personnel or customers could negatively impact the future operating results of any acquired business.

Our indebtedness, which is currently collateralized by substantially all of our assets, could restrict our operations and make us more vulnerable to adverse economic conditions.

As of December 31, 2018, the Company owed approximately $40.4 million to banks, financial institutions, and other parties under various collateralized debt obligations.

Our current and future indebtedness could have important consequences. For example, it could:

If we are unable to generate sufficient cash flow or are otherwise unable to obtain the funds required to make principal and interest payments on our indebtedness, or if we otherwise fail to comply with the various debt service covenants and/or reporting covenants in the business loan agreements or other instruments governing our current or any future indebtedness, we could be in default under the terms of our credit facilities or such other debt agreements.

The availability of borrowings under our credit facility is based on a borrowing base which is subject to redetermination by our lender based on a number of factors and the lender’s internal credit criteria. In the event the amount outstanding under our credit facility at any time exceeds the borrowing base at such time, we may be required to repay a portion of our outstanding borrowings on an accelerated basis.

In the event of a default, the holders of our indebtedness could elect to declare all the funds borrowed under those instruments to be due and payable together with accrued and unpaid interest, the lenders under our credit facility could elect to terminate their commitments there-under and we or one or more of our subsidiaries could be forced into bankruptcy or liquidation. Any of the foregoing consequences could restrict our ability to grow our business and cause the value of our common stock to decline.

We may be unable to meet the obligations of various financial covenants that are contained in the terms of our loan agreements with our principal lender, East West Bank.

The Company’s agreements with East West Bank impose various obligations and financial covenants on the Company. The outstanding amount under the Amended Loan and Security Agreement, entered into with East West Bank in August 2017 and amended in November 2017 and October 2018 is due in August 2020. The revolving credit agreement with East West Bank has a variable interest rate and is collateralized by substantially all of the assets of the Company and its subsidiaries.

Further, the related agreements with East West Bank impose various financial covenants on the Company including maintaining a prescribed fixed charge coverage ratio, a minimum liquidity ratio at certain times, and limit the Company's ability to make capital investments. There can be no assurance that we will be able to comply with these covenants in the future, or that if we violate a covenant East West Bank would be willing to provide a waiver of such covenant. Violation of these covenants could result in the acceleration of maturities under the default provisions of our loan and security agreement. As of December 31, 2018, we were in compliance with all financial covenants.

The variable rate indebtedness with East West Bank subjects us to interest rate risk, which could cause our debt service obligations to increase significantly.

The Company’s borrowings through East West Bank bear interest at variable rates, exposing the Company to interest rate risk. As of December 31, 2018, the Company had entered into a hedging arrangement to protect against the interest rate risk associated with a portion of the balance of the senior revolving credit facility.

Our debt obligations, which may increase in the future, may reduce our financial and operating flexibility.

As of December 31, 2018, we had borrowed approximately $33.9 million under our senior revolving credit facility and had approximately $3.0 million of borrowing capacity available under this facility. Additionally, as of December 31, 2018 we owed approximately $6.5 million to other parties pursuant to various secured and unsecured subordinate debt agreements. Although the Company plans to utilize cash flow from operations during the first half of 2019 to reduce our outstanding borrowings, we may incur substantial additional indebtedness in the future. If the Company is unable to reduce debt as planned or new debt or other liabilities are added to our current debt levels, the related risks that we now face would increase.

A high level of indebtedness subjects us to a number of material adverse risks. In particular, a high level of indebtedness may make it more likely that a reduction in the borrowing base of our credit facility following a periodic redetermination could require us to repay a portion of outstanding borrowings, may impair our ability to obtain additional financing in the future, and increases the risk that we may default on our debt obligations. In addition, we may be required to devote a significant portion of our cash flows to servicing our debt, and we are subject to interest rate risk under our credit facility, which bears interest at variable rates. An increase in our interest rates could have an adverse impact on our financial condition, results of operations and growth prospects.

Our ability to meet our debt obligations and to reduce our level of indebtedness depends on our future performance. General economic conditions, oil and natural gas prices and financial, business and other factors affect our operations and our future performance. Many of these factors are beyond our control. If we do not have sufficient funds on hand to pay our debt when due, we may be required to seek a waiver or amendment from our lenders, refinance our indebtedness, incur additional indebtedness, sell assets or sell additional shares of our common stock. We may not be able to complete such transactions on terms acceptable to us, or at all. Our failure to generate sufficient funds to pay our debts or to undertake any of these actions successfully could result in a default on our debt obligations, which would materially adversely affect our business, results of operations and financial condition.

We have no plans to pay dividends on our common stock for the foreseeable future. Stockholders may not receive funds without selling their shares.

We do not anticipate paying any cash dividends on our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to pay down debt and finance the expansion of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our business, financial condition, results of operations, capital requirements and investment opportunities. In addition, we have agreed with East West Bank, our principal lender that we will not pay any cash dividends on our common stock until our obligations to East West Bank are paid in full. Accordingly, realization of a gain on a shareholder’s investment will depend on the appreciation of the price of our common stock.

Our board of directors can, without stockholder approval, cause preferred stock to be issued on terms that adversely affect holders of our common stock.

Under our certificate of incorporation, our board of directors is authorized to issue up to 10,000,000 shares of preferred stock, of which none are issued and outstanding as of the date of this annual report. Also, our board of directors, without stockholder approval, may determine the price, rights, preferences, privileges and restrictions, including voting rights, of those shares. If our board of directors causes shares of preferred stock to be issued, the rights of the holders of our common stock would likely be subordinate to those of preferred holders and therefore could be adversely affected. Our board of directors’ ability to determine the terms of preferred stock and to cause its issuance, while providing desirable flexibility in connection with possible acquisitions and other corporate purposes, could have the effect of making it more difficult for a third party to acquire a majority of our outstanding common stock. Preferred shares issued by our board of directors could include voting rights or super voting rights, which could shift the ability to control the Company to the holders of the preferred stock. Preferred stock could also have conversion rights into shares of our common stock at a discount to the market price of our common stock, which could negatively affect the market for our common stock. In addition, preferred stock would have preference in the event of liquidation of the corporation, which means that the holders of preferred stock would be entitled to receive the net assets of the corporation distributed in liquidation before the holders of our common stock receive any distribution of the liquidated assets. We have no current plans to issue any shares of preferred stock.

The price of our common stock may be volatile regardless of our operating performance, and you may not be able to resell shares of our common stock at or above the price you paid or at all.

The trading price of our common stock may be volatile, and you may not be able to resell your shares at or above the price at which you paid for such shares. Our stock price volatility can be in response to a number of factors, including those listed in this section and elsewhere in this annual report. Many of these volatility factors are beyond our control. Other factors that may affect the market price of our common stock include:

In addition, the U.S. securities markets have experienced significant price and volume fluctuations over the past several years. These fluctuations often have been unrelated to the operating performance of companies in these markets. Market fluctuations and broad market, economic and industry factors may negatively affect the price of our common stock, regardless of our operating performance. Any volatility or a significant decrease in the market price of our common stock could also negatively affect our ability to make acquisitions using our common stock. Further, if we were to be the object of securities class action litigation as a result of volatility in our common stock price or for other reasons, it could result in substantial costs and diversion of our management’s attention and resources, which could negatively affect our financial results.

Our existing shareholders would experience dilution if we elect to raise equity capital to meet our liquidity needs or finance a strategic transaction.

As part of our strategy we may desire to raise capital and or utilize our common stock to effect strategic business transactions. Either such action will likely require that we issue equity (or debt) securities which would result in dilution to our existing stockholders. Although we will attempt to minimize the dilutive impact of any future capital-raising activities or business transactions, we cannot offer any assurance that we will be able to do so. If we are successful in raising additional working capital, we may have to issue additional shares of our common stock at prices at a discount from the then-current market price of our common stock.

The value of our common stock may decline significantly if we are unable to maintain our NYSE American listing.

Our common stock has sold and may continue to sell at a price per share well below $1.00. The NYSE American rules contain requirements with respect to continued listing standards, which include, among other things, when it appears to the Board of Directors of the Exchange that “the extent of public distribution or the aggregate market value of the security has become so reduced as to make further dealings on the Exchange inadvisable” (Rule 1002). Rule 1003 also provides that the Exchange will not normally consider removing shares from listing where, like Enservco at the present time, “the issuer has at least 1,100,000 shares publicly held, a market value of publicly held shares of at least $15,000,000 and 400 round lot shareholders”.

We believe we are in compliance with NYSE American listing requirements, but there can be no assurance that we will continue to meet those listing requirements in the future. If we fail to meet the requirements, our common stock may be delisted. If our common stock is delisted, we would be forced to list our common stock on the OTC Markets or some other quotation medium, depending on our ability to meet the specific requirements of those quotation systems. In that case, we may lose some or all of our institutional investors, and selling our common stock on the OTC Markets would be more difficult because smaller quantities of shares would likely be bought and sold and transactions could be delayed. These factors could result in lower prices and larger spreads in the bid and ask prices for shares of our common stock. Further, because of the additional regulatory burdens imposed upon broker-dealers with respect to de-listed companies, delisting could discourage broker-dealers from effecting transactions in our stock, further limiting the liquidity of our shares. These factors could have a material adverse effect on the trading price, liquidity, value and marketability of our stock.

Concentration of ownership makes it unlikely that any stockholder will be able to influence the election of directors or engage in a change of control transaction.

Five stockholders directly and indirectly own approximately 50.1% of the Company’s outstanding common stock and have the ability to heavily influence the election of our directors when they again stand for reelection. Furthermore, it is likely that no person seeking control of the Company through stock ownership will be able to succeed in doing so without negotiating an arrangement to do so with these stockholders. For so long as these stockholders continue to own a significant percentage of the outstanding shares of the Company common stock, they will retain such influence over the election of the board of directors and the negotiation of any change of control transaction.

Provisions in our charter documents could prevent or delay a change in control or a takeover.

Provisions in our bylaws provide certain requirements for the nomination of directors which preclude a stockholder from nominating a candidate to stand for election at any annual meeting. As described in Section 2.12 of the Company’s bylaws, nominations must be presented to the Company well in advance of a scheduled annual meeting, and the notification must include specific information as set forth in that section. The Company believes that such a provision provides reasonable notice of the nominees to the board of directors, but it may preclude stockholder nomination at a meeting where the stockholder is not familiar with nomination procedures and, therefore, may prevent or delay a change of control or takeover.

Although the Delaware General Corporation Law includes §112 which provides that bylaws of Delaware corporations may require the corporation to include in its proxy materials one or more nominees submitted by stockholders in addition to individuals nominated by the board of directors, the bylaws of the Company do not so provide. As a result, if any stockholder desires to nominate persons for election to the board of directors, the proponent will have to incur all of the costs normally associated with a proxy contest.

Indemnification of officers and directors may result in unanticipated expenses.

The Delaware General Corporation Law, our Amended and Restated Certificate of Incorporation and bylaws, and indemnification agreements between the Company and certain individuals provide for the indemnification of our directors, officers, employees, and agents, under certain circumstances, against attorney’s fees and other expenses incurred by them in any litigation to which they become a party arising from their association with us or activities on our behalf. We also will bear the expenses of such litigation for any of our directors, officers, employees, or agents, upon such person’s promise to repay them if it is ultimately determined that any such person shall not have been entitled to indemnification. This indemnification policy could result in substantial expenditures by us that we may be unable to recoup and could direct funds away from our business and products (if any).

Because we are a public company filing reports under the Securities Exchange Act of 1934, we are subject to increased regulatory scrutiny and extensive and complex regulation. The Securities and Exchange Commission has the right to review the accuracy and completeness of our reports, press releases, and other public documents. In addition, we are subject to extensive requirements to institute and maintain financial accounting controls and for the accuracy and completeness of our books and records. In addition to regulation by the SEC, we are subject to the NYSE American rules. The NYSE American rules contain requirements with respect to corporate governance, communications with shareholders, and various other matters.

Our operations are subject to cyber-attacks that could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.

Our operations are increasingly dependent on digital technologies and services. We use these technologies for internal purposes, including data storage, processing and transmissions, as well as in our interactions with customers and suppliers. Digital technologies are subject to the risk of cyber-attacks. If our systems for protecting against cybersecurity risks prove not to be sufficient, we could be adversely affected by, among other things: loss of or damage to intellectual property, proprietary or confidential information, or customer, supplier, or employee data; interruption of our business operations; and increased costs required to prevent, respond to, or mitigate cybersecurity attacks. These risks could harm our reputation and our relationships with customers, suppliers, employees and other third parties, and may result in claims against us. These risks could have a material adverse effect on our business, consolidated results of operations and consolidated financial condition.

The following table sets forth real property owned and leased by the Company and its subsidiaries as of December 31, 2018. Unless otherwise indicated, the properties are used in Heat Waves’ operations.

Enservco and Heat Waves were defendants in a civil lawsuit in federal court in Colorado, Civil Action No. 1:15-cv-00983-RBJ (“Colorado Case”), that alleged that Enservco and Heat Waves, in offering and selling frac water heating services, infringed and induced others to infringe two patents owned by Heat-On-The-Fly, LLC (“HOTF”)- i.e., the ‘993 Patent and the ‘875 Patent. In March of 2019, the parties moved to dismiss the Colorado Case. On March 15, 2019, the Colorado Case was dismissed in its entirety without any finding of wrongdoing by Enservco or Heat Waves.

HOTF dismissed its claims with regard to the ‘993 Patent with prejudice and its claims with regard to the ‘875 Patent without prejudice. However, HOTF agreed not to sue Enservco or Heat Waves in the future for infringement of the ‘875 Patent based on the same type of frac water heating services offered by Heat Waves prior to and through March 13, 2019. Heat Waves dismissed its counterclaims against HOTF without prejudice in order to preserve its defenses.

While the Colorado Case was pending, HOTF was issued two additional patents, which were related to the ‘993 and ‘875 Patents, but were not part of the Colorado Case. However, in March of 2015, a North Dakota federal court determined in an unrelated lawsuit (not involving Enservco or Heat Waves) that the ‘993 Patent was invalid. The same court also found that the ‘993 Patent was unenforceable due to inequitable conduct by the patent owner and/or the inventor. The Federal Circuit Court of Appeals later confirmed, among other things, the North Dakota court’s findings of inequitable conduct. In light of the foregoing, Management believes that final findings of invalidity and/or unenforceability of the ‘993 Patent based on inequitable conduct could serve as a basis to affect the validity and/or enforceability of these additional HOTF patents.

ITEM 5. MARKET FOR COMMON EQUITY AND RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Our common stock is traded on the NYSE American under the symbol “ENSV”. The table below sets forth the high and low daily closing sales prices of the Company’s Common Stock during the periods indicated as reported by the New York Stock Exchange for each of the quarters in the years ended December 31, 2018 and 2017, respectively:

The closing sales price of the Company’s common stock as reported on March 15, 2019, was $0.53 per share.

As of March 15, 2019, there were 445 holders of record of Company common stock. This does not include an indeterminate number of persons who hold our Common Stock in brokerage accounts and otherwise in “street name”.

Holders of common stock are entitled to receive such dividends as may be declared by the Company’s Board of Directors. The Company did not declare or pay dividends during its fiscal years ended December 31, 2018 or 2017, and has no plans at present to declare or pay any dividends.

Decisions concerning dividend payments in the future will depend on income and cash requirements. However, in its agreements with East West Bank, our principal lender, the Company represented that it would not pay any cash dividends on its common stock until its obligations to East West Bank are satisfied. Furthermore, to the extent the Company has any earnings, it will likely retain earnings to pay down debt, or expand corporate operations and not use such earnings to pay dividends.

The following is provided with respect to compensation plans (including individual compensation arrangements) under which equity securities are authorized for issuance as of December 31, 2018:

On July 27, 2010, the Company’s Board of Directors adopted the 2010 Stock Incentive Plan (the “2010 Plan”). The 2010 Plan permitted the granting of equity-based awards to our directors, officers, employees, consultants, independent contractors and affiliates. The 2010 Plan was approved by the Company’s stockholders in October 2010 and permitted the issuance of options that qualify as Incentive Stock Options pursuant to Section 422 of the Internal Revenue Code of 1986, as amended (the “Code”).

As discussed below, the 2010 Plan has been replaced by a new stock option plan and no additional stock option grants will be granted under the 2010 Plan. However, as of December 31, 2018, there were options to purchase 834,166 shares which remain outstanding under the 2010 Plan that were awarded prior to the adoption of the 2016 Plan described below.

On July 18, 2016, the Board of Directors unanimously approved the adoption of the Enservco Corporation 2016 Stock Incentive Plan (the “2016 Plan”), which was approved by the stockholders on September 29, 2016. The 2016 Plan is administered by our Board of Directors, which may in turn delegate authority to administer the 2016 Plan to a committee. Our plan administrator may make grants of cash and equity awards under the 2016 Plan to facilitate compliance with Section 162(m) of the Code. Subject to the terms of the 2016 Plan, the plan administrator may determine the recipients, numbers and types of awards to be granted, and the terms and conditions of the awards, including the period of their exercisability and vesting. On November 29, 2017, the Board of Directors established a compensation committee that will administer the 2016 Plan.

The aggregate number of shares of our common stock reserved for issuance under the 2016 Plan will not exceed 10,391,711 shares through September 29, 2026 (the stated life of the 2016 plan). As of December 31, 2018, there were options to purchase 1,710,499 shares outstanding, 926,666 options had been exercised pursuant to the 2016 Plan, and 836,667 Restricted Stock Award shares outstanding under the 2016 Plan.

Unless sooner discontinued or terminated by the Board, the 2016 Plan will expire on September 29, 2026. No awards may be made after that date. However, unless otherwise expressly provided in an applicable award agreement, any award granted under the 2016 Plan prior to expiration extends beyond the expiration of the 2016 Plan through the award’s normal expiration date.

Without the approval of the Company’s stockholders, the Committee will not re-price, adjust or amend the exercise price of any options or the grant price of any SAR previously awarded, whether through amendment, cancellation and replacement grant or any other means, except in connection with a stock dividend or other distribution, including a stock split, merger or other similar corporate transaction or event, in order to prevent dilution or enlargement of the benefits, or potential benefits intended to be provided under the 2016 Plan.

In November 2012, the Company granted each of the principals of its existing investor relations firm a warrant to purchase 112,500 shares of the Company’s common stock (a total of 225,000 shares) for the firm’s part in creating awareness for the Company’s private equity placement, in November 2012, as discussed herein. The warrants were exercisable at $0.55 per share for a five-year term. Each of the warrants may be exercised on a cashless basis. The warrants also provide that subject to various conditions, the holders have piggy-back registration rights with respect to the shares of common stock that may be acquired upon the exercise of the warrants. None of these warrants remain outstanding at December 31, 2018.

In June 2017, in connection with a subordinated loan agreement, the Company granted Cross River Partners, L.P. two five-year warrants to buy an aggregate total of 1,612,902 shares of the Company’s common stock at an exercise price of $0.31 per share, the average closing price of the Company’s common stock for the 20-day period ended May 11, 2017. The warrants had a grant-date fair value of $0.19 per share and vested in full on June 28, 2017. These warrants are accounted for as a liability in the balance sheet included in our financial statements included in Part III of this Annual Report on Form 10-K. On June 29, 2018, all of these warrants were exercised, resulting in the issuance of $1,612,902 shares of the Company's common stock, and resulting in proceeds of approximately $500,000 which were used to repay subordinated debt due to Cross River Partners, L. P.

On November 30, 2017, a principal of the Company’s investor relations firm exercised common stock warrants to purchase 112,500 shares of Common Stock, $0.005 par value, of the Company. The warrants were granted pursuant to an investor relations services agreement between the Company and that firm as partial compensation for that firm’s part in creating awareness for the Company’s private equity placement in November 2012. The warrants were exercisable at $0.55 per share for a five-year term ending on November 30, 2017. Pursuant to the terms of the warrant agreement, the warrants were exercised on a cashless basis and resulted in the issuance of 26,729 shares of common stock to the holder, and no cash proceeds to the Company. There were no underwriters involved in any of the exercise transactions, and the Company paid no commissions or other remuneration as a result of the exercise of the warrants. The holder of the warrant to whom the shares were issued is an existing security holder of the Company and represented to the Company that he is an accredited investor; therefore, the shares were issued in reliance upon the exemptions from registration provided in Section 3(a)(9), and Sections 4(a)(2) and (5) of the Securities Act, as amended, and the rules promulgated thereunder. The transaction was made without any form of advertising or general solicitation, and the holder of the warrant represented to the Company that he intended to acquire the shares for investment purposes only and without a view toward further distribution.

On June 29, 2018, Cross River Partners, L.P. ("Cross River") exercised warrants to acquire 1,612,902 shares of our common stock. Proceeds of $500,000 were used to reduce the principal balance of a subordinated loan held by Cross River. There were no underwriters involved in the transaction and the Company issued the shares to Cross River in reliance on the exemption from registration under the Securities Act of 1933, as amended, as a transaction not involving a public offering under Section 4(a)(2) of that act.

We are a smaller reporting company as defined in Rule 12b-2 of the Exchange Act and are not required to provide the information under this Item.

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

The following discussion provides information regarding our results of operations for the years ended December 31, 2018 and 2017, and our financial condition, liquidity and capital resources as of December 31, 2018 and 2017.

The following discussion and analysis should be read in conjunction with our historical consolidated financial statements and the accompanying notes included elsewhere in this Annual Report on Form 10-K, which contain further detailed information, as well as the Risk Factors and the Cautionary Note Regarding Forward-Looking Statements included above.

The Company, through its subsidiaries, provides the following oil field services to the domestic onshore oil and natural gas industry – (i) frac water heating, hot oiling, pressure testing, and acidizing (well enhancement services) and (ii) water transfer services. The Company owns and operates through its subsidiaries a fleet of more than 450 specialized trucks, trailers, frac tanks and other well-site related equipment and serves customers in several major domestic oil and gas areas including the DJ Basin/Niobrara area in Colorado, the Bakken area in North Dakota, the San Juan Basin in northwestern New Mexico, the Marcellus and Utica Shale areas in Pennsylvania and Ohio, the Jonah area, Green River and Powder River Basins in Wyoming, the Eagle Ford Shale in Texas and the Stack and Scoop plays in the Anadarko Basin in Oklahoma.

In 2018, overall demand for our services increased due to generally stable and modestly improved industry conditions compared to 2017. Our acquisition of Adler in October 2018 enhanced our position for frac water heating and hot oiling services in most of the basins we operate. Relative stability in completion activity, aided by relatively stable oil and gas prices, allowed us to grow relationships with our largest customers by offering bundled services (e.g. frac water heating and water transfer as a combined service), and obtain more commitments from our frac water heating customers through our heating season, and from our water transfer customers for multi-well projects, than we were able to obtain in recent years. During 2018, we also ceased operations of Dillco Fluid Service, Inc. and our Heat Waves location in Kansas, while increasing our presence in the Powder River Basin in eastern Wyoming, due to our outlook for activity levels in each location.

Revenues for 2018 increased $9.9 million, or 27%, over 2017, due to a 23% increase in our core well enhancement revenue. Higher frac water heating revenues in our Rocky Mountain region, improved demand for hot oil services in the Bakken, and continued expansion of hot oiling and acidizing services in the Eagle Ford all contributed to the increase in well enhancement revenues. Water transfer revenues were approximately $2.0 million higher than last year due to continued expansion of services.

Segment profits for 2018 improved by approximately $2.0 million or 27%, to profit of approximately $9.5 million from a profit of approximately $7.4 million in 2017 due to improved results from our well enhancement services and the improved results from our water transfer segment. Selling, general, & administrative expenses, excluding severance and transition costs and acquisition-related expenses, increased by approximately $833,000 for the year ended December 31, 2018, compared to 2017, due primarily to the addition of a formal business development team, in addition to increases in compensation costs and benefits. In 2018, the resignations of officer and the Senior Vice President of Operations resulted in Severance and Transition costs of approximately $633,000. Severance and transition costs related to the resignation of two officers of approximately $784,000 were incurred during 2017. Interest expense for 2018 was essentially flat primarily due to $327,000 of accelerated amortization of debt issuance costs related to reduction in term and extinguishment of the credit facility provided by PNC during 2017, being mostly offset by an increase in borrowing costs due to the higher average borrowing balance, which in turn were incurred in connection with the Adler acquisition.

For the year ended December 31, 2018, the Company recognized a net loss of approximately $5.9 million or ($0.11) per share compared to a net loss of $6.9 million or ($0.14) per share last year primarily due to the increase in higher margin well enhancement revenues, partially offset by increases in Selling, general, and administrative costs.

Adjusted EBITDA for the year ended December 31, 2018 was approximately $4.9 million compared to approximately $3.8 million in 2017. Adjusted EBITDA is a non-GAAP number, and for a reconciliation to GAAP, see "Adjusted EBITDA" below.

During 2018, relatively stable commodity prices and rig activity in North America resulted in modest increases in production and completion activities by our customers, which led to generally stronger demand for our services. While demand and pricing for the services we provide remain below levels we experienced before the industry downturn that began in the last half of 2014, we believe current activity levels should support continued modest improvement in both metrics. The Company has reacted to increases in demand by allocating resources to our most active customers and basins, as we focus on increasing utilization levels and optimizing the deployment of our equipment and workforce, and maintaining a high service quality and safety record. The recent market recovery has also allowed us to compete on the basis of the quality and breadth of our service offerings, as our customers are focused on optimization in production.

The United States rig count bottomed out at approximately 400 in the spring of 2016 and increased to approximately 1,080 as of December 31, 2018 compared to approximately 930 at December 31, 2017, which translated into increased activity for the year ended December 31, 2018, compared to 2017.

Enservco’s reportable business segments are Well Enhancement Services and Water Transfer Services. These segments have been selected based on changes in management’s resource allocation and performance assessment in making decisions regarding the Company.

Well Enhancement Services: This segment utilizes a fleet of frac water heating units, hot oil trucks and acidizing units to provide well enhancement and completion services to the domestic oil and gas industry. These services include frac water heating, hot oil services, pressure testing, pressure pumping, and acidizing services. This segment includes the results of operations of Heat Waves and Adler.

Water Transfer Services: This segment utilizes high and low volume pumps, lay flat hose, aluminum pipe and manifolds and related equipment to move fresh and/or recycled water from a water source such as a pond, lake, river, stream, or water storage facility to frac tanks at drilling locations to be used in connection with well completion activities.

The following tables set forth revenue from operations and segment profits for the Company’s business segments for the fiscal years ended December 31, 2018 and 2017 (amounts in thousands):

For 2018, well enhancement service revenue increased $8.1 million, or 23%, to $42.8 million. The increased demand for services is due to increased demand for services due to improved industry conditions led to increased activity with our customer base.

Frac water heating revenues for the year ended December 31, 2018 increased 48% to $27.3 million compared to $18.4 million in 2017. Improved industry conditions including higher commodity prices and increased drilling rig activity increased demand for our services over 2017. Our acquisition of Adler allowed us to realize revenue from several customers we did not previously perform significant work for, and allowed us to increase services to other customers, particularly in the Bakken and D-J Basin. We experienced increased demand in the Marcellus Shale and Utica Shale locations in Pennsylvania as general industry activity has increased in the region particularly as compared to the 2016-2017 heating season.

Hot oil revenues for the year ended December 31, 2018 increased 5% to $11.7 million compared to $11.1 million in 2017. Our acquisition of Adler provided for increased revenues in the DJ Basin and North Dakota, and we experienced modest growth in hot oil revenues from our operation in south Texas.

Acidizing revenues for the year ended December 31, 2018 decreased 19% to $2.9 million compared to $3.6 million in 2017. The year-over-year decline was primarily driven by a decline in services performed for two customers based on changes in their maintenance programs, particularly in the Green River Basin and in the Eagle Ford Shale. The declines were partially offset by new customer wins and growth in services performed for other customers and in new geographies. The Company continues to pursue customers and partner with chemical suppliers to develop new cost-effective acid programs to continue to expand our acidizing services across our geographies.

Segment profits for our core well enhancement services increased $1.1 million or 13% in 2018 compared to 2017, due to the increases in revenues described above, which was the result of the redeployment of our fleet into our most active basins, along with certain cost reduction initiatives implemented in the second half of 2018. Some of these initiatives included additional costs incurred during 2018, that are not recurring, such as costs associated with the closure of facilities and re-deployment of our productive assets.

In January 2016, the Company acquired approximately $4.3 million of water transfer and water treatment assets, with the intent of launching a new water transfer service line. In 2018, we invested an additional $723,000 to augment and increase our asset base. This service is complementary to our frac water heating service in that the frac water we heat is provided by water transfer and allows bundling of these services with our frac water heating services.

For the year ended December 31, 2018, Water Transfer Services accounted for 9% of total revenue, and increased by $2.0 million or 95%, to $4.2 million, due to (i) adding nine new water transfer customers and (ii) expanding the amount of services performed for our largest customers. We believe the water transfer services segment is an opportunity to grow our business with both new and existing customers and believe it offers opportunity to reduce the level of seasonality we have historically experienced.

Water Transfer segment profits for the year ended December 31, 2018, were approximately $188,000, compared to losses of $538,000 in the year ended December 31, 2017. The Company ceased the marketing and conducting proof of concept studies for the new water treatment technology utilized in devices sold under the name of HydroFLOW. As of January 1, 2018, the Company terminated its agreement with HydroFLOW. During the years ended December 31, 2018 and 2017, the Company recognized minimal revenues related to HydroFLOW products.

Unallocated and other costs include costs which are not specifically allocated to the business segments above including labor, travel, and operating costs for regional managers.

During 2018, unallocated costs decreased 22% to $626,000 compared to $803,000 in 2017, due to a reduction in the number of regional managers employed by the Company.

The Company only does business in the United States, in what it believes are three geographically diverse regions. The following table sets forth revenue from operations for the Company’s three geographic regions during the fiscal years ended December 31, 2018 and 2017 (amounts in thousands):

Well enhancement segment revenues in the Rocky Mountain Region increased $4.1 million or 27% for the year ended December 31, 2018, compared to the prior year due to an increase in activity in the DJ Basin and Bakken area and our acquisition of Adler. Water transfer segment revenues increased $2.0 million or 95% for the year ended December 31, 2018 compared to prior year due to (i) adding nine new water transfer customers and (ii) expanding the amount of services performed for our largest customers.

Well enhancement segment revenues in the Central USA region increased approximately $1.3 million or 14% for the year ended December 31, 2018, compared to the year ended December 31, 2017, primarily due to increased frac heating services performed from our Oklahoma location.

Well enhancement segment revenues in the Eastern USA region increased approximately $2.4 million or 133% for the year ended December 31, 2018, compared to the year ended December 31, 2017 primarily due to increased service work in the Marcellus shale formation due to increased activity levels and colder temperatures in early 2018 as compared to early 2017.

Because of the seasonality of our frac water heating and hot oiling business, revenues generated during the first and fourth quarters of our fiscal year, covering the months during what we call our “heating season,” are significantly higher than revenues earned during the second and third quarters of the year. In addition, the revenue mix of our service offerings also changes among quarters as our Well Enhancement Services (which includes frac water heating and hot oiling) decrease as a percentage of total revenues and Water Transfer Services increase as a percentage of total revenues during the second and third quarters. Thus, the revenues recognized in our quarterly financials in any given period are not indicative of the annual or quarterly revenues through the remainder of that fiscal year.

As an indication of this quarter-to-quarter seasonality, the Company generated revenues of $35.2 million, or 75%, of its 2018 revenues during the first and fourth quarters of 2018 compared to $11.8 million, or 25%, during the second and third quarters of 2018. In 2017, the Company generated revenues of $26.0 million, or 70%, of its 2017 revenues during the first and fourth quarters of 2017 compared to $11.1 million, or 30%, during the second and third quarters of 2017. While the Company is pursuing various strategies to lessen these quarterly fluctuations by expanding and/or adding non-seasonal service lines, there can be no assurance that we will be successful in doing so. As an example, our acquisition of $4.3 million of water transfer and water treatment assets in early 2016 was an effort to mitigate seasonality. Additionally, in an effort to grow our year-round hot oiling revenues, we recently introduced a commission program in an effort to attract and retain experienced hot oil operators, as these operators are able to retain customers in some cases regardless of which company the operator works for.

Direct operating expenses, which include labor costs, propane, fuel, chemicals, truck repairs and maintenance, supplies, insurance, and site overhead costs for our operating segments increased by approximately $8.3 million or 29% during 2018 compared to 2017, primarily due to the overall increase in service activity in our well enhancement service segment as well as our water transfer division.

Sales, general and administrative expenses increased approximately $833,000, or 19%, to $5.2 million in 2018 compared to $4.4 million in 2017 primarily due to (i) the full year costs of our business development team (sales efforts were previously performed by our operations managers, whose compensation costs are included within segment expenses) (ii) approximately $224,000 in professional fees incurred in connection with our acquisition of Adler, and (iii) increases in corporate employee compensation costs year over year.

Patent litigation and defense costs for the year ended December 31, 2018 declined to $80,000 compared to $129,000 for 2017. As discussed in Item 3. – Litigation, the U.S. District Court for the District of Colorado issued a decision on March 15, 2019 this case was dismissed in its entirety without any finding of wrongdoing by Enservco or Heat Waves.

Depreciation and amortization expense for the year ended December 31, 2018 increased approximately $156,000, or 3%, from 2017, primarily due to the acquisition of Adler, partially offset by certain of our equipment becoming fully-depreciated during the year.

During the year ended December 31, 2018, the Company recognized costs of approximately $633,000, related to the departure of a former officer and the former Senior Vice President of Field Operations. The costs incurred primarily consist of payments to the former officer and Senior Vice President of Field Operations, but also include acceleration of stock-based compensation costs. During the year ended December 31, 2017, the Company recognized costs of approximately $784,000, related to the departures of two former officers. The costs incurred were payments to the former officers pursuant to their respective termination agreements and legal and professional costs directly related to the transition to the new management team. In addition, as described above, upon the accelerated vesting of option grants made to one of the former officers, we incurred an incremental $100,000 in stock-based compensation expense.

For the year ended December 31, 2018, the Company recognized a loss from operations of $2.4 million compared to a loss from operations of $3.8 million for 2017. The improvement of $1.4 million was primarily due to a $2.0 million increase in segment profits, partially offset by the increase in Sales, general and administrative expenses discussed above.

Interest expense decreased approximately $33,000 or 1%, from 2017. The extinguishment of our previous senior secured credit facility with PNC during 2017, resulted in accelerated recognition of approximately $327,000 of debt issuance costs during 2017. The increase in our average borrowings along with increased interest rates on our floating rate debt, partially offset the decrease from the accelerated charges.

Loss from discontinued operations decreased approximately $125,000 or 13% from 2017. Loss from discontinued operations for the year ended included an impairment loss on assets held-for-sale of approximately $130,000 partially offset by a gain on disposal of equipment of approximately $129,000.

As of December 31, 2018, the Company had recorded a full valuation allowance on a net deferred tax asset of $2.8 million. Our income tax provision of $1.3 million for the year ended December 31, 2018 reduced the amount of the deferred tax asset and we reduced the valuation allowance by a like amount which resulted in a net tax provision of approximately $32,000. Income tax expense was approximately $32,000 in 2018, compared to a tax benefit of $561,000 in 2017.

Management believes that, for the reasons set forth below, Adjusted EBITDA (even though a non-GAAP measure) is a valuable measurement of the Company's liquidity and performance and is consistent with the measurements offered by other companies in the Company's industry.

The following table presents a reconciliation of net income to Adjusted EBITDA for years ended December 31, 2018 and 2017 (amounts in thousands):

Use of Non-GAAP Financial Measures: Non-GAAP results are presented only as a supplement to the financial statements and for use within management’s discussion and analysis based on U.S. generally accepted accounting principles (GAAP). The non-GAAP financial information is provided to enhance the reader's understanding of the Company’s financial performance, but no non-GAAP measure should be considered in isolation or as a substitute for financial measures calculated in accordance with GAAP. Reconciliations of the most directly comparable GAAP measures to non-GAAP measures are provided herein.

EBITDA is defined as net income (earnings), before interest expense, income taxes, and depreciation and amortization. Adjusted EBITDA excludes stock-based compensation from EBITDA and, when appropriate, other items that management does not utilize in assessing the Company’s ongoing operating performance as set forth in the next paragraph. None of these non-GAAP financial measures are recognized terms under GAAP and do not purport to be an alternative to net income as an indicator of operating performance or any other GAAP measure.

All of the items included in the reconciliation from net income to EBITDA and from EBITDA to Adjusted EBITDA are either (i) non-cash items (e.g., depreciation, amortization of purchased intangibles, stock-based compensation, impairment losses, etc.) or (ii) items that management does not consider to be useful in assessing the Company’s ongoing operating performance (e.g., income taxes, gain or losses on sale of equipment, acquisition-related expenses, patent litigation and defense costs, severance and transition costs, other expense (income), EBITDA related to discontinued operations, etc.). In the case of the non-cash items, management believes that investors can better assess the company’s operating performance if the measures are presented without such items because, unlike cash expenses, these adjustments do not affect the Company’s ability to generate free cash flow or invest in its business.

We use, and we believe investors benefit from the presentation of, EBITDA and Adjusted EBITDA in evaluating our operating performance because it provides us and our investors with an additional tool to compare our operating performance on a consistent basis by removing the impact of certain items that management believes do not directly reflect our core operations. We believe that EBITDA is useful to investors and other external users of our financial statements in evaluating our operating performance because EBITDA is widely used by investors to measure a company’s operating performance without regard to items such as interest expense, taxes, and depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. Additionally, our fixed charge coverage ratio covenant associated with our Loan and Security Agreement with East West Bank require the use of Adjusted EBITDA in specific calculations.

Because not all companies use identical calculations, the Company’s presentation of non-GAAP financial measures may not be comparable to other similarly titled measures of other companies. However, these measures can still be useful in evaluating the Company’s performance against its peer companies because management believes the measures provide users with valuable insight into key components of GAAP financial disclosures.

Adjusted EBITDA from operations improved $1.1 million to $4.9 million for the year ended December 31, 2018 compared to an adjusted EBITDA of $3.8 million for 2017, primarily due to the $2.0 million improvement in segment profit discussed above, partially offset by the increase in sales, general and administrative costs discussed above.

The following table summarizes our statements of cash flows for the years ended December 31, 2018 and 2017 and (combined with the working capital table and discussion below) is important for understanding our liquidity (amounts in thousands):

The following table sets forth a summary of certain aspects of our consolidated balance sheets at December 31, 2018 and 2017 (amounts in thousands):

We have relied on cash flow from operations, borrowings under our revolving credit agreements, and proceeds from equity offerings to satisfy our liquidity needs. Our ability to fund operating cash flow shortfalls, fund capital expenditures, and make acquisitions will depend upon our future operating performance and on the availability of equity and debt financing. At December 31, 2018, we had approximately $257,000 of cash and cash equivalents and approximately $3.0 million available under our asset based senior revolving credit facility. Our capital requirements over the next 12 months are anticipated to include, but are not limited to, operating expenses, debt servicing, and capital expenditures including maintenance of our existing fleet of assets.

As described in more detail Note 7 to our consolidated financial statements included in “Item 8. Financial Statements” of this report, on August 10, 2017, we entered into a Loan and Security Agreement (the “2017 Credit Agreement”) with East West Bank (“East West Bank”) which provides for a three-year $30 million senior secured revolving credit facility (the “New Credit Facility”), that replaced the $30 million senior secured revolving credit Facility (the “Prior Credit Facility”) provided under the Amended and Restated Revolving Credit and Security Agreement (the “2014 Credit Agreement”) with PNC Bank, National Association (“PNC”).

The 2017 Credit Agreement allows us to borrow up to 85% of our eligible receivables and up to 85% of the appraised value of our eligible equipment. We used initial proceeds of approximately $21.8 million to repay all amounts due pursuant to the 2014 Credit Agreement, and pay other closing costs and fees. Upon entering into the 2017 Credit Agreement, we had approximately $4.6 million available under the terms of the agreement.

In connection with the acquisition of Adler Hot Oil Service, LLC, on October 26, 2018 (the "Adler Acquisition"), Enservco and East West Bank entered into a Second Amendment to Loan and Security Agreement and Consent (the “Second Amendment to LSA”), which amended the 2017 Credit Agreement. Pursuant to the Second Amendment to LSA, East West Bank consented to the Adler Acquisition and increased the maximum borrowing limit of the senior secured revolving credit facility provided to Enservco under the Loan Agreement to $37.0 million. Proceeds of $6.2 million from the increased senior secured revolving credit facility were used in the Adler Acquisition to make the cash payments at closing and retire the indebtedness of Adler. In connection with the Second Amendment to LSA the capital expenditure limitation contained within the Loan Agreement was increased to $3.0 million from $2.5 million.

On October 26, 2018, in connection with the Second Amendment to LSA, Adler entered into a Joinder Agreement, pursuant to which Adler was joined as a party to the Loan Agreement.

On March 31, 2017, our largest shareholder, Cross River Partners, L.P., posted a letter of credit in the amount of $1.5 million in accordance with the terms of the Tenth Amendment to the 2014 Credit Agreement that was subsequently converted into subordinated debt with a maturity date of June 28, 2022 with a stated interest rate of 10% per annum and a five-year warrant to purchase 967,741 shares of our common stock at an exercise price of $0.31 per share. On May 10, 2017, Cross River Partners, L.P. also provided $1.0 million in subordinated debt to us as required under the terms of our Tenth Amendment to the 2014 Credit Agreement. In connection with this issuance of subordinated debt, Cross River Partners L.P. was granted a five-year warrant to purchase 645,161 shares of our common stock at an exercise price of $0.31 per share. On June 29, 2018, Cross River Partners, L. P. exercised warrants for 1,612,902 shares, and we used proceeds from the exercise of the warrants described above, to repay $500,000 due under the subordinated debt.

As of December 31, 2018, we had an outstanding principal loan balance under the 2017 Credit Agreement of approximately $33.9 million with weighted-average interest rates of 6.02% per year for the $33.0 million of outstanding LIBOR Rate borrowings and 7.25% per year for the $883,000 of outstanding prime rate borrowings.

The 2017 Credit Agreement has certain customary financial covenants and consisted of the following as of December 31, 2018, as described below:

As of December 31, 2018, our available liquidity was $3.3 million, which was substantially comprised of $3.0 million of availability on the New Credit Facility (subject to a covenant requirement that we maintain $1.5 million of available liquidity in periods where our fixed charge coverage ratio is less than 1.2:1) and $257,000 in cash. We utilize the New Credit Facility to fund working capital requirements and investments, and during the year ended December 31, 2018, we received net cash proceeds from our various lines of credit of approximately $6.8 million, and additionally received $141,000 in non-cash proceeds to fund expenses related to the notes.

On August 10, 2017, an initial advance of $21.8 million was made under the New Credit Facility to repay in full all obligations outstanding under the Prior Credit Facility and fees and expenses incurred in connection with the termination of the 2014 Credit Agreement and the origination of the 2017 Credit Agreement. Upon entering the 2017 Credit Agreement and repaying all amounts due pursuant to the 2014 Credit Agreement, we had availability of approximately $4.6 million under the New Credit Facility.

The Company incurred substantial losses for the years ended December 31, 2018 and 2017 of approximately $5.9 million and $6.9 million, respectively. During 2017, we experienced negative cash flows from operations. While we expect that recent positive industry trends and our focus on increasing the utilization of our assets will allow us to improve our GAAP operating income and cash flows from operations, there is no assurance that we will not continue to incur losses from operations and our liquidity will be negatively impacted as a result.

As of December 31, 2018, we had working capital of approximately $6.1 million compared to working capital of $8.0 million as of December 31, 2017. The decrease in working capital was primarily attributable to the short term note payable to the seller of Adler, partially offset by a decrease in our other current liabilities as of December 31, 2018, compared to December 31, 2017.

As of December 31, 2018, the Company had recorded a valuation allowance to reduce its net deferred tax assets to zero.

Cash provided by operating activities for the year ended December 31, 2018 increased approximately $5.3 million to $1.3 million compared to cash used in operating activities of $4.0 million during 2017, primarily due to (i) the increase in cash provided by the monetization of accounts receivable during the year ended December 31, 2018 compared to 2017, and (ii) the decrease in Loss Before Tax Expense (Benefit) related to improved operating results.

Cash used in investing activities for the year ended December 31, 2018 was $7.3 million compared to $1.3 million during 2017. The increase is primarily attributable to the acquisition of Adler, as described in more detail Note 4 to our financial statements included in “Item 8. Financial Statements” of this report. Other investing activities include investments in water transfer equipment and investments to extend the useful lives of our operating assets, and certain new equipment purchases (primarily within the Water Transfer division). During 2017, the cash used primarily comprised investments made to extend the useful lives of our operating assets and for assets acquired pursuant to our agreement with HydroFLOW.

Cash provided by financing activities for year ended December 31, 2018 was $5.8 million compared to $5.1 million for the year ended 2017. During the year ended December 31, 2018, we received proceeds from our revolving credit facility to fund the acquisition of Adler. This increase was partially offset by the Company making higher total payments to its revolving credit facility than during the comparable period in 2017, due to increased receipts from our higher accounts receivable balance at the beginning of 2018 compared to the beginning of 2017.

We believe that the current oil and gas environment provides us an opportunity to increase our cash flows through the increased utilization of our asset base, due to industry dynamics and our increased focus on redeploying our assets into areas where our services are in higher demand. We have seen an increase in such demand due to the increase and relative stability in oil and natural gas commodity prices from 2016 lows, and increases in the level of production and development activities across the industry. Our generally improved financial results in 2018 and 2017 reflect our successful operational execution in response to this increased demand, and we are optimistic about the prospects for 2019 and beyond. Our long-term goals include driving increased utilization of our assets, the optimized deployment of our fleet, and the right-sizing of our balance sheet by paying down debt. We continue to seek opportunities to expand our business operations through organic growth, including increasing the volume and scope of current services offered to our new and existing customers. We may identify additional services to offer to our customer base, and make related investments as capital and market conditions permits. We will continue to explore adding high margin services that, diversify and expand our customer relationships while maintaining an appropriate balance between recurring maintenance work and drilling and completion related services.

The Company’s capital obligations as of December 31, 2018 consists primarily of scheduled principal payments under certain term loans and operating leases. We repaid all amounts due under the 2014 Credit Agreement using proceeds from the 2017 Credit Agreement during 2017. We do not have any scheduled principal payments under the 2017 Credit Agreement until August 10, 2020, however, the Company may need to make future principal payments based upon collateral availability. General terms and conditions for amounts due under these commitments and obligations are summarized in the notes to the financial statements.

The Company has no significant off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that are material to our stockholders.

The preparation of financial statements in conformity with U.S. generally accepted accounting principles requires management to make a variety of estimates and assumptions that affect (i) the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements, and (ii) the reported amounts of revenues and expenses during the reporting periods covered by the financial statements.

Our management routinely makes judgments and estimates about the effect of matters that are inherently uncertain. As the number of variables and assumptions affecting the future resolution of the uncertainties increase, these judgments become even more subjective and complex. Although we believe that our estimates and assumptions are reasonable, actual results may differ significantly from these estimates. Changes in estimates and assumptions based upon actual results may have a material impact on our results of operation and/or financial condition. Our significant accounting policies are disclosed in Note 2 in the Notes to Consolidated Financial Statements included in Item 8 of this Form 10-K.

While all of the significant accounting estimates are important to the Company’s financial statements, the following accounting policies and the estimates derived there from have been identified as being critical.

Accounts receivable are stated at the amounts billed to customers, net of an allowance for uncollectible accounts. The Company provides an allowance for uncollectable accounts based on a review of outstanding receivables, historical collection information and existing economic conditions. The allowance for uncollectible amounts is continually reviewed and adjusted to maintain the allowance at a level considered adequate to cover future losses. The allowance is management's best estimate of uncollectible amounts and is determined based on historical collection experience related to accounts receivable coupled with a review of the current status of existing receivables. The losses ultimately incurred could differ materially in the near term from the amounts estimated in determining the allowance.

The Company reviews its long-lived assets, including property and equipment, for impairment whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recovered. The Company looks primarily to the discounted future cash flows in its assessment of whether or not long-lived assets have been impaired. The Company recorded an impairment charge, included in discontinued operations, of $130,000 related to land and building sold subsequent to December 31, 2018.

The Company recognizes deferred tax liabilities and assets based on the differences between the tax basis of assets and liabilities and their reported amounts in the financial statements that will result in taxable or deductible amounts in future years. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities will be recognized in income in the period that includes the enactment date. Deferred income taxes are classified as a net current or non-current asset or liability based on the classification of the related asset or liability for financial reporting purposes. A deferred tax asset or liability that is not related to an asset or liability for financial reporting is classified according to the expected reversal date. The Company records a valuation allowance to reduce deferred tax assets to an amount that it believes is more likely than not expected to be realized.

The Company accounts for any uncertainty in income taxes by recognizing the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The Company measures the tax benefits recognized in the financial statements from such a position based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution. The application of income tax law is inherently complex. Laws and regulations in this area are voluminous and are often ambiguous. As such, the Company is required to make many subjective assumptions and judgments regarding income tax exposures. Interpretations of and guidance surrounding income tax law and regulations change over time and may result in changes to the Company’s subjective assumptions and judgments which can materially affect amounts recognized in the consolidated balance sheets and consolidated statements of income. The result of the reassessment of the Company’s tax positions did not have an impact on the consolidated financial statements.

Interest and penalties associated with tax positions are recorded in the period assessed as income tax expense. The Company files income tax returns in the United States and in the states in which it conducts its business operations. The Company’s United States federal income tax filings for tax years 2014 through 2018 remain open to examination. In general, the Company’s various state tax filings remain open for tax years 2014 to 2018.

We utilize the purchase method to account for acquisitions of businesses and assets. The value of the purchase consideration takes into account the degree to which the consideration is objective and measurable such as cash consideration paid to a seller. Pursuant to purchase method accounting, we allocate the cost of the acquisition to assets acquired and liabilities assumed based on fair values as of the acquisition date. The purchase price allocations are based on appraisals, discounted cash flows, quoted market prices and estimates by management.

In estimating the fair values of assets acquired and liabilities assumed, we make various assumptions. The most significant assumptions relate to the estimated fair values assigned to intangible assets. To estimate the fair values of these assets, we employed the income, market, or a cost approach, as appropriate. The income valuation method represents the present value of future cash flows over the life of the asset using: (i) discrete financial forecasts, which rely on management’s estimates of volumes, commodity prices, revenue and operating expenses; (ii) long-term growth rates; and (iii) appropriate discount rates. The market valuation method uses prices paid for a reasonably similar asset by other purchasers in the market, with adjustments relating to any differences between the assets. The cost valuation method is based on the replacement cost of a comparable asset at prices at the time of the acquisition reduced for depreciation of the asset.

We are a smaller reporting company as defined in Rule 12b-2 of the Exchange Act and are not required to provide the information under this Item.

We have audited the accompanying consolidated balance sheet of Enservco Corporation (the “Company”) as of December 31, 2018, the related consolidated statement of operations, stockholders' equity, and cash flows for the year then ended, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2018, and the results of its operations and its cash flows for the year ended December 31, 2018, in conformity with accounting principles generally accepted in the United States of America.

The Company's management is responsible for these financial statements. Our responsibility is to express an opinion on the Company’s financial statements based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit, we are required to obtain an understanding of internal control over financial reporting, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audit included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audit provide a reasonable basis for our opinion.

We have audited the accompanying consolidated balance sheet of Enservco Corporation (the “Company”) as of December 31, 2017, and the related consolidated statement of operations, stockholders’ equity, and cash flows, for the year ended December 31, 2017, and the related notes (collectively referred to as the “financial statements”).

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2017, and the results of its operations and its cash flows for the year ended December 31, 2017, in conformity with accounting principles generally accepted in the United States of America.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud.

Note 2 - Summary of Significant Accounting Policies

Cash and Cash Equivalents

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company continually monitors its positions with, and the credit quality of, the financial institutions with which it invests. Enservco maintains its excess cash in various financial institutions, where deposits may exceed federally insured amounts at times.

Accounts Receivable

Concentrations

As of December 31, 2018, no single customer comprised more than 10% of the Company's accounts receivable balance. Revenues from one customer represented approximately 10% of total revenues for the year ended December 31, 2018. As of December 31, 2017, one customer comprised more than 10% of the Company’s accounts receivable balance; at approximately 12%. Revenues from this customer represented approximately 9% of total revenues for the year ended December 31, 2017. In addition, there was one other customer which represented more than 10% of total revenue for the year at approximately 15% for the year ended December 31, 2017.

Inventories

Inventory consists primarily of propane, diesel fuel and chemicals that are used in the servicing of oil wells and is carried at the lower of cost or net realizable value in accordance with the first in, first out method (FIFO). The Company periodically reviews the value of items in inventory and provides write-downs or write-offs, of inventory based on its assessment of market conditions. Write-downs and write-offs are charged to cost of goods sold. During the years ended December 31, 2018 and 2017, the Company did not recognize any write-downs or write-offs of inventory.

Property and Equipment

Property and equipment consists of (1) trucks, trailers and pickups; (2) water transfer pumps, pipe, lay flat hose, trailers, and other support equipment; (3) real property which includes land and buildings used for office and shop facilities and wells used for the disposal of water; and (4) other equipment such as tools used for maintaining and repairing vehicles, office furniture and fixtures, and computer equipment. Property and equipment is stated at cost less accumulated depreciation. The Company capitalizes interest on certain qualifying assets that are undergoing activities to prepare them for their intended use. Interest costs incurred during the fabrication period are capitalized and amortized over the life of the assets. The Company charges repairs and maintenance against income when incurred and capitalizes renewals and betterments, which extend the remaining useful life, expand the capacity or efficiency of the assets. Depreciation is recorded on a straight-line basis over estimated useful lives of 5 to 30 years.

Any difference between net book value of the property and equipment and the proceeds of an assets’ sale or settlement of an insurance claim is recorded as a gain or loss in the Company’s earnings.

Leases

The Company conducts a major part of its operations from leased facilities. Each of these leases is accounted for as an operating lease. Normally, the Company records rental expense on its operating leases over the lease term as it becomes payable. If rental payments are not made on a straight-line basis, per terms of the agreement, the Company records a deferred rent expense and recognizes the rental expense on a straight-line basis throughout the lease term. The majority of the Company’s facility leases contain renewal clauses and expire through April 2024. In most cases, management expects that in the normal course of business, leases will be renewed or replaced by other leases. As of December 31, 2018, and 2017, the Company had a deferred rent liability of approximately $64,000 and $96,000, respectively.

The Company amortizes leasehold improvements over the shorter of the life of the lease or the life of the improvements. During the years ended December 31, 2018 and 2017, the Company recognized amortization for leasehold improvements of approximately $33,000 and $39,000.

The Company has leased trucks and equipment in the normal course of business, which were recorded as operating leases. The Company recorded rental expense on equipment under operating leases over the lease term as it becomes payable; there were no rent escalation terms associated with these equipment leases. There are no significant equipment leases outstanding as of December 31, 2018 and 2017.

Long-Lived Assets

The Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recovered. The Company reviews both qualitative and quantitative aspects of the business during the analysis of impairment. During the quantitative review, the Company reviews the undiscounted future cash flows in its assessment of whether or not long-lived assets have been impaired. The Company recorded an impairment charge, included in discontinued operations, of $130,000 related to land and building sold subsequent to December 31, 2018.

Goodwill and Other Intangible Assets

Goodwill represents the excess purchase price over the fair value of identifiable assets received attributable to business acquisitions and combinations. Goodwill and other intangible assets are measured for impairment at least annually and/or whenever events and circumstances arise that indicate impairment may exist, such as a significant adverse change in the business climate. In assessing the value of goodwill, assets and liabilities are assigned to the reporting units and the appropriate valuation methodologies are used to determine fair value at the reporting unit level. Identified intangible assets are amortized using the straight-line method over their estimated useful lives.

Revenue Recognition

As described below, we adopted Accounting Standards Update 2014-09, Revenue - Revenue from Contracts with Customers, Accounting Standards Codification ("ASC") Topic 606, beginning January 1, 2018, using the modified retrospective approach, which we have applied to contracts within the scope of the standard. There was no material impact on the Company's condensed consolidated financial statements from adoption of this new standard. The Company evaluates revenue when we can identify the contract with the customer, the performance obligations in the contract, the transaction price, and we are certain that the performance obligations have been met. Revenue is recognized when the service has been provided to the customer. The vast majority of the Company's services and product offerings are short-term in nature. The time between invoicing and when payment is due under these arrangements is generally 30 to 60 days. Revenue is not generated from contractual arrangements that include multiple performance obligations.

The Company’s agreements with its customers are often referred to as “price sheets” and sometimes provide pricing for multiple services. However, these agreements generally do not authorize the performance of specific services or provide for guaranteed throughput amounts. As customers are free to choose which services, if any, to use based on the Company’s price sheet, the Company prices its separate services on the basis of their standalone selling prices. Customer agreements generally do not provide for performance, cancellation, termination, or refund type provisions. Services based on price sheets with customers are generally performed under separately issued “work orders” or “field tickets” as services are requested.

Revenue is recognized for certain projects that take more than one day projects over time based on the number of days during the reporting period and the agreed upon price as work progresses on each project.

Earnings (Loss) Per Share

Earnings (loss) per share is computed by dividing net income (loss) by the weighted average number of common shares outstanding for the period. Diluted earnings per share is calculated by dividing net income (loss) by the diluted weighted average number of common shares. The diluted weighted average number of common shares is computed using the treasury stock method for common stock that may be issued for outstanding stock options and warrants.

As of December 31, 2018, and 2017, there were outstanding stock options and warrants to acquire an aggregate of 2,574,665 and 6,457,335 shares of Company common stock, respectively, which have a potentially dilutive impact on earnings per share. For the years ended December 31, 2018 and 2017, the Company incurred losses of approximately $5.8 million and $6.9 million, respectively. As of December 31, 2018, the aggregate intrinsic value of outstanding stock options and warrants was approximately $93,000. Dilution is not permitted if there are net losses during the period. As such, the Company does not show diluted earnings per share for the years ended December 31, 2018 and 2017.

Loan Fees and Other Deferred Costs

In the normal course of business, the Company enters into loan agreements and amendments thereto with its primary lending institutions. The majority of these lending agreements and amendments require origination fees and other fees in the course of executing the agreements. For all costs associated with the execution of the lending agreements, the Company recognizes these as capitalized costs and amortizes these costs over the remaining term of the loan agreement. All other costs not associated with the execution of the loan agreements are expensed as incurred. As of December 31, 2018, we had approximately $208,000 in unamortized loan fees and other deferred costs associated with the 2017 Credit Agreement, which we expect to charge to expense ratably over the three-year term of that agreement.

Derivative Instruments

From time to time, the Company has interest rate swap agreements in place to hedge against changes in interest rates. The fair value of the Company’s derivative instruments are reflected as assets or liabilities on the balance sheet. The accounting for changes in the fair value of a derivative instrument depends on the intended use of the derivative instrument and the resulting designation. Transactions related to the Company’s derivative instruments accounted for as hedges are classified in the same category as the item hedged in the consolidated statement of cash flows. The Company did not hold derivative instruments at December 31, 2018 or 2017, for trading purposes.

On February 23, 2018, we entered into an interest rate swap agreement with East West Bank in order to hedge against the variability in cash flows from future interest payments related to the 2017 Credit Agreement. The terms of the interest rate swap agreement included an initial notional amount of $10.0 million, a fixed payment rate of 2.52% paid by us and a floating payment rate equal to LIBOR paid by East West Bank. The purpose of the swap agreement is to adjust the interest rate profile of our debt obligations. The fair value of the interest rate swap agreement is recorded in Other Assets and changes to the fair value are recorded to Other Income (Expense).

On September 17, 2015, we entered into an interest rate swap agreement with PNC in order to hedge against the variability in cash flows from future interest payments related to the 2014 Credit Agreement. The terms of the interest rate swap agreement included an initial notional amount of $10.0 million, a fixed payment rate of 1.88% plus applicable a margin ranging from 4.50% to 5.50% paid by us and a floating payment rate equal to LIBOR plus applicable margin of 4.50% to 5.50% paid by PNC. The purpose of the swap agreement was to adjust the interest rate profile of our debt obligations and to achieve a targeted mix of floating and fixed rate debt.

In connection with the termination of the 2014 Credit Agreement, on August 10, 2017, we terminated the interest rate swap agreement with PNC. Changes in the fair value of the interest rate swap agreement were recorded in earnings. The Company was not party to any derivative instruments as of December 31, 2017.

Income Taxes

The Company recognizes deferred tax liabilities and assets (Note 9) based on the differences between the tax basis of assets and liabilities and their reported amounts in the consolidated financial statements that will result in taxable or deductible amounts in future years. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities will be recognized in income in the period that includes the enactment date. Deferred income taxes are classified as non-current asset or liability based on the classification of the related asset or liability for financial reporting purposes. A deferred tax asset or liability that is not related to an asset or liability for financial reporting is classified according to the expected reversal date. The Company records a valuation allowance to reduce deferred tax assets to an amount that it believes is more likely than not expected to be realized.

The Company accounts for any uncertainty in income taxes by recognizing the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The Company measures the tax benefits recognized in the financial statements from such a position based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution. The application of income tax law is inherently complex. Laws and regulations in this area are voluminous and are often ambiguous. As such, the Company is required to make many subjective assumptions and judgments regarding income tax exposures. Interpretations of and guidance surrounding income tax law and regulations change over time and may result in changes to the Company’s subjective assumptions and judgments which can materially affect amounts recognized in the consolidated balance sheets and consolidated statements of income. The result of the reassessment of the Company’s tax positions did not have an impact on the consolidated financial statements.

Interest and penalties associated with tax positions are recorded in the period assessed as Other expense. The Company files income tax returns in the United States and in the states in which it conducts its business operations. The Company’s United States federal income tax filings for tax years 2014 through 2018 remain open to examination. In general, the Company’s various state tax filings remain open for tax years 2014 to 2018.

Fair Value

The Company follows authoritative guidance that applies to all financial assets and liabilities required to be measured and reported on a fair value basis. The Company also applies the guidance to non-financial assets and liabilities measured at fair value on a nonrecurring basis, including non-competition agreements and goodwill. The guidance defines fair value as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The guidance establishes a hierarchy for inputs used in measuring fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used when available.

Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in pricing the asset or liability based on the best information available in the circumstances. Beginning in 2017, the Company valued its warrants using the Binomial Lattice model ("Lattice"). The Company did not have any transfers between hierarchy levels during the year ended December 31, 2018. The financial and nonfinancial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement.

The hierarchy is broken down into three levels based on the reliability of the inputs as follows:

Level 1:

Quoted prices are available in active markets for identical assets or liabilities;

Level 2:

Quoted prices in active markets for similar assets and liabilities that are observable for the asset or liability; or

Level 3:

Unobservable pricing inputs that are generally less observable from objective sources, such as discounted cash flow models or valuations.

Stock-based Compensation

Stock-based compensation cost is measured at the date of grant, based on the calculated fair value of the award as described below, and is recognized over the requisite service period, which is generally the vesting period of the equity grant.

The Company uses the Black-Scholes pricing model as a method for determining the estimated grant date fair value for all stock options awarded to employees, independent contractors, officers, and directors. The expected term of the options is based upon evaluation of historical and expected exercise behavior. The risk-free interest rate is based upon U.S. Treasury rates at the date of grant with maturity dates approximately equal to the expected life of the grant. Volatility is determined upon historical volatility of our stock and adjusted if future volatility is expected to vary from historical experience. The dividend yield is assumed to be none as we have not paid dividends nor do we anticipate paying any dividends in the foreseeable future.

The Company uses a Lattice model to determine the fair value of certain warrants. The expected term used was the remaining contractual term. Expected volatility is based upon historical volatility over a term consistent with the remaining term. The risk-free interest rate is derived from the yield on zero-coupon U.S. government securities with a remaining term equal to the contractual term of the warrants. The dividend yield is assumed to be zero.

The Company used the market-value of Company stock to determine the fair value of the performance-based restricted stock awarded in 2018. The fair-value is updated quarterly based on actual forfeitures.

The Company used a Monte Carlo simulation program to determine the fair value of market-based restricted stock awarded in 2018.

Management Estimates

The preparation of the Company’s consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include the realization of accounts receivable, evaluation of impairment of long-lived assets, stock-based compensation expense, income tax provision, the valuation of deferred taxes, and the valuation of warrant liability and the Company’s interest rate swap. Actual results could differ from those estimates.

Reclassifications

Certain prior-period amounts have been reclassified for comparative purposes to conform to the fiscal 2018 presentation. These reclassifications, primarily related to discontinued operations, have no effect on the Company’s consolidated statement of operations.

Business Combinations

We recognize and measure the assets acquired and liabilities assumed in a business combination based on their estimated fair values at the acquisition date, with any remaining difference recorded as goodwill or gain from a bargain purchase. For material acquisitions, management typically engages an independent valuation specialist to assist with the determination of fair value of the assets acquired, liabilities assumed, noncontrolling interest, if any, and goodwill, based on recognized business valuation methodologies. If the initial accounting for the business combination is incomplete by the end of the reporting period in which the acquisition occurs, an estimate will be recorded. Subsequent to the acquisition, and not later than one year from the acquisition date, we will record any material adjustments to the initial estimate based on new information obtained about facts and circumstances that existed as of the acquisition date. An income, market or cost valuation method may be utilized to estimate the fair value of the assets acquired, liabilities assumed, and noncontrolling interest, if any, in a business combination. The income valuation method represents the present value of future cash flows over the life of the asset using: (i) discrete financial forecasts, which rely on management’s estimates of volumes, commodity prices, revenue and operating expenses; (ii) long-term growth rates; and (iii) appropriate discount rates. The market valuation method uses prices paid for a reasonably similar asset by other purchasers in the market, with adjustments relating to any differences between the assets. The cost valuation method is based on the replacement cost of a comparable asset at prices at the time of the acquisition reduced for depreciation of the asset. See Note 4 – Business Combinations for additional information regarding our business combinations.

Accounting Pronouncements

Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board ("FASB") issued ASU 2016-02 “Leases (Topic 842)”, which requires a lessee to record a right-of-use asset and a lease liability on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the income statement. The new standard is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Either a modified retrospective transition approach for lessees for capital and operating leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements, or a modified retrospective transition method recognizing the cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption is required. We will adopt the New Lease standard and subsequent amendments effective January 1, 2019 under the modified retrospective approach for all active contracts as of December 31, 2018. Based upon our implementation progress to date, we expect the adoption of the New Lease Standard to result in increases to total assets and total liabilities of approximately $2.2 million at January 1, 2019, with no adjustment to the opening balance of accumulated deficit.

Recently Adopted

In May 2014, the FASB issued new revenue recognition guidance under Accounting Standards Update ("ASU") 2014-09 that superseded the existing revenue recognition guidance under GAAP. The new standard focuses on creating a single source of revenue guidance for revenue arising from contracts with customers for all industries. The objective of the new standard is for companies to recognize revenue when it transfers the promised goods or services to its customers at an amount that represents what the company expects to be entitled to in exchange for those goods or services. In July 2015, the FASB deferred the effective date by one year (ASU 2015-14). This ASU is now effective for annual periods, and interim periods within those annual periods, beginning on or after December 15, 2017. Since the issuance of the original standard, the FASB has issued several other subsequent updates including the following: 1) clarification of the implementation guidance on principal versus agent considerations (ASU 2016-08); 2) further guidance on identifying performance obligations in a contract as well as clarifications on the licensing implementation guidance (ASU 2016-10); 3) rescission of several SEC Staff Announcements that are codified in Topic 605 (ASU 2016-11); and 4) additional guidance and practical expedients in response to identified implementation issues (ASU 2016-12). The Company adopted the new guidance effective January 1, 2018 using the modified retrospective approach, which recognizes the cumulative effect of application recognized on that date. The adoption of this standard had no impact on our consolidated financial statements; however, our footnote disclosure was expanded.

In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and Cash Payments (a consensus of the FASB Emerging Issues Task Force) (ASU 2016-15)”, that clarifies how entities should classify certain cash receipts and cash payments on the statement of cash flows. The guidance also clarifies how the predominance principle should be applied when cash receipts and cash payments have aspects of more than one class of cash flows. The guidance is effective for annual periods beginning after December 15, 2017 and interim periods within those annual periods. Early adoption is permitted. The Company adopted the new guidance effective on January 1, 2018 using a retrospective transition method to each period presented. The adoption of ASU 2016-15 did not result in any impact to the presentation of our statement of cash flows.

In January 2017, the FASB issued ASU 2017-01, "Business Combinations (Topic 805): Clarifying the Definition of a Business," that clarifies the definition of a business. This ASU provides a screen to determine whether a group of assets constitutes a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business. This screen reduces the number of transactions that need to be further evaluated as acquisitions. If the screen is not met, this ASU (1) requires that to be considered a business, a set must include, at a minimum, an input and a substantive process that together significantly contribute to the ability to create an output and (2) removes the evaluation of whether a market participant could replace missing elements. Although outputs are not required for a set to be a business, outputs generally are a key element of a business; therefore, the FASB has developed more stringent criteria for sets without outputs. We adopted this ASU in the first quarter of 2018 and the adoption of this ASU did not have a material impact on the consolidated financial statements.

In May 2017, the FASB issued ASU 2017-09, "Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting," which provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. The Company adopted this ASU on January 1, 2018, and the adoption did not have a material impact on the Company’s consolidated financial statements.

Note 4 – Business Combinations

Acquisition of Adler Hot Oil Service, LLC

On October 26, 2018, Enservco Corporation entered into a Membership Interest Purchase Agreement (the “Agreement”) with Adler Hot Oil Holdings, LLC, a Delaware limited liability company (the “Seller”), pursuant to which Enservco acquired all of the outstanding membership interests of Adler Hot Oil Service, LLC, a Delaware limited liability company (“Adler”) for a gross aggregate purchase price of $12.5 million, plus approximately $500,000 in working capital adjustments (the “Transaction”). The purchase price allocation differs from the gross aggregate purchase price due to fair value adjustments to the indemnity holdback, earnout, plus the discount on the subordinated note. Certain former members of Adler are also parties to the Agreement. Adler is a provider of frac water heating and hot oiling services, whose assets consist primarily of vehicles and equipment, with a complementary base of customers in several oil and gas producing basins where Enservco operates.

The consideration paid or to be paid by Enservco under the Agreement includes: (i) $3.7 million in cash paid to or for the benefit of the Seller at the closing; (ii) a subordinated promissory note issued to the Seller in the principal amount of $4.8 million, plus interest accrued thereon (the “Seller Subordinated Note”), as further discussed below; (iii) retirement by Enservco of $2.5 million in indebtedness of Adler; (iv) an earn-out payment of up to $1.0 million in cash payable to the Seller, the actual amount of which is subject to Enservco’s satisfaction of certain EBITDA-related performance conditions during 2019; and (v) $1.0 million in cash held by Enservco and payable to the Seller on the 18 month anniversary of October 26, 2018, subject to offset by Enservco for any indemnification obligations owed by the Seller or certain former members of Adler under the Agreement.

The acquisition of Adler qualified as a business combination and as such, we estimated the fair value of the assets acquired and liabilities assumed as of the closing date. The fair value measure of the assets acquired and liabilities assumed applied various valuation methods to estimate the value of the intangibles that would provide a fair and reasonable value to a market participant, in view of the facts available at the time. Each valuation method was analyzed to determine which method would generate the most reasonable estimate of value of the Company’s intangible assets as of October 26, 2018. Both internal and external factors influencing the value of the intangibles were considered such as Adler’s financial position, results of operations, historical financial data, future financial expectations, economic conditions, status of the oil and gas industry and Adler’s position in the industry.

The goodwill of approximately $245,000 arising from the acquisition consists largely of the expected synergies expected be achieved from combining the operations of Enservco and Adler. None of the goodwill is expected to be deductible for income tax purposes.

Our Consolidated Statements of Operations include approximately $3.2 million in revenues, and approximately $371,000 in income before taxes. We expensed approximately $224,000 of transaction and due diligence costs related to the acquisition of Adler that are included in Sales, general, and administrative expenses in the accompanying Consolidated Statements of Operations.

The following tables represent the consideration paid to the Seller and the estimated fair value of the assets acquired and liabilities assumed.

Consideration paid to Seller:
Cash consideration, including payment to retire Adler debt	$	6,206
Subordinated note, net of discount		4,580
Indemnity holdback at fair value		873
Earnout at fair value		44
Net purchase price	$	11,703

Recognized amounts of identifiable assets acquired and liabilities assumed:
Cash	$	43
Accounts receivable, net		1,317
Prepaid expenses and other current assets		239
Property, plant, and equipment		9,664
Intangible assets		1,045
Accounts payable and accrued liabilities		(850	)
Total identifiable net assets		11,458
Goodwill		245
Total identifiable assets acquired	$	11,703

Below are consolidated results of operations for the years ended December 31, 2018 and 2017 as though the acquisition of Adler had been completed on January 1, 2017.

	December 31,			December 31,
	2018			2017

Total Revenues	$	59,442		$	54,071
Loss from continuing operations	$	(5,475	)	$	(4,698	)
Loss per common share - basic and diluted	$	(0.12	)	$	(0.11	)

The pro forma results for the years ended December 31, 2018 and 2017 include adjustments related to the following purchase accounting and acquisition related items:

- Elimination of Adler interest expense.

- Additional interest expense related to long-term debt issued to fund the acquisition.

- Adjustment to depreciation expense based on the adjustment of Adler's Property, plant, and equipment to fair value.

- Adjustment to remove certain professional fees from Adler's expenses.

- Adjustment to remove gain on extinguishment of debt from Adler's results.

Subordinated Note

In connection with the Transaction and pursuant to the terms of the Agreement, on October 26, 2018, Enservco issued to the Seller the Seller Subordinated Note in the original principal amount of $4.8 million, and unpaid amounts thereunder bear simple interest at a rate of 8% per annum. Enservco was required to and made principal payments on November 30, 2018 of $800,000, on February 28, 2019 of $200,000, and on the final maturity date of the Seller Subordinated Note of March 31, 2019 of all remaining outstanding principal and interest. Enservco may prepay the Seller Subordinated Note in whole or in part, without penalty or premium, at any time prior to its maturity date. The Seller Subordinated Note is guaranteed by Enservco’s subsidiaries and secured by a junior security interest in substantially all assets of Enservco and its subsidiaries. The Seller Subordinated Note is subject to a subordination agreement by and among Enservco, the Seller, and East West Bank.

Second Amendment to Loan and Security Agreement and Consent

In connection with the Transaction, on October 26, 2018, Enservco and East West Bank entered into a Second Amendment to Loan and Security Agreement and Consent (the “Second Amendment to LSA”), which amended the Loan and Security Agreement dated August 10, 2017 by and between Enservco and East West Bank (the “Loan Agreement”). Pursuant to the Second Amendment to LSA, East West Bank consented to the Transaction and increased the maximum borrowing limit of the senior secured revolving credit facility provided to Enservco under the Loan Agreement to $37.0 million. Proceeds of $6.2 million from the increased senior secured revolving credit facility were used in the Transaction to make the cash payments at closing and retire the indebtedness of Adler. In connection with the Second Amendment to LSA the capital expenditure limitation contained within the Loan Agreement was increased to $3.0 million from $2.5 million.

On October 26, 2018, in connection with the Second Amendment to LSA, Adler entered into a Joinder Agreement, pursuant to which Adler was joined as a party to the Loan Agreement.

Note 7 – Debt

East West Bank Revolving Credit Facility

On August 10, 2017, we entered into the 2017 Credit Agreement with East West Bank which provides for a three-year $30 million senior secured revolving credit facility (the "New Credit Facility"). The 2017 Credit Agreement allows us to borrow up to 85% of our eligible receivables and up to 85% of the appraised value of our eligible equipment. Under the 2017 Credit Agreement, there are no required principal payments until maturity and we have the option to pay variable interest rate based on (i) 1-month LIBOR plus a margin of 3.5% or (ii) interest at the Wall Street Journal prime rate plus a margin of 1.75%. Interest is calculated monthly and paid in arrears. Additionally, the New Credit Facility is subject to an unused credit line fee of 0.5% per annum multiplied by the amount by which total availability exceeds the average monthly balance of the New Credit Facility, payable monthly in arrears. The New Credit Facility is collateralized by substantially all of our assets and subject to financial covenants. The outstanding principal loan balance matures on August 10, 2020. Under the terms of the 2017 Credit Agreement, collateral proceeds will be collected in bank-controlled lockbox accounts and credited to the New Credit Facility within one business day.

As of December 31, 2018, we had an outstanding principal loan balance under the 2017 Credit Agreement of approximately $33.9 million with weighted average interest rates of 6.06% per year for $33.0 million of outstanding LIBOR Rate borrowings and 7.25% per year for the approximately $883,000 of outstanding Prime Rate borrowings. As of December 31, 2018, approximately $3.0 million was available to be drawn under the 2017 Credit Agreement, subject to limitations including the minimum liquidity covenant described below. As of December 31, 2017, we had an outstanding principal loan balance under the 2017 Credit Agreement of approximately $27.1 million with interest rates of 5.06% and 4.88% per year for $24.5 million of outstanding LIBOR Rate borrowings and 6.25% per year for the approximately $2.6 of outstanding Prime Rate borrowings. As of December 31, 2017, approximately $2.1 million was available to be drawn under the 2017 Credit Agreement, subject to limitations including the minimum liquidity covenant described below.

Under to the 2017 Credit Agreement, we are subject to the following financial covenants:

(1) Maintenance of a Fixed Charge Coverage Ratio (“FCCR”) of not less than 1.10 to 1.00 at the end of each month, with a buildup beginning on January 1, 2017, through December 31, 2017, upon which the ratio will be measured on a trailing twelve-month basis;

(2) In periods when the trailing twelve-month FCCR is less than 1.20 to 1.00, we are required to maintain minimum liquidity of $1,500,000 (including excess availability under the 2017 Credit Agreement and balance sheet cash).

On August 10, 2017, an initial advance of approximately $21.8 million was made under the New Credit Facility to repay in full all obligations outstanding under our Prior Credit Facility and fund certain closing costs and fees.

On November 20, 2017, Enservco Corporation (the “Company”) entered into a First Amendment and Waiver (the “Amendment and Waiver”) with respect to the 2017 Credit Agreement, dated November 20, 2017, by and among the Company and East West Bank. Pursuant to the Amendment and Waiver, East West Bank waived an event of default with respect to the Company’s failure to satisfy the minimum fixed charge coverage ratio set forth in the 2017 Credit Agreement for the reporting period ended September 30, 2017, and permitted the Company to forego testing of its fixed charge coverage ratio as of October 31, 2017 and November 30, 2017. In connection with the Amendment and Waiver, the Company agreed to pay East West Bank an amendment fee in the amount of $20,000.

In connection with the acquisition of Adler Hot Oil Service, LLC ("Adler") (See Note 4), on October 26, 2018, Enservco and East West Bank entered into a Second Amendment to Loan and Security Agreement and Consent (the “Second Amendment to LSA”), which amended the Loan and Security Agreement dated August 10, 2017 by and between Enservco and East West Bank (the “Loan Agreement”). Pursuant to the Second Amendment to LSA, East West Bank consented to the Transaction and increased the maximum borrowing limit of the senior secured revolving credit facility provided to Enservco under the Loan Agreement to $37.0 million. Proceeds of $6.2 million from the increased senior secured revolving credit facility were used in the Transaction to make the cash payments at closing and retire the indebtedness of Adler. In connection with the Second Amendment to LSA the capital expenditure limitation contained within the Loan Agreement was increased to $3.0 million from $2.5 million.

On October 26, 2018, in connection with the Second Amendment to LSA, Adler entered into a Joinder Agreement, pursuant to which Adler was joined as a party to the Loan Agreement.

As of December 31, 2018, we were in compliance with all covenants contained in the 2017 Credit Agreement.

2014 PNC Credit Facility

In September 2014, the Company entered into an Amended and Restated Revolving Credit and Security Agreement (the "2014 Credit Agreement") with PNC Bank, National Association ("PNC") which provided for a five-year $30 million senior secured revolving credit facility which replaced a prior revolving credit facility and term loan with PNC that totaled $16 million (the "2012 Credit Agreement"). The 2014 Credit Agreement allowed the Company to borrow up to 85% of eligible receivables and up to 75% of the appraised value of trucks and equipment. Under the 2014 Credit Agreement, there were no required principal payments until maturity and the Company had the option to pay variable interest rate based on (i) 1, 2 or 3-month LIBOR plus an applicable margin ranging from 4.50% to 5.50% for LIBOR Rate Loans or (ii) interest at PNC Base Rate plus an applicable margin of 3.00% to 4.00% for Domestic Rate Loans. Interest was calculated monthly and added to the principal balance of the loan. Additionally, the Company incurred an unused credit line fee of 0.375%. The revolving credit facility was collateralized by substantially all of the Company’s assets and subject to financial covenants. On August 10, 2017 we repaid all amounts due under our Prior Credit Facility with PNC Bank using proceeds from New Credit Facility.

Debt Issuance Costs

We have capitalized certain debt issuance costs incurred in connection with the credit agreements discussed above and these costs are being amortized to interest expense over the term of the facility on a straight-line basis. The long-term portion of debt issuance costs of approximately $208,000 and $232,000 is included in Other Assets in the accompanying condensed consolidated balance sheets for December 31, 2018 and 2017, respectively. During the years ended December 31, 2018 and 2017, the Company amortized approximately $105,000 and $121,000 of these costs to Interest Expense. During the year ended December 31, 2017, the Company expensed unamortized debt issuance costs of $327,000 upon repayment of the Prior Credit Facility.

Notes Payable

Long-term debt consists of the following at years December 31, 2018 and 2017 (in thousands):

	December 31,			December 31,
	2018			2017

Seller Subordinated Note. Interest is at 8%. Matures March 31, 2019	$	4,000		$	-

Subordinated Promissory Note with related party, Interest is at 10%, interest is paid quarterly. Matures June 28, 2022		1,000			1,500

Subordinated Promissory Note with related party, Interest is at 10%, interest is paid quarterly. Matures June 28, 2022		1,000			1,000

Real Estate Loan for our facility in North Dakota, interest at 3.75%, monthly principal and interest payment of $5,255 ending October 3, 2028. Collateralized by land and property purchased with the loan.		258			309

Vehicle loans for three trucks, interest at 8.59%, monthly principal and interest payments of $3,966, matures in August 2021		113			-

Note payable to the seller of Heat Waves. The note was garnished by the Internal Revenue Service (“IRS”) in 2009 and is due on demand; paid in annual installments of $36,000 per agreement with the IRS.		89			125
Total		6,460			2,934
Less debt discount		(167	)		(271	)
Less current portion		(4,149	)		(182	)
Long-term debt, net of current portion	$	2,144		$	2,481

Aggregate maturities of debt, excluding the 2017 Credit Agreement described in Note 5, are as follows (in thousands):

Years Ended December 31,
2019	$	4,149
2020		64
2021		53
2022		2,024
2023		25
Thereafter		145
Total	$	6,460

Note 9 – Income Taxes

The income tax provision (benefit) from operations consists of the following (in thousands):

	December 31,
	2018		2017
Current
Federal	$	-	$	-
State		32		-
Total Current		32		-
Deferred
Federal		-		(499	)
State		-		(62	)
Total Deferred		-		(561	)
Total Income Tax Benefit	$	32	$	(561	)

Reduction of U.S. federal corporate tax rate

On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”). The Tax Act reduces the corporate tax rate to 21 percent, effective January 1, 2018. Consequently, we have recorded a decrease related to deferred tax assets of approximately $585,000, with a corresponding adjustment to deferred income tax benefit for the year ended December 31, 2017. In addition, for tax years beginning after January 1, 2018, net operating losses can offset only 80% of taxable income in any given year. Furthermore, net operating losses can no longer be carried back, they must be carried forward. The 20-year carryforward period has been replaced with an indefinite carryforward period.

A reconciliation of computed income taxes by applying the statutory federal income tax rate of 21% to income (loss) from operations before taxes to the provision (benefit) for income taxes for the years ended December 31, 2018 and 2017 is as follows (in thousands):

	December 31,
	2018			2017

Computed income taxes at 21% for 2018 and 2017, respectively	$	1,047		$	(2,203	)

Increase in income taxes resulting from:
State and local income taxes, net of federal impact		(142	)		(173	)
Change in valuation allowance		1,373			834
Stock-based compensation		(204	)		408
Change in tax rate		-			585
Other		52			(12	)

(Expense) Benefit for income taxes	$	32		$	(561	)

In assessing the realization of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment.

Based upon the level of historical taxable income and projections for future taxable income over the periods in which the deferred tax assets are deductible, management believes a valuation allowance should be recorded to reduce its net deferred tax assets to zero.

We have a requirement of reporting of taxes based on tax positions which meet a more likely than not standard and which are measured at the amount that is more likely than not to be realized. Differences between financial and tax reporting which do not meet this threshold are required to be recorded as unrecognized tax benefits. This standard also provides guidance on the presentation of tax matters and the recognition of potential IRS interest and penalties. As of December 31, 2018 and 2017, the Company does not have an unrecognized tax liability.

The Company has approximately $23.5 million of net operating losses that will begin to expire in the year 2035.

The components of deferred income taxes for the years ended December 31, 2018 and 2017 are as follows (in thousands):

	December 31,
	2018			2017

Deferred tax assets
Reserves and accruals	$	476		$	204
Amortization		(11	)		41
Capital losses and other		1			1
Non-qualified stock option expense		165			164
Loss Carryforwards		5,901			5,116
Total deferred tax assets		6,532			5,526
Valuation allowance		(3,081	)		(1,500	)
Net deferred tax assets		3,451			4,026

Deferred tax liabilities
Depreciation		(3,451	)		(4,026	)
Total deferred tax liabilities		(3,451	)		(4,026	)

Net deferred tax assets (liabilities)	$	-		$	-

The Company uses significant judgment in forming conclusions regarding the recoverability of its deferred tax assets and evaluates all available positive and negative evidence to determine if it is more-likely-than-not that the deferred tax assets will be realized. To the extent recovery does not appear likely, a valuation allowance must be recorded. The Company recorded a valuation allowance of $3.1 million and $1.5 million as of December 31, 2018 and 2017, respectively.

It is possible that the relative weight of positive and negative evidence regarding the realization of deferred tax assets may change, which could result in a material increase or decrease in the Company’s valuation allowance. Such a change could result in a material increase or decrease to income tax expense in the period the assessment was made.

The Company classifies penalty and interest expense related to income tax liabilities as an other expense. The Company did not incur any interest and penalties for the years ended December 31, 2018 and 2017, respectively.

The Company files tax returns in the United States, in various states including Colorado, Kansas, North Dakota, Ohio, Pennsylvania, and Texas. The Company’s United States federal income tax filings for tax years 2014 through 2018 remain open to examination. In general, the Company’s various state tax filings remain open for tax years 2014 to 2018.

Note 11 – Stock Options and Restricted Stock

Stock Option Plans

On July 27, 2010, the Company’s Board of Directors adopted the 2010 Stock Incentive Plan (the “2010 Plan”). The aggregate number of shares of common stock that could be granted under the 2010 Plan was reset at the beginning of each year based on 15% of the number of shares of common stock then outstanding. As such, on January 1, 2016 the number of shares of common stock available under the 2010 Plan was reset to 5,719,069 shares based upon 38,127,129 shares outstanding on that date. Options were typically granted with an exercise price equal to the estimated fair value of the Company's common stock at the date of grant with a vesting schedule of one to three years and a contractual term of 5 years. As discussed below, the 2010 Plan has been replaced by a new stock option plan and no additional stock option grants will be granted under the 2010 Plan. As of December 31, 2018, there were options to purchase 834,166 shares outstanding under the 2010 Plan.

On July 18, 2016, the Board of Directors unanimously approved the adoption of the Enservco Corporation 2016 Stock Incentive Plan (the “2016 Plan”), which was approved by the stockholders on September 29, 2016. The aggregate number of shares of common stock that may be granted under the 2016 Plan is 8,000,000 shares plus authorized and unissued shares from the 2010 Plan totaling 2,391,711 for a total reserve of 10,391,711 shares. As of December 31, 2018, there were options to purchase 1,710,499 shares outstanding under the 2016 Plan.

A summary of the range of assumptions used to value stock options granted for the year ended December 31, 2017 are as follows:

	For the Year Ended December 31,
		2017

Expected volatility		89	-	93%
Risk-free interest rate		1.4	–	1.5%
Dividend yield		-	-	-
Expected term (in years)		3.0	–	3.5

During the year ended December 31, 2018, no stock options were granted. During the year ended December 31, 2018, 1,230,002 options were exercised resulting in the issuance of 663,938 shares. During the year ended December 31, 2017, the Company granted options to acquire 2,971,600 shares of common stock with a weighted-average grant-date fair value of $0.19 per share. During the year ended December 31, 2017, no options were exercised.

The following is a summary of stock option activity for all equity plans for the years ended December 31, 2018 and 2017:

	Shares				Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (Years)		Aggregate Intrinsic Value (in thousands)

Outstanding at January 1, 2017		4,211,168			$	1.09		2.85	$	46
Granted		2,971,600				0.32
Exercised		-				-
Forfeited or Expired		(2,368,334	)	⁽¹⁾		0.90

Outstanding at December 31, 2017		4,814,434			$	0.71		3.46	$	1,007
Granted		-
Exercised		(1,230,002	)			0.44
Forfeited or Expired		(1,039,767	)			0.71
Outstanding at December 31, 2018		2,544,665			$	0.85		2.54	$	93
Vested at December 31, 2018		1,950,832			$	1.00		2.29	$	64
Exercisable at December 31, 2018		1,950,832			$	1.00		2.29	$	64

(1) 1,230,002 options exercised using the cashless option resulted in 663,938 shares of common stock being issued.

The aggregate intrinsic value in the table above represents the total intrinsic value (the difference between the estimated fair value of the Company’s common stock and the exercise price, multiplied by the number of in-the-money options) that would have been received by the option holders had they exercised their options on December 31, 2018.

During the years ended December 31, 2018 and 2017, the Company recognized stock-based compensation costs for stock options of approximately $241,000 and $704,000, respectively, in sales, general and administrative expenses. As of December 31, 2018, the Company expected all outstanding options to vest. Compensation cost is revised if subsequent information indicates that the actual number of options vested due to service is likely to differ from previous estimates.

A summary of the status of non-vested shares underlying the options are presented below:

	Number of Shares			Weighted- Average Grant- Date Fair Value

Non-vested at January 1, 2017		1,659,834		$	0.58
Granted		2,971,600			0.19
Vested		(2,003,167	)		0.43
Forfeited		(96,668	)		0.55
Non-vested at December 31, 2017		2,531,599		$	0.24
Granted		-			-
Vested		(1,284,666	)		0.27
Forfeited		(653,100	)		0.22
Non-vested at December 31, 2018		593,833		$	0.20

As of December 31, 2018, there was approximately $141,000 of total unrecognized compensation costs related to non-vested shares under the qualified stock option plans which will be recognized over the remaining weighted-average period of 0.68 years.

Restricted Stock

Restricted shares issued pursuant to restricted stock awards under the 2016 Stock Plan are restricted as to sale or disposition. These restrictions lapse periodically generally over a period of three years. Restrictions may also lapse for early retirement and other conditions in accordance with our established policies. Upon termination of employment, shares on which restrictions have not lapsed must be returned to us, resulting in restricted stock forfeitures. The fair market value on the date of the grant of the stock with a service condition is amortized and charged to income on a straight-line basis over the requisite service period for the entire award. The fair market value on the date of the grant of the stock with a performance condition shall be accrued and recognized when it becomes probable that the performance condition will be achieved. Restricted shares that contain a market condition are amortized and charged over the life of the award.

During the year ended December 31, 2018, the Company's Board of Director's granted approximately 1.0 million shares of restricted stock to the Company's employees. The awards had an aggregate grant-date fair value of approximately $1.1 million.

A summary of the restricted stock activity is presented below:

	Number of Shares			Weighted Average Grant- Date Fair Value
Restricted shares at January 1, 2018		-			-
Granted		1,042,500			1.07
Vested		(58,333	)		1.11
Forfeited		(147,500	)		0.72
Restricted shares at December 31, 2018		836,667			0.98

During the year ended December 31, 2018, the Company recognized stock-based compensation costs for restricted stock of approximately $153,000 in sales, general, and administrative expenses. Compensation cost is revised if subsequent information indicates that the actual number of restricted stock vested due to service is likely to differ from previous estimates.

Note 12 – Commitments and Contingencies

Operating Leases

As of December 31, 2018, the Company leases facilities under lease commitments that expire through April 2024. All of these facility leases are accounted for as operating leases. Future minimum lease commitments for these facilities and other operating leases are as follows (in thousands):

Year Ended December 31,
2019	$	746
2020		671
2021		477
2022		284
2023		106
Thereafter		36
Total	$	2,320

Rent expense under operating leases for the years ended December 31, 2018 and 2017 were approximately $849,000 and $804,000, respectively.

HydroFLOW Agreement

Pursuant to a Sales Agreement with HydroFLOW USA, HWWM had the exclusive right to sell or rent patented hydropath devices in connection with bacteria deactivation and scale treatment services for treating injection and disposal wells, fracking water and recycled water in the oil and gas industry to HWWM customers in the United States. Pursuant to the sales agreement, HWWM was required to pay 3.5% royalties of its gross revenues on certain rental transactions and, in order to maintain the exclusivity provision under the agreement, the Company was required to purchase approximately $655,000 of equipment per year commencing in 2016 and ending 2025. In November 2016, the Company and HydroFLOW USA agreed to allocate $220,000 of the 2016 commitment to 2017, thereby increasing the minimum purchase requirement for 2017 to $875,000. During the year ended December 31, 2017, the Company completed the purchase of $280,000 of equipment to fulfill its 2016 purchase commitment for exclusivity. During the years ended December 31, 2017 and 2016, the Company did not accrue or pay any royalties to HydroFLOW. The Company negotiated a release of all 2016 and 2017 purchase commitments, while leaving intact the exclusive right to sell or rent the patented hydropath devices through 2017. As of January 9, 2018, the Company terminated its Sales Agreement with HydroFLOW USA.

Self-Insurance

In June 2015, the Company became self-insured under its Employee Group Medical Plan, and currently is responsible to pay the first $50,000 in medical costs per individual participant for claims incurred in the calendar year up to a maximum of approximately $1.8 million per year in the aggregate based on enrollment. The Company had an accrued liability of approximately $60,000 and $102,000 as of December 31, 2018 and December 31, 2017, respectively, for insurance claims that it anticipates paying in the future related to claims that occurred prior to December 31, 2018.

Effective April 1, 2015, the Company had entered into a workers’ compensation and employer’s liability insurance policy with a term through March 31, 2018. Under the terms of the policy, the Company was required to pay premiums in addition to a portion of the cost of any claims made by our employees, up to a maximum of approximately $1.8 million over the term of the policy (an amount that was variable with changes in annualized compensation amounts). As of December 31, 2018, a former employee of ours had an open claim relating to injuries sustained while in the course of employment, and the projected maximum cost of the policy as determined by the insurance carrier included estimated claim costs that have not yet been paid or incurred in connection with the claim. During the year ended December 31, 2017, our insurance carrier formally denied the workers' compensation claim and is moving to close the claim entirely. Per the terms of our insurance policy, through December 31, 2018, we had paid in approximately $1.8 million of the projected maximum plan cost of $1.8 million, and had recorded approximately $1.6 million as expense over the term of the policy. Subsequent to March 31, 2018, additional claims related to incidents that occurred prior to March 31, 2018 were processed pursuant to the agreement, and we recorded approximately $267,000 in additional costs under the plan, reducing the balance of the long-term asset. We recorded the remaining approximately $189,000 in payments made under the policy as a long-term asset, which we expect will either be recorded as expense in future periods, or refunded to us by the insurance carrier, depending on the outcome of the individual claim described above, and the final cost of any additional open claims incurred under the policy. As of December 31, 2018, we believe we have paid all amounts contractually due under the policy. Effective April 1, 2018, we entered into a new workers’ compensation policy with a fixed premium amount determined annually, and therefore are no longer partially self-insured for workers' compensation and employer's liability.

Litigation

Note 13- Segment Reporting

Enservco’s reportable business segments are Well Enhancement Services and Water Transfer Services. These segments have been selected based on management’s resource allocation and performance assessment in making decisions regarding the Company.

The following is a description of the segments.

Water Transfer Services: This segment utilizes a high and low volume pumps, lay flat hose, aluminum pipe and manifolds and related equipment to move fresh and/or recycled water from a water source such as a pond, lake, river, stream, or water storage facility to frac tanks at drilling locations to be used in connection with well completion activities. Also included in this segment are water treatment services whereby the Company uses patented hydropath technology under a sales agreement with HydroFLOW USA to remove bacteria and scale from water.

Unallocated and other includes general overhead expenses and assets associated with managing all reportable operating segments which have not been allocated to a specific segment.

The following table sets forth certain financial information with respect to Enservco’s reportable segments (in thousands):

	Well Enhancement		Water Transfer Services			Unallocated & Other			Total
Year Ended December 31, 2018:
Revenues	$	42,759	$	4,160		$	-		$	46,919
Cost of Revenue		32,852		3,972			626			37,450
Segment Profit	$	9,907	$	188		$	(626	)	$	9,469

Depreciation and Amortization	$	4,848	$	1,118		$	23		$	5,989

Capital Expenditures	$	988	$	724		$	69		$	1,781

Identifiable assets⁽¹⁾	$	41,442	$	3,080		$	427		$	44,949


Year Ended December 31, 2017:
Revenues	$	34,686	$	2,128		$	254		$	37,068
Cost of Revenue		25,902		2,666			1,057			29,625
Segment Profit	$	8,784	$	(538	)	$	(803	)	$	7,443

Depreciation and Amortization	$	4,817	$	985		$	31		$	5,833

Capital Expenditures	$	1,184	$	487		$	6		$	1,677

Identifiable assets⁽¹⁾	$	37,651	$	2,986		$	511		$	41,148

(1)

Identifiable assets is calculated by summing the balances of accounts receivable, net; inventories; property and equipment, net; and other assets.

The following table reconciles the segment profits reported above to the loss from operations reported in the consolidated statements of operations (in thousands):

	December 31,			December 31,
	2018			2017

Segment profit	$	9,469		$	7,443
Selling, general and administrative expense		(5,225	)		(4,392	)
Patent litigation defense costs		(80	)		(129	)
Severance and transition costs		(633	)		(784	)
Gain (loss) from disposal of equipment		108			(62	)
Depreciation and amortization		(5,989	)		(5,833	)
Loss from Operations	$	(2,350	)	$	(3,757	)

Geographic Areas:

	For the Year Ended December 31,
	2018		2017
BY SERVICE LINE AND GEOGRAPHY:
Well Enhancement Services:
Rocky Mountain Region ⁽¹⁾	$	27,582	$	23,514
Central USA Region ⁽²⁾		10,950		9,613
Eastern USA Region⁽³⁾		4,227		1,813
Total Well Enhancement Services		42,759		34,940

Water Transfer Services:
Rocky Mountain Region ⁽¹⁾		4,160		2,128
Central USA Region ⁽²⁾		-		-
Eastern USA Region⁽³⁾		-		-
Total Water Transfer Services		4,160		2,128
Total Revenues	$	46,919	$	37,068

Notes to tables:

(1)

Includes the D-J Basin/Niobrara field (northeastern Colorado and southeastern Wyoming), the San Juan Basin (southeastern Colorado and northeastern New Mexico), the Powder River and Green River Basins (northeastern and southwestern Wyoming), the Bakken area (western North Dakota and eastern Montana).

(2)

Includes the Scoop/Stack Shale in Oklahoma and the Eagle Ford Shale.

(3)

Consists of the southern region of the Marcellus Shale formation (southwestern Pennsylvania and northern West Virginia) and the Utica Shale formation (eastern Ohio).

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in our reports filed or submitted under the 1934 Act is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in our reports filed under the 1934 Act is accumulated and communicated to management, including our principal executive officer and our principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Our management, under the direction of our Chief Executive Officer (who is our principal executive officer), and Chief Financial Officer (who is our principal accounting officer) has evaluated the effectiveness of our disclosure controls and procedures as required by 1934 Act Rule 13a-15(b) as of December 31, 2018 (the end of the period covered by this report). Based on that evaluation, our principal executive officer and our principal accounting officer concluded that these disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed by the Company in the reports that it files or submits under the 1934 Act is accumulated and communicated to management, including the Chief Executive Officer and the Chief Financial Officer, to allow timely decisions regarding required disclosure and are effective to provide reasonable assurance that such information is recorded, processed, summarized and reported within the time periods specified by the SEC’s rules and forms.

The Company, including its Chief Executive Officer and Chief Financial Officer, does not expect that its internal controls and procedures will prevent or detect all error and all fraud. A control system, no matter how well conceived or operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met.

In accordance with Item 308 of SEC Regulation S-K, management is required to provide an annual report regarding internal controls over our financial reporting. This report, which includes management’s assessment of the effectiveness of our internal controls over financial reporting, is found below. Inasmuch as the Company is neither an accelerated filer nor a large accelerated filer, the Company is not obligated to provide an attestation report on the Company’s internal control over financial reporting by the Company’s registered public accounting firm.

Our management is also responsible for establishing and maintaining adequate internal control over financial reporting (“ICFR”) as defined in Rules 13a-15(f) and 15d-15(f) under the 1934 Act. Our ICFR are intended to be designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with U.S. generally accepted accounting principles. Our ICFR are expected to include those policies and procedures that management believes are necessary that:

Management recognizes that there are inherent limitations in the effectiveness of any system of internal control, and accordingly, even effective internal control can provide only reasonable assurance with respect of financial statement preparation and may not prevent or detect misstatements. In addition, effective internal control at a point in time may become ineffective in future periods because of changes in conditions or due to deterioration in the degree of compliance with our established policies and procedures.

As of December 31, 2018, management (with the participation of the Chief Executive Officer and the Chief Financial Officer) conducted an evaluation of the effectiveness of the Company’s ICFR based on the framework set forth in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) and SEC guidance on conducting such assessments by smaller reporting companies and non-accelerated filers. Based on that assessment, management (with the participation of the Chief Executive Officer and the Chief Financial Officer) concluded that, during the period covered by this report, such internal controls and procedures were effective as of December 31, 2018.

The information required by this item will be included under the headings "Board of Directors," "Executive Officers," "Section 16(a) Beneficial Ownership Reporting Compliance," and "Corporate Governance" in our definitive proxy statement for our 2019 Annual Meeting of Stockholders, and such required information is incorporated therein.

The information required by this item will be included under the heading "Compensation of Directors and Executive Officers" in our definitive proxy statement for our 2019 Annual Meeting of Stockholders, and such required information is incorporated herein by reference.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

The information required by this item will be included under the heading "Security Ownership of Certain Beneficial Owners and Management" in our definitive proxy statement for our 2019 Annual Meeting of Stockholders, and such required information is incorporated herein by reference.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

The information required by this item will be included under the heading "Certain Relationships and Related Transactions" in our definitive proxy statement for our 2019 Annual Meeting of Stockholders, and such required information is incorporated herein by reference.

The information required by this item will be included under the heading "Principal Accountant Fees and Services" in our definitive proxy statement for our 2019 Annual Meeting of Stockholders, and such required information is incorporated herein by reference.

In accordance with Section 13 or 15(d) of the Securities Exchange Act 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Each person whose signature appears below constitutes and appoints Ian Dickinson and Dustin Bradford his true and lawful attorneys-in-fact and agents, each acting along, with full power of stead, in any and all capacities, to sign any or all amendments to this annual report on Form 10-K for the year ended December 31, 2018, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, each acting alone, full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises, as fully to all intents and purposes as he might or could do in each acting alone, or his substitute or substitutes, may lawfully do or cause to be done by virtue thereof.

Pursuant to the requirement of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated:

	Delaware		84-0811316
	(State or other jurisdiction of incorporation or organization)		(IRS Employer Identification No.)

	999 18th Street, Suite 1925N Denver, CO		80202
	(Address of principal executive offices)		(Zip Code)

Title of each class	Name of each exchange on which registered
Common stock, $0.005 par value	NYSE American

Large accelerated filer ☐			Accelerated filer ☐
Non-accelerated filer ☐			Smaller reporting company ☒
(Do not check if a smaller reporting company)			Emerging growth company ☐



	PART I
Item 1.	Business	5
Item 1A.	Risk Factors	16
Item 1B.	Unresolved Staff Comments	31
Item 2.	Description of Properties	31
Item 3.	Legal Proceedings	33
Item 4.	Mine Safety Disclosures	33

	PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	34
Item 6.	Selected Financial Data	38
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	38
Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	53
Item 8.	Financial Statements	53
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	89
Item 9A.	Controls and Procedures	89
Item 9B.	Other Information	90

	PART III
Item 10.	Directors, Executive Officers and Corporate Governance	91
Item 11.	Executive Compensation	91
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	91
Item 13.	Certain Relationships and Related Transactions, and Director Independence	91
Item 14.	Principal Accountant Fees and Services	91

	PART IV
Item 15.	Exhibits and Financial Statement Schedules	92
Item 16.	Summary of Form 10-K	94

Name	State of Formation	Ownership	Business
Heat Waves Hot Oil Service LLC (“Heat Waves”)	Colorado	100% by Enservco	Oil and natural gas well services, including logistics and stimulation.

Adler Hot Oil Service, LLC ("Adler")	Delaware	100% by Enservco	Oil and natural gas well services, including logistics and stimulation.

Dillco Fluid Service, Inc. ("Dillco")	Kansas	100% by Enservco	Operations discontinued during 2018.

Heat Waves Water Management LLC (“HWWM”)	Colorado	100% by Enservco	Water Transfer and Water Treatment Services.

HE Services, LLC (“HES”)	Nevada	100% by Heat Waves	No active business operations. Owns construction equipment used by Heat Waves.

	●	Rocky Mountain Region, including eastern Colorado and southern Wyoming (D-J Basin and Niobrara formations), central Wyoming (Powder River and Green River Basins), northwestern New Mexico (San Juan Basin), and western North Dakota and eastern Montana (Bakken area). The Rocky Mountain Region operations are deployed from Heat Waves’ and Adler's operations centers in Killdeer, ND, Williston, ND; Rock Springs, WY, Douglas, WY, and, Platteville, CO.

	●	Eastern USA Region, including the southern region of the Marcellus Shale formation (southwestern Pennsylvania and northern West Virginia) and the Utica Shale formation in eastern Ohio. The Eastern USA Region operations are deployed from Heat Waves’ operations center in Carmichaels, PA.

	●	Central USA Region, including the Texas panhandle, and northwestern Oklahoma, and the Eagle Ford Shale in south Texas. The Central USA Region operations are deployed from operations centers in Okarche, OK; and Jourdanton, TX.

	(2)	To expand its footprint, in early 2010 Heat Waves began providing services in the Marcellus Shale natural gas field in southwestern Pennsylvania and West Virginia, and in September 2011 Heat Waves extended its services into the D-J Basin / Niobrara formation and the Bakken formation through opening new operation centers in southern Wyoming and western North Dakota, respectively. In late 2012 the Company expanded its operations, through its Pennsylvania operation center, into the Utica Shale formation in eastern Ohio. Also, in early 2015 the Company expanded its operations into the Eagle Ford formation through opening a new operations center in southern Texas. In early 2019, the Company expanded operations in the Powder River Basin by opening a new operations center in Douglas, Wyoming.

	(3)	To expand its services, in January 2016, Enservco acquired various water transfer assets for approximately $4.3 million in order to provide water transfer services to its customers in all of its operating areas.

	●	Compensation Committee Charter,
	●	Trading Blackout Policy, and

	■	Personal injury or loss of life,
	■	Damage to or destruction of property, equipment and the environment, and
	■	Suspension of operations by our customers.

	■	Impair our ability to make investments and obtain additional financing for working capital, capital expenditures, acquisitions or other general corporate purposes,

	■	Limit our ability to use operating cash flow in other areas of our business because we must dedicate a substantial portion of these funds to make principal and interest payments on our indebtedness,

	■	Make us more vulnerable to a downturn in our business, our industry or the economy in general as a substantial portion of our operating cash flow will be required to make principal and interest payments on our indebtedness, making it more difficult to react to changes in our business and in industry and market conditions,

	■	Put us at a competitive disadvantage to competitors that have less debt, and

	■	Increase our vulnerability to interest rate increases to the extent that we incur additional variable rate indebtedness.

Location/Description	Approximate Size	Base Rent	Lease Expiration
Platteville, CO ● Shop ● Land	3,200 sq. ft. 1.5 acres	$3,000	Month-to-month
La Salle, CO ● Shop ● Land	6,000 sq. ft. 3.0 acres	$8,000	January 2021
Fort Lupton, CO ● Land	7.0 acres	$4,500	June 2018
Ault, CO ● Shop	4 Bays in shop	$3,120	Month-to-month
Nunn, CO ● Shop ● Land	5.0 acres	$3,500	Month-to-month
Nunn, CO ● Mobile Office ● Storage	400 sq. ft.	$620	Month-to-month
Eaton, CO ● Office	98 sq. ft.	$210	March 2019
Rifle, CO ● Shop ● Land	2 acres	$1,500	Month-to-month
Rock Springs, WY ● Shop ● Land	10,200 sq. ft. 3 acres	$6,500	Month-to-month
Carmichaels, PA ● Shop ● Land	5,000 sq. ft. 12.1 acres	$7,500	April 2022
Jourdanton, TX ● Shop ● Land	5,850 sq. ft. 2.3 acres	$8,150	June 2020
Bryan, TX⁽³⁾ ● Shop ● Land	6,000 sq. ft. 1.6 acres	$5,345	August 2022
Okarche, OK ● Shop ● Land	5,000 sq. ft. 2 acres	$6,000	October 2020
Williston, ND ● Shop ● Office	480 sq. ft. office (20% of facility) 4,760 sq. ft. shop (20% of facility)	$7,000	July 2019
Idaho Falls, ID ● Office	200 sq. ft.	$150	Month-to-month
Vernal, UT ● Office	1,350 sq. ft.	$1,200	Month-to-month
Denver, CO ⁽⁴⁾ ● Corporate offices	7,352 sq. ft.	$15,976	June 2022
Denver, CO ● Corporate offices	4,021 sq. ft.	$7,854	April 2024

	(3)	Company is receiving $5,500 in monthly minimum rent under a sublease agreement for this leased property.
	(4)	Company is receiving approximately $10,900 in monthly minimum rent under a sublease agreement for this leased property.
	Note - All leases have renewal clauses

	2018				2017
	Price Range				Price Range
	High		Low		High		Low
First Quarter	$	1.06	$	0.63	$	0.62	$	0.26
Second Quarter		1.47		0.86		0.47		0.21
Third Quarter		1.23		0.65		0.61		0.28
Fourth Quarter		0.80		0.34		0.77		0.43

	Page

Report of Independent Registered Public Accounting Firm	54

Financial Statements as of December 31, 2018 and 2017:

Consolidated Balance Sheets	56

Consolidated Statements of Operations	57

Consolidated Statement of Stockholders’ Equity	58

Consolidated Statements of Cash Flows	59

Notes to Consolidated Financial Statements	60

	For the Year Ended
	December 31,
	2018			2017

Revenues
Well enhancement services	$	42,759		$	34,686
Water transfer services		4,160			2,128
Other		-			254
Total revenues		46,919			37,068

Expenses
Well enhancement services		32,852			25,902
Water transfer services		3,972			2,666
Functional support and other		626			1,057
Selling, general and administrative expenses		5,225			4,392
Patent litigation and defense costs		80			129
Severance and transition costs		633			784
(Gain) loss on disposal of equipment		(108	)		62
Depreciation and amortization		5,989			5,833
Total operating expenses		49,269			40,825

Loss from operations		(2,350	)		(3,757	)

Other income (expense)
Interest expense		(2,228	)		(2,261	)
Other (expense)		(407	)		(463	)
Total other expense		(2,635	)		(2,724	)

Loss from continuing operations before tax benefit		(4,985	)		(6,481	)
Income tax (expense) benefit		(32	)		561
Loss from continuing operations	$	(5,017	)	$	(5,920	)
Discontinued operations (Note 6)
Loss from operations of discontinued operations (including gain on disposal of $129,000 and loss on impairment of $130,000)		(848	)		(973	)
Income tax benefit		-			-
Loss on discontinued operations		(848	)		(973	)
Net loss	$	(5,865	)	$	(6,893	)

Loss from continuing operations per common share – basic and diluted	$	(0.09	)	$	(0.12	)
Loss from discontinued operations per common share – basic and diluted		(0.02	)		(0.02	)
Net loss per share	$	(0.11	)	$	(0.14	)

Basic weighted average number of common shares outstanding		52,865			51,070

	Common Shares			Common Stock			Additional Paid-in Capital			Accumulated Earnings (Deficit)			Total Stockholders’ Equity

Balance at January 1, 2017		51,068		$	255		$	18,868		$	(4,708	)	$	14,415

Cashless exercise of warrants, net of issuance costs		26			-			-			-			-
Stock-based compensation, net of issuance costs		-			-			703			-			703
Net loss		-			-			-			(6,893	)		(6,893	)

Balance at December 31, 2017		51,094		$	255		$	19,571		$	(11,601	)	$	8,225

Cashless exercise of warrants		1,613			9			1,862			-			1,871
Stock-based compensation, net of issuance costs		-			-			371			-			371
Cashless option exercise		663			3			(3	)		-			-
Restricted share issuance		1,043			5			(5	)		-			-
Restricted share cancellation		(127	)		(1	)		1			-			-
Net loss		-			-			-			(5,865	)		(5,865	)

Balance at December 31, 2018		54,286		$	271		$	21,797		$	(17,466	)	$	4,602

	2019		2020		2021		2022		2023
Customer relationships	$	125	$	125	$	125	$	125	$	104
Intellectual property		80		80		80		80		66
Total intangible asset amortization expense	$	205	$	205	$	205	$	205	$	170

	Fair Value Measurement Using
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Fair Value Measurement
December 31, 2018
Derivative Instrument
Interest rate swap asset	$	-	$	75	$	-	$	75

December 31, 2017
Derivative Instrument
Warrant liability	$	-	$	-	$	831	$	831

	Year Ended December 31,
	2018			2017

Fair value of Level 3 instrument at the beginning of the period		831			-
Issues		-			307
Settlements		(1,371	)		-
Change in fair value of warrant liability		540			524
Fair value of Level 3 instrument at the end of period	$	-		$	831

						Weighted
				Weighted		Average
				Average		Remaining		Aggregate
				Exercise		Contractual		Intrinsic
Warrants	Shares			Price		Life (Years)		Value

Outstanding at January 1, 2017		180,001		$	0.57		1.5	$	2
Issued		1,612,902			0.31		4.5		539
Exercised		(112,500	)		0.55		-		-
Forfeited/Cancelled		(37,500	)		-		-		-
Outstanding at December 31, 2017		1,642,903		$	0.32		4.5	$	539
Issued
Exercised		(1,612,902	)		0.31		-		-
Forfeited/Cancelled		-			-		-		-
Outstanding at December 31, 2018		30,000		$	0.70		2.5	$	-

Exercisable at December 31, 2018		30,000		$	0.70		2.5	$	-

Exhibit No.		Title

3.01		Second Amended and Restated Certificate of Incorporation. ⁽¹⁾
3.02		Certificate of Amendment of Second Amended and Restated Certificate of Incorporation ⁽²⁾
3.03		Amended and Restated Bylaws. ⁽³⁾
10.01		2016 Stock Incentive Plan ⁽⁴⁾
10.02		Employment Agreement between the Company and Ian Dickinson. ⁽⁵⁾
10.03		Employment Agreement between the Company and Dustin Bradford ⁽⁸⁾
10.04		Employment Agreement between the Company and Kevin Kersting ⁽⁹⁾
10.05		Loan and Security Agreement with East West Bank, a California banking corporation.
10.06		Form of Indemnification Agreement. ⁽⁶⁾
10.07		Subordinated Loan Agreement⁽¹⁰⁾
10.08		Subordinated Promissory Note – $1.0 Million⁽¹⁰⁾
10.09		Subordinated Promissory Note – $1.5 Million ⁽¹⁰⁾
10.10		Warrant – 645,161 Shares⁽¹⁰⁾
10.11		Warrant – 967,741 Shares⁽¹⁰⁾
10.12		Executive Severance Agreement dated January 8, 2018, by and between Tucker Franciscus and the Company ⁽¹¹⁾
10.13		Executive Severance Agreement dated April 27, 2018, by and between Austin Peitz and the Company ⁽¹²⁾
10.14		First Amendment to Loan and Security Agreement and Waiver, dated November 20, 2017.⁽¹³⁾
10.15		Second Amendment to Loan and Security Agreement dated October 26, 2018.⁽²⁷⁾
10.16		Amended and Restated Revolving Credit and Security Agreement dated as of September 12, 2014. ⁽¹⁶⁾
10.17		Consent and First Amendment to Amended and Restated Revolving Credit and Security Agreement dated February 27, 2015⁽¹⁷⁾
10.18		Second Amendment to Amended and Restated Revolving Credit and Security Agreement effective March 29, 2015.⁽¹⁸⁾
10.19		Third Amendment to Amended and Restated Revolving Credit and Security Agreement effective July 16, 2015.⁽¹⁹⁾
10.20		Fourth Amendment to Amended and Restated Revolving Credit and Security Agreement and First Amendment to Amended and Restated Pledge Agreement effective October 19, 2015.⁽²⁰⁾
10.21		Fifth Amendment to Amended and Restated Revolving Credit and Security Agreement effective December 31, 2015. ⁽²¹⁾
10.22		Sixth Amendment to Amended and Restated Revolving Credit and Security Agreement dated March 29, 2016.⁽²²⁾
10.23		Seventh Amendment to Amended and Restated Revolving Credit and Security Agreement effective August 10, 2016.⁽²³⁾
10.24		Eighth Amendment to Amended and Restated Revolving Credit and Security Agreement effective October 4, 2016.⁽²⁴⁾
10.25		Ninth Amendment to Amended and Restated Revolving Credit and Security Agreement effective December 31, 2016⁽²⁵⁾
10.26		Underwriting agreement to issue and sell to William Blair & Company, LLC an offer and sale in a firm commitment offering of 11,250,000 common stock shares.⁽²⁶⁾
10.27		Membership Interest Purchase Agreement to purchase Adler Hot Oil Service, LLC. ⁽²⁷⁾
10.28		Seller Subordinated Promissory Note. ⁽²⁷⁾

23.1		Consent of Plante & Moran, PLLC
23.2		Consent of EKS&H LLLP
11.1		Statement of Computation of per share earnings. Filed herewith. (contained in Note 2 to the Consolidated Financial Statements).
14.1		Code of Business Conduct and Ethics Whistleblower Policy. ⁽⁷⁾
21.1		Subsidiaries of Enservco Corporation. Filed herewith.
31.1		Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Principal Executive Officer). Filed herewith.
31.2		Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Principal Financial Officer). Filed herewith.
32.1		Certification pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes- Oxley Act of 2002 (Chief Executive Officer). Filed herewith.
32.2		Certification pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes Oxley Act of 2002 (Chief Financial Officer). Filed herewith.
101.INS		XBRL Instance Document
101.SCH		XBRL Schema Document
101.CAL		XBRL Calculation Linkbase Document
101.LAB		XBRL Label Linkbase Document
101.PRE		XBRL Presentation Linkbase Document
101.DEF		XBRL Definition Linkbase Document

(14)	Incorporated by reference from the Company's Current Report on Form 8-K dated December 12, 2017, and filed on December 18, 2017.
(15)	Incorporated by reference from the Company's Current Report on Form 8-K dated May 5, 2017, and filed on May 11, 2017.
(16)	Incorporated by reference from the Company’s Current Report on Form 8-K dated September 12, 2014, and filed on September 18, 2014.
(17)	Incorporated by reference from the Company’s Current Report on Form 8-K dated February 27, 2015, and filed on March 5, 2015.
(18)	Incorporated by reference from the Company's Form 10-Q for the period ended March 31, 2015, nd filed on May 14, 2015.
(19)	Incorporated by reference from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, and filed on August 14, 2015.
(20)	Incorporated by reference from Exhibit 10.12 to the Company’s Annual Report on Form 10-K dated December 31, 2015 and filed on March 30, 2016.
(21)	Incorporated by reference from the Company’s Current Report on Form 8-K dated January 19, 2016, and filed on January 20, 2016.
(22)	Incorporated by reference from Exhibit 10.14 to the Company’s Annual Report on Form 10-K dated December 31, 2015 and filed on March 30, 2016.
(23)	Incorporated by reference from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, and filed on August 12, 2016.
(24)	Incorporated by reference from the Company’s Current Report on Form 8-K dated September 29, 2016, and filed on October 5, 2016.
(25)	Incorporated by reference from the Company’s Current Report on Form 8-K dated February 3, 2017, and filed February 7, 2017.
(26)	Incorporated by reference from the Company’s Current Report on Form 8-K dated December 2, 2016, and filed on December 7, 2016.
(27)	Incorporated by reference from the Company's Current Report on From 8-K dated October 26, 2018 and filed on November 1, 2018.

Date	Name and Title	Signature

March 28, 2019	Ian Dickinson	/s/ Ian Dickinson
	Chief Executive Officer (principal executive officer)

March 28, 2019	Dustin Bradford	/s/ Dustin Bradford
	Treasurer and Chief Financial Officer (principal financial officer and principal accounting officer)

March 28, 2019	Richard A. Murphy	/s/ Richard A. Murphy
	Chairman of the Board and Director

March 28, 2019	Keith J. Behrens	/s/ Keith J. Behrens
	Director

March 28, 2019	Robert S. Herlin	/s/ Robert S. Herlin
	Director

March 28, 2019	William A. Jolly	/s/ William A. Jolly
	Director

March 28, 2019	Christopher Haymons	/s/ Christopher Haymons
	Director