UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

For the fiscal year ended December 31, 2016

For the fiscal year ended December 31, 2017

For the transition period from _______ to ______

Commission file number:number: 001-36335

ENSERVCO CORPORATION

 (Exact name of registrant as specified in its charter)

RegistrantRegistrant’s’s telephone number: (303) 333-3678

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

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 registrantregistrant 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 registrantregistrant 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 bestbest of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.     ☑

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company, or an emerging growth company. See the definitions of “large“large accelerated filer,” “accelerated filer”filer,” “smaller reporting company,” and “smaller reporting“emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.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☑Yes ☐ No ☑

The aggregate market value of the common stock held by non-affiliates of the Registrant was approximately $13,569,684$12.2 million based upon the closing sale price of the Registrant’sRegistrants Common Stock of $0.62$0.31 as of June 30, 2016,2017, the last trading day of the registrant’sregistrants most recently completed second fiscal quarter. This determination of affiliate status is not necessarily a conclusive determination for other purposes.

As of March 28, 2017,15, 2018, there were 51,067,66051,263,334 shares of the Enservco Corporation’sCorporation’s common stock outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Certain portions of the registrant’sregistrant’s definitive information statement to be filed with the Securities and Exchange Commission pursuant to Regulation 14A not later than 120 days after the registrant's fiscal year ended December 31, 2016,2017, in connection with the registrant’s 20172018 Annual Meeting of Shareholders, are incorporated herein by reference into Part III of this Annual Report on Form 10-K.

CAUTIONARY STATEMENT

TABLE OF CONTENTS

CAUTIONARY STATEMENT

REGARDING FORWARD-LOOKING STATEMENTS

This annual report on Form 10-K contains certain statements that are, or may be deemed to be, “forward-looking“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.

PART I

ITEM 1. BUSINESS

Overview

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); water transfer and water treatment (water transfer services); water hauling, fluid disposal, frac tank rental (water hauling services); and, excavating, grading, and dirt hauling services (construction services). The Company owns and operates a fleet of more than 650630 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 and Austin Chalk in Texas, and the Mississippi Lime and Hugoton field area in Kansas and the Stack and Scoop plays in the Anadarko Basin in Oklahoma.

Enservco was originally incorporatedincorporated 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’sCompany’s executive (or corporate) offices are located at 501 South Cherry St., Ste. 1000, Denver, CO 80246. Our telephone number is (303) 333-3678, and our facsimile number is (720) 974-3417. Our website is www.enservco.com.

Corporate Structure 

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

OnIn November 24, 2015, HWWM was organized under Colorado law as a wholly owned subsidiary of Enservco for the purpose of launching a water transfer service division. Effective January 1, 2016, HWWM acquired various water transfer assets from WET Oil Services, LLC (‘WET”) including vehicles, high and low volume pumps, manifolds, pipe, and other support equipment. In addition, effective January 1, 2016, HWWM acquired water treatment equipment which utilizes technology in devices sold under the name of HydroFLOW and various water transfer assets including high and low volume pumps, lay flat hose, trailers, generators, pipe and other equipment from HII Technologies, Inc. and its affiliates (“HIIT”). The total purchase price for both acquisitions was approximately $4.3 million. HydroFLOW products offer water treatment services based on patented hydropath technology that can remove bacteria and scale from water using electrical induction to reduce or eliminate down-hole scaling and corrosion. HWWM provides water transfer services and water treatment services to the onshore oil and natural gas sector.

Overview of Business Operations

Enservco primarily conducts its business operations through its principal operating subsidiaries (Heat Waves, HWWM, and Dillco), 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 Dillco 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:

As described in this report, the past two fiscalThe years have been very2014 through early 2017 were challenging for us. The decline in drilling, completion and service activities throughout the industry that started in 2014 and continued during most of 2016 due to low oil and natural gas prices combined with warm winter weather in our frac heating markets resulted in a significant drop insignificantly reduced demand for our services in 2015 and 2016. In addition,Positive developments occurred in 2017 as industry conditions improved, with increased and stable commodity prices and an increase in completion and production activities, which we believe had an impact on us beginning with our fourth quarter 2017 results. To fund operations through the downturn and into the recent recovery, we have hadrelied on cash provided by various lenders, including senior lenders pursuant to borrow from our credit facilityfacilities. Our borrowing balance historically peaks early in orderthe first quarter of the year as the increase in our direct variable costs related to fund our operations,frac water heating services are incurred and aspaid. During the latter portion of the first quarter and throughout the second quarter we convert the related receivables into cash which we use to reduce our outstanding borrowings.  As of March 28, 2017,15, 2018, we had approximately $25.7 million outstanding on the facility and $4.1 million available under theour revolving credit facility. See“Management’s “Management’s Discussion and Analysis of Financial Condition and Results of Operations”Operations” for further information.

Subject to overcoming our significant cash needs and increasing our operating results which will likely require significant price increases inAs the domestic onshore oil and natural gas industry continues the current recovery, the Company expects to continue to pursue its growth strategies by increasing utilization of  its existing fleet of equipment, increasing the volume and scope of current services offered to our new and existing customers, exploring additional acquisitions potentiallyrelating to existing or complimentary service lines as capital and market conditions permit, expanding the geographic areas in which it operates, and diversifying the products and services it provides to customers, as well as making further investments in adding to its current assets and equipment.

Operating Entities

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

Dillco. From its inception in 1974, Dillco has focused primarily on providing water hauling/disposal/storage services, well site construction services and frac tank rental to energy companies working in the Hugoton gas field in southwestern Kansas and northwestern Oklahoma. Water hauling and disposal services have been the primary sources of Dillco’s revenue. Dillco currently owns and operates a fleet of water hauling trucks and related assets, including specialized tank trucks, frac tanks, water disposal wells, construction and other related equipment. These assets transport, store and dispose of both fresh and salt water, as well as provide well site construction and maintenance services.

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’Waves’ operations are currently in the major oil and natural gas areas in Colorado, Kansas, Texas,Montana, North Dakota, Ohio, Oklahoma, Wyoming, Colorado, Pennsylvania, Texas, West Virginia, Ohio, North Dakota, and Montana.Wyoming.

HWWM. HWWM was organized in November 2015 as a new wholly owned subsidiary of Enservco for the purpose of launching a new water management division. In connection therewith, HWWM acquired approximately $4.3 million of water management assets from HIIT and WET in January 2016.

HWWM provides water transfer services, bacteria and scaling treatment solutions,solutions, 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. In addition to providing traditional water transfer services, HWWM also utilizesutilized a patented hydropath technology (distributed under the name of HydroFLOW) to provide bacteria and scaling treatment services to the oil and gas industry. HydroFLOW utilizes electrical induction to reduce or eliminate down-hole scaling and corrosion and to reduce or eliminate bacteria in water. The hydropath technology is owned by HydroPath Holdings Limited. Pursuant to a Sales Agreement with the North American master distributor, HydroFLOW U.S.A., HWWM hashad the exclusive right to sell or rent HydroFLOW 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 customers in the United States (except in Texas where the right regarding injection and disposal wells is exclusive to only 20 companies but non-exclusive for the remaining companies in Texas). We believe thisHydroFLOW has a potentially lower-cost and environmentally friendly alternative to conventional chemical treatment of frac and recycled water willwhich could significantly reduce the use, and therefore cost, of chemicals now used by oil and gas companies.companies; however, in 2017 demand for the technology did not support our previous purchase commitments to HydroFLOW. Therefore, as of January 1, 2018, HWWM terminated its agreement with HydroFLOW.

Areas of Operations

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

Business Segments

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.

Well Enhancement Services

The Company’sCompany’s well enhancement services consist of frac water heating, acidizing, hot oiling services, and pressure testing. These services are provided primarily by Heat Waves which, currently utilizesas of December 31, 2017 utilized a fleet of approximately 198240 custom designed trucks and other related equipment. Heat Waves’ operations are currently in southwestern Kansas, northwestern Oklahoma, Texas panhandle, southern 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)Shale and Austin Chalk). Well enhancement services accounted for approximately 73%85% and 85%73% of the Company’s total revenues for fiscal years ended December 31, 2017 and 2016, and 2015, respectively.

FracWaterHeating – 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, 2017, Heat Waves currently ownsowned and operatesoperated a fleet 53fleet of 52 frac heaters (or the equivalent of 81 burner80 burner boxes) 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, 2017, Heat Waves currently ownsowned and operatesoperated a fleet of 7 acidizing units 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 thesethis paraffin builds up depends on the chemical character of the crude oil or natural gas being produced. This isThese 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.

Hot oil servicing also includesincludes the heating of oil storage tanks. The heating of storage tanks is done (1)(i) to eliminate frozen water and other soluble waste in the tank for which the operator’s revenue is reduced at the refinery; and (2)(ii) because heated oil flows more efficiently from the tanks to transports taking oil to the refineries in colder weather.

As of December 31, 2016,2017, Heat Waves ownsowned and operatesoperated a fleet of 5657 hot oil trucks. Based on customer needs and seasonal conditions, these vehicles are deployed among the serviceservice regions as necessary in seeking to maximize their productive time.

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 TransferServices

Water transfer services consistconsists primarily of water transfer services and water treatment services. These services commenced in first quarter of 2016 with revenue being generated in the fourth quarter of 2016 after acquisition of water transfer assets from WET and HIIT in January 2016.Water transfer services accounted for approximately 5% and 1% of the Company’s total revenues for fiscal 2016.2017 and 2016, respectively.

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 Treatment Services – The Company uses patented hydropath technology under a sales agreement with HydroFLOW USA to remove bacteria and scale from water. The process uses electrical induction to reduce or eliminate down-hole scaling and corrosion in an environmentally friendly manner.

Water Hauling Services

Water hauling services include water hauling, salt water disposal, and frac tank rental services. These services are primarily provided by Dillco to customers in the Hugoton gas field in western Kansas and northwestern Oklahoma.Water hauling services accounted for approximately 16%9% and 15%16% of the Company’s total revenues for fiscal 20162017 and 2015,2016, respectively.

Water Hauling – The As of December 31, 2017, the Company currently ownsowned or leases,leased, and operatesoperated approximately 6567 water hauling trucks and trailers equipped with pumps to move water from/to wells, tanks and other storage facilities. A majority of the Company’s trucks consist of transports with a hauling capacity of up to 130 barrels (each barrel being equal to 42 U.S. gallons). The trucks are used to:

Most wells produce residual salt or fresh water in conjunction with the extraction of the oil or natural gas. The Company’sCompany’s trucks pick up water at the well site and transport it to a disposal well for injection or to other environmentally sound surface recycling facilities. This is regular maintenance work that is performed on a periodic basis depending on the volume of water a well produces.

Typically, the Company and a customer enter into a contract for water hauling services after that customer has completed a competitive bidding process. However, inIn these instances, we are our customers' "first call" for services, and work is performed for the customer based on agreed-upon rates and actual work performed. In other certain instances, customers with requirements for minor or incidental water hauling services usually purchase the services on a “call out” basis and charged according to a published schedule of rates. The Company competes for services on both on a call out and contractual basis.

Disposal Well Services –The Company owns four disposal wells in Kansas and Oklahoma that allow for the injection of salt water and incidental non-hazardous oil and natural gas wastes. These wells are used exclusively by the Company for its customers.

Our trucks frequently transport fluids to be disposed of into these disposal wells. These wells areare located in proximity to our customers’ producing wells. Most oil and natural gas wells produce varying amounts of water throughout their productive lives. In the states in which we operate, oil and natural gas wastes and water produced from oil and natural gas wells are required by law to be disposed of in authorized facilities, including permitted water disposal wells. All of the Company’s disposal wells are licensed by state authorities pursuant to guidelines and regulations of the Environmental Protection Agency and the Safe Drinking Water Act and are completed in an environmentally sound manner in permeable formations below the fresh water table.

Frac Tank Rental –The Company also generates a small amount of revenues from the rental of frac tanks in the Hugoton field area. TheAs of December 31, 2017, the Company currently ownsowned approximately 2026 frac tanks, which can store up to 500 barrels of water and are used by oilfield operators to store fluids at the well site, including fresh water, salt water, and acid for frac jobs, flowback, temporary production and mud storage. Frac tanks are used during all phases of the life of a producing well. The Company generally rents frac tanks at daily rates and charges hourly rates for the transportation of the tanks to and from the well site.

Construction Services

Construction services consist of excavation, grading and dirt hauling services. These services are primarily provided in Colorado to help increase utilization of the Company’sCompany’s equipment and personnel during the slower non-heating months. This segment also utilizes sub-contractors as needed to supplement Company resources. Construction services accounted for approximately 1% and 11% of the Company’s total revenues for fiscal 2016.2017 and 2016, respectively.

Ownership of Company Assets

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 loans and credit facility made tofacilities utilized by the Company.

Historically, as supply and demand requires,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.

CompetitiveCompetitive Business Conditions

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.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 andand 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’sCompany’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 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.

Dependence on One or a Few Major Customers

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

As of December 31, 2016, three customers each2017, a receivable from one customer comprised more than 10% of the Company’s accounts receivable balance; at approximately 14%, 14% and 11%, respectively.. Revenues from these three customersthis customer represented 14%, 11% and 12%8% of total revenues respectively, for the year ended December 31, 2016.2017.

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’sCompany’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.

Seasonality 

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 2017, approximately 69% of revenue was earned during the first and fourth 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 pressurepressure testing are performed throughout the year with higher revenues typically during non-winter months.

Water hauling from producing wells is not as seasonal as our other services since wells produce water whenever they are pumping regardless of weather conditions. Hauling of water for the drilling or fracturing of wells is also not seasonal but dependent on when customers decide to drill or complete wells.

Although they are relatively new businesses to us, we believe water transfer services and bacteria and scaling solutions are not seasonal. However, our water transfer services and to a certain extent our bacteria and scaling solutions, depend upon the level of drilling, well completion, and production activities.

Raw Materials 

             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

The Company enters into agreements with local property owners where its disposal wells are located by which the Company generallygenerally agrees to pay those property owners a fixed amount per month plus a percentage of revenues derived from utilizing those wells. The terms of these agreements are separately negotiated with the giveneach property owner, and during its 20152017 and 2016 fiscal years the total amount paid under these various agreements by the Company was immaterial to the Company and its business operations.

As is the situation with all companies in the frac water heating service business, we rely on certain procedures and practicespractices 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. 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.

Pursuant to a Sales Agreement with HydroFLOW USA (“Sales Agreement”), HWWM hashad 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,wells, frack water and recycled water in the oil and gas industry to customers in the United States.The hydropath technology is owned by HydroPath Holdings Limited. Pursuant to the Sales Agreement, the Company iswas required to pay royalties on certain rental transactions and mustwas required to meet certain annual purchase commitments in order to maintain the exclusivity provision under the Sales Agreement. As of MarchDecember 31, 2017, no royalties havehad been paid under the Sales agreement. As of January 1, 2018, HWWM terminated its agreement and the Company has met its 2016 purchase commitments required to maintain its exclusivity provision.with HydroFLOW USA.

Government Regulation

The Company and its subsidiaries are subject to a variety of government regulations ranging from environmental to OSHA to the Department of Transportation. Our operations are also subject to stringent federal, state and local laws regulating thethe discharge of materials into the environment or otherwise relating to health and safety or the protection of the environment. Thesefederal,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 recent trend in environmental legislation and regulation is generally toward stricter standards, and we expect that this trend will continue as the 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. Strict 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 LiabilityLiability Act (“CERCLA”), also known as “Superfund,” and comparable state statutes imposestrict,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”“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”“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 (Kansas and Oklahoma)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 federalFederal Energy Policy Act of 2005 amended the SDWA to exclude hydraulic fracturing from the definition of “underground“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 is currently conductingconducted a national study examining the potential impacts of hydraulic fracturing on drinking water resources and issued a draftfinal assessment report in June 2015. The EPA has asked the EPA Science Advisory Board (“SAB”) to peer review the draft assessment report.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 thethe 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 restrictrestrict 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 the federal Occupational Safety and Health Act, or OSHA, and comparable state laws, whose purpose is to protect the health and safety of workers. In addition, the OSHA hazardhazard 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’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, Dillco 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.

Employees

As of March 24, 2017,February 28, 2018, the Company employed 204249 full time employees. Of these employees, 140170 are employed by Heat Waves, 3437 by Dillco, 2027 by HWWM, and 1015 are employedemployed by Enservco. From time to time, the Company may hire contractors to perform work.

Available Information

We maintain a website athttp://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 Sections 13(a) and 15(d) of 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:

ITEM 1A. RISK FACTORS

The Company’sCompany’s securities are highly speculative and involve a high degree of risk, including among other items the risk factors described below. The below risk factors are intended to generally describe certain risks that could materially affect the Company and its current business operations and activities.

YouYou 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.

Operations RelatedRelated Risks

Our business may beis materially impacted by seasonal weather conditions.

Our businesses, particularly our frac heating and hot oil services, can beare impacted by weather conditions and temperatures. Unseasonably warm weather during winter months can reducemonths reduces demand for the heating services and resultresults in higher operating costs, as a percentage of revenue, due to the need to retain equipment operators during these low demand periods. The Company has experienced unseasonably warm weather during parts of its heating season during the years ended December 31, 20162017 and 2015,2016, which has impacted well enhancement service revenues and profits. 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 movemove our equipment between locations during periods of heavy snow, ice or rain, and during the spring some areas impose transportation restrictions due to the muddy conditions caused by the spring thaws.

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

We periodically seek to increase the prices of our services to offset rising costs and to generate higher returns for our stockholders. Currently, the prices we are able to charge for our services and the demand for our services are depressed. 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 participate 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 abilityability 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 personnelpersonnel 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 in the labor pool 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 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.

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 exempttax-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, 2016,2017, we had U.S. federal NOLs of approximately $15.7$20.3 million and state NOLs of approximately $14.8$24.5 million.

New U.S. tax legislation could adversely affect us and our shareholders.

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 the Company.

Our business depends on domestic (United States) spending by the crude oil and natural gas industry which has suffered significant negative 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’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, most exploration and production companies shut down or substantially reduced drilling programs and required service providers to make pricing concessions. Over the two years ended December 31, 2016,2017, the Company has 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 conditionsconditions and specifically the market price for crude oil and natural gas are influenced by numerous domestic and global factors over which the Company has 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 merger and divestiture activity among oil and natural gas producers. 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 some of our customers. Where declining prices lead to reduced exploration and development activities in the Company’s market areas, the reduction in exploration and development activities also may have a negative long-term impact on the Company’s business. Continued decline in 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.

There has also been significant political pressures for the United StatesStates 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 the Company’s service areas, particularly in Colorado. These activities may make oil and gas investment andproductionlessand productionless attractive.

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

Ongoing volatility and uncertainty in the domestic and global economic and political environments have caused the oilfield services industry to experience volatility in terms of demand. 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. 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 the Company’s services, the rates we can charge, and equipment utilization. In addition, certain of the Company’s customers could become unable to pay their suppliers, including the Company. Any of these conditions or events could adversely affect our operating results.

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

We dependdepend to a large extent on the services of certain of our executive officers. The loss of the services of Rick Kasch,Ian Dickinson, Austin Peitz, Robert DeversDustin Bradford or other key personnel, could disrupt our operations. Although we have entered or intend to enter into employment agreements with Messrs. Kasch,Dickinson, Peitz and Devers,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,customers, and a loss of one or more significant customers could adversely affect our results of operations. 

The Company’s customers consist primarily of major and independent oil and natural gas companies. During fiscal year 2016, three of the Company’s customers accounted for 37% of consolidated revenues and during fiscal year 2015, two of the Company’s customers accounted for 21% of consolidated revenues. No other customer exceeded 10% of revenues.

The Company’sCompany’s top five customers accounted for approximately 52%43% and 38%52% of its total annual revenues for 20162017 and 2015,2016, 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 the Company’s results of operations.

While the Company believes our equipment could be redeployed in the current market environment if we lost any material customers, such loss could have an adverse effect on the Company’sCompany’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.

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

Beginning in the second half of 2014, oil prices have declined substantially from historical highs. This causedhighs, causing many of our customers to reduce or delay their oil and natural gas exploration and production spending in 2015 and 2016, which consequently hasconsequently reduced their demand for our services, and exerted downward pressure on the prices that we charged for our services and products. Given various domestic and global factors, oil and natural gas prices may remain depressed for the foreseeable future.

Also, under an environment of increasing oil and natural gas prices it 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 reducedreduced 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 the Company of providing those services, has generally increased along with significant increases in oil and natural gas prices. The resulting reduction in cash flows being experienced by our customers during the past months due to the decline inperiods 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 the Company, 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.

The Company uses hazardous substances and transports hazardous wastes in its 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 the Company to incur costs and penalties, or become the basis of new or increased liabilities that could reduce its earnings and cash available for operations. The Company believes it is currently in substantial compliance with environmental laws and regulations.

Intense competitioncompetition 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 the Company. The Company’s larger competitors have greater resources that allow those competitors to compete more effectively than the Company. The Company’s 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.

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

AsAs is the situation with allother 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.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 30, 2017,15, 2018, the U.S. Court of Appeals for the Federal Circuit has not issued a ruling on this case.

In October 2014, the Company was served with a complaint that alleges that EnservcoEnservco 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. The lawsuit is now stayed pending the outcome of the appeal by the Patent Owner of the summary judgment invalidating the Patent Owner’s first patent as set forth above. (See Item 3 –Litigation, for more information about this matter.)

However, if Enservco and/or Heat Waves are found to be infringing, they could be liable for the payment of substantial damages/royalties and attorneys’attorneys’ fees, and/or be subject to a preliminary or permanent injunction prohibiting Heat Waves from heating frac water in a manner it may have been using.

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 the Company.

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 conditionsconditions 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.

The Company maintains insurance coverage that we believe to be customary in the industry against these hazards. In addition, in June 2015, the Company became self-insured under its Employee Group Medical Plan for the first $75,000$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. 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.

WhileWhile our growthgrowth strategy includes appropriateseeking acquisitions weof other oilfield services companies, we may not be successful in identifying, making and integrating businessor assetacquisitions, if any, in the future.

We anticipate that a component of our growth strategy may be to make geographically focusedfocused 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 stock.

In addition to restricted fundingfunding 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.

In January 2016, HWWM, a wholly owned subsidiary of the Company, acquired various assets including the water transfer assets of HIIT and WET for approximatelyapproximately $4.3 million dollars. The Company’s ability to successfully integrate these acquisitions and expand the water transfer and bacteria and scaling solutions services is a going to be challenging given the current industry environment. There can be no assurance that we will successfully integrate these acquisitions and expand these services.million. 

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 could adversely impact our business.

Some states and certain municipalities have regulated, or are considering regulating hydraulic fracturing (“fracking”)fracking which, if accomplished, could impact certain of our operations. While the Company does 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 the Company’s business operations and revenues.

Debt Related Risks

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

As of December 31, 2016,2017, the Company owed approximately $23.8$30.0 million to banks, and financial institutions, and other parties under various collateralized debt.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 instruments.

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 withwith accrued and unpaid interest, the lenders under our credit facility could elect to terminate their commitments there underthere-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 withour principal lender, East West Bank.PNC Bank, National Association.

The Company’sCompany’s agreements with PNCEast West Bank impose various obligations and financial covenants on the Company. The outstanding amount under the Amended and Restated Revolving CreditLoan and Security Agreement, entered into with PNCEast West Bank in September 2014August 2017 and amended various times,in November 2017 is due in full on April 30, 2018.August 2020. The revolving credit agreement with PNCEast 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 agreementsagreements with PNCEast West Bank impose various financial covenants on the Company including maintaining a prescribed fixed charge coverage ratio, maximum leveragea minimum liquidity ratio at certain times, and limit the Company’sCompany's ability to incur additional debt or operating lease obligations. The depressed conditions in the oil and natural gas industry and the resultant reduction in drilling activity in our service areas has made it more difficult to meet our financial covenants.

On March 31, 2017, we entered into the tenth amendment to our 2014 Credit Agreement with PNC. In connection with such amendment, PNC has required us to (among other things) raise $1 million of subordinated debt by May 15, 2017. In addition, the amendment accelerated the maturity date of the loan from September 12, 2019 to April 30, 2018. Thus, beginning in May 2017, the outstanding loan with PNC will be classified as a current liability. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.” Although the Company has obtained waivers of financial covenants or modifications to our credit agreements in the past when we have failed to meet specific provisions (including for various periods in the 2016 fiscal year), theremake capital investments. There can be no assurance that we will be able to obtaincomply with these waivers or modificationscovenants in the future.Iffuture, 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 Company is unable to comply with its obligations and covenantsacceleration of maturities under the 2014 Credit Agreementdefault provisions of our loan and it declares an eventsecurity agreement. As of default,December 31, 2017, we were in compliance with all of its obligations to PNC could become immediately due. In addition, considering our limited financial resources and reduced operating results due to the depressed oil and gas markets, we cannot assure investors that the Company will be successful in extending or replacing the 2014 Credit Agreement on its new maturity date. Failure to extend, replace or repay the loan in full at maturity will likely force us to consider a sale of the Company.covenants.

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

The Company’sCompany’s borrowings through PNCEast West Bank bear interest at variable rates, exposing the Company to interest rate risk. In September 2015,As of December 31, 2017, the Company had not yet entered into an Interest Rate Swap Agreement with a notional balance of $10 million in conjunction with the senior revolving credit facility with PNC bank. The Company has decided nothedging arrangement to hedgeprotect against the interest rate risk associated with the remaining balance of the senior revolving credit facility (with a maximum available balance of $30 million). We may increase, decrease or terminate some or all of these hedging arrangements in the future. Depending on our overall hedging level, our debt service obligations could increase significantly in the event of large increases in interest rates. The Sixth Amendment to our 2014 Credit Agreement with PNC resulted in (among other things) an increase in our variable interest rate by 1.75% for the balance of the term of the agreement.facility. 

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

As of December 31, 2016,2017, we had borrowed approximately $23.2$27.1 million under our senior revolving credit facility and had approximately $4.5$2.1 million of borrowing capacity available under this facility.facility. Although the Company plans to utilize cash flow from operations during the first half of 20172018 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 adverse risks. In particular, a high level of indebtedness may make it more likelylikely 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 a variable rate and increased by 1.75% as a result of the Sixth Amendment. Any furtherrates. An increase in our interest rates (whether by amendment to our 2014 Credit Agreement or as the result of economic conditions) 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 securities. 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.

Risks Related to Our Common Stock

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 PNC,East West Bank, our principal lender that we will not pay any cash dividends on our common stock until our obligations to PNCEast 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 certificatecertificate 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 voting 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,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. Our stockstock 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. 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.

OurOur existing shareholders could experience further 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 capitalcapital 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 MKTAmerican listing.

Our common stock has recently sold and may continue to sell at a price per share well below $1.00. The NYSE MKTAmerican 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 MKTAmerican 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.

General Corporate Risks

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

SevenFive stockholders directly and indirectly own approximately 53.8%47% of the Company’sCompany’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 electionelection 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§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 indemnificationindemnification 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).

We have significant obligations under the 1934 Act and the NYSE MKTAmerican..

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.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 MKTAmerican rules. The NYSE MKTAmerican rules contain requirements with respect to corporate governance, communications with shareholders, and various other matters.

Our operations are subject to cyber-attacks thatcould 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.

Forward-looking statements may prove to be inaccurate.

In our effort to make the information in this report more meaningful, this report contains both historical and forward-looking statements. All statements other than statements of historical fact are forward-looking statements within the meanings of Section 27A of the Securities Act of 1933 and Section 21E of the 1934 Act. Forward-looking statements in this report are not based on historical facts, but rather reflect the current expectations of our management concerning future results and events. We have attempted to qualify our forward-looking statements with appropriate cautionary language to take advantage of the judicially-created doctrine of “bespeaks caution” and other protections.

Forward-looking statements involve known and unknown risks, uncertainties and other factors which may cause our actual results, performance and achievements to be different from any future results, performance and achievements expressed or implied by these statements. These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in the forward-looking statements in this annual report. Other unknown or unpredictable factors also could have material adverse effects on our future results.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None

ITEM 2. DESCRIPTION OF PROPERTIES

The following table sets forth real property owned and leasedleased by the Company and its subsidiaries as of December 31, 2016.2017. Unless otherwise indicated, the properties are used in Heat Waves’ operations.

Owned Properties:

(1) Property is collateral for mortgage debt obligation.

(2) Company is receiving $1,500 monthly under a short-term sublease agreement.Location not currently in operations.

Leased Properties:

Note - All leases have renewal clauses

ITEM 3. LEGAL PROCEEDINGS

Enservco Corporation (“Enservco”("Enservco") and its subsidiary Heat Waves Hot Oil Service LLC (“Heat Waves”) are defendants in a civil lawsuit in federal court in Colorado, Civil Action No. 1:15-cv-00983-RBJ (“Colorado Case”), 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 Heat-On-The-Fly, LLC (“HOTF”)-i.e., U.S. Patent Nos. 8,171,993 (“the ‘993 Patent”) and 8,739,875 (“the ‘875 Patent”). The complaintseeks various remedies including injunctive relief and unspecified damages, and relates to only a portion of Heat Waves’the frac water heating services. In July 2015, the Company and HOTF jointly asked the Colorado Court to stay the case pending any appealservices provided by HOTF of the partial summary judgment ruling invalidating the ‘993 Patent referenced below, and on July 20, 2015, the Court granted the parties’ joint request.Heat Waves. The Colorado caseCase is now stayed pending resolution of an appeal by HOTF of a North Dakota court’s ruling that the primary patent (“the ‘993 Patent”) in the Colorado Case was invalid. Neither Enservco nor Heat Waves is a party to the North Dakota Court’s invalidity ruling, as referenced below.

HOTF is currently involved in another litigation with a group ofCase, which involves other energy companies (which does not include Enservco or Heat Waves) that sought, among other things, to invalidate the ‘993 Patent (“North Dakota Case”). In March 2015, the North Dakota Court granted the energy companies’ partial summary judgment motion, finding that the ‘993 Patent was invalid and later entered a judgment on this issue. In September 2015, a jury trial was conducted. While it did not find that HOTF committed the tort of deceit, the jury found that HOTF represented to a customer of one of the accused energy companies that HOTF had a valid patent and this representation was made in bad faith. The jury also found, among other things, that HOTF unlawfully interfered with a contract and prospective business relationship with that customer and as such, awarded the energy company $750,000 in damages. Lastly, the Court also held a bench trial on the energy companies’ claim that the ‘993 Patent is unenforceable due to inequitable conduct by the inventor of the ‘993 Patent before the U.S. Patent and Trademark Office (“USPTO”). In January 2016, the Court ruled that the ‘993 Patent is unenforceable due to inequitable conduct by the inventor and/or HOTF. In February 2016, HOTF filed an appeal with the U.S. Court of Appeals for the Federal Circuit relating to all adverse judgments and certain related orders in the North Dakota Case. The energy companies also appealed the denial of their attorneys’ fees by the North Dakota Court. Both HOTF and the group of energy companies are in the process of fully briefing all issues and as such, the U.S. Court of Appeals for the Federal Circuit has not yet ruled on the parties’ appeals.companies.

The ‘993 Patent has undergone several reexaminations by the USPTO and in February 2015, the USPTO rejected all 99 claims of the ‘993 Patent in the latest reexamination.  However, in May 2016, the USPTO reversed its decision and confirmed all 99 claims as being patentable over the cited prior art in the reexamination proceeding. Further, in September 2016 and February 2017, HOTF was issued two additional patents, both of which could be asserted against the Company.Enservco and/or Heat Waves. 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 each of HOTF’s patents. If these Patents are ultimately held to be invalid and/or enforceable, the Colorado Case would become moot.

As noted above, the Colorado Case has been stayed. However, in the event that HOTF’sHOTF’s appeal is successful and the ‘993 Patent is found to be valid and/or enforceable in the North Dakota Case, the Colorado Case may resume. To the extent that Enservco and Heat Waves are unsuccessful in their defense of the Colorado Case, they could be liable for enhanced damages and attorneys’ fees (both of which may be significant) and Heat Waves could possibly be enjoined from using any technology that is determined to be infringing. Either result could negatively impact Heat Waves’ business and operations. At this time, the Company is unable to predict the outcome of this case, and accordingly has not recorded an accrual for any potential loss.

ITEM 4.MINE SAFETY DISCLOSURES

Not applicable.

PART II

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

Market Information

Our common stock is traded on the NYSE MKTAmerican under the symbol “ENSV”“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, 2017 and 2016, and 2015, respectively:

The closing sales price of the Company’sCompany’s common stock as reported on March 24, 2017,15, 2018, was $0.38$0.95 per share.

Holders

As of March 24, 2017,15, 2018, there were approximately 450 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”.

Dividends

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, 20162017 or 2015,2016, and has no plans at present to declare or pay any dividends.

Decisions concerning dividend paymentspayments in the future will depend on income and cash requirements. However, in its agreements with PNC,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 PNCEast 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.

Securities Authorized for Issuance Under Equity Compensation Plans

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, 2016:2017: 

Description of the 2010 Stock Incentive Plan:

On July 27, 2010, the Company’sCompany’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 optionoption grants will be granted under the 2010 Plan. However, as of December 31, 2016,2017, there were options to purchase 2,251,1681,467,833 shares which remain outstanding under the 2010 Plan that were awarded prior to the adoption of the 2016 Plan described below.

Description of the 20162016 Stock Incentive Plan:

On July 18, 2016, the Board of Directors unanimously approved the adoption of the Enservco Corporation 2016 Stock Incentive Plan (the “2016“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 Board of Directors has not formed a compensation committee, but should one be formed the Board may delegate the authority to administer the 2016 Plan to the compensation committee. 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 over the next ten years (the stated life of the 2016 plan). As of December 31, 2016,2017, there were options to purchase 1,960,0003,346,600 shares outstanding under the 2016 Plan.

The 2016 PlanPlan permits the granting of:

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’sCompany’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.

OtherStockCompensation Arrangements:

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’sCompany’s common stock (a totaloftotal 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 arewere exercisable at $0.55 per share for a five yearfive-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. A total of 112,500None of these warrants were exercised in 2014 and 112,500 remain outstanding at December 31, 2016.2017.

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. As of December 31, 2017, all of these warrants remain outstanding.

Recent Sales of Unregistered Securities

NoneOn 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.

ITEM 6. SELECTED FINANCIAL DATA

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

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

The following discussion provides information regarding theour results of operations for the years ended December 31, 20162017 and 2015,2016, and our financial condition, liquidity andand capital resources as of December 31, 20162017 and 2015.2016.

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

OVERVIEW

The Company, through its subsidiaries, provides the following oil field services to the domesticdomestic onshore oil and natural gas industry – (i) frac water heating, hot oiling, pressure testing, and acidizing (well enhancement services); (ii) water transfer and waterbacteria and scale treatment services (water transfer services); (iii) waterfreshwater and saltwater hauling, fluid disposal, frac tank rental (water hauling services); and, (iv) dirt excavatingwell site construction and dirt haulingother general oil field services (construction services). The Company owns and operates through its subsidiaries a fleet of more than 650630 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 and Austin Chalk in Texas and the Mississippi Lime and Hugoton areas in Kansas and Oklahoma.

RESULTS OF OPERATIONS

RESULTS OF OPERATIONS

Executive Summary

The past two fiscal years were very challenging for us. The declineSeveral positive developments occurred in drilling, completion and service activities throughout the industry that started in 2014 and continued during most of 2016 due to low oil and natural gas prices combined with warm winter weather in our frac heating markets resulted in a significant drop in2017.  Overall demand for our services increased due to improved industry conditions and cooler temperatures in several of our heating markets compared to 2016.  In addition, we added three major customers that expanded our frac water heating business that helped to offset warm weather in the Marcellus/Utica shale market during 2015the winter of 2016-2017. Also, we continued to grow and expand our water transfer business. We acquired these assets in January 2016 and due to the low crude oil prices in 2016, we were not able to generate any water transfer business until late in the fourth quarter of 2016. As

Revenues for 2017 increased $16.1 million, or 66%, over 2016, due to a result, revenues from94% increase in our core well enhancement revenue.  Higher frac water heating revenues in our Rocky Mountain region, improved demand for hot oil services duringin 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 $1.9 million higher than last year due to continued expansion of services.

Segment profits (losses) for 2017 improved by approximately $7.4 million, to profit of approximately $7.1 million from a loss of approximately $213,000 in 2016 declined $15.0 million or 46% compareddue to 2015. Despite the decline,improved results from our well enhancement segment generated a profit of $2.2 million or 12% of segment revenues for 2016.

In an effort to offset some ofservices and the seasonal decline inresults from our heating related services, the Company launched two new business segments – water transfer servicessegment. General & administrative expenses, excluding severance and construction services. In January 2016, we acquired $4.3 million of water transfer assets from WET and HIIT in an effort to launch a new water transfer service division. Water transfer services are a year-round service that is also complementary to our frac water heating business.    In May 2016, we expanded our construction services segment to provide dirt hauling to the construction industry in an effort to help retain and increase utilization of frac water heating operators during offseason quarters and slow periods. Although the Company made significant strides in getting these business segments up and running during 2016, start-up and carryingtransition costs, from these two segments diluted our fiscal 2016 segment profits, operating income and Adjusted EBITDA.

Although management took various actions to reduce variable operating costs in line with the decrease in revenues and to reduce fixed expenses where possible, the decline in higher margin well enhancement services combined with the incremental start-up costs from our new business segments of increased by approximately $1.7 million resulted in a $10.2 million decline in segment profits during 2016 as compared to last year.

For$679,000 for the year ended December 31, 2017, compared to 2016, due primarily to an increase in personnel costs at the corporate level. Severance and transition costs related to the resignation of the Company’s former President and Chief Executive Officer and Chief Financial Officer of approximately $784,000 were incurred during 2017.  Interest expense for 2017 increased approximately $495,000 from 2016 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, and due to an increase in borrowing costs due to the higher weighted-average interest rate paid on borrowings with PNC and other lenders, partially offset by savings related to the lower interest rate on our new credit facility provided by East West Bank, which we closed on August 10, 2017.

For the year ended December 31, 2017, the Company realizedrecognized a net loss of $8.55approximately $6.9 million or ($0.220.13) per share) asshare compared to a net loss of $1.3$8.6 million or ($0.030.22) per share)share last year primarily due to the decline in revenues and corresponding segment profits described above. In addition, a $1.1 millionaforementioned increase in depreciation and amortization expense attributable to our purchase of water transfer assets also contributed to the increase in net loss in 2016.higher margin well enhancement revenues.

Adjusted EBITDA for the year ended December 31, 20162017 was approximately $3.4 million compared to a negative EBITDA of approximately $3.3 million as compared to $6.3 million in 2015. For further details on the calculation of Adjusted EBITDA see Adjusted EBITDA section below.2016. 

Industry Overview

The low crude oilDuring 2017, improved commodity prices since July 2014 that continued through 2016and an increase in active rigs in North America resulted in an increase in production and completion activities by our customers, significantly scaling back drillingwhich led to an increase in demand for our services. While demand and completion programs, shifting capitalpricing 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 higher margin basins, requiring substantial concessions from vendors, and reducing or delaying certain maintenance related work to preserve capital. Further, the overall reduction in drilling, completion and service work resulted in more service vendors seeking fewer jobs putting even further downward pressure on the pricing of services. Some competitors responded by pricing work at what we believe to be negative margins. Although the Company has been able to partially mitigate the impact of the operating environment by deploying resources to moreour most active customers and basins, as we focus on increasing utilization levels and optimizing the deployment of our revenue growthequipment and operating margins have been significantly negatively impacted by reduced overall demand forworkforce, 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 services, requiring pricing concessions and the delay of hot oiling and acidizing maintenance work.

Manyservice offerings, as our customers implemented capital spending programs at the beginning of 2016 and some customers suspended drilling and completion programs altogether until oil and natural gas prices recover and stabilize at an economical price for continuing operations. In addition, some customers delayed their routine hot oiling and acidizing maintenance work.focus on optimization in production.  

Crude prices and the North American rig count have increased significantly since the low points in February 2016 and May 2016, respectively, signaling that the industry downturn may have hit bottom and begun a market recovery. In the fourth quarter of 2016, the averagerespectively. The United States rig count bottomed out at approximately 400 in the spring of 2016 and increased 23%to approximately 930 as of December 31, 2017, which translated into increased activity for the year ended December 31, 2017, compared to the third quarter, and we started to see a pickup in completion and production maintenance service activity towards the end of the fourth quarter.2016. 

Segment Overview

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

The following is a description of the segments:

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, and acidizing services.

Water TransferServices:   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. Also included in this segment are water treatment services whereby to remove bacteria and scale from water, the Company usesused patented hydropath technology under an agreement with HydroFLOW USA.

Water Hauling Services:    This segment utilizes a fleet of trucks and related assets, including specialized tank trucks, vacuum trailers, storage tanks, and disposal facilities to provide various water hauling services. These services are primarily provided by Dillco in the Hugoton area in Kansas and Oklahoma.

ConstructiConstructionon Services:    This segment utilizes a fleet of trucks and equipment to provide supplementary construction and roustabout services to the oil and gas and construction industry. In 2016, the Company started utilizingused this fleet of equipment to provide dirt hauling services to a general construction contractor in Colorado.Colorado but due to low margins in this segment did not generate meaningful revenue in 2017.

Segment Results:

The following tables set forth revenue from operations and segment profits for the Company’sCompany’s business segments for the fiscal years ended December 31, 2017 and 2016 and 2015:(amounts in thousands):

Well Enhancement Services:

For 2016,2017, well enhancement service revenue declined $15.0increased $16.8 million, or 46%94%, to $17.9$34.7 million. A significant decline inThe increased demand for services is due to improved industry conditions, the addition of three major customers in our frac water heating services due to unseasonably warm weatherbusiness, more normal winter temperatures, and an extended heating season in our two largest frac water heating markets (D-J/Niobrara and Marcellus/Utica) andall contributed to the overall declineincrease in drilling and completions activity related to low oil and natural gas price were the primary reasons for the decline in revenues. These declines were partially offset by $2.3 million of incremental revenues from our geographic expansion into the Texas area.over last year.

Frac water heating revenues for the year ended December 31, 2016 declined 64%2017 increased 175% to $18.4 million compared to $6.7 million as compared to $18.3 million in 2015. Unseasonably warm winter weather in the DJ Basin2016. Improved industry conditions including higher commodity prices and Marcellus/Utica Basin in the first and fourth quarters of 2016 significantly reducedincreased drilling rig activity increased demand for our services over 2016. Particularly strong gains are occurring from Marcellus Shale and Utica Shale locations in Pennsylvania as general industry activity has increased in the region due to increased demand. Further, the addition of three additional customers in the Rocky Mountain region also contributed to a substantial increase in frac water heating services in these, our two largest frac heating markets. Our Eastern USA region was hit particularly hard as sufficiently cold weather did not materialize in first and fourth quarter 2016, contributing to a $3.8 million, or 83%, decline in heating revenues in the Marcellus/Utica Shale Basin. Further, industry wide declines in drilling and completion programs due to low oil and natural gas prices and price concessions issued to customers also contributed to the annual decline in frac heating revenues.this area. 

Hot oil revenues for the year ended December 31, 2016 decreased 26%2017 increased 29% to $11.1 million compared to $8.6 million as compared to $11.7 million in 2015. 2016. Incremental hot oil service revenues of $2.3 million from our geographic expansion into Texas offset lower equipment utilizationthe Eagle Ford combined with increased revenues in the DJ Basin and price concessions in several markets. Hot oil equipment utilization fell from North Dakota due to improved commodity prices were the primary drivers of the increase over last year as customers in several locations scaled back frequency of service and reduced service hours in an effort to reduce costs.year.

Acidizing revenues for the year ended December 31, 20162017 increased 41%64% to $3.6 million compared to $2.2 million as compared to $1.5 million in 2015.2016. The Company’sCompany’s continued efforts to aggressively pursue customers and partner with chemical suppliers to develop new cost effectivecost-effective acid programs hashave allowed us to expand our acidizing services into the Eagle Ford Shale basinformation in Texas.

Segment profits for our core well enhancement services declined $8.5increased $6.6 million or 80%297% in 2016 as2017 compared to last year. Additional labor costs incurred to retain personnel during unseasonably warm weather, price concessions granted to2016. Increased revenues from the aforementioned more normal winter temperatures, the extension of heating season into the second quarter, the rebound of oil prices, and addition of new customers and overall fixed costs associated with maintaining our geographical locations and extensive fleet all contributed to the lowerimproved segment profits. TheIn the near future, the Company plans to continue to re-deploy equipment to more active regionsbasins to increase utilization which should result in improvingand improve this segment’s profits.

Water TransferServices:

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. Water transfer services involve the use of water pumps, lay flat hose, and aluminum pipe to transport water from a water source to a frac site. 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.

The continuing industry wide downturn significantly impacted our ability to penetrate this market in 2016. Accordingly, the Company recognized water transfer revenues of only $184,000 during 2016, with a majority of that revenue recognized in the fourth quarter. The Company has been awarded several water transfer jobs in early 2017 and expects future revenues to increase significantly over 2016.

Also, in connection with the acquisition above, the Company acquired a new water treatment technology utilized in devices sold under the name of HydroFLOW.HydroFLOW but discontinued the contract with HydroFLOW as of January 1, 2018 due to lack of meaningful sales. HydroFLOW products offer water treatment services based on patented hydropath technology that can remove bacteria and scale from water using electrical induction to reduce or eliminate down-hole scaling and corrosion. During 2016,We continue to evaluate potential use cases for the Company marketed this producttechnology for customers within and outside of the oil and natural gas industry.

For the year ended December 31, 2017, Water Transfer Services accounted for 5% of total revenue, and increased by $1.9 million, to several$2.1 million, due to the incremental revenues from three new customers during 2017. We consider the water transfer services segment to be an opportunity to grow our business with both new and existing customers and completedbelieve it offers opportunity to reduce the level of seasonality we have historically experienced. Segment results for the water transfer segment in the years ended December 31, 2017 and 2016 include approximately $283,000 and $325,000 of marketing and trial costs related to the HydroFLOW water treatment services, respectively.

Water Transfer segment losses for the year ended December 31, 2017, were approximately $538,000, compared to losses of $1.4 million in the year ended December 31, 2016. The Company continued to market and conduct proof of concept studies.

During 2016, this segment realized a loss of $1.4 million. Several factors contributed to this loss including carrying costs associated with the initial management team hired to run and grow the water transfer business who were dismissed in June 2016. Also, contributing to the segment loss were the marketing efforts to launch these new services and conducting no revenue proof-of-concept studies for HydroFlow services.

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 year ended December 31, 2017, the Company recognized revenues of approximately $22,000 related to HydroFLOW products.

Water Hauling Services

WaterWater hauling service revenues, which represent approximately 16%9% of our 20162017 consolidated revenues, declined $2.0 million,approximately $154,000, or 35%4%, during 2016 asin 2017 compared to last year. The decline was primarily attributable to lower water hauling revenues in our Central USUSA region due to scaled back service work, pricing concessions, and the cessation of certain low margin accounts.accounts, and reduced service activity in our Central USA region due to heavy rains during February.

Water hauling revenues have continued to decline over the last four years as this segment of the oil and gas industry has become highly competitive,competitive, which has resulted in downward pressure on prices. As noted above, the Company has reduced prices to remain competitive but also elected to eliminate certain low margin work.

DueThe Company recorded a segment loss of approximately $295,000 during the year ended December 31, 2017 compared to cost reduction efforts, including an across the board pay reduction in March 2016, this segment recognized a profit of $40,000approximately $41,000 in 2016 as compared to a loss of $57,000 in 2015.2016.

Construction Services:

In May 2016, the Company began to provide dirt excavation and hauling services to general contractors in the construction industry to offset some of the seasonal decline in revenues from our frac heating business and to utilize and retain key frac heating operators over the summer months. The Company used some of its existing construction equipment in both Heat Waves and Dillco to launch this service.

During 2016,For the year ended December 31, 2017, the Company recognized approximately $254,000 in construction services revenue compared to approximately $2.7 million of construction service revenue,during 2016, of which $2.5 million related to a specific dirt hauling project in Colorado. Due to the size and deadlines associated with this project, the Company supplemented its existing resources with sub-contractors. Logistical challenges and equipment issues related to the Colorado project, resulted in a segment loss of $279,000 during 2016.The Company has utilized the construction segment to retain employees during slow periods.

The Company may continue this business segment, but will focus primarily on dirt hauling projects which are less labor intensive or complex as the project in Colorado.

Unallocated and OtherOther::

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 and sales personnel that sell services for various segments.managers.

During 2016,2017, unallocated costs increased 6%14% to $845,000 compared to $740,000 as compared to $699,000 in 2015.2016.

Geographic Areas:

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, 2017 and 2016 and 2015:(amounts in thousands):

Notes to tables:

Revenues in the Rocky Mountain Region decreased $9.5increased $12.0 million or 41%,88% for the year ended December 31, 20162017, compared to the prior year due to several factors including (i) decreasedincreased frac water heating activity in the DJ Basin/Niobrara Shale/DJ BasinShale, Bakken area, and Bakken Field as discussed above;Wyoming basins due to more normal winter temperatures and incremental revenues generated from three new customers, (ii) decreasedthe ramp up of our water transfer business during 2017, and (iii) increased hot oiling service activity in the Bakken Fieldarea and Wyoming basins due to delayed maintenance programs by customers and (iii) price concessions granted to customers.DJ Basin.