Edgar Filing: Enservco Corp

ensv20141231_10k.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

[X]

ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.

For the fiscal year ended December 31, 2014

[ ]	TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.

For the transition period from _______ to ______

Commission file number: 000-9494

ENSERVCO CORPORATION

(Exact name of registrant as specified in its charter)

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

501 South Cherry St., Ste. 320 Denver, CO		80246
(Address of principal executive offices)		(Zip Code)

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

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

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

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

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

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

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

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Securities Exchange Act of 1934.

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

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

The aggregate market value of the common stock held by non-affiliates of the Registrant was approximately $45,405,810 based upon the closing sale price of the Registrant’s Common Stock of $2.58 as of June 30, 2014, the last trading day of the registrant’s most recently completed second fiscal quarter. This determination of affiliate status is not necessarily a conclusive determination for other purposes.

As of March 12, 2015, there were 37,619,913 shares of the Enservco Corporation’s common stock outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Certain portions of the registrant’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, 2013, in connection with the registrant’s 2014 Annual Meeting of Shareholders, are incorporated herein by reference into Part III of this Annual Report on Form 10-K.

PART I

ITEM 1. BUSINESS

Enservco Corporation (“Enservco”) and its wholly-owned subsidiaries (collectively referred to as the “Company”, “we” or “us”) provides well enhancement and fluid management services to the domestic onshore oil and natural gas industry. These services include frac water heating, hot oiling and acidizing (well enhancement services), and water hauling, fluid disposal, frac tank rental (fluid management services) and other general oilfield services. The Company owns and operates a fleet of more than 250 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 field in Colorado, the Bakken field in North Dakota, the Marcellus and Utica Shale fields in Pennsylvania and Ohio, the Jonah Field, Green River and Powder River Basins in Wyoming, the Eagle Ford Shale in Texas and the Mississippi Lime and Hugoton Fields in Kansas and Oklahoma.

Enservco was incorporated as Aspen Exploration Corporation under the laws of the State of Delaware 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 (the “Merger Transaction”). On December 30, 2010, Aspen changed its name to “Enservco Corporation.” As such, throughout this report the terms the “Company” and/or “Enservco” are intended to refer to the Company on a post Merger Transaction basis and as a whole, with respect to both historical and forward looking contexts.

The Company’s executive (or corporate) offices are located at 501 South Cherry St., Ste. 320, Denver, CO 80246. Our telephone number is (303) 333-3678, and our facsimile number is (720) 974-3417. Our website is www.enservco.com.

Cautionary Note Regarding Forward-Looking Statements

The information discussed in this annual report on Form 10-K as well as some statements in press releases and some oral statements of the Company’s officers during presentations about the Company include “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 (the “Securities Act”) and Section 21E of the Securities Exchange Act of 1934 (the “Exchange Act”). All statements, other than statements of historical facts, included herein and therein concerning, among other things, planned capital expenditures, future cash flows and borrowings, pursuit of potential acquisition opportunities, our financial position, business strategy and other plans and objectives for future operations, are forward-looking statements. These forward-looking statements are identified by their use of terms and phrases such as “may,” “expect,” “estimate,” “project,” “plan,” “believe,” “intend,” “achievable,” “anticipate,” “will,” “continue,” “potential,” “should,” “could,” and similar terms and phrases. Although we believe that the expectations reflected in these forward-looking statements are reasonable, they do involve certain assumptions, risks and uncertainties and are not (and should not considered to be) guarantees of future performance. Our results could differ materially from those anticipated in these forward-looking statements as a result of certain factors, including, among others:

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Our capital requirements and the uncertainty of being able to obtain additional funding on terms acceptable to us;

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The volatility of domestic and international oil and natural gas prices and the resulting impact on production, and the effect that lower prices may have on our customers’ demand for our services, the result of which may adversely impact our revenues and financial performance;

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The broad geographical diversity of our operations which, while expected to diversify the risks related to a slow-down in one area of operations, also adds to our costs of doing business;

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The financial constraints imposed as a result of our indebtedness, including restrictions imposed on us under the terms of our credit facility agreement and our need to generate sufficient cash flows to repay our debt obligations;

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Our history of losses and working capital deficits which, at times, were significant;

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Adverse weather and environmental conditions;

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Our reliance on a limited number of customers;

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Our ability to retain key members of our senior management and key technical employees;

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The potential impact of environmental, health and safety, and other governmental regulations, and of current or pending legislation with which we and our customers must comply;

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Developments in the global economy;

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Changes in tax laws;

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The effects of competition;

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The effect of seasonal factors;

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The effect of further sales or issuances of our common stock and the price and volume volatility of our common stock; and

●

Our common stock’s limited trading history.

Finally, our future results will depend upon various other risks and uncertainties, including, but not limited to, those detailed in the section entitled “Risk Factors” included elsewhere in this annual report. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the cautionary statements in this section and elsewhere in this annual report. Other than as required under securities laws, we do not assume a duty to update these forward-looking statements, whether as a result of new information, subsequent events or circumstances, changes in expectations or otherwise.

Corporate Structure

The Company’s business operations are conducted primarily through Heat Waves and Dillco. The below table provides an overview of the Company’s current subsidiaries and their activities.

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

Dillco Fluid Service, Inc. (“Dillco”)	Kansas	100% by Enservco	Oil and natural gas field fluid logistic services primarily in the Hugoton Basin in western Kansas and northwestern Oklahoma.

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

Real GC, LLC (“Real GC”)	Colorado	100% by Heat Waves	No active business operations. Owns real property in Garden City, Kansas that is used by Heat Waves.

On May 29, 2013, three of the Company’s former subsidiaries not included in the above table (Trinidad Housing, LLC, Aspen Gold Mining Company, and Heat Waves, LLC) were dissolved. The charter of another subsidiary, Enservco Frac Services, LLC, was administratively dissolved by operation of law in 2013. None of these dissolved subsidiaries was engaged in active business operations prior to its dissolution or were material. As part of a corporate reorganization in May 2013, Dillco transferred its ownership in Heat Waves to Enservco through a tax free exchange.

Overview of Business Operations

As described above, the Company primarily conducts its business operations through its principal operating subsidiaries, Dillco and Heat Waves, which provide oil field services to the domestic onshore oil and natural gas industry. These services include pressure testing, hot oiling, acidizing, frac water heating, 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 and Dillco in their business operations are owned by other subsidiary entities. The Company currently operates in the following geographic regions:

●

Eastern USA Region, including the southern region of the Marcellus Shale formation (southwestern Pennsylvania and northern West Virginia) and the Utica Shale formation in eastern Ohio. The Eastern USA Region operations are deployed from Heat Waves’ operations center in Carmichaels, Pennsylvania which opened in the first quarter of 2011.

●

Rocky Mountain Region, including western Colorado and southern Wyoming (D-J Basin and Niobrara formations), and western North Dakota and eastern Montana (Bakken formation). The Rocky Mountain Region operations are deployed from Heat Waves’ operations centers in Killdeer, North Dakota, Rock Springs, Wyoming and Platteville, Colorado.

●

Central USA Region, including southwestern Kansas, Texas panhandle, northwestern Oklahoma, and northern New Mexico. The Central USA Region operations are deployed from operations centers in Garden City and Hugoton, Kansas.

Management believes that the Company is strategically positioned with its ability to provide its services to a large customer base in key oil and natural gas basins in the United States. Management is optimistic that as a result of the significant expenditures the Company has made in new equipment in combination with expanding into new basins and geographical locations, the Company will be able to further grow and develop its business operations, although our ability to do so is clearly subject to domestic and international conditions in the oil and gas industry which have been adversely impacted by the substantial decline in crude oil prices since July 2014.

Historically, the Company focused its growth strategy on strategic acquisitions of operating companies and then expanding operations through additional capital investment consisting of the acquisition and fabrication of property and equipment. That strategy also included expanding the Company’s geographical footprint as well as expanding the services it provides. These strategies are exemplified by the acquisitions of operating entities (described in the Operating Entities section below) and:

(1)

In 2012, 2013 and 2014, Dillco and Heat Waves spent approximately $3.8 million, $5.8 million, and $24.0 million, respectively, for the acquisition and fabrication of property and equipment; and

(2)

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

Going forward, and subject to the availability of adequate financing, the Company expects to continue to pursue its growth strategies of exploring additional acquisitions, potentially 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 its assets and equipment.

Operating Entities

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

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 western 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:

(1)

Assist in the fracturing of formations for newly drilled oil and natural gas wells; and

(2)

Help maintain and enhance the production of existing wells throughout their productive life.

These services consist of frac water heating, hot oiling and acidizing. Heat Waves also provides some water hauling and well site construction services. Heat Waves’ operations are currently in southwestern Kansas, Texas panhandle, northwestern Oklahoma, southern and central Wyoming (Niobrara formation), Colorado (D-J Basin), southwest Pennsylvania/ northwestern West Virginia (Marcellus Shale) region, eastern Ohio (Utica Shale), and western North Dakota and eastern Montana (Bakken formation).

HES. HES owns construction and related equipment that Heat Waves used in its well site construction and maintenance services. However, HES does not currently engage in any business activities itself. HES also owns a disposal well near Garden City, Kansas that Dillco uses for salt water disposal.

Products and Services

The Company provides a range of services to owners and operators of oil and natural gas wells. Such services can generally be grouped into the three following categories:

(1)

Well enhancement services, i.e., hot oiling, acidizing, frac water heating, and pressure testing;

(2)

Fluid management services, i.e., water/fluid hauling, frac tank rental, and disposal services; and

(3)

Well site construction and roustabout services.

The following map shows the primary areas in which Heat Waves and Dillco currently have active business operations.

The following is a more complete description of the services provided by The Company through its subsidiaries.

Well Enhancement Services.

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 utilizes a fleet of approximately 178 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), and western North Dakota and eastern Montana (Bakken formation). Well enhancement services accounted for approximately 84% of the Company’s total revenues for its 2014 fiscal year on a consolidated basis as compared to 80% for the 2013 fiscal year.

Frac Water Heating - Fracturing services are intended to enhance the production from crude oil and natural gas wells where the natural flow has been restricted by underground formations through the creation of conductive flowpaths to enable the hydrocarbons to reach the wellbore. The fracturing process consists of pumping a fluid slurry, which largely consists of fresh water and a “proppant” (explained below), into a cased well at sufficient pressure to fracture (i.e. create conductive flowpaths) the producing formation. Sand, bauxite or synthetic proppants are suspended in the fracturing fluid slurry and are pumped into the well under great pressure to fracture the formation. To ensure these solutions are properly mixed (gel frac) or that plain water (used in slick water fracs) can flow freely, the water frequently needs to be heated to a sufficient temperature as determined by the well owner/operator. Heat Waves currently owns and operates a fleet 53 frac heaters (or the equivalent of 81 burner boxes) designed to heat large amounts of water stored in reservoirs or frac tanks. During 2014, the Company added the equivalent of 41 burner boxes representing a 103% increase in ending units over last year. The majority of the increase in capacity came in the fourth quarter due to addition of 18 mega heaters (equivalent to 36 burner boxes) as part of the 2014 CAPEX program.

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 and allowed time to react. The spent fluids are then flowed or swabbed out of the well, after which the well is put back into production. 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 in the formation or through perforations in the well casing. For most customers, Heat Waves supplies the acid solution and also pumps that solution into a given well. There are customers who provide their own solutions and hire Heat Waves to pump the solution. During 2014, the Company added three mobile acid transport and pumping trucks – two at the end of June and one at the end of December increasing our fleet to six as of December 31, 2014. The Company has one mobile acid transport in fabrication and expects delivery near the end of the first quarter of 2015.

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 oil or natural gas well. These paraffin deposits build up over a period of time from normal production operations, although the rate at which these products build up depends on the chemical character of the crude oil and natural gas being produced. This is performed by circulating the hot oil down the casing and back up the tubing to remove the deposits from the well bore.

Hot oil servicing also includes the heating of oil storage tanks. The heating of storage tanks is done:

(1)

To eliminate water and other soluble waste in the tank for which the operator’s revenue is reduced at the refinery; and

(2)

Because heated oil flows more efficiently from the tanks to transports taking oil to the refineries in colder weather.

As of December 31, 2014, Heat Waves owns and operates a fleet of 51 hot oil trucks. During 2014, the Company added 24 hot oil trucks - four trucks from our 2013 CAPEX program were added in June, eight trucks from our 2014 CAPEX program and twelve trucks were acquired as part of an asset purchase during the fourth quarter, increasing the ending number of hot oiling trucks by 89% from last year. The Company currently has eight hot oil trucks in fabrication and expects delivery near the end of the first quarter of 2015.

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.

Fluid Services.

Water Hauling – Water hauling accounted for approximately 15% of the Company’s revenues on a consolidated basis during 2014 as compared to 19% during our 2013 fiscal year. The Company currently owns or leases, and operates approximately 65 water hauling trucks and trailers equipped with pumps to move water from or into wells, tanks and other storage facilities in order to assist customers in managing their water-cost needs. Each truck has a hauling capacity of up to 130 barrels (each barrel being equal to 42 U.S. gallons). The trucks are used to:

(1)

Transport water to fill frac tanks on well locations,

(2)

Transport contaminated water produced as a by-product of producing wells to disposal wells, including disposal wells that we own and operate, and

(3)

Transport drilling and completion fluids to and from well locations; following completion of fracturing operations, the trucks are used to transport the flow-back produced as a result of the fracturing process from the well site to disposal wells.

Most wells produce residual salt or fresh water in conjunction with the extraction of the oil or natural gas. The Company’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 done on a periodic basis depending on the volume of water a well produces. Water-cost management is an ongoing need for oil and natural gas well operators throughout the life of a well.

The Company’s ability to outperform competitors in this segment is primarily dependent on logistical factors such as the proximity between areas where water is produced or used and the strategic placement and/or access to both disposal wells and recycling facilities. The Company owns four water disposal wells in Kansas and Oklahoma. It is management’s intent to maintain the Company’s disposal well holdings and access to recycling facilities, but also to use disposal wells and other facilities owned by third parties where appropriate.

Typically the Company and a customer enter into a contract for services after that customer has completed a competitive bidding process. Requirements for minor or incidental water hauling services are usually purchased on a “call out” basis and charged according to a published schedule of rates. The Company competes for services both on a call out and contractual basis.

Workover, completion, and remedial activities also provide the opportunity for higher operating margins from tank rentals and water hauling services. Drilling and workover jobs typically require water for multiple purposes. Completion and workover procedures often also require large volumes of water for fracturing operations, a process of stimulating a well hydraulically to increase production. All fluids are required to be transported from the well site to an approved disposal facility.

Competitors in the water hauling business, where the Company provides this service, are mostly small, regionally focused companies. The level of water hauling activity is comprised of a relatively stable demand for services related to the maintenance of producing wells and a highly variable demand for services used in the drilling and completion of new wells. As a result, the level of domestic onshore drilling activity significantly affects the level of the Company’s activity in this service area, and may vary from region to region and from season to season.

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.

Our trucks frequently transport fluids to be disposed of into these disposal wells. The Company’s disposal wells are located in southwestern Kansas and northwestern Oklahoma in areas in proximity to our customers’ producing wells in those areas. 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 imposed by 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 Basin. The Company currently owns approximately 20 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 and Roustabout Services.

Well-site construction and roustabout services accounted for less than 1% of the Company’s revenues on a consolidated basis during 2014 and, similarly, accounted for an immaterial portion of the Company’s consolidated revenues during the 2013 fiscal year.

Ownership of Company Assets

As described above, the Company (through Heat Waves and Dillco) owns and uses a fleet of trucks, frac tanks, disposal wells and other assets to provide its services and products. Substantially all of the equipment and personal property assets owned by Dillco and Heat Waves are subject to a security interest to secure loans made to the Company and its wholly-owned subsidiaries.

Historically, during portions of our fiscal year as supply and demand requires, the Company has leased additional trucks and equipment. These leases 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.

Competitive Business Conditions

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

The demand for our services fluctuates primarily in relation to the worldwide commodity price (or anticipated price) of oil and natural gas which, in turn, is largely driven by the 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 depends on events that are not within our control. Generally, as supply of those commodities 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.

The Company’s competition primarily consists of small regional or local contractors. The Company attempts to differentiate itself from its competition in large part through its superior equipment and the 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 large and small 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 continue to grow our business.

Dependence on One or a Few Major Customers

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

During the fiscal year ended December 31, 2014, one of the Company’s customers accounted for approximately 18% of consolidated revenues. No other customer exceeded 10% of consolidated revenues. The Company’s top five customers in 2014 accounted for approximately 46% of its total revenues. 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.

During the fiscal year ended December 31, 2013, one of the Company’s customers accounted for approximately 17% of consolidated revenues. No other customer exceeded 10% of consolidated revenues. The Company’s top five customers in 2013 accounted for approximately 44% of its total revenues.

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

Seasonality

Portions of the Company’s operations are impacted by seasonal factors, particularly with regards to its frac water heating and hot oiling services. In regards to frac water heating, because customers rely on Heat Waves to heat large amounts of water for use in fracturing formations, demand for this service is much greater in the colder months. Similarly, hot oiling services are in higher demand during the colder months when they are needed for maintenance of existing wells and to heat oil storage tanks.

Acidizing and pressure testing are done all year long with higher revenues during non-winter months.

The hauling of water 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.

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 generally 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 given property owner, and during its 2013 and 2012 fiscal years the total amount paid under these various agreements by the Company was immaterial to the Company and its business operations.

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

In the course of the Company’s operations, it does not typically generate materials that are considered “hazardous substances.” One exception, however, would be spills that occur prior to well treatment materials being circulated down hole. For example, if the Company spills acid on a roadway as a result of a vehicle accident in the course of providing well enhancement/stimulation services, or if a tank with acid leaks prior to down hole circulation, the spilled material may be considered a “hazardous substance.” In this respect, the Company may occasionally be considered to “generate” materials that are regulated as hazardous substances and, as a result, may incur CERCLA liability for cleanup costs. Also, claims may be filed for personal injury and property damage allegedly caused by the release of hazardous substances or other pollutants.

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

The Safe Drinking Water Act (the “SDWA”), and the Underground Injection Control (“UIC”) program promulgated thereunder, regulate the drilling and operation of subsurface injection wells, such as the disposal wells owned and operated by the Company. 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 wells (Kansas and Oklahoma) require us to obtain a permit to operate each of our disposal wells. The applicable regulatory agency may suspend or modify one of our permits if the Company’s well operations are likely to result in pollution of freshwater, substantial violation of permit conditions or applicable rules, or if the well leaks into the environment.

The federal Energy Policy Act of 2005 amended the SDWA to exclude hydraulic fracturing from the definition of “underground injection” under certain circumstances. However, the repeal of this exclusion has been advocated by certain advocacy organizations and others in the public. The EPA at the request of Congress is currently conducting a national study examining the potential impacts of hydraulic fracturing on drinking water resources, with a draft of the final report expected to be released in 2014.

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

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

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

Because our trucks travel over public highways to get to customer’s 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, the continued violation of regulations could result in a shutdown of all of the vehicles of either Dillco or Heat Waves. 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 6, 2015, the Company employed approximately 236 full time employees. Of these employees, approximately 172 are employed by Heat Waves, approximately 50 by Dillco and 14 are employed by Enservco.

Available Information

We maintain a website at http://www.enservco.com. The information contained on, or accessible through, our website is not part of this Annual Report on Form 10-K. Our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to reports filed or furnished pursuant to 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:

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a Code of Business Conduct and Ethics for Directors, Officers and Employees which contains information regarding our whistleblower procedures,

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our Insider Trading Policy,

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our Audit Committee Charter,

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our Trading Blackout Policy, and

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our Related Party Transaction Policy.

ITEM 1A. RISK FACTORS

The Company’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.

You should carefully consider the risks described below and elsewhere herein in connection with any decision whether to acquire, hold or sell the Company’s securities. 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 Related Risks

Our business depends on domestic spending by the crude oil and natural gas industry which has suffered significant negative price volatility since July 2014, volatility which 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’ 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. Recent declines in oil and natural gas prices since July 2014 (when prices were at approximately $100 per barrel) have resulted in significant declines in capital spending and drilling programs across the industry. As a result of this significant decline in oil and natural gas prices, many exploration and production companies have asked service providers to make pricing concessions. Over the last several months, the Company has offered temporary pricing concessions to a limited number of customers. Typically, these concessions have been made with the intent to maintain existing service volumes and/or develop additional business.

There has also been significant political pressures for the United States economy to reduce its dependence on crude oil and natural gas due to the perceived impacts on climate change. Furthermore there have been significant political efforts to reduce or eliminate hydraulic fracturing operations in certain of the Company’s service areas. These activities may make oil and gas investment and production less attractive.

Industry conditions and specifically the market price for crude oil and natural gas production 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.

Higher oil and gas prices do not necessarily result in increased drilling activity because our 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:

	●	demand for crude oil and natural gas;
	●	political pressures against crude oil and natural gas exploration and production;

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cost of exploring for, producing, and delivering oil and natural gas;

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expectations regarding future energy prices;

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advancements in exploration and development technology;

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adoption or repeal of laws regulating oil and gas production in the U.S.;

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imposition or lifting of economic sanctions against foreign companies;

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weather conditions;

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rate of discovery of new oil and natural gas reserves;

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tax policy regarding the oil and gas industry; and

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development and use of alternative energy sources.

Ongoing volatility and uncertainty in the global economic environment has caused the oilfield services industry to experience volatility in terms of demand. While the Company 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 curtail drilling programs as well as discretionary spending on well services, which may result in a reduction in the demand for the Company’s services, the rates we can charge and our 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 any executive or key personnel could disrupt our business operations.

We depend to a large extent on the services of certain of our executive officers. The loss of the services of Rick Kasch, Austin Peitz, Robert Devers or other key personnel, could disrupt our operations. Although we have entered into employment agreements with Messrs. Kasch, Peitz and Devers, that contain, among other things non-compete and confidentiality provisions, we may not be able to enforce the non-compete and/or confidentiality provisions in the employment agreements.

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

The Company’s customers consist primarily of major and independent oil and natural gas companies. During both fiscal years 2014 and 2013, only one of the Company’s customers accounted for more than 10% of consolidated revenues, at approximately 18% and 17%, respectively, of consolidated revenues; no other customer exceeded 10% of revenues.

The Company’s top five customers accounted for approximately 46% and 44% of its total annual revenues for 2014 and 2013, 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’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 on 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.

Demand for the majority of our services depends substantially on the level of expenditures by participants in the domestic (United States) oil and natural gas industry for the exploration, development and production of oil and natural gas reserves. These expenditures are sensitive to the industry’s view of future economic growth in the United States and elsewhere, and the resulting impact on demand for oil and natural gas. The worldwide deterioration in the financial and credit markets, which began in the second half of 2008, resulted in diminished demand for oil and natural gas and significantly lower oil and natural gas prices during 2009 and at least the first half of 2010. This caused many of our customers to reduce or delay their oil and natural gas exploration and production spending in 2009 and the first half of 2010, which consequently reduced their demand for our services, and exerted downward pressure on the prices that we charged for our services and products. The industry returned to higher activity levels in 2011 and remained relatively stable through the middle of 2014. However, beginning in the second half of 2014, oil prices declined substantially from historical highs and may remain depressed for the foreseeable future.

Furthermore, 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 reduced the overall costs of producing oil and natural gas, the price of drill rigs, pipe, other equipment, fluids, and oil field services and the cost to companies like the Company of providing those services, has generally increased 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 in oil 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. 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 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.

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

Although the well services industry is highly fragmented, it is highly competitive. The well services industry 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 could 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.

As is the situation with all companies in the frac water heating service business, we rely on certain procedures and practices in performing our services. We have a patent pending regarding certain of these used in our process of heating frac water. We are aware that one unrelated company (the “Patent Owner”) has been awarded two patents related, in part, to the process they use for heating of frac water and is currently seeking additional patents. The Patent Owner is currently in litigation with two different groups of energy companies that are seeking to invalidate the first patent and against Enservco and Heat Waves for allegedly infringing on its two patents. Enservco and Heat Waves have denied any infringement and are aggressively defending the litigation. (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 or royalties or be subject to a temporary or permanent injunction prohibiting us from heating frac water in a manner we 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 conditions can cause:

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Personal injury or loss of life,

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Damage to or destruction of property, equipment and the environment, and

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Suspension of operations by our customers.

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 our 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. 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.

While our growth strategy includes appropriate acquisitions, we may not be successful in identifying, making and integrating business or asset acquisitions, if any, in the future.

We anticipate that a component of our growth strategy may be to make geographically focused acquisitions of businesses or assets aimed to strengthen our presence and expand services offered in selected regional markets. Pursuit of this strategy may be restricted by the on-going volatility and uncertainty within the credit markets which may significantly limit the availability of funds for such acquisitions. Our ability to use of 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 funding availability, the success of this strategy will depend on our ability to identify suitable acquisition candidates and to negotiate acceptable financial and other terms. There is no assurance that we will be able to do so. The success of an acquisition also depends on our ability to perform adequate due diligence before the acquisition and on our ability to integrate the acquisition after it is completed. While the Company intends to commit significant resources to ensure that it conducts comprehensive due diligence, there can be no assurance that all potential risks and liabilities will be identified in connection with an acquisition. Similarly, while we expect to commit substantial resources, including management time and effort, to integrating acquired businesses into ours, there is no assurance that we will be successful 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.

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”) 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 substantially all of our assets, could restrict our operations and make us more vulnerable to adverse economic conditions.

As of December 31, 2014, the Company owed approximately $29.8 million to banks and financial institutions under various collateralized debt facilities.

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

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

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

	■	Limit our ability to pay dividends to our stockholders,

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

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

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

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 with accrued and unpaid interest, the lenders under our credit facility could elect to terminate their commitments there under and we or one or more of our subsidiaries could be forced into bankruptcy or liquidation. Any of the foregoing consequences could restrict our ability to grow our business and cause the value of our common stock to decline.

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

The Company’s agreements with PNC impose various obligations and financial covenants on the Company. The outstanding amount under the Amended and Restated Revolving Credit and Security Agreement, entered into with PNC in September 2014, is due in full in September 2019. The revolving credit agreement with PNC has a variable interest rate and is collateralized by substantially all of the assets of the Company and its subsidiaries.

Further, the related agreements with PNC impose various financial covenants on the Company including maintaining a prescribed fixed charge coverage ratio, maximum leverage ratio, and limit the Company’s ability to incur additional debt or operating lease obligations. If the Company is unable to comply with its obligations and covenants under the loan agreements and it declares an event of default, all of its obligations to PNC could be immediately due.

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, there can be no assurance that we will be able to obtain these waivers or modifications in the future.

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

The Company’s borrowings through PNC bear interest at variable rates, exposing the Company to interest rate risk. The Company entered into an Interest Rate Swap Agreement with a notional balance of $11 million in conjunction with the November 2012 Revolving Credit, Term Loan, and Security Agreement entered into with PNC. The Company elected to maintain this interest rate swap agreement with its new senior credit facility, effectively hedging approximately $7.7 million of our outstanding debt at approximately 3.3% through October 31, 2015. The Company has decided not to hedge against the interest rate risk associated with the remaining balance of the senior revolving credit facility (with a maximum available balance of $40 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.

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

As of December 31, 2014, we had borrowed approximately $28.6 million under our senior revolving credit facility and have approximately $11.1 million of borrowing capacity available under this facility. Although the Company plans to utilize cash flow from operations during the first half of 2015 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 likely that a reduction in the borrowing base of our credit facility following a periodic redetermination could require us to repay a portion of outstanding borrowings, may impair our ability to obtain additional financing in the future, and increases the risk that we may default on our debt obligations. In addition, we may be required to devote a significant portion of our cash flows to servicing our debt, and we are subject to interest rate risk under our credit facility, which bears interest at a variable rate. Any increase in our interest rates could have an adverse impact on our financial condition, results of operations and growth prospects.

Our ability to meet our debt obligations and to reduce our level of indebtedness depends on our future performance. General economic conditions, oil and natural gas prices and financial, business and other factors affect our operations and our future performance. Many of these factors are beyond our control. If we do not have sufficient funds on hand to pay our debt when due, we may be required to seek a waiver or amendment from our lenders, refinance our indebtedness, incur additional indebtedness, sell assets or sell additional shares of 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

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

A significant portion of our common stock is currently considered restricted stock pursuant to Rule 144 and is subject to the rules applicable to “former shell companies”.

A significant portion of our outstanding common stock has been issued as “restricted securities” under Rule 144 under the Securities Act, including the shares issued to our President and Chairman in July 2010 and in an equity placement completed in November 2012. As a former shell company, to the extent that any person holds restricted securities of the Company or otherwise must rely on Rule 144 for resale, Rule 144(i) imposes additional restrictions on the ability of any holder to utilize the exemption from registration for sales contained in Rule 144.

Because we have no plans to pay dividends on our common stock, investors must look solely to stock appreciation for a return on their investment in us.

We do not anticipate paying any cash dividends on our common stock in the foreseeable future. We currently intend to retain all future earnings to fund the development and growth of our business. Any payment of future dividends will be at the discretion of our board of directors and will depend on, among other things, our earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applying to the payment of dividends and other considerations that the board of directors deems relevant.

Investors must rely on sales of their common stock after price appreciation, which may never occur, as the only way to realize a return on their investment. Investors seeking cash dividends should not purchase our common stock.

General Corporate Risks

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

Because Mr. Herman directly and indirectly owns approximately 26.1% of the Company’s outstanding common stock, he has 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 Mr. Herman. For so long as Mr. Herman continues to own a significant percentage of the outstanding shares of the Company common stock, he will retain such influence over the election of the board of directors and the negotiation of any change of control transaction.

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

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

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

Indemnification of officers and directors may result in unanticipated expenses.

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

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

Because we are a public company filing reports under the Securities Exchange Act of 1934, we are subject to increased regulatory scrutiny and extensive and complex regulation. The Securities and Exchange Commission has the right to review the accuracy and completeness of our reports, press releases, and other public documents. In addition, we are subject to extensive requirements to institute and maintain financial accounting controls and for the accuracy and completeness of our books and records.

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. It should be noted that because we are a “penny stock,” the protections provided by Section 27A of the Securities Act of 1933, and Section 21E of the 1934 Act do not apply to us. 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 leased by the Company and its subsidiaries. Unless otherwise indicated, the properties are used in Heat Waves’ operations.

Owned Properties:

Location/Description

Approximate Size

Killdeer, ND(1)

●Shop

●Land – shop

●Housing

●Land – housing

10,000 sq. ft.

8 acres

5,000 sq. ft.

2 acres

Tioga, ND

●Shop

●Land

4,000 sq. ft.

6 acres

Garden City, KS

●Shop(1)

●Land – shop(1)

●Land – acid dock, truck storage, etc.

11,700 sq. ft.

1 acre

10 acres

Trinidad, CO (1) (2)

●Shop

●Land – shop

9,200 sq. ft.

5 acres

Hugoton, KS (Dillco)

●Shop/Office/Storage

●Land – shop/office/storage

●Office

●Land – office

9,367 sq. ft.

3.3 acres

1,728 sq. ft.

10 acres

(1) Property is collateral for mortgage debt obligation.

(2) Company is receiving $2,300 monthly under a short-term sublease agreement.

Leased Properties:

Location/Description

Approximate Size

Monthly Rental

Lease Expiration

Platteville, CO

●Shop

●Land

3,200 sq. ft.

1.5 acres

$3,000

Month-to-month

La Salle, CO (3)

●Shop

●Land

6,000 sq. ft.

3.0 acres

$8,000

January 2021

Rock Springs, WY

●Shop

●Land

10,200 sq. ft.

3 acres

$6,500

August 2017

Casper, WY

●Shop

●Land

5,000 sq. ft.

1.0 acres

$4,500

May 2017

Tioga, ND

●Housing

$4,750

Month-to-month

Carmichaels, PA

●Shop

●Land

5,000 sq. ft.

12.1 acres

$9,000

April 2015

Perryton, TX

●Land

$1,000

Month-to-month

Denver, CO

●Corporate offices

3,497 sq. ft.

$6,120

December 2016

(3) Lease commenced on February 1, 2014

Note - All leases have renewal clauses

ITEM 3. LEGAL PROCEEDINGS

On October 10, 2014, the Company received service of a complaint filed in the United States District Court for the Northern District of Texas, Dallas Division (Civil Action No. 3:14-cv-03631) by Heat-On-The-Fly, LLC (“HOTF”) naming the Enservco Corporation (“Enservco”) and its subsidiary Heat Waves Hot Oil Service, LLC (“Heat Waves”) as defendants. The complaint alleges that Enservco and Heat Waves, in offering and selling frac water heating services, infringed and induced others to infringe two patents owned by HOTF (U.S. Patent Nos. 8,171,993 (“the ‘993 Patent”) and 8,739,875 (“the ‘875 Patent”)). The complaint seeks various remedies including injunctive relief and unspecified damages and relates to only a portion of Heat Waves’ frac water heating services. The case is still in its early stages. Heat Waves has filed a motion to transfer the case to Colorado and Enservco has filed a motion to dismiss the case against it based on a lack of personal jurisdiction. A hearing on these motions is set for April 6, 2015.

Enservco and Heat Waves deny that they are infringing any valid, enforceable claims of the asserted patents and intend to vigorously defend themselves against the lawsuit. Heat Waves has offered on demand water heating services well before these patents were even filed.

The Company previously reported in its Annual Report on Form 10-K for the fiscal year ended December 31, 2013 that it was aware of the HOTF ‘993 Patent relating, in part, to the heating of frac water, but also reported that the Company did not believe at that time, and still does not believe, that Heat Waves’ operations infringed any valid claim of that patent. The Company is aware that HOTF has been involved in litigation dating back to January of 2013 with a group of energy companies that are seeking to, among other things, invalidate the ‘993 Patent. Further, the Company is aware of another claim filed by a third party against HOTF in August 2014 also seeking to, among other things, invalidate the ‘993 Patent.

Although the first 12 claims of the ‘993 Patent survived a prior reexamination, the United States Patent and Trademark Office (“USPTO”) granted a second request on July 1, 2014, to reexamine the ‘993 Patent in its entirety (all 99 claims, including the prior 12 claims that survived the prior, limited reexamination) based on different reasoning. On February 11, 2015, the USPTO issued initial findings in the second reexamination proceeding that rejected all 99 claims of the ‘993 Patent as being unpatentable. HOTF has until April 11, 2015, to file a response with the USPTO, but can request an extension of the deadline if it shows good cause. The timing of HOTF’s response and any decision resulting therefrom is uncertain, is subject to appeal, and may be a year or more in the future. Further, HOTF has at least two additional pending patent applications that are based on the ‘993 Patent and ‘875 Patents that if granted could be asserted against the Company. As the ‘993 Patent and the ‘875 Patent are based on the same subject matter, management believes that a finding of invalidity of the ‘993 Patent could serve as a basis to affect the validity of the ‘875 Patent. If the Patents are found to be invalid, the litigation would become moot.

Until such time as the validity of the Patents is finalized and the case is dismissed, the Company will be expending funds for its defense. To the extent that the Company and Heat Waves are unsuccessful in their defense, they could be liable for damages (which may be significant) and possibly an injunction preventing them from using any infringing technology. Either result could negatively impact the Company’s business and operations.

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

As of March 10, 2014, our common stock is traded on the NYSE MKT under the symbol “ENSV”. Prior to March 10, 2014, our common stock was quoted on the Over-the-Counter Bulletin Board (“OTCBB”) and the OTCQX under the symbol “ENSV.” Prior to January 4, 2011 our common stock was quoted under symbol “ASPN”.

The table below sets forth the high and low closing prices of the Company’s Common Stock during the periods indicated as reported by the Internet source Yahoo Finance (http://finance.yahoo.com). The quotations reflect inter-dealer prices without retail mark-up, mark-down or commission and may not reflect actual transactions.

	2014				2013
	Price Range				Price Range
	High		Low		High		Low
First Quarter	$	2.68	$	1.76	$	1.27	$	0.63
Second Quarter		3.10		1.88		1.35		0.90
Third Quarter		3.89		2.46		1.62		0.90
Fourth Quarter		3.89		1.36		1.83		1.22

The closing sales price of the Company’s common stock as reported on March 12, 2015, was $2.00 per share.

Holders

As of March 12, 2015, there were approximately 420 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, 2014 or 2013, and has no plans at present to declare or pay any dividends.

Decisions concerning dividend payments in the future will depend on income and cash requirements. However, in its agreements with PNC, our principal lender, the Company represented that it would not pay any cash dividends on its common stock until its obligations to PNC are satisfied. Furthermore, to the extent the Company has any earnings, it will likely retain earnings to 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, 2013:

Equity Compensation Plan Information

Number of Securities

Remaining Available

for Future Issuance

Number of Securities

Under Equity

to be Issued Upon

Weighted-Average

Compensation Plans

Exercise of

Exercise Price of

(Excluding Securities

Outstanding Options,

Reflected in Column

Plan Category

Warrants, and Rights

(a))

and Description

(a)

(b)

(c)

Equity Compensation Plans Approved by Security Holders ⁽¹⁾

3,350,168

0.92

2,144,264

⁽³⁾

Equity Compensation Plans Not Approved by Security Holders

400,001

⁽²⁾

0.55

Total

3,750,169

0.88

2,144,264

(1)

Represents options granted pursuant to the Company’s 2010 Stock Incentive Plan.

(2)

Consists of: (i) options to acquire 150,000 shares of Company common stock granted pursuant to Aspen’s 2008 Equity Plan at $0.41 per share; (ii) warrants issued in 2011 to acquire 100,000 shares of Company common stock exercisable at $0.77 per share, (iii) warrants issued November 2012 to the principals of the Company’s existing investor relations firm to acquire 112,500 shares of Company common stock exercisable at $0.55 per share, and (iv) warrants issued November 2012 in conjunction with stock subscription agreements executed with equity investors to acquire 37,501 shares of Company common stock exercisable at $0.55 per share.

(3)

Calculated as 5,558,432 shares of common stock reserved per the 2010 Stock Incentive Plan (being 15% of 37,056,215 shares issued and outstanding at January 1, 2015 per the renewal clause noted within the plan) less 3,350,168 shares of common stock noted in Column (a) and 64,000 shares exercised under the plan.

Description of the 2008 Equity Plan:

On February 27, 2008 Aspen’s Board of Directors adopted the 2008 Equity Plan (the “2008 Plan”). One million shares of common stock were initially reserved for the grant of stock options or issuance of stock bonuses under the 2008 Plan. The 2008 Plan was not approved by Aspen’s stockholders and therefore none of the options granted under the 2008 Plan qualify as incentive stock options under Section 422 of the Internal Revenue Code. The 2008 Plan provided that an option may be exercised through the payment of cash or remittance of any combination of cash, common shares of the Company, or property, as defined by the 2008 Plan. The options may also be exercised in accordance with the 2008 Plan’s cashless exercise provision. On July 27, 2010, the 2008 Plan was terminated, although persons holding vested options under the 2008 Plan continued to hold those options in accordance with the terms of their contractual agreement(s). As of March 12, 2015 all of the options granted under the 2008 Plan have either been exercised or expired.

Description of the 2010 Stock Incentive Plan:

On July 27, 2010 the Company’s Board of Directors adopted the 2010 Stock Incentive Plan (the “2010 Plan”). The 2010 Plan permits the granting of equity-based awards to our directors, officers, employees, consultants, independent contractors and affiliates. Equity-based awards are intended to be determined by a compensation committee (or, in the absence of a compensation committee, the Board of Directors and in either case referred to herein as the “Committee”) and are granted only in compliance with applicable laws and regulatory policy.

The 2010 Plan was approved by the Company’s stockholders in October 2010 and permits 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”). In the absence of a compensation committee, the Board of Directors administers the 2010 Plan. Any employee, officer, consultant, independent contractor or director providing services to the Company or any of its affiliates, who is selected by the Committee, is eligible to receive an award under the 2010 Plan.

When the 2010 Plan was adopted, the aggregate number of shares of our common stock that could be issued was 3,500,000 shares of common stock. Beginning on January 1, 2012 and on January 1 of each subsequent year that the 2010 Plan is in effect, the aggregate number of Shares that may be issued under the 2010 Plan shall be automatically adjusted to equal 15% of the Company’s issued and outstanding shares of common stock, calculated as of January 1 of the respective year. As a result of the January 1, 2015 adjustment, the maximum number of shares that are subject to equity awards under the 2010 Plan was increased to 5,558,432. The maximum number of shares of restricted stock, restricted stock units and stock awards that may be granted under the 2010 Plan is 2,000,000 shares.

The 2010 Plan permits the granting of:

	●	Stock options (including both incentive and non-qualified stock options);
	●	Stock appreciation rights (“SARs”);
	●	Restricted stock and restricted stock units;
	●	Performance awards of cash, stock, other securities or property;
	●	Other stock grants; and
	●	Other stock-based awards.

Unless sooner discontinued or terminated by the Board, the 2010 Plan will expire on July 27, 2020. No awards may be made after that date. However, unless otherwise expressly provided in an applicable award agreement, any award granted under the 2010 Plan prior to expiration extends beyond the expiration of the 2010 Plan through the award’s normal expiration date.

Without the approval of the Company’s stockholders, the Committee will not re-price, adjust or amend the exercise price of any options or the grant price of any SAR previously awarded, whether through amendment, cancellation and replacement grant or any other means, except in connection with a stock dividend or other distribution, including a stock split, merger or other similar corporate transaction or event, in order to prevent dilution or enlargement of the benefits, or potential benefits intended to be provided under the 2010 Plan.

Other Compensation Arrangements:

On July 28, 2010, the Company entered into an agreement with an investor relations firm and as part of the compensation paid pursuant to that agreement granted each of the principals of the firm a warrant to purchase 112,500 shares of the Company’s common stock (a total of 225,000 shares). The warrants are exercisable at $0.49 per share for a four 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 42,500 and 182,500 of these warrants were exercised in 2014 and 2013, respectively and there are no remaining warrants outstanding at December 31, 2014.

On May 9, 2011, the Company entered into an agreement with a financial advisor and as part of the compensation paid pursuant to that agreement granted the advisor a warrant to purchase 100,000 shares of the Company’s common stock. The warrants are exercisable at $0.77 per share for a five year term. 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. As of December 31, 2014, 100,000 of these warrants remain outstanding.

In November 2012, the Company granted each of the principals of its existing investor relations firm a warrant to purchase 112,500 shares of the Company’s common stock (a total of 225,000 shares) for the firm’s part in creating awareness for the Company’s private equity placement, in November 2012, as discussed herein. The warrants are exercisable at $0.55 per share for a five year term. Each of the warrants may be exercised on a cashless basis. The warrants also provide that subject to various conditions, the holders have piggy-back registration rights with respect to the shares of common stock that may be acquired upon the exercise of the warrants. A total of 112,500 of these warrants were exercised in 2014 and 112,500 remain outstanding at December 31, 2014.

In connection with the Company’s private placement in November 2012, the Company granted warrants to purchase 449,456 shares of the Company’s common stock to numerous unaffiliated consultants, for services rendered for the finding and execution of multiple stock subscriptions agreements with several equity investors. These warrants are exercisable at $0.55 for a five year term and have the same terms and conditions as the warrants issued in the private placement. A total of 105,000 and 344,456 of these warrants were exercised in 2014 and 2013, respectively and there are no remaining warrants outstanding at December 31, 2014.

On November 29, 2012, the Company entered into an investor relations services agreement with an unaffiliated consulting firm. Pursuant to this services agreement, the Company issued the consulting firm 125,000 shares of common stock, at $0.40 per share, in lieu of cash fees. The Company also granted the consulting firm a warrant to purchase 200,000 shares of the Company’s common stock. The warrants became exercisable on May 31, 2013, based on certain conditions as set forth in the warrant agreement, at $0.40 per share for a five year term. Each of the warrants may be exercised on a cashless basis. The warrants also provide that subject to various conditions, the holders have piggy-back registration rights with respect to the shares of common stock that may be acquired upon the exercise of the warrants. A total of 200,000 of these warrants were exercised in 2014 and there are no remaining warrants outstanding at December 31, 2014.

Recent Sales of Unregistered Securities

During the period from November 3, 2014 through March 12, 2015, one holder of common stock warrants exercised those warrants and received shares of common stock as a result of such exercise. The warrants had originally been issued to a financial advisor as part of an advisory agreement. In total, warrants to acquire 100,000 shares of common stock at an exercise price of $0.77 per share were exercised by the financial advisor resulting in cash proceeds of $77,000.

The following sets forth the information regarding the issuance required by Item 701 of SEC Regulation S-K.

(a) Securities Sold: Common Stock, $0.005 par value, of the Company. The dates of the sales are outlined above.

(b) Underwriters and Other Purchasers. The persons who exercised the warrants were all accredited investors as that term is defined in the federal securities laws. 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.

(c) Consideration. Warrants to acquire 100,000 common shares were exercised resulting in cash proceeds to the Company of $77,000.

(d) Exemption from Registration Claimed. The shares were issued upon exercise of the warrants to accredited investors and to underwriters pursuant to the exemptions from registration under the Securities Act of 1933 found in Section 4(a)(2) thereof and Rule 506 thereunder, as well as in Section 4(a)(5) thereof in that each of the purchasers was an accredited investor, and Section 3(a)(9) inasmuch as each of the warrant holders was an existing security holder of the Company. The offer was made without any form of advertising or general solicitation, and each of the accredited investors represented to the Company that they acquired the shares and the underlying securities for investment purposes only and without a view toward further distribution.

(e) Terms of Conversion or Exercise. Not applicable.

(f) Use of Proceeds. Not applicable.

ITEM 6. SELECTED FINANCIAL DATA

Smaller reporting companies are not required to provide the information required by this Item.

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

The following discussion provides information regarding the results of operations for the years ended December 31, 2014 and 2013, and our financial condition, liquidity and capital resources as of December 31, 2014 and 2013. The financial statements and the notes thereto contain detailed information that should be referred to in conjunction with this discussion.

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 Form 10-K, as well as the Risk Factors and the Cautionary Note Regarding Forward-Looking Statements included above.

OVERVIEW

The Company provides well enhancement and fluid management services to the domestic onshore oil and natural gas industry. These services include frac water heating, hot oiling and acidizing (well enhancement services), and water hauling, fluid disposal, frac tank rental (fluid management services) and other general oilfield services. The Company owns and operates a fleet of more than 250 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 field in Colorado, the Bakken field in North Dakota, the Marcellus and Utica Shale fields in Pennsylvania and Ohio, the Jonah Field, Green River and Powder River Basins in Wyoming, the Eagle Ford Shale in Texas and the Mississippi Lime and Hugoton Fields in Kansas and Oklahoma.

The Company expects to continue to pursue its growth strategies of exploring additional acquisitions, potentially 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 its assets and equipment provided it can do so on reasonable terms and conditions. The Company will most likely require additional debt or equity financing to fund the costs necessary to expand the services it offers. There can be no assurance that the Company will be able to raise outside capital or have access to outside funding on reasonable terms, if at all.

RESULTS OF OPERATIONS

The following table shows selected financial data for the periods noted. Please see information following the table for management’s discussion of significant changes.

	For the Quarter Ended December 31,						For the Year Ended December 31,
	2014			2013			2014			2013
FINANCIAL RESULTS:
Revenues	$	18,278,289		$	15,154,458		$	56,563,944		$	46,472,677
Cost of Revenue		12,049,312			11,175,528			41,257,600			31,869,312
Gross Profit		6,228,977			3,978,930			15,306,344			14,603,365
Gross Margin		34	%		26	%		27	%		31	%

Income From Operations	$	3,729,331		$	2,411,487		$	6,948,399		$	8,248,865
Net Income	$	2,518,831		$	1,098,277		$	4,005,741		$	4,301,237
Earnings per Common Share – Diluted	$	0.07		$	0.03		$	0.10		$	0.12
Diluted weighted average number of common shares outstanding		38,702,938			37,359,035			38,999,005			37,113,017

OTHER:
Adjusted EBITDA*	$	5,267,873		$	2,921,819		$	11,476,118		$	10,999,633
Adjusted EBITDA* Margin		29	%		19	%		20	%		24	%

^(*)

Management believes that, for the reasons set forth below, adjusted EBITDA and adjusted EBITDA margin (even though a non-GAAP measure) is a valuable measurement of the Company's liquidity and performance and is consistent with the measurements offered by other companies in our industry. See further discussion of our use of EBITDA, the risks of non-GAAP measures, and the reconciliation to Net Income, in item 7.

Although the Company does not have segmented business operations, which would require segment reporting within the notes of its financial statements per accounting standards, we believe that revenue by service offering may be useful to readers of our financial statements. The following tables set forth revenue from operations for the Company’s three service offerings during the quarter and fiscal years ended December 31, 2014 and 2013:

	For the Quarter Ended December 31,				For the Year Ended December 31,
	2014		2013		2014		2013
BY SERVICE OFFERING:
Well Enhancement Services ⁽¹⁾	$	16,086,194	$	12,638,091	$	47,511,850	$	37,160,625

Fluid Management ⁽²⁾		2,034,552		2,443,353		8,515,583		9,014,182

Other ⁽³⁾		157,543		73,014		536,511		297,870

Total Revenues	$	18,278,289	$	15,154,458	$	56,563,944	$	46,472,677

The Company has also determined that an understanding of the diversity of its operations by geography is important to an understanding of its business operations. 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 quarter and fiscal years ended December 31, 2014 and 2013:

	For the Quarter Ended December 31,				For the Year Ended December 30,
	2014		2013		2014		2013
BY GEOGRAPHY:
Rocky Mountain Region ⁽⁴⁾	$	12,531,770	$	9,331,292	$	33,827,814	$	26,059,306

Central USA Region⁽⁶⁾		3,204,662		2,932,146		12,680,429		11,996,320

Eastern USA Region ⁽⁵⁾		2,541,857		2,891,020		10,055,701		8,417,051

Total Revenues	$	18,278,289	$	15,154,458	$	56,563,944	$	46,472,677

Notes to tables:

(1)

Includes frac water heating, acidizing, hot oil services, and pressure testing.

(2)

Includes water hauling, fluid disposal and frac tank rental.

(3)

Includes construction and roustabout services.

(4)

Includes the D-J Basin/Niobrara field (northern Colorado and southeastern Wyoming), the Powder River and Green River Basins (central Wyoming), the Bakken Field (western North Dakota and eastern Montana). Heat Waves is the only Company subsidiary operating in this region.

(5)

Includes the Mississippi Lime and Hugoton Field in Kansas, Oklahoma, and Texas. Both Dillco and Heat Waves engage in business operations in this region.

(6)

Consists of the southern region of the Marcellus Shale formation (southwestern Pennsylvania and northern West Virginia) and the Utica Shale formation (eastern Ohio). Heat Waves is the only Company subsidiary operating in this region.

Revenues:

Revenues from operations increased $10.1 million or 22% to a record annual revenue of $56.6 million for the year ended December 31, 2014. The revenue growth for 2014 was primarily attributable to revenues from our well enhancement services, which increased $10.4 million or 28% from 2013 and overcame a 6% decline in revenues from fluid management services. As discussed below, the increase in well enhancement revenues during 2014 was partially offset by lower propane revenues and unseasonably warm weather during our 2014 fourth quarter.

Well Enhancement Services:

Well enhancement services increased $10.4 million or 28% to $47.5 million for the year ended December 31, 2014 primarily due to a 17% and 62% increase in frac water heating and hot oil services, respectively. Increased heating capacity due to the addition of new equipment combined with increased utilization of hot oil trucks were the primary reason for the increase over last year. The following table details the increase in heating capacity.

	Frac Water Heater Burner Boxes ⁽¹⁾				Hot Oil Trucks
	Q4 2014		FY2014		Q4 2014		FY 2014

Net Additions		30		41		19		24
Ending Units		81		81		51		51

Average Equivalent Units ⁽²⁾		66.0		48.9		38.2		30.8
Average Equivalent Units – Last Year		36.5		35.2		26.0		26.0
Change from same period last year		29.5		13.7		12.2		4.8
Increase in Equivalent Heating Capacity ⁽³⁾		81%		39%		47%		19%

Notes to tables:

(1)

The Company’s bobtail frac heaters are equal to one burner box whereas the Company’s double burner frac heaters and mega frac heaters are the equivalent of 2 burner boxes.

(2)

Average equivalent units represents the average number of trucks or burner boxes in service for each month during the period represented.

(3)

The increase in equivalent heating capacity represents the % change in equivalent units during the period over the equivalent units for the same period last year.

Revenues from frac water heating services increased $4.6 million or 17% to $31.3 million for the year ended December 31, 2014 primarily due to a 39% increase in equivalent heating capacity during 2014 as compared to last year. The majority of the increase came in the fourth quarter of 2014, when the Company placed into service 18 mega heaters (equivalent to 36 burner boxes) from the Company’s 2014 CAPEX program. The incremental revenues from the additional heating capacity was partially mitigated by lower revenues from a safety related halt in frac water heating services by a major customer in the second quarter and unseasonably warm weather in October and early November of 2014.

Propane revenues from frac water heating service fluctuated significantly during 2014 due to significant changes in propane prices, changes in billing methods, and customer utilization of our new bi-fuel capabilities. During the first quarter of 2014, a sharp increase in propane prices and a shift to cost plus billing for several customers in our Rocky Mountain region resulted in an approximately $2.4 million increase in propane revenues over the comparable first quarter of 2013. Conversely, during the fourth quarter of 2014, propane revenues dropped approximately $2.5 million over the comparable fourth quarter last year due to a 38% decrease in propane prices combined with a significant drop in propane usage as several customers took advantage of our new bi-fuel capabilities and provided natural gas or well gas to use as our fuel source thereby reducing the amount of propane used and billed to customers. Although, the introduction of bi-fuel capabilities have reduced our propane revenues and costs, it has helped to gain market share in several locations. These fluctuations in propane volumes and prices also impacted cost of goods sold and gross profit margins. See further discussion of these impacts in the gross profit and propane discussion below.

Hot oil revenues increased $5.2 million or 62% to $13.4 million in 2014 primarily due to an increase in equipment capacity and higher utilization over last year. During 2014, the Company added 24 hot oil trucks to its fleet increasing its annual equivalent heating capacity by 19% over last year. The majority of the increase came in the fourth quarter when the company placed into service 8 trucks from its 2014 CAPEX program and added another 12 trucks from an asset acquisition in North Dakota. These resulted in an increase in equivalent heating capacity of 81% for the fourth quarter of 2014. Hot oil equipment utilization increased 37% during 2014 as compared to 2013 primarily due to the expansion of the Company’s services in Wyoming and North Dakota.

Acidizing revenues increased $596,000 or 29% despite some significant challenges in obtaining hydrochloric acid during the second and third quarter due to national shortages. The addition of two new acid trucks and transports in late June was the primary reason for the overall increase in revenues.

Fluid Management:

Fluid management service revenues, which represent approximately 15% of our 2014 consolidated revenues, declined $499,000 or 6% during 2014 as compared to last year primarily due to a decline in water hauling revenues in the Hugoton Basin. With the growth and expansion of well enhancement services, we anticipate that fluid management services will continue to decline as a percentage of our consolidated revenues.

Geographic Areas:

For the year ended December 31, 2014, revenues in the Rocky Mountain Region increased $7.8 million or 30% from last year due to several factors including (i) increased frac water heating activity in the Niobrara Shale/DJ Basin; (ii) increased hot oiling and acidizing revenues related to expansion of service into Rock Springs, Wyoming and (iii) increased frac water heating and hot oiling revenues from our asset acquisition in Tioga, North Dakota.

Revenues in the Eastern USA region increased $1.6 million or 19% to $10.1 million for the year ended December 31, 2014 primarily due to higher frac water services in the Utica Shale field during the first quarter of 2014. The addition of two new customers during the first quarter combined with a significant increase in propane prices during the first quarter contributed to the increase. These increases were partially offset by lower propane prices in fourth quarter of 2014 as compared to the fourth quarter last year.

Revenues in the Central USA region increased $684,000 or 6% from last year primarily due to an increase in frac water heating and hot oil services related to our expansion of services in Texas and was partially mitigated by a slight decline in water hauling services in the Hugoton Basin.

Historical Seasonality of Revenues:

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

As an indication of this quarter-to-quarter seasonality, the Company generated revenues of $43.5 million or 77% of its 2014 revenues during the first and fourth quarters of 2014 compared to $13.1 million or 23% during the second and third quarters of 2014. In 2013, the Company earned revenues of $33.7 million or 73% of its 2013 revenues during the first and fourth quarters of 2013, compared to $12.8 million or 27% during the second and third quarters of 2013. While the Company is pursuing various strategies to lessen these quarterly fluctuations by increasing non-seasonal business opportunities, there can be no assurance that we will be successful in doing so.

Cost of Revenues:

Cost of revenues for the year ended December 31, 2014 increased $9.4 million or 29% from the comparable period last year primarily due to increased labor costs, higher fleet costs and expenses related to our fleet and geographic expansion. As the Company's fleet of trucks has expanded, expenses such as labor, insurance and repairs and maintenance have increased correspondingly. Labor costs also increased significantly during the third quarter due to the incremental cost to hire and train a large number of additional frac water heating operators and hot oil truck operators for our fleet expansion and additional labor costs to test and demonstrate our ability to use natural gas and wellhead gas as a fuel source. In addition, we also spent approximately $650,000 during 2014 to expand our safety program. As described above, changes in propane prices and volumes during the first and fourth quarter of 2014 also impacted cost of revenues as compared to the same quarters last year.

Gross Profit:

Gross profit for the year ended December 31, 2014 increased $703,000 or 5% to $15.3 million dollars primarily due to strong well enhancement revenues during the Company’s first and fourth quarter of 2014 as compared to the same periods last year. Increased heating capacity during the Company’s fourth quarter resulted in a $2.3 million or 58% increase in gross profit over the same quarter in 2013. The fourth quarter increase in gross profits was tempered by unseasonably warm weather during October and November of 2014. Further, the annual gross profits were tempered by lower frac water heating revenues during the 2014 second quarter and higher labor costs during the third quarter of 2014 as compared to the same quarters last year.

Gross profit as a percentage of revenue declined to 27% for the year ended December 31, 2014 as compared to 31% for the comparable period last year. In addition to the factors mentioned above, the largest impact on the gross profit percentage decline was due to the mathematical impacts of higher propane costs experienced in the first quarter (see “Propane Impact Discussion” below). In addition, the continuing decline in revenues and the resultant lower operating margins in our fluid management business during 2014 has contributed to the overall decline in our gross profit percentage from last year.

Propane Impact Discussion:

Prior to January 2014, many of our frac water heating customers in the DJ Basin were billed on a “per barrel of water heated” basis which included the price of propane. As result, our gross profit percentage was immediately impacted once propane prices started to rise in December 2013 and was further impacted as prices continued to rise significantly in January 2014. In late January and early February, the Company was able to renegotiate pricing for propane with customers in the DJ Basin to a cost plus basis which is similar to the billing method we use in our other regions. Under this method, propane is billed at cost plus a fixed dollar per gallon mark-up. This change in pricing eliminated the negative impact on gross profit and gross profit percentage due to increases in propane prices. Management estimates that the negative impact to gross profits from higher propane prices under the old per barrel billing prior to price renegotiations was approximately $500,000 for the quarter ended March 31, 2014.

Conversely, propane revenues and costs declined in the Company’s most recent fourth quarter as compared to the fourth quarter of 2013. A 38% decline in propane prices and combined with a reduction in propane volumes related to customers utilizing our new bi-fuel capabilities whereby customers provide natural gas or well gas as their fuel source thereby reducing the amount of propane used and billed to customers. Although, the bi-fuel capabilities have reduced our propane revenues and costs, it has helped to gain market share in several locations.

Changes in propane prices impact our gross profit percentages for customers that use propane. Higher propane prices tend to reduce gross profit percentages on frac heating customers which bill propane on a cost plus basis. Typically, our mark-up on propane is a fixed dollar amount per gallon. Therefore, as propane prices increase, this fixed dollar mark-up becomes a smaller percentage of the billed propane costs resulting in a lower gross profit percentages. The increase in propane prices also causes propane revenues to become a larger portion of total revenues. As a result, the lower propane margins tend to dilute our overall gross profit percentage. We estimate that the higher propane prices and corresponding impact diluted our overall gross profit percentage in 2014 by approximately 1% of revenues.

The Company anticipates that propane prices will continue to fluctuate in the future based on the relative demand and availability of propane in different geographic areas across the United States. Since the Company passes along the cost of propane to its customers on a cost plus mark-up basis, fluctuations in the price of propane will continue to impact revenues, cost of revenues and gross profit percentages. Decreases in propane prices will tend to reduce well enhancement revenues and cost of revenues and may increase our overall gross profit percentage as the dollar value of lower margin propane revenue and cost of revenue becomes a lower percentage of total revenue. Conversely, increases in propane prices similar to what the Company experienced during the Company’s first quarter, will tend to increase well enhancement revenues and cost of revenues and may decrease our gross profit percentage, as the dollar value of lower margin propane revenue and cost of revenue becomes a higher percentage of total revenue.

General and Administrative Expenses:

For the year ended December 31, 2014, general and administrative expenses increased $317,000 or 8% from 2013. Higher personnel and office costs to support the Company’s growth combined with higher costs related to the Company’s listing on the NYSE MKT exchange were the primary reasons for the increase. Stock based compensation related to option grants also contributed to the increase. Bad debt expense, which is included in general and administrative expense, declined $153,000 partially mitigating some of the increases above.

As a percentage of revenues, general and administrative expenses decreased to 8% of revenues for the year ended December 31, 2014 as compared to 9% of revenues for the year ended December 31, 2013.

Patent Litigation and Defense Costs:

Patent litigation and defense costs increased in 2014 as compared to 2013 as a result of the Company’s defense of the HOTF litigation described in Item 3 – Litigation, and legal and professional fees related to the Company’s efforts to defend the positions taken therein. It can be expected that these legal fees will continue at this higher level as long as the litigation continues. Enservco and Heat Waves deny that they are infringing any valid, enforceable claims of the asserted HOTF patents and intend to vigorously defend themselves against the lawsuit and challenge the validity of the underlying patents.

Depreciation and Amortization:

Depreciation and amortization expense for the year ended December 31, 2014 increased $1.3 million, or 63% from 2013 primarily due to new equipment added over the last 18 months from the Company’s 2013 and 2014 CAPEX programs.

Income from operations:

For the year ended December 31, 2014, the Company recognized income from operations of approximately $6.9 million as compared to $8.2 million for the comparative period last year. As discussed above, strong top line revenue growth, particularly in our core well enhancement services, was offset by higher cost of revenues associated with our fleet and geographic expansion. During 2014, the Company incurred higher labor costs to train and hire additional operators, expand our safety program, and demonstrate our ability to use natural gas and wellhead gas with our new bi-fuel system. The Company also incurred additional personnel and facility costs to expand our operations in Wyoming, Texas and North Dakota. We believe these incremental costs will benefit our future expansion efforts in 2015 and beyond. Furthermore, unexpected frac water heating downtime in the second quarter and unseasonably warm weather in the fourth quarter also resulted in additional labor costs while we waited to resume services. Higher operating costs including a $1.3 million increase in depreciation and amortization costs associated with the Company’s fleet expansion also contributed to the lower income from operations.

Management believes that the decline in our results of operations, in particular the increase in general and administrative expenses and depreciation expense reflects the incremental costs incurred to expand our fleet and geographic footprint (as discussed throughout this report). We believe that as long as we are able to control our costs and increase our revenues as a result of our expanding fleet and service areas, our financial performance will continue to improve over the long run, although on a quarter-to-quarter basis, there may still be periods of loss due to the seasonality of our operations, as discussed several times herein.

Interest Expense:

Interest expense for the year ended December 31, 2014 decreased $283,000 or 26% from 2013 primarily due to reduction in effective interest rates related to 2014 PNC credit facility and capitalization of $139,000 of interest expense during 2014 related to the Company’s fabrication of equipment under the Company’s CAPEX programs.

Income Taxes:

For the year ended December 31, 2014, the Company recognized income tax expense of $2.4 million on pre-tax net income before taxes of approximately $6.4 million as compared to income tax expense of $3.1 million on pre-tax net income of $7.4 million in 2013. The effective tax rate on income from operations for 2014 was approximately 37%. This rate is higher than the federal statutory corporate tax rate of 34% primarily due to state and local income taxes. See Note 7 Income Taxes in the notes to the accompanying audited consolidated financial statements for further details.

Adjusted EBITDA*:

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

Management uses these non-GAAP measures in its operational and financial decision-making, believing that it is useful to eliminate certain items in order to focus on what it deems to be a more reliable indicator of ongoing operating performance and the company’s ability to generate cash flow from operations. Management also believes that investors may find non-GAAP financial measures useful for the same reasons, although investors are cautioned that non-GAAP financial measures are not a substitute for GAAP disclosures.

The following table presents a reconciliation of net income to Adjusted EBITDA for each of the periods indicated:

	For the Quarter Ended December 31,						For the Year Ended December 31,
	2014			2013			2014			2013
EBITDA*
Net Income	$	2,518,831		$	1,098,277		$	4,005,741		$	4,301,237
Add Back
Interest Expense		70,670			259,861			791,159			1,073,875
Provision for income taxes expense		1,315,241			916,289			2,371,872			3,079,330
Depreciation and amortization		1,113,478			394,896			3,402,330			2,088,767
EBITDA*		5,018,220			2,669,323			10,571,102			10,543,209
Add Back (Deduct)
Stock-based compensation		42,385			26,357			562,903			472,356
Patent litigation and defense costs		382,679			89,079			562,486			189,645
Loss (Gain) on sale and disposal of equipment		(170,159	)		144,105			(179,903	)		(169,194	)
Interest and other income		(5,252	)		(7,045	)		(40,470	)		(36,383	)
Adjusted EBITDA*	$	5,267,873		$	2,921,819		$	11,476,118		$	10,999,633

*Note: See discussion to follow below for use of non-GAAP financial measurements.

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

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

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

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

Changes in Adjusted EBITDA*

Adjusted EBITDA from operations increased $476,000 or 4% to $11.5 million for the year ended December 31, 2014 as compared to $11.0 million for 2013. This increase was primarily due to a $2.3 million or 80% increase in Adjusted EBITDA for the fourth quarter of 2014 as compared to fourth quarter last year. Increased well enhancement revenues and gross profits within our Rocky Mountain region were the primary reason for the fourth quarter increase in Adjusted EBITDA.

Despite the significant increase in Adjusted EBITDA during the fourth quarter of 2014, Adjusted EBITDA for the year ended December 31, 2014 was tempered due to several factors mentioned above including the unseasonably warm weather in October and November 2014 that delayed the start of the 2014-2015 frac water heating season, fluctuating propane prices during 2014 as compared to last year, and reduction in propane revenues due to impact of customers taking advantage of our bi-fuel capabilities. Management estimates the negative impact on Adjusted EBITDA for these items was approximately $1.6 million for the fourth quarter of 2014 and approximately $2.9 million for the year ended December 31, 2014.

LIQUIDITY AND CAPITAL RESOURCES

The following table summarizes our statements of cash flows for the years ended December 31, 2014 and 2013 and (combined with the working capital table and discussion below) is important for understanding our liquidity:

	Years Ended December 31,
	2014			2013

Net cash provided from operating activities	$	6,225,338		$	5,324,900
Net cash used in investing activities		(23,585,603	)		(3,783,558	)
Net cash provided by (used in) financing activities		16,446,133			(206,779	)
Net (Decrease) Increase in Cash and Cash Equivalents		(914,132	)		1,334,563

Cash and Cash Equivalents, Beginning of Period		1,868,190			533,627

Cash and Cash Equivalents, End of Period	$	954,058		$	1,868,190

The following table sets forth a summary of certain aspects of our balance sheets at December 31, 2014 and 2013:

	Years Ended December 31,
	2014		2013

Current Assets	$	19,475,754	$	15,129,379
Total Assets (including assets of discontinued operations)		58,282,681		33,422,248
Current Liabilities		5,812,683		6,955,618
Total Liabilities		40,241,369		20,577,132
Working Capital (Current Assets net of Current Liabilities)		13,663,071		8,173,761
Stockholders’ equity		18,041,312		12,845,116

Overview:

We have relied on cash flow from operations, borrowings under our revolving credit facilities, and equipment financing to satisfy our liquidity needs. Our ability to fund operating cash flow shortfalls, fund capital expenditures, and make acquisitions will depend upon our future operating performance and on the availability of equity and debt financing. At December 31, 2014, we had approximately $954,000 of cash and cash equivalents and approximately $11.1 million available under our asset based senior revolving credit facility.

In September 2014, the Company entered into an Amended and Restated Revolving Credit and Security Agreement (the “2014 Credit Agreement”) with PNC Bank, National Association ("PNC") which provides for a five-year $30 million senior secured revolving credit facility (which was subsequently increased to $40 million in December 2014). The facility replaced the Company’s prior revolving credit facility and term loan with PNC that totaled $16 million (the "2012 Credit Agreement") and allows the Company to borrow up to 85% of eligible receivables, 85% of the appraised value of trucks and equipment, and up to 90% of the cost of new equipment. The Company has the option to pay variable interest rate based on (a) 1, 2 or 3 month LIBOR plus applicable margin ranging from 2.50% to 3.50% for LIBOR Rate Loans or (b) interest at PNC Base Rate plus applicable margin of 1.00% to 2.00% for Domestic Rate Loans. The interest rate at December 31, 2014 ranged from 2.65% to 2.67% for the $27,400,000 of LIBOR Rate Loans and 4.25% for the $1,234,037 of Domestic Rate Loans.

As of December 31, 2014, the Company had an outstanding loan balance of $28.6 million and approximately $11.1 million available under the revolving credit facility.

The PNC credit facility has certain customary financial covenants that include, among others:

(i)

a minimum fixed charge coverage ratio (as defined, not less than 1.15 to 1.0, for the fiscal quarter ended December 31, 2014, and 1.25 to 1.00, for the quarter ended March 31, 2015 and each subsequent fiscal quarter thereafter, measured as of the last day of each fiscal quarter based on trailing twelve month information.); and

(ii)

a maximum leverage ratio of funded debt to adjusted EBITDA (as defined, not more than 3.00 to 1.0 for the quarter ended December 31, 2014 and 2.75 to 1.0 for the quarter ended March 31, 2015 and each subsequent quarter, measured as of the last day of each fiscal quarter, adjusted EBITDA must be determined based on trailing twelve month information).

These financial covenants could restrict our ability to secure additional debt financing or access funds under our revolving credit facility. At December 31, 2014, the Company did not meet one of the financial covenants imposed by the PNC loan agreements which resulted in an event of default under the loan documents. PNC waived this event of default for the period. As a result of the waiver, no default was declared. The Company believes that it is in line to meet the debt covenants and all other future covenant requirements.

The Company used the facility to fund a portion of its 2014 capital expenditures and consolidate its existing PNC term loan and other equipment loans at a lower average interest rate. The Company intends to use the facility to supplement future capital expenditures and to fund working capital needs.

Working Capital:

As of December 31, 2014 the Company had working capital of approximately $13.7 million, an increase in working capital of approximately $5.5 million as compared to our 2013 fiscal year end. This significant increase in working capital was attributable to the more than $6.2 million of cash flow from operations generated in 2014. Accounts receivable also increased $3.0 million or 26% from the comparable period last year due to higher monthly revenues during the fourth quarter of 2014.

Cash flow from Operating Activities:

Cash flow from operating activities for the year ended December 31, 2014 increased $900,000 or 17% from 2013 primarily due to increased cash flows related to higher revenues in 2014. This increase in cash flow from operations during 2014 was partially offset by approximately $4.7 million of net cash outflows for changes in working capital with a majority of this change related to increases in accounts receivable and income tax receivable.

Cash flow Used In Investing Activities:

Cash flow used in investing activities for the fiscal year 2014 was $23.6 million as compared to $3.8 million during the comparable period last year. The $19.8 million increase was primarily due to the large increase in capital expenditures to purchase and fabricate new equipment under the Company’s 2014 CAPEX program and to acquire $4 million of facilities and hot oil trucks in North Dakota. During 2013, the Company expended $5.8 million to purchase and fabricate equipment under its 2013 CAPEX program and was partially offset by $2.1 million of cash proceeds from the sale of well-site construction equipment.

Cash flow from Financing Activities:

Cash provided by financing activities for fiscal 2014 was $16.4 million as compared to cash used in financing activities of $207,000 for the comparable period last year. During 2014, the Company used proceeds of $28.6 million from its senior revolving credit facility to pay off $12.6 million in term debt and to fund $16.0 million of capital expenditures. During 2013, the Company used $3.0 million to make scheduled principal payments under its existing term debt which was offset by $1.6 million of net borrowings under the revolving credit facility and $1.2 million of cash proceeds from warrant exercises

Outlook:

The Company plans to continue to expand its business operations through organic growth such as geographic expansion, acquiring and fabricating additional equipment, and increasing the volume and scope of services offered to our existing customers. The Company will also look to expand its business operations through acquisitions. The Company will continue to focus on adding high margin services that reduce our seasonality, diversify our service offerings, and maintain a good balance between recurring maintenance work and drilling and completion related services.

As discussed above, in September 2014 the Company closed on a five-year, $30 million revolving credit facility, which was subsequently increased to $40 million in December 2014. As of December 31, 2014, the Company had $11.1 million available under the credit facility and plans to use the facility to fund working capital needs and to supplement future capital expenditures.

On April 16, 2014, the Company filed a Registration Statement on Form S-3 with the Securities and Exchange Commission (SEC) that was declared effective by the SEC on April 30, 2014. The Form S-3 provides the Company with the flexibility to offer and sell from time to time, up to $50 million of the Company’s common stock in order to supplement our cash flows from operations and financing activities. The Company currently does not have any immediate plans to sell securities under the shelf registration statement, but plans to maintain the registration statement in the event there is a need to supplement its existing capital resources.

Capital Commitments and Obligations:

The Company’s capital obligations as of December 31, 2014 consists primarily of scheduled principal payments under certain term loans and operating leases. The Company does not have any scheduled principal payments under its new five-year, $40 million revolving credit facility with PNC Bank. However, the Company may need to make future principal payments based upon collateral availability and to maintain required leverage ratios. General terms and conditions for amounts due under these commitments and obligations are summarized in the notes to the financial statements.

As of December 31, 2014, the Company had approximately $1.9 million in outstanding purchase commitments that are necessary to complete the purchase and fabrication of eight hot oil trucks and an acid truck included in the Company’s 2014 CAPEX programs. The Company intends to finance the remaining purchase commitments of this equipment through cash flow from operations and through its senior revolving credit facility.

As of March 12, 2015, the Company has not established a 2015 CAPEX program.

OFF-BALANCE SHEET ARRANGEMENTS

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

CRITICAL ACCOUNTING POLICIES

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

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

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

Accounts Receivable:

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

Revenue Recognition:

The Company recognizes revenue when evidence of an arrangement exists, the fee is determinable, and services are provided and collection is reasonably assured.

Property and Equipment:

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

Long-Lived Assets:

The Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recovered. The Company looks primarily to the discounted future cash flows in its assessment of whether or not long-lived assets have been impaired. No impairments were recorded during the years ended December 31, 2014 or 2013.

Income Taxes:

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

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

Interest and penalties associated with tax positions are recorded in the period assessed as income tax expense. The Company files income tax returns in the United States and in the states in which it conducts its business operations. The Company’s United States federal income tax filings for tax years 2011 through 2014 remain open to examination. In general, the Company’s various state tax filings remain open for tax years 2010 to 2014.

Stock-based Compensation:

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

The Company also uses the Black-Scholes valuation model to determine the fair value of warrants. Expected volatility is based upon the weighted average of historical volatility over the contractual term of the warrant and implied volatility. The risk-free interest rate is based upon implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the contractual term of the warrants. The dividend yield is assumed to be none.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not required.

ITEM 8. FINANCIAL STATEMENTS

The information required by this Item begins on page 51 of Part III of this report on Form 10-K and is incorporated into this part by reference.

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

None.

ITEM 9A CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

Our management, under the direction of our Chief Executive Officer (who is our principal executive officer), and Chief Financial Officer (who is our principal accounting officer) has evaluated the effectiveness of our disclosure controls and procedures as required by 1934 Act Rule 13a-15(b) as of December 31, 2014 (the end of the period covered by this report). Based on that evaluation, our principal executive officer and our principal accounting officer concluded that these disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed by the Company in the reports that it files or submits under the 1934 Act is accumulated and communicated to management, including the Chief Executive Officer and the Chief Financial Officer, to allow timely decisions regarding required disclosure and are effective to provide reasonable assurance that such information is recorded, processed, summarized and reported within the time periods specified by the SEC’s rules and forms.

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

Management’s Annual Report on Internal Control Over Financial Reporting

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

Internal Control Over Financial Reporting

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

(1)

Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company;

(2)

Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with proper authorizations of management and our directors; and

(3)

Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company’s assets that could have a material effect on the financial statements.

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

As of December 31, 2014, management (with the participation of the Chief Executive Officer and the Chief Financial Officer) conducted an evaluation of the effectiveness of the Company’s ICFR based on the framework set forth in Internal Control--Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) and SEC guidance on conducting such assessments by smaller reporting companies and non-accelerated filers. Based on that assessment, management (with the participation of the Chief Executive Officer and the Chief Financial Officer) concluded that, during the period covered by this report, such internal controls and procedures were effective as of December 31, 2014.

ITEM 9B. OTHER INFORMATION

None.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The information responsive to Items 401, 405, 406 and 407 of Regulation S-K to be included in our definitive Information Statement for our 2015 Annual Meeting of Shareholders, to be filed within 120 days of December 31, 2014, pursuant to Regulation 14A under the Securities Exchange Act of 1934, as amended (the “Information Statement”), is incorporated herein by reference.

ITEM 11. EXECUTIVE COMPENSATION

The information responsive to Items 402 and 407 of Regulation S-K to be included in our Information Statement is incorporated herein by reference.

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

The information responsive to Items 201(d) and 403 of Regulation S-K to be included in our Information Statement is incorporated herein by reference.

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

The information responsive to Items 404 and 407 of Regulation S-K to be included in our Information Statement is incorporated herein by reference.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

The information responsive to Item 9(e) of Schedule 14A to be included in our Information Statement is incorporated herein by reference.

PART IV.

ITEM 15. EXHIBITS

Exhibit No.		Title

3.01		Second Amended and Restated Certificate of Incorporation. ⁽¹⁾
3.02		Amended and Restated Bylaws. ⁽²⁾
10.01		2008 Equity Plan. ⁽³⁾
10.02		2010 Stock Incentive Plan. ⁽²⁾
10.03		Employment Agreement between the Company and Rick Kasch. ⁽²⁾⁽⁴⁾⁽⁵⁾⁽⁶⁾⁽¹¹⁾⁽⁸⁾
10.04		Employment Agreement between the Company and Austin Peitz. ⁽⁸⁾
10.05		Employment Agreement between the Company and Robert Devers. ⁽⁸⁾
10.06		Form of Indemnification Agreement. ⁽¹⁰⁾
10.08		Amended and Restated Revolving Credit and Security Agreement dated as of September 12, 2014 ⁽⁷⁾
10.09		Consent and First Amendment to Amended and Restated Revolving Credit and Security Agreement dated February 27, 2015 ⁽⁹⁾
11.1		Statement of Computation of per share earnings. Filed herewith. (contained in Note 2 to the Consolidated Financial Statements).
14.1		Code of Business Conduct and Ethics Whistleblower Policy. ⁽¹¹⁾
14.2		Related Party Transaction Policy. ⁽¹¹⁾
14.3		Audit Committee Charter. ⁽¹¹⁾
21.1		Subsidiaries of Enservco Corporation. Filed herewith.
23.2		Consent from EKS&H LLLP regarding Form S-8. Filed herewith.
31.1		Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Principal Executive Officer). Filed herewith.
31.2		Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Principal Financial Officer). Filed herewith.
32.1		Certification pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes- Oxley Act of 2002 (Chief Executive Officer). Filed herewith.
32.2		Certification pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes Oxley Act of 2002 (Chief Financial Officer). Filed herewith.

101.INS		XBRL Instance Document
101.SCH		XBRL Schema Document
101.CAL		XBRL Calculation Linkbase Document
101.LAB		XBRL Label Linkbase Document
101.PRE		XBRL Presentation Linkbase Document
101.DEF		XBRL Definition Linkbase Document

(1)	Incorporated by reference from the Company’s Current Report on Form 8-K dated December 30, 2010, and filed on January 4, 2011.

(3)	Incorporated by reference from the Company’s Current Report on Form 8-K dated July 27, 2010, and filed on July 28, 2010.

(4)	Incorporated by reference from the Company’s Current Report on Form 8-K dated February 27, 2008, and filed on March 10, 2008.

(5)	Incorporated by reference from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2011, and filed on August 15, 2011.

(6)	Incorporated by reference from the Company’s Current Report on Form 8-K dated February 10, 2012, and filed on February 13, 2012.

(7)	Incorporated by reference from the Company’s Current Report on Form 8-K dated September 12, 2014, and filed on September 18, 2014.

(8)	Incorporated by reference from the Company’s Current Report on Form 8-K dated July 1, 2014, and filed on July 3, 2014.

(9)	Incorporated by reference from the Company’s Current Report on Form 8-K dated February 27, 2015, and filed on March 5, 2015.

(10)	Incorporated by reference from Exhibit 10.07 to the Company’s Annual Report on Form 10-K dated December 31, 2013 and filed on March 20, 2014.

(11)	Incorporated by reference from Exhibit 10.03 to the Company’s Form 10-K/A for the year ended December 31, 2012 and filed on October 8, 2013.

(12)	Incorporated by reference from the Company’s Current Report on Form 8-K dated May 29, 2013, and filed on May 31, 2013.

SIGNATURES

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

March 19, 2015

	ENSERVCO CORPORATION,
	a Delaware Corporation

	/s/ Rick D. Kasch
	Principal Executive Officer

	/s/ Robert J. Devers
	Principal Financial Officer & Principal Accounting Officer

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

Date	Name and Title	Signature

March 19, 2015	Rick D. Kasch	/s/ Rick D. Kasch
	Chief Executive Officer (principal executive officer), and Chairman of the Board

March 19, 2015	Robert J. Devers	/s/ Robert J. Devers
	Treasurer and Chief Financial Officer (principal financial officer and principal accounting officer)

March 19, 2015	Steven P. Oppenheim	/s/ Steven P. Oppenheim
	Director

March 19, 2015	Keith J. Behrens	/s/ Keith J. Behrens
	Director

March 19, 2015	Robert S. Herlin	/s/ Robert S. Herlin
	Director

March 19, 2015	William A. Jolly	/s/ William A. Jolly
	Director

ENSERVCO CORPORATION AND SUBSIDIARIES

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

	Page

Report of Independent Registered Public Accounting Firm	52

Financial Statements as of December 31, 2014 and 2013:

Consolidated Balance Sheets	53

Consolidated Statements of Operations and Comprehensive (Loss) Income	54

Consolidated Statement of Stockholders’ Equity	55

Consolidated Statements of Cash Flows	56-57

Notes to Consolidated Financial Statements	58-77

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders

Enservco Corporation

Denver, Colorado

We have audited the accompanying consolidated balance sheets of Enservco Corporation and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive (loss) income, stockholders' equity, and cash flows for each of the years ended December 31, 2014 and 2013. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Enservco Corporation and subsidiaries as of December 31, 2014 and 2013, and the consolidated results of their operations and their cash flows for each of the years ended December 31, 2014 and 2013, in conformity with accounting principles generally accepted in the United States of America.

/s/ EKS&H LLLP

March 19, 2015

Denver, Colorado

ENSERVCO CORPORATION

Consolidated Balance Sheets

	December 31,		December 31,
	2014		2013

ASSETS
Current Assets
Cash and cash equivalents	$	954,058	$	1,868,190
Accounts receivable, net		14,679,858		11,685,866
Prepaid expenses and other current assets		1,540,667		923,758
Inventories		390,081		315,004
Income tax receivable		1,776,035		-
Deferred tax assets		135,055		336,561
Total current assets		19,475,754		15,129,379

Property and equipment, net		37,789,004		17,425,828
Goodwill		301,087		301,087
Long-term portion of interest rate swap		-		18,616
Other assets		716,836		547,338

TOTAL ASSETS	$	58,282,681	$	33,422,248

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts payable and accrued liabilities	$	5,462,268	$	3,102,912
Income taxes payable		-		1,278,599
Current portion of long-term debt		340,520		2,562,141
Current portion of interest rate swap		9,895		11,966
Total current liabilities		5,812,683		6,955,618

Long-Term Liabilities
Senior revolving credit facility		28,634,037		-
Long-term debt, less current portion		801,968		11,200,048
Deferred income taxes, net		4,992,681		2,421,466
Total long-term liabilities		34,428,686		13,621,514
Total liabilities		40,241,369		20,577,132

Commitments and Contingencies (Note 10)

Stockholders’ Equity
Preferred stock, $.005 par value, 10,000,000 shares authorized, no shares issued or outstanding		-		-
Common stock, $.005 par value, 100,000,000 common shares authorized, 37,159,815 and 34,926,136 shares issued, respectively; 103,600 shares of treasury stock; and 37,056,215 and 34,822,536 shares outstanding, respectively		185,282		174,113
Additional paid-in-capital		12,751,389		11,568,033
Accumulated earnings		5,104,641		1,098,900
Accumulated other comprehensive income		-		4,070
Total stockholders’ equity		18,041,312		12,845,116

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	58,282,681	$	33,422,248

See accompanying notes to consolidated financial statements.

ENSERVCO CORPORATION

Consolidated Statements of Operations and Comprehensive (Loss) Income

	For the Years Ended
	December 31,
	2014			2013

Revenues	$	56,563,944		$	46,472,677

Cost of Revenue		41,257,600			31,869,312

Gross Profit		15,306,344			14,603,365

Operating Expenses
General and administrative expenses		4,393,129			4,076,088
Patent litigation and defense expenses		562,486			189,645
Depreciation and amortization		3,402,330			2,088,767
Total operating expenses		8,357,945			6,354,500

Income from Operations		6,948,399			8,248,865

Other Income (Expense)
Interest expense		(791,159	)		(1,073,875	)
Gain on sale and disposal of equipment		179,903			169,194
Other income		40,470			36,383
Total other expense		(570,786	)		(868,298	)

Income Before Tax Expense		6,377,613			7,380,567
Income Tax Expense		(2,371,872	)		(3,079,330	)

Net Income	$	4,005,741		$	4,301,237

Other Comprehensive (Loss) Income
Unrealized (loss) gain on interest rate swap, net of tax		(7,025	)		8,875
Settlements – interest rate swap		19,368			27,331
Reclassification into earnings		(16,413	)		(27,331	)
Total other comprehensive (loss) income		(4,070	)		8,875
Comprehensive income	$	4,001,671		$	4,310,112

Earnings per Common Share – Basic	$	0.11	$	0.13

Earnings (Loss) per Common Share – Diluted	$	0.10	$	0.12

Basic weighted average number of common shares outstanding		36,529,906		32,454,965
Add: Dilutive shares assuming exercise of options and warrants		2,469,099		4,658,052
Diluted weighted average number of common shares outstanding		38,999,005		37,113,017

See accompanying notes to consolidated financial statements.

ENSERVCO CORPORATION

Consolidated Statement of Stockholders’ Equity

	Common Shares		Common Stock		Additional Paid-in Capital			Accumulated Earnings (Deficit)			Accumulated Other Comprehensive Income			Total Stockholders ‘Equity

Balance at January 1, 2013		31,825,294	$	159,127	$	9,864,363		$	(3,202,337	)	$	(4,805	)	$	6,816,348

Exercise of warrants		2,266,000		11,330		1,234,970			-			-			1,246,300
Cashless exercise of warrants		716,028		3,580		(3,580	)		-			-			-
Cashless exercise of stock options		15,214		76		(76	)		-			-			-
Stock-based compensation		-		-		472,356			-			-			472,356
Net income		-		-		-			4,301,237			-			4,301,237
Other comprehensive income		-		-		-			-			8,875			8,875

Balance at December 31, 2013		34,822,536	$	174,113	$	11,568,033		$	1,098,900		$	4,070		$	12,845,116

Exercise of warrants		482,357		2,413		262,885			-			-			265,298
Exercise of stock options		244,999		1,225		126,762			-			-			127,987
Cashless exercise of warrants		1,482,041		7,410		(7,410	)		-			-			-
Cashless exercise of stock options		24,282		121		(121	)		-			-			-
Stock-based compensation		-		-		562,903			-			-			562,903
Tax benefits related to exercise of options and warrants		-		-		238,337			-			-			238,337
Net income		-		-		-			4,005,741			-			4,005,741
Other comprehensive income		-		-		-			-			(4,070	)		(4,070	)

Balance at December 31, 2014		37,056,215	$	185,282	$	12,751,389		$	5,104,641		$	-		$	18,041,312

See accompanying notes to consolidated financial statements.

ENSERVCO CORPORATION

Consolidated Statements of Cash Flows

	For the Years Ended
	December 31,
	2014		2013

OPERATING ACTIVITIES
Net income	$	4,005,741	$	4,301,237
Adjustments to reconcile net income to net cash provided by operating activities: