Enservco (ENSV) 10-Q 2016 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period endedSeptember 30, 2016

or

[  ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ________ to ________

Commission File Number 001-36335

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. 1000 Denver, CO	80246
(Address of principal executive offices)	(Zip Code)

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

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 Enservco was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes X  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 X  No ☐

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

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

                                                                                

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).               Yes ☐    NoX

Indicate the number of shares outstanding of each of the Issuer's classes of common stock as of the latest practicable date.

Class	Outstanding at November 5, 2016
Common stock, $.005 par value	38,130,160

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TABLE OF CONTENTS

	Page
Part I – Financial Information
Item 1. Financial Statements
Condensed Consolidated Balance Sheets	3
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)	4
Condensed Consolidated Statements of Cash Flows	5
Notes to Condensed Consolidated Financial Statements	6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	20
Item 3. Quantitative and Qualitative Disclosures about Market Risk	33
Item 4. Controls and Procedures	34
Part II
Item 1. Legal Proceedings	34
Item 1A. Risk Factors	34
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	35
Item 3. Defaults Upon Senior Securities	35
Item 4. Mine Safety Disclosures	35
Item 5. Other Information	35
Item 6. Exhibits	35

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PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ENSERVCO CORPORATION

Condensed Consolidated Balance Sheets

	September 30,			December 31,
	2016			2015
	(Unaudited)
ASSETS
Current Assets
Cash and cash equivalents	$	781,275		$	804,737
Accounts receivable, net		3,370,676			7,037,419
Prepaid expenses and other current assets		916,553			1,072,479
Inventories		362,582			308,297
Income tax receivable		223,847			222,447
Total current assets		5,654,933			9,445,379
Property and Equipment, net		36,242,244			36,494,661
Goodwill		301,087			301,087
Other Assets		154,481			180,730
TOTAL ASSETS	$	42,352,745		$	46,421,857
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts payable and accrued liabilities	$	2,794,122		$	3,039,859
Current portion of long-term debt		338,178			314,263
Total current liabilities		3,132,300			3,354,122
Long-Term Liabilities
Senior revolving credit facility, net of unamortized deferred loan costs of $469,054 and $532,870, respectively		24,849,530			20,173,371
Long-term debt, less current portion		459,010			590,505
Deferred income taxes, net		1,343,961			4,417,043
Total long-term liabilities		26,652,501			25,180,919
Total liabilities		29,784,801			28,535,041
Commitments and Contingencies (Note 8)
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 shares authorized, 38,233,760 and 38,230,729 shares issued, respectively; 103,600 shares of treasury stock; and 38,130,160 and 38,127,129 shares outstanding, respectively		190,650			190,634
Additional paid-in-capital		14,347,719			13,852,563
Accumulated (deficit) earnings		(1,970,425	)		3,843,619
Total stockholders’ equity		12,567,944			17,886,816
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	42,352,745		$	46,421,857

See notes to condensed consolidated financial statements.

3

ENSERVCO CORPORATION

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)

(Unaudited)

	For the Three Months Ended						For the Nine Months Ended
	September 30,						September 30,
	2016			2015			2016			2015
Revenues	$	5,503,211		$	5,308,854		$	17,948,622		$	30,150,900
Cost of Revenue		5,961,540			5,355,942			17,669,806			22,184,102
Gross Profit (Loss)		(458,329	)		(47,088	)		278,816			7,966,798
Operating Expenses
General and administrative expenses		966,873			954,831			2,894,769			3,115,557
Patent litigation and defense costs		33,171			53,844			108,783			493,058
Depreciation and amortization		1,602,901			1,489,352			4,968,493			4,252,124
Total operating expenses		2,602,945			2,498,027			7,972,045			7,860,739
Income (Loss) from Operations		(3,061,274	)		(2,545,115	)		(7,693,229	)		106,059
Other Income (Expense)
Interest expense		(553,049	)		(360,434	)		(1,426,500	)		(860,865	)
Gain (Loss) on disposal of equipment		-			-			233,473			(1,071	)
Other income		5,198			22,642			12,204			54,893
Total other expense		(547,851	)		(337,792	)		(1,180,823	)		(807,043	)
Income (Loss) Before Tax Expense		(3,609,125	)		(2,882,907	)		(8,874,052	)		(700,984	)
Income Tax Benefit (Expense)		1,251,301			1,234,716			3,060,008			330,162
Net Income (Loss)	$	(2,357,824	)	$	(1,648,191	)	$	(5,814,044	)	$	(370,822	)
Other Comprehensive Income (Loss)		-			-			-			-
Comprehensive Income (Loss)	$	(2,357,824	)	$	(1,648,191	)	$	(5,814,044	)	$	(370,822	)
Earnings (Loss) per Common Share – Basic	$	(0.06	)	$	(0.04	)	$	(0.15	)	$	(0.01	)
Earnings (Loss) per Common Share – Diluted	$	(0.06	)	$	(0.04	)	$	(0.15	)	$	(0.01	)
Basic weighted average number of common shares outstanding		38,130,160			38,101,647			38,129,994			37,740,843
Add: Dilutive shares assuming exercise of options and warrants		-			-			-			-
Diluted weighted average number of common shares outstanding		38,130,160			38,101,647			38,129,994			37,740,843

See notes to condensed consolidated financial statements.

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ENSERVCO CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	For the Three Months Ended						For the Nine Months Ended
	September 30,						September 30,
	2016			2015			2016			2015
OPERATING ACTIVITIES
Net income (loss)	$	(2,357,824	)	$	(1,648,191	)	$	(5,814,044	)	$	(370,822	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization		1,602,901			1,489,352			4,968,493			4,252,124
(Gain) loss on disposal of equipment		-			-			(233,473	)		1,071
Deferred income taxes		(1,264,375	)		(1,178,098	)		(3,073,082	)		(368,933	)
Stock-based compensation		175,954			170,972			493,458			442,243
Stock issued for services		-			-			1,714			-
Amortization of debt issuance costs		39,123			32,265			113,816			90,048
Bad debt expense		58,953			8,205			145,902			21,050
Changes in operating assets and liabilities
Accounts receivable		(726,901	)		657,071			3,520,841			11,446,199
Inventories		(4,451	)		(19,733	)		(54,285	)		65,503
Prepaid expense and other current assets		190,956			(263,144	)		155,926			278,560
Income taxes receivable		-			(62,091	)		(1,400	)		(191,697	)
Other assets		26,249			14,849			26,249			14,849
Accounts payable and accrued liabilities		624,521			958,066			(245,737	)		(2,806,459	)
Net cash provided by (used in) operating activities		(1,634,894	)		159,523			4,378			12,873,736
INVESTING ACTIVITIES
Purchases of property and equipment		(232,010	)		(429,623	)		(4,804,328	)		(3,574,725	)
Proceeds from disposal of equipment		-			-			321,725			5,000
Net cash provided by (used in) investing activities		(232,010	)		(429,623	)		(4,482,603	)		(3,569,725	)
FINANCING ACTIVITIES
Net line of credit borrowings (payments)		2,117,214			376,522			4,612,343			(9,704,621	)
Repayment on long-term debt		(36,221	)		(34,703	)		(107,580	)		(202,562	)
Payment of debt issuance costs		-			(100,000	)		(50,000	)		(100,000	)
Proceeds from exercise of warrants		-			-			-			77,100
Proceeds from exercise of stock options		-			12,250			-			198,285
Excess tax benefits from exercise of options and warrants		-			3,109			-			221,229
Net cash provided by (used in) financing activities		2,080,993			257,178			4,454,763			(9,510,569	)
Net Increase (Decrease) in Cash and Cash Equivalents		214,089			(12,922	)		(23,462	)		(206,558	)
Cash and Cash Equivalents, Beginning of Period		567,186			760,422			804,737			954,058
Cash and Cash Equivalents, End of Period	$	781,275		$	747,500		$	781,275		$	747,500
Supplemental cash flow information:
Cash paid for interest	$	574,076		$	219,192		$	1,194,908		$	841,252
Cash paid for taxes	$	13,074		$	2,362		$	14,474		$	9,236
Supplemental Disclosure of Non-cash Investingand Financing Activities:
Cashless exercise of stock options and warrants	$	-		$	-		$	-		$	2,751

See notes to condensed consolidated financial statements.

5

ENSERVCO CORPORATION

Notes to the Condensed Consolidated Financial Statements

Note 1 – Basis of Presentation

The accompanying consolidated financial statements have been derived from the accounting records of Enservco Corporation, Heat Waves Hot Oil Service LLC (“Heat Waves”), Dillco Fluid Service, Inc. (“Dillco”), Heat Waves Water Management LLC (“HWWM”), HE Services LLC, and Real GC LLC (collectively, the “Company”) as of September 30, 2016 and December 31, 2015 and the results of operations for the three and nine months ended September 30, 2016 and 2015.

The below table provides an overview of the Company’s current ownership hierarchy:

Name	State of Formation	Ownership	Business
Dillco Fluid Service, Inc. (“Dillco”)	Kansas	100% by Enservco	Oil and natural gas field fluid logistic services.
Heat Waves Hot Oil Service LLC (“Heat Waves”)	Colorado	100% by Enservco	Oil and natural gas well services, including logistics and stimulation.
Heat Waves Water Management LLC (“HWWM”)	Colorado	100% by Enservco	Water Transfer and Water Treatment Services.
HE Services LLC (“HES”)	Nevada	100% by Heat Waves	No active business operations. Owns construction equipment used by Heat Waves.
Real GC, LLC (“Real GC”)	Colorado	100% by Heat Waves	No active business operations. Owns real property in Garden City, Kansas that is utilized by Heat Waves.

On November 24, 2015, Heat Waves Water Management LLC (“HWWM”) was organized under Colorado law as a wholly owned subsidiary of Enservco for the purpose of launching a new water management division. Effective January 1, 2016, HWWM acquired various water transfer assets from WET Oil Services, LLC (“WET”) and HII Technologies, Inc. and its affiliates (“HIIT”) for approximately $4.0 million. As part of the HIIT transaction, HWWM also acquired a new water treatment technology utilized in devices sold under the name of HydroFLOW. HydroFLOW products offer water treatment services based on patented hydropath technology that can remove bacteria and scale from water using electrical induction to reduce or eliminate down-hole scaling and corrosion. HWWM provides water transfer services and water treatment services to the onshore oil and natural gas sector.

The accompanying unaudited Condensed Consolidated Financial Statements of the Company have been prepared in accordance with accounting principles for interim financial information and with the instructions to Form 10-Q and Article 8 of Regulation S-X. Accordingly, they do not include all of the disclosures required by generally accepted accounting principles in the United States for complete financial statements. In the opinion of management, all of the normal and recurring adjustments necessary to fairly present the interim financial information set forth herein have been included. The results of operations for interim periods are not necessarily indicative of the operating results of a full year or of future years.

The accompanying unaudited Condensed Consolidated Financial Statements were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and follow the same accounting policies and methods of their application as the most recent annual financial statements. These interim financial statements should be read in conjunction with the financial statements and related footnotes included in the Annual Report on Form 10-K of Enservco Corporation for the year ended December 31, 2015. All significant inter-company balances and transactions have been eliminated in the accompanying condensed consolidated financial statements.

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The accompanying Condensed Consolidated Balance Sheet at December 31, 2015 has been derived from the audited financial statements at that date, but does not include all of the information and notes required by GAAP for complete financial statements. For further information, refer to the consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015.

Note 2 - Summary of Significant Accounting Policies

Cash and Cash Equivalents

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company monitors its positions with, and the credit quality of, the financial institutions with which it invests.

Accounts Receivable 

Accounts receivable are stated at the amounts billed to customers, net of an allowance for uncollectible accounts. The Company provides an allowance for uncollectable accounts based on a review of outstanding receivables, historical collection information and existing economic conditions. The 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. As of September 30, 2016 and December 31, 2015, the Company had an allowance for doubtful accounts of $26,371 and $158,800, respectively. For the three and nine months ended September 30, 2016, the Company recorded bad debt expense (net of recoveries) of $58,953 and $145,902, respectively. For the three and nine months ended September 30, 2015, the Company recorded bad debt expense (net of recoveries) of $8,205 and $21,050, respectively.

Inventory 

Inventory consists primarily of propane, diesel fuel and chemicals used in the servicing of oil wells, and is carried at the lower of cost or market in accordance with the first in, first out method. The Company periodically reviews the value of items in inventory and provides write-downs or write-offs of inventory based on its assessment of market conditions. Write-downs and write-offs are charged to cost of goods sold.

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 undiscounted future cash flows in its assessment of whether or not long-lived assets have been impaired. No impairments were recorded during the three and nine month periods ended September 30, 2016 and 2015.

Property and Equipment

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

7

Leases

The Company conducts a major part of its operations from leased facilities. Each of these leases is accounted for as an operating lease. Normally, the Company records rental expense on its operating leases over the lease term as it becomes payable. If rental payments are not made on a straight-line basis, in accordance with the terms of the agreement, the Company records a deferred rent expense and recognizes the rental expense on a straight-line basis throughout the lease term. The majority of the Company’s facility leases contain renewal clauses and expire through June 2022. In most cases, management expects that in the normal course of business, leases will be renewed or replaced by other leases.

The Company has leased trucks and equipment in the normal course of business, which was recorded as an operating lease. The Company recorded rental expense on equipment under operating leases over the lease term as it becomes payable; there were no rent escalation terms associated with these equipment leases. The equipment leases contained a purchase option that allowed the Company to purchase the leased equipment at the end of the lease term, based on the market price of the equipment at the time of the lease termination. In October 2015, the Company exercised the purchase option on three frac water heaters. There are no significant equipment leases outstanding as of September 30, 2016.

Revenue Recognition

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

Earnings (Loss) Per Share

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

As of September 30, 2016 and 2015, there were outstanding stock options and warrants to acquire an aggregateof 4,490,669 and 3,635,169 shares of Company common stock, respectively, which have a potentially dilutive impact on earnings per share. Dilution is not permitted if there are net losses during the period. As such, the Company does not show dilutive loss per share for the three and nine months ended September 30, 2016 or for the three and nine months ended September 30, 2015.

Intangible Assets

Goodwill. Goodwill represents the excess of the cost over the fair value of net assets acquired, including identified intangible assets, recorded in connection with the acquisition of Heat Waves. Goodwill is not amortized but is assessed for impairment at least annually.

Impairment.The Company assesses goodwill for impairment at the reporting unit level on an annual basis and between annual tests if events occur or circumstances change that would more likely than not reduce the fair value below its carrying amount. Guidance allows a qualitative assessment of impairment to determine whether it is more-likely-than-not that goodwill is impaired. If it is determined that it is more-likely-than-not that an impairment exists, accounting guidance requires that the impairment test be performed through the application of a two-step fair value test. The Company utilizes this method and recognizes a goodwill impairment loss in the event that the fair value of the reporting unit does not exceed its carrying value. During fiscal year ended December 31, 2015, the Company performed the annual impairment test and determined that no impairment existed. For the three and nine month periods ended September 30, 2016 and 2015, the Company did not note any events that occurred, nor did any circumstances change, that would require goodwill to be assessed for impairment.

8

Loan Fees and Other Deferred Costs

In the normal course of business, the Company enters into loan agreements and amendments thereto with its primary lending institutions. The majority of these lending agreements and amendments require origination fees and other fees in the course of executing the agreements. For all costs associated with the execution of the lending agreements, the Company recognizes these as capitalized costs and amortizes these costs over the term of the loan agreement using the effective interest method. These deferred costs are classified on the balance sheet as a direct deduction from the carrying amount of the related debt liability. All other costs not associated with the execution of the loan agreements are expensed as incurred.

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.  The Company records a valuation allowance to reduce deferred tax assets to an amount that it believes is more likely than not to be realized.

The Company accounts for any uncertainty in income taxes by recognizing the tax benefit from an uncertain tax position only if, in the Company’s opinion, 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. A review of the Company’s current tax positions did not identify any uncertain tax positions that would have an impact on the consolidated financial statements.

Interest and penalties associated with tax positions are recorded in the period assessed as general and administrative expenses. The Company files tax returns in the United States and in the states in which it conducts its business operations. The tax years 2012 through 2015 remain open to examination in the taxing jurisdictions to which the Company is subject.

Fair Value

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

Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in pricing the asset or liability based on the best information available in the circumstances. The Company did not change its valuation techniques nor were there any transfers between hierarchy levels during the three and nine months endedSeptember 30, 2016. The financial and non-financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement.

9

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

Level 1: Quoted prices are available in active markets for identical assets or liabilities;

Level 2: Quoted prices in active markets for similar assets and liabilities that are observable for the asset or liability; or

Level 3: Unobservable pricing inputs that are generally less observable from objective sources, such as discounted cash flow models or valuations.

Stock-based Compensation

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

The Company uses the Black-Scholes pricing model as a method for determining the estimated grant date fair value for all stock options awarded to employees, independent contractors, officers, and directors. The expected term of the options is based upon evaluation of historical and expected 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.

Management Estimates 

The preparation of the Company’s financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include the realization of accounts receivable, stock based compensation expense, income tax provision, the valuation of interest rate swaps, and the valuation of deferred taxes. Actual results could differ from those estimates.

Accounting Pronouncements

Recently Issued

In May 2014, the FASB issued ASU No. 2014-09,Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The ASU will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. In August 2015 the FASB agreed to defer the effective date by one year, the new standard becomes effective for us on January 1, 2018. Early adoption is permitted. The standard permits the use of either the retrospective or cumulative effect transition method. We are evaluating the effect that ASU 2014-09 will have on our consolidated financial statements and related disclosures. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.

In August 2014, the FASB issued ASU 2014-15,“Presentation of Financial Statements—Going Concern: Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern”. The standard requires an entity's management to evaluate whether there are conditions or events that raise substantial doubt about the entity's ability to continue as a going concern within one year after the date that the financial statements are issued. Public entities are required to apply the standard for annual reporting periods ending after December 15, 2016, and interim periods thereafter. Early application is permitted. The adoption of this guidance is not expected to impact the Company’s consolidated financial position, results of operations, or cash flows.

10

In July 2015, the FASB issued ASU 2015-11, “Simplifying the Measurement of Inventory”, effective for annual and interim periods beginning after December 15, 2016. ASU 2015-11 changes the inventory measurement principle for entities using the first-in, first out (FIFO) or average cost methods. For entities utilizing one of these methods, the inventory measurement principle will change from lower of cost or market to the lower of cost and net realizable value.The adoption of this guidance is not expected to impact the Company’s consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02 “Leases (Topic 842)”, which requires a lessee to record a right-of-use asset and a lease liability on the balance sheet for all leases with terms longer than 12 months. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the income statement. The new standard is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. A modified retrospective transition approach is required for lessees for capital and operating leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. We are currently evaluating the impact of our pending adoption of the new standard on our consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09“Compensation – Stock Compensation (Topic 718)”, which simplifies several aspects of the accounting for share-based payments, including immediate recognition of all excess tax benefits and deficiencies in the income statement, changing the threshold to qualify for equity classification up to the employees' maximum statutory tax rates, allowing an entity-wide accounting policy election to either estimate the number of awards that are expected to vest or account for forfeitures as they occur, and clarifying the classification on the statement of cash flows for the excess tax benefit and employee taxes paid when an employer withholds shares for tax-withholding purposes. The Company is evaluating the full effect that ASU 2016-09 will have on its consolidated financial statements.

Recently Adopted

Effective January 1, 2016, the Company adopted ASU 2015-03, “Simplifying the Presentation of Debt Issuance Costs.” ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The ASU was effective for annual periods beginning after December 15, 2015, and interim periods within those annual periods. Our adoption resulted in a reclassification of deferred debt costs related to long-term debt from an asset to an offset of the related liability of $532,870 at December 31, 2015. The adoption of the ASU did not affect our method of amortizing debt issuance costs, and will not affect the statement of operations.

Effective January 1, 2016, the Company elected to early adopt ASU 2015-17, “Balance Sheet Classification of Deferred Taxes”, which was effective for annual and interim reporting periods beginning after December 15, 2016, with early adoption permitted. ASU 2015-17 requires that all deferred tax liabilities and assets, as well as any related valuation allowance, be classified in the balance sheet as non-current. The Company has elected to apply this guidance retrospectively to all periods presented.Our adoption resulted in a reclassification of current deferred tax assets of $237,411 to an offset of long-term deferred income taxes resulting in net long-term deferred income taxes of $4,417,043 as of December 31, 2015.

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Note 3 - Property and Equipment

Property and equipment consists of the following:

	September 30,			December 31,
	2016			2015
Trucks and vehicles	$	54,269,251		$	54,153,487
Water transfer equipment		4,347,803			176,412
Other equipment		3,193,615			3,158,758
Buildings and improvements		3,835,110			3,752,841
Land		873,428			873,428
Disposal wells		391,003			391,003
Total property and equipment		66,910,210			62,505,929
Accumulated depreciation		(30,667,966	)		(26,011,268	)
Property and equipment – net	$	36,242,244		$	36,494,661

Effective January 1, 2016, HWWM acquired various water transfer assets from WET and HIIT for approximately $4 million. These assets include high and low volume pumps, aluminum pipe, manifolds, lay flat hose, generators, other support equipment including vehicles and trailers. As part of the HIIT acquisition, HWWM also acquired a new water treatment technology utilized in devices sold under the name of HydroFLOW. In accordance with FASB Accounting Standards Codification 805, Business Combinations, the Company has accounted for the transactions with both HIIT and WET as asset acquisitions.

Note 4 – PNC Credit Facility

2014 PNC Credit Facility

In September 2014, the Company entered into an Amended and Restated Revolving Credit and Security Agreement (the "2014 Credit Agreement") with PNC Bank, National Association ("PNC") which provides for a five-year $30 million senior secured revolving credit facility which replaced a prior revolving credit facility and term loan with PNC that totaled $16 million (the "2012 Credit Agreement"). The 2014 Credit Agreement allows the Company to borrow up to 85% of eligible receivables and up to 85% of the appraised value of trucks and equipment. Under the 2014 Credit Agreement, there are no required principal payments until maturity and the Company had the option to pay variable interest rate based on (i) 1, 2 or 3 month LIBOR plus an applicable margin ranging from 2.50% to 3.50% for LIBOR Rate Loans or (ii) interest at PNC Base Rate plus an applicable margin of 1.00% to 2.00% for Domestic Rate Loans. Interest is calculated monthly and added to the principal balance of the loan. Additionally, the Company incurs an unused credit line fee of 0.375%. The revolving credit facility is collateralized by substantially all of the Company’s assets and subject to financial covenants.

Effective February 27, 2015, the Companyentered into a Consent and First Amendment (the “First Amendment”) with respect to the 2014 Credit Agreement. The First Amendment, among other things, (i) modified certain financial covenants, and (ii) consented to a $100,000 principal prepayment by the Company to a third party bank. Effective March 29, 2015, the Company entered into a second amendment to the 2014 Credit Agreement with PNC to increase the Company’s leverage ratio, as defined from 2.75 to 1 to 3.50 to 1 and to exclude certain capital expenditures from the calculation of the fixed charge ratio. In July and October 2015, the Company entered into a third and fourth amendment, respectively, to the 2014 Credit Agreement with PNC.  The amendments were made to administrative terms of the agreement and did not modify any terms of the financial covenants. Effective December 31, 2015, the Company entered into a fifth amendment to the 2014 Credit Agreement. The fifth amendment, among other things, (i) increased the applicable margin for Domestic Rate Loans and LIBOR Rate Loans by 25 basis points (ii) adjusted the Company’s leverage ratio, as defined, to 4.25 to 1.00 as of December 31, 2015, 4.50 to 1.00 as of March 31, 2016, and 3.50 to 1.00 as of June 30, 2016 and each quarter thereafter, and (iii) limited capital expenditures, as defined to an aggregate amount of $7,800,000 during the period commencing October 1, 2015 through June 30, 2016.

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On March 29, 2016, the Company entered into a Sixth Amendment (the “Sixth Amendment”) to the 2014 Credit Agreement. The Sixth Amendment, among other things, (i) reduced the revolving line of credit commitment from $40 million back to its original $30 million, (ii) reset the fixed charge coverage ratio to build to a trailing four quarters beginning with the quarter ended December 31, 2015, (iii) added a new covenant which established a minimum monthly availability requirement for the period of March 2016 through March 2017 ranging from $1.5 million to $8.0 million, (iv) converted the leverage and fixed charge coverage ratios to springing covenants which would only be triggered upon failure to meet the new availability covenant until it expires in March 2017; thereafter they will be individually tested quarterly, (v) increased the applicable margin for Domestic Rate Loans and LIBOR Rate Loans by 175 basis points, and (vi) reinstated a full cash dominion requirement.

On August 10, 2016, the Company entered into a Seventh Amendment to the 2014 Credit Agreement that among other things; (i) reset and extended the minimum monthly availability covenant from the date of amendment through June 30, 2017 at amounts ranging from $658,000 to $3.5 million, (ii) extended the period of time that the leverage ratio and fixed charge coverage ratio are springing covenants through July 1, 2017; (iii) provided for a 0.5% monthly reduction in the advance rate on the appraised value of equipment to 80% through February 2017, and (iv) included an amendment fee of $200,000.     

On October 4, 2016, the Company entered into an Eighth Amendment to the 2014 Credit Agreement that among other things; (i) reset the minimum monthly availability covenant to $500,000 from September 1, 2016 through November 30, 2016 and $1 million thereafter; and (ii) reset the leverage ratio for each quarterly period as follows:

Fiscal Quarter Ending:	Maximum Leverage Ratio
March 31, 2017	5.50:1.00
June 30, 2017	4.50:1.00
September 30, 2017	4.50:1.00
December 31, 2017	7.00:1.00
March 31, 2018	5.50:1.00
June 30, 2018	5.00:1.00
September 30, 2018	5.00:1.00
December 31, 2018	5.00:1.00
March 31, 2019	3.50:1.00
June 30, 2019 and each fiscal quarter thereafter	3.50:1.00

As of September 30, 2016, the Company had an outstanding principle loan balance of $25,318,584 and unamortized debt issuance costs of $469,054. The interest rate at September 30, 2016 was 5.0% for the $25,250,000 of outstanding LIBOR Rate Loans and6.5% for the $68,584 of outstanding Domestic Rate Loans.The outstanding principle loan balance matures in September 2019. As of September 30, 2016, approximately $1.3 million was available under the revolving credit facility.

Interest Rate Swap

On September 17, 2015, the Company entered into an interest rate swap agreement with PNC which the Company designated as a fair value hedge against the variability in future interest payments related to its 2014 Credit Agreement. The terms of the interest rate swap agreement include a notional amount of $10 million, a fixed payment rate of 1.88% plus applicable a margin ranging from 4.50% to 5.50% paid by the Company and a floating payment rate equal to LIBOR plus applicable margin of 4.50% to 5.50% paid by PNC. The purpose of the swap agreement is to adjust the interest rate profile of the Company’s debt obligations and to achieve a targeted mix of floating and fixed rate debt.

During the three months ended September 30, 2016, the fair market value of the swap instrument increased by $65,000 and resulted in a decrease to the liability and a reduction in interest expense. During the nine months ended September 30, 2016, the fair market value of the swap decreased by $107,000 and resulted in an increase in the liability and additional interest expense.

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Note 5 – Long-Term Debt

Long-term debt consists of the following:

	September 30,			December 31,
	2016			2015
Real Estate Loan for our facility in North Dakota, interest at 3.75%, monthly principal and interest payment of $5,255 ending October 3, 2028. Collateralized by land and property purchased with the loan.	$	503,691		$	536,038
Note payable to the seller of Heat Waves. The note was garnished by the Internal Revenue Service (“IRS”) in 2009 and is due on demand; paid in monthly installments of $3,000 per agreement with the IRS.		179,000			206,000
Mortgage payable to a bank, interest at 5.9%, monthly principal and interest payments of $1,550 through January 2017 with a balloon payment of $88,118 on February 1, 2017; secured by land.		93,637			103,191
Mortgage payable to a bank; interest at 7.25%, due in monthly principal and interest payments of $4,555 through February 2017, secured by land.		20,860			59,539
Total		797,188			904,768
Less current portion		(338,178	)		(314,263	)
Long-term debt, net of current portion	$	459,010		$	590,505

Aggregate maturities of debt, excluding the 2014 Credit Agreement described in Note 4, are as follows:

Twelve Months Ending September 30,
2017	$	338,178
2018		46,409
2019		48,205
2020		50,033
2021		52,006
Thereafter		262,357
Total	$	797,188

Note 6 – Fair Value Measurements

The following table presents the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis by level within the fair value hierarchy:

	Fair Value Measurement Using
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Fair Value Measurement
September 30, 2016
Derivative Instrument
Interest rate swap	$	-	$	270,000	$	-	$	270,000
December 31, 2015
Derivative Instrument
Interest rate swap	$	-	$	163,000	$	-	$	163,000

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The interest rate swap consisted of a liability of $270,000 and $163,000 as of September 30, 2016 and December 31, 2015, respectively (classified withinAccounts payable and accrued liabilities).

The Company’s derivative instrument (e.g. interest rate swap or “swap”) is valued using models which require a variety of inputs, including contractual terms, market prices, yield curves, credit spreads, and correlations of such inputs. Some of the model inputs used in valuing the derivative instruments trade in liquid markets therefore the derivative instrument is classified within Level 2 of the fair value hierarchy. For applicable financial assets carried at fair value, the credit standing of the counterparties is analyzed and factored into the fair value measurement of those assets. The fair value estimate of the swap does not reflect its actual trading value.

Note 7 – Income Taxes

Income tax expense during interim periods is based on applying an estimated annual effective income tax rate to year-to-date income, plus any significant unusual or infrequently occurring items which are recorded in the interim period.  The provision for income taxes for the nine months endedSeptember 30, 2016 and 2015 differs from the amount that would be provided by applying the statutory U.S. federal income tax rate of 34% to pre-tax income primarily because of state income taxes and estimated permanent differences.

The computation of the annual estimated effective tax rate at each interim period requires certain estimates and significant judgment including, but not limited to, the expected operating income for the year, projections of the proportion of income earned and taxed in various jurisdictions, permanent differences, and the likelihood of recovering deferred tax assets generated in the current year.  The accounting estimates used to compute the provision for income taxes may change as new events occur, more experience is obtained, additional information becomes known or as the tax environment changes.

Note 8 – Commitments and Contingencies

Operating Leases

As of September 30, 2016, the Company leases facilities under lease commitments that expire through June 2022. Future minimum lease commitments for these operating lease commitments are as follows:

Twelve Months Ending September 30,
2017	$	679,673
2018		502,349
2019		468,525
2020		450,451
2021		252,127
Thereafter		162,663
Total	$	2,515,788

Self-Insurance

The Company is self-insured under its Employee Group Medical Plan for the first $50,000 per individual participant. The Company has accrued a liability of approximately $36,000 as of September 30, 2016 for insurance claims that it anticipates paying in the future related to claims that occurred during the period ended September 30, 2016.

Litigation

Enservco Corporation (“Enservco”) and its subsidiary Heat Waves Hot Oil Service LLC (“Heat Waves”) are defendants in a civil complaint, Civil Action No. 1:15-cv-00983-RBJ (“Colorado Case”), that alleges that Enservco and Heat Waves, in offering and selling frac water heating services, infringed and induced others to infringe two patents owned by Heat-On-The-Fly, LLC (“HOTF”). The complaint relates to only a portion of the frac water heating services provided by Heat Waves. The Colorado Case is now stayed pending resolution of appeal by HOTF of a North Dakota court’s ruling that the primary patent (“the ‘993 Patent”) in the Colorado Case was invalid. Neither Enservco nor Heat Waves is a party to the North Dakota Case, which involves other energy companies.

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

See disclosure in the Item 3 of our annual Form 10-K for the year ended December 31, 2015, and updates disclosed in our Notes to the Condensed Consolidated Financial Statements of our quarterly reports on Form 10-Q for the quarters ended June 30, 2016 and March 31, 2016.

Note 9 – Stockholders Equity

Warrants

In conjunction with a private placement transaction and subordinated debt conversion in November 2012, the Company granted warrants to purchase shares of the Company’s common stock, 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. As of September 30, 2016, 150,001 of these warrants remain outstanding.

A summary of warrant activity for the nine months ended September 30, 2016 is as follows:

					Weighted
			Weighted		Average
			Average		Remaining		Aggregate
			Exercise		Contractual		Intrinsic
Warrants	Shares		Price		Life (Years)		Value
Outstanding at December 31, 2015		150,001	$	0.55		1.9	$	-
Issued for Services		30,000		0.70		5.0	$	-
Exercised		-		-
Forfeited/Cancelled		-
Outstanding at September 30, 2016		180,001	$	0.57		1.8	$	4,500
Exercisable at September 30, 2016		150,001	$	0.55		1.2	$	4,500

In June 2016, the Company granted a principal of the Company’s existing investor relations firm warrants to acquire 30,000 shares of the Company’s common stock in connection with a reduction of the firms ongoing monthly cash service fees. The warrants had a grant-date fair value of $0.36 per share and vest over a one year period, 15,000 on December 21, 2016 and 15,000 on June 21, 2017, provided the principal of the investor relations firm remains a consultant of the Company at time of vesting.

During the nine months ended September 30, 2015, warrants to acquire 100,000 shares were exercised for cash payments totaling $77,100. The warrants exercised had a total intrinsic value of $102,000 at the time of exercise. No warrants were issued during the nine months ended September 30, 2015.

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Stock Issued for Services

In January 2016, the Company issued 3,031 shares of common stock to a consultant as partial compensation for services provided to the Company. The shares were granted under the 2010 Stock Incentive Plan and were fully vested and unrestricted at the time of issuance. For the nine months ended September 30, 2016, the Company recorded $1,700 of consulting expense for these services in the accompanying consolidated statement of operations and comprehensive income (loss).

Note 10 – Stock Options

Stock Option Plans

On July 27, 2010, the Company’s Board of Directors adopted the 2010 Stock Incentive Plan (the “2010 Plan”). The aggregate number of shares of common stock that could be granted under the 2010 Plan was reset at the beginning of each year based on 15% of the number of shares of common stock then outstanding. As such, on January 1, 2016 the number of shares of common stock available under the 2010 Plan was reset to 5,719,069 shares based upon 38,127,129 shares outstanding on that date.Options were typically granted with an exercise price equal to the estimated fair value of the Company's common stock at the date of grant with a vesting schedule of one to three years and a contractual term of 5 years. As discussed below, the 2010 Plan has been replaced by a new stock option plan and no additional stock option grants will be granted under the 2010 Plan. As of September 30, 2016, there were options to purchase 2,350,668 shares outstanding under the 2010 Plan.

On July 18, 2016, the Board of Directors unanimously approved the adoption of the Enservco Corporation 2016 Stock Incentive Plan (the “2016 Plan”), which was approved by the stockholders on September 29, 2016. The aggregate number of shares of common stock that may be granted under the 2016 Plan is 8,000,000 shares plus authorized and unissued shares from the 2010 Plan totaling 2,391,711 for a total reserve of 10,391,711 shares. As of September 30, 2016, there were options to purchase 1,960,000 shares outstanding under the 2016 Plan.

A summary of the range of assumptions used to value stock options granted for the three and nine months ended September 30, 2016 and 2015 are as follows:

	For theThreeMonthsEnded					For theNine Months Ended
	September 30,					September 30,
	2016			2015		2016			2015
Expected volatility	81%	-	104%		-	81%	-	102%	107	-	109%
Risk-free interest rate	0.6%	-	0.9%		-	0.9%	-	1.2%	0.75	-	0.86%
Forfeiture rate			0%		-			0%			0%
Dividend yield			-		-			-			-
Expected term (in years)	0.1	-	3.3		-	3.1	-	3.5			3.4

During the nine months ended September 30, 2016, the Company granted options to acquire 3,525,000 shares of common stock with a weighted-average grant-date fair value of $0.28 per share. During the nine months ended September 30, 2016, no options were exercised.

During the nine months ended September 30, 2015, the Company granted options to acquire 1,123,500 shares of common stock with a weighted-average grant-date fair value of $1.19 per share. During the nine months ended September 30, 2015, options to acquire 720,333 shares of common stock were exercised by way of a cashless exercise whereby the option holders elected to receive 550,276 shares of common stock by paying the exercise price for such shares by canceling the remaining options for 170,057 shares. The options had an intrinsic value of $1,131,371 at the time of exercise. In addition, options to acquire 404,667 shares of common stock were exercised for cash payments of $198,285. The options had an intrinsic value of $423,837 at the time of exercise.

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The following is a summary of stock option activity for all equity plans for the nine months ended September 30, 2016:

	Shares			Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (Years)		Aggregate Intrinsic Value
Outstanding at December 31, 2015		3,485,168		$	1.31		2.53	$	63,067
Granted		3,525,000			0.78
Exercised		-			-
Forfeited or Expired		(2,699,500	)		0.93
Outstanding at September 30, 2016		4,310,668		$	1.11		3.12	$	54,100
Vested or Expected to Vest at September 30, 2016		4,310,668		$	1.11		3.12	$	54,100
Exercisable at September 30, 2016		2,042,832		$	1.23		1.92	$	31,600

The aggregate intrinsic value in the table above represents the total intrinsic value (the difference between the estimated fair value of the Company’s common stock on September 30, 2016, and the exercise price, multiplied by the number of in-the-money options) that would have been received by the option holders had they exercised their options on September 30, 2016.

As discussed below in theForfeiture and Grant of Stock Options paragraph, on July 18, 2016, options to purchase 2,560,000 shares of common stock that were granted under the 2010 Plan to certain officers and directors were cancelled pursuant to certain letter agreements. The Company subsequently granted options to purchase 1,960,000 of shares under the 2016 Plan, which was approved by the stockholders on September 29, 2016. The New Options contain relatively the same terms as the forfeited options, with the exception that the exercise price on New Options was not below the closing market price on the date the Special Committee approved the New Options. Accordingly, the Company will treat the forfeiture and granting of New Options as a modification of stock options for accounting purposes.    

During the nine months ended September 30, 2016 and 2015, the Company recognized stock-based compensation costs for stock options of $493,458 and $442,243, respectively in general and administrative expenses. During the three months ended September 30, 2016 and 2015, the Company recognized stock-based compensation costs for stock options of $175,954 and $170,972, respectively. The Company currently expects all outstanding options to vest. Compensation cost is revised if subsequent information indicates that the actual number of options vested due to service is likely to differ from previous estimates.

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

	Number of Shares			Weighted-Average Grant-Date Fair Value
Non-vested at December 31, 2015		1,323,669		$	1.22
Granted		3,525,000			0.28
Vested		(1,401,333	)		0.55
Forfeited or Expired		(1,179,500	)		0.53
Non-vested at September 30, 2016		2,267,836		$	0.53

As of September 30, 2016, there was $924,960 of total unrecognized compensation costs related to non-vested shares under the qualified stock option plans which will be recognized over the remaining weighted-average period of 1.6 years.

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Forfeiture and Grant of Stock Options

On June 17, 2016, the Board of Directors appointed a special committee of disinterested directors (the “Special Committee”) to address certain claims in a letter dated June 14, 2016 from an attorney purporting to represent a stockholder of the Company regarding the Company’s 2010 Stock Incentive Plan (the “2010 Plan”) and equity awards granted thereunder. After investigation and consultation with special counsel, the Special Committee verified that certain stock options granted under the 2010 Plan had exceeded an applicable limitation in the 2010 Plan.

On July 7, 2016, the Special Committee unanimously approved: (a) the rescission (and forfeiture by the holders) of certain stock option awards to purchase 2,560,000 shares of the Company’s common stock that had been granted to various officers and directors in excess of the 2010 Plan’s limitations (“Excess Shares”), and (b) the grant of new options to purchase 1,960,000 shares of the Company’s common stock (the “New Options”), pursuant to the 2016 Plan. The New Options were subject to: (i) each of the option holders entering into a rescission letter agreement with the Company and (ii) stockholder approval of the 2016 Plan.

On July 18, 2016, the Board of Directors unanimously approved the adoption of the 2016 Plan, which after stockholder approval thereof, replaced the 2010 Plan. Further, the Company entered into rescission letter agreements with the various executive officers and directors whereby each such officer/director agreed to forfeit their Excess Shares. The Company agreed to grant the New Options pursuant to new stock option agreements that provide for vesting on substantially the same schedule as the Excess Shares would have vested but could not have been exercised prior to stockholder approval of the 2016 Plan on September 29, 2916. The exercise price of the New Options is the greater of the original exercise price of the Excess Shares or the closing market price on July 7, 2016, the date the Special Committee approved the New Options. Under the letter agreements, the termination date of each New Option is the termination date of the rescinded option, except that if the termination date of the rescinded option is prior to the two-year anniversary of the date of the letter agreement, then the termination date of the New Option is extended six months past the termination date of the rescinded option. Further, the Company agreed to submit the 2016 Plan to the stockholders of the Company for approval and on September 29, 2016, the stockholders approved the 2016 Plan. 

In November 2016, the Special Committee reached a settlement with the attorney and stockholder that sent the initial demand letter and agreed to pay an immaterial amount in settlement of the matter above. 

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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion provides information regarding the results of operations for the three and nine month periods ended September 30, 2016 and 2015, and our financial condition, liquidity and capital resources as of September 30, 2016, and December 31, 2015. The financial statements and the notes thereto contain detailed information that should be referred to in conjunction with this discussion.

Forward-Looking Statements

The information discussed in this Quarterly Report includes “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 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. Our results could differ materially from those anticipated in these forward-looking statements as a result of certain factors, including, among others:      

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

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

● 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;

● 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;

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

● Adverse weather and environmental conditions;

● Our reliance on a limited number of customers;

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

● 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;

● Developments in the global economy;

● Changes in tax laws;

● The effects of competition;

● The risks associated with the use of intellectual property that may be claimed by others and actual or potential litigation related thereto;

● The effect of seasonal factors; and

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

Finally, our future results will depend upon various other risks and uncertainties, including, but not limited to, those detailed in our filings with the SEC and in Part II, Item 1A of this Quarterly Report. For additional information regarding risks and uncertainties, please read our filings with the SEC under the Exchange Act and the Securities Act, including our Annual Report on Form 10-K for the fiscal year ended December 31, 2015. 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 paragraph and elsewhere in this Quarterly 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.

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BUSINESS OVERVIEW

The Company, through its subsidiaries, 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 transfer, water treatment, water hauling, fluid disposal, frac tank rental (fluid management services) and other general oilfield services. The Company owns and operates through its subsidiaries a fleet of more than 340 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.

In January 2016, the Company took advantage of the recent industry downturn and acquired various water transfer assets and other equipment from WET and HIIT for approximately $4 million dollars. These assets, which include high and low volume pumps, piping, manifolds, and other support equipment, as well as the exclusive U.S. rights to an environmentally friendly, innovative technology for the treatment of bacteria and scaling in the oil and gas industry, were purchased at an average of approximately 20% to 25% of their original cost. These strategic acquisitions, funded through our PNC credit facility, gave us the opportunity to acquire a sizable amount of assets that enabled us to launch a new water management division that can provide water transfer services in several markets. We believe the opportunity to bundle these services with our existing services including our frac water heating services will give us a competitive advantage over our competitors. Although we believe our ability to launch this division and enter into new markets will be challenging in the near term due to the current industry downturn, we believe these acquisitions will position us for substantial growth once commodity prices recover and well completion activity picks up.

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 and operating results for the periods noted. Following the table, please see management’s discussion of significant changes.

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2016			2015			2016			2015
FINANCIAL RESULTS:
Revenues	$	5,503,211		$	5,308,854		$	17,948,622		$	30,150,900
Cost of Revenue		5,961,540			5,355,942			17,669,806			22,184,102
Gross Profit (Loss)		(458,329	)		(47,088	)		278,816			7,966,798
Gross Margin		(8	)%		(1	)%		2	%		26	%
Income (Loss) From Operations	$	(3,061,274	)	$	(2,545,115	)	$	(7,693,229	)	$	106,059
Net Income (Loss)	$	(2,357,824	)	$	(1,648,191	)	$	(5,814,044	)	$	(370,822	)
Earnings (Loss) per Common Share – Diluted	$	(0.06	)	$	(0.04	)	$	(0.15	)	$	(0.01	)
Diluted weighted average number ofcommon shares outstanding		38,130,160			38,101,647			38,129,994			37,740,843
OTHER:
Adjusted EBITDA*	$	(1,249,248	)	$	(830,947	)	$	(2,122,495	)	$	5,293,484
Adjusted EBITDA* Margin		(22	)%		(16	)%		(11	)%		18	%

* Management believes that, for the reasons set forth below under the Adjusted EBITDA section, 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 within the Company’s industry. See further discussion of our use of EBITDA, the risks of non-GAAP measures, and the reconciliation to Net Income, below.

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Executive Summary

Market conditions continued to negatively impact our business during the third quarter of 2016, which is traditionally one of our slowest quarters of the year due to the normal seasonal decline in heating revenues during the warm summer months. Reduced drilling, completion and service activity throughout the industry due to low crude oil and natural gas prices continued to result in lower demand for our services during the third quarter of 2016 as compared to the same quarter last year. We continued to offer pricing concessions/discounts to customers with the intent to maintain existing service volumes and offset the drop in demand. The combination of these factors resulted in a decline in third quarter well enhancement revenues of $370,000, or 11%, from the same quarter last year. In addition to the factors discussed above, unseasonably warm weather in our two largest heating markets during the first half of 2016 resulted in an $11.9 million or 48% decline in well enhancement revenues for the nine months ended September 30, 2016 as compared to the same period last year. Incremental revenues from our geographic expansion into the Eagle Ford Shale helped to offset some of the decline in revenues in other markets. In addition, $1.4 million of additional revenues from a dirt hauling project in Colorado helped to offset these declines.

Management continued to take actions to reduce variable operating costs in line with the decrease in revenues and to reduce fixed expenses where possible. However, the decline in higher margin well enhancement services, price concessions, and carrying costs from our water management division resulted in a decline in gross profit of $411,000 and a corresponding decline in Adjusted EBITDA of $418,000 for the three months ended September 30, 2016 as compared to the same quarter last year. For the nine months ended September 30, 2016, gross profits declined $7.7 million and Adjusted EBITDA declined $7.4 million as compared to the same period last year. For further details on the calculation of Adjusted EBITDA, see Adjusted EBITDA section below.

Declines in patent litigation costs of 38% reduced operating costs by approximately $21,000 during the quarter ended September 30, 2016 as compared to the same quarter last year. These declines were partially offset by a $114,000, or 8%, increase in noncash depreciation and amortization expense during the quarter related to the purchase of approximately $4 million of water transfer assets in January 2016. For the nine months ended September 30, 2016, general and administrative expenses and patent litigation defense costs decreased $605,000, or 17%. This decrease in cash operating expenses was offset by an increase in noncash depreciation and amortization expense of $716,000, or 17%, due to the purchase of water transfer assets discussed above.

Net loss for the three months ended September 30, 2016 was $2.4 million or ($0.06 per share) as compared to net loss of $1.6 million or ($0.04 per share) for the comparable quarter last year. For the nine months ended September 30, 2016, net loss was $5.8 million or ($0.15 per share) as compared to a net loss of $371,000 or ($0.01) per diluted share for the comparable period last year.

Industry Overview

Crude oil prices dropped below $30 per barrel twice in the first quarter and then gradually improved to just over $50 per barrel in early June and seems to have settled into the $45 to $50 per barrel range. The overall decline in crude oil prices since July 2014 has resulted in our customers scaling back drilling and completion programs, shifting capital resources to higher margin basins, requesting pricing concessions from vendors, and reducing or delaying certain maintenance related work to save costs. Further, the overall reduction in drilling, completion and service work has resulted in more service vendors chasing fewer jobs putting even further downward pressure on the pricing of services. Some competitors have responded by pricing work at negative margins. The Company has been able to partially mitigate the impact of these decisions by deploying resources to more active customers and basins.

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Earlier this year, many customers announced reduced capital spending programs for 2016 and some customers suspended drilling and completion programs altogether until oil and natural gas prices recover and stabilize at an economical price for continuing such operations. In addition, some customers delayed their routine hot oiling and acidizing maintenance work. Similar to the last down cycle, once prices stabilize at a profitable level we anticipate a rebound in routine hot oiling and acidizing maintenance as the deferred maintenance needs to be done to maintain production levels and protect the integrity of a well. 

Revenues

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 revenues by service offering may be useful to readers of our financial statements. The following tables set forth revenue by service offering and geographic region during the three and nine months ended September 30, 2016 and 2015:

	For the Three months Ended September 30,				For the Nine months Ended September 30,
	2016		2015		2016		2015
BY SERVICE OFFERING:
Well Enhancement Services(1)	$	3,006,190	$	3,375,722	$	12,682,802	$	24,596,063
Fluid Management and Other(2)		2,497,021		1,933,132		5,265,820		5,554,837
Total Revenues	$	5,503,211	$	5,308,854	$	17,948,622	$	30,150,900

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 three geographically diverse regions. The following tables set forth revenue by service offering and geographic region during the three and nine months ended September 30, 2016 and 2015:

	For the Three months Ended September 30,				For the Nine months Ended September 30,
	2016		2015		2016		2015
BY GEOGRAPHY:
Rocky Mountain Region(3)	$	2,840,640	$	2,419,921	$	9,833,499	$	17,584,921
Eastern USA Region(4)		93,097		188,818		1,097,629		4,789,075
Central USA Region(5)		2,569,474		2,700,115		7,017,494		7,776,904
Total Revenues	$	5,503,211	$	5,308,854	$	17,948,622	$	30,150,900

Notes to tables:

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

(2) Includes water hauling, water transfer, water treatment services, fluid disposal, frac tank rental, and construction and roustabout services.

(3) 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.

(4) 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.

(5) Includes the Eagle Ford Shale (South Texas), Mississippi Lime and Hugoton Field (Kansas, Oklahoma, and Northern Texas). Both Dillco and Heat Waves engage in business operations in this region.

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Well Enhancement Services

For the three months ended September 30, 2016, well enhancement service revenue declined $370,000 or 11% from the same period last year. The decline was primarily due to the year over year decline in demand for our hot oil services in several markets with the most significant declines noted in the Bakken and Wyoming Basins. This decline was partially offset by incremental hot oil and acidizing revenues from our geographic expansion into the Eagle Ford Shale in Texas.

For the nine months ended September 30, 2016, well enhancement service revenue declined $11.9 million, or 48%, from the comparative period last year to $12.7 million. A significant decline in demand for our frac water heating services due to unseasonably warm weather in our two largest frac water heating markets (D-J/Niobrara and Marcellus/Utica) during the first half of 2016 and the overall decline in drilling and completions activity related to falling oil and natural gas price were the primary reason for the decline in revenues. These declines were partially offset by incremental revenues from our geographic expansion into the Eagle Ford Shale basin in Texas.

Frac water heating revenues for the three months ended September 30, 2016 and 2015 were minimal due to normal seasonal decline in heating revenues during the warm summer months. For the nine months ended September 30, 2016, frac water heating revenues declined 68%, or $9.6 million, from 2015 due to the aforementioned unseasonably warm weather and industry wide declines in drilling and completion programs. Our Eastern USA region was hit particularly hard as cold temperatures never materialized during the first half of 2016 resulting in a $3.6 million, or 86%, decline in heating revenues in the Marcellus/Utica Shale Basin.

Hot oil revenues for the three months ended September 30, 2016 decreased 30% to $1.8 million as compared to $2.6 million in 2015. Incremental hot oil service revenues from our geographic expansion into Texas offset lower equipment utilization and price concessions in several markets. Hot oil equipment utilization fell from last year as customers in several locations scaled back frequency of service and reduced service hours in an effort to reduce costs. During the last two years, the Company has granted pricing concessions to customers in several markets in order to retain or increase market share.

Acidizing revenues for the three months ended September 30, 2016 increased 55% from the same period last year to $1.1 million. The Company’s continued efforts to aggressively pursue customers and partner with chemical suppliers to develop new cost effective acid programs has allowed us to expand our acidizing services into the Eagle Ford Shale basin in Texas resulting in an increase in quarter-over-quarter acidizing revenues. For the nine months ended September 30, 2016, acidizing revenues increased 16% from the same period last year.

Fluid Management and Other:

Fluid management services and other revenues increased $564,000 or 29% during the three months ended September 30, 2016 as compared to same quarter last year primarily due to $1.5 million of incremental revenues attributable to a dirt hauling project in Colorado which began in May 2016. This increase was partially offset by an $718,000 or 45% decline in water hauling revenues which was primarily attributable to lower water hauling revenues in our Central US region due to scaled back service work, pricing concessions and declining to perform certain low margin business.

Geographic Areas:

Revenues in the Rocky Mountain Region increased $421,000 or 17%, for the three months ended September 30, 2016 primarily due to incremental dirt hauling revenues described above. This increase was partially offset by a decline in hot oiling services in the Bakken and Wyoming basins. For the nine months ended September 30, 2016, revenues in the Rocky Mountain Region decreased $7.8 million, or 44%, primarilydue to decreased frac water heating activity in the Niobrara Shale/DJ Basin attributable to the unseasonably warm weather and reduced drilling activity in the region as discussed above and decreased hot oiling due to delayed maintenance programs by our customers.

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Revenues in the Eastern USA declined $96,000, or 51% to $93,000 during the third quarter ended September 30, 2016 primary due to decline in service activities and cessation of certain water hauling activities. For the nine months ended September 30, 2016, revenues decreased $3.7 million, or 77%, primarily due to lower frac water heating activity in the Marcellus and Utica shale basins. Similar to our most recent fourth quarter, the unseasonably warm weather throughout the first quarter of 2016 heating season essentially eliminated most of our frac water heating revenue during the first half of 2016. In addition, reduced drilling and completion activities due to falling prices also contributed to the overall decline in revenues.

Revenues in the Central USA region decreased $131,000, or 5%, to $2.6 million for the three months ended September 30, 2016. Incremental revenues from our geographic expansion into the Eagle Ford Shale were offset by a decline in well enhancement and fluid management service activity within the Hugoton Basin. Scaled back service work, price concessions and elimination of certain low margin water hauling business were the primary reasons for decline in fluid management service activity in the Hugoton Basin. For the nine months ended September 30, 2016,revenues in the Central USA region decreased $759,000 or 10%, to $7.0 million. Similar to our third quarter results, incremental revenues from our geographic expansion into the Eagle Ford Shale were offset by a decline in well enhancement and fluid management service activity within 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 outside our heating season 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 72% of its 2015 revenues during the first and fourth quarters of 2015 compared to 28% during the second and third quarters of 2015. In 2014, the Company earned 77% of its 2014 revenues during the first and fourth quarters of 2014, compared 23% during the second and third quarters of 2014. 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 quarter ended September 30, 2016 increased $606,000, or 11%, from the comparable quarter last year primarily due to $1.6 million of incremental operating costs from our dirt hauling project in Colorado. Excluding these incremental costs, cost of revenues decline $1.0 million or 19% from the comparable quarter last year primarily due to management’s efforts to reduce operating costs such as direct labor, insurance and supplies in order to minimize the negative impact of reduced well enhancement and fluid management revenues. Managements’ efforts included reducing overtime and non-billable time, reducing indirect labor to correspond with lower activity, negotiating supplier discounts and implementing cost management tools. Although management makes every effort to manage labor costs during its seasonal fluctuations in revenue, it is difficult to fully reduce labor costs during our slower quarters in proportion with the decline in revenues as we must retain a number of experienced frac water heating operators for the upcoming heating season. In addition to managements’ efforts to reduce costs, lower propane and fuel costs also contributed to the decline in cost of revenues. The decline in cost of revenues above was partially offset by carrying costs from our new water management division and increased costs from our expanded operations in Texas. For the nine months ended September 30, 2016, cost of revenues decreased $4.5 million, or 20%, from the comparable period last yeardue to the same factors that impacted the third quarter cost of revenues discussed above.

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Gross Profit:

Gross profit, which is typically lower during the third quarter due to the normal seasonal decline in frac water heating services, decreased $411,000 to negative $458,000 during the quarter ended September 30, 2016 as compared to a negative $47,000 for the same quarter last year. The decline in gross profits was primarily due to the decline in our higher margin well enhancement service revenues of approximately $370,000 as discussed above. In addition, gross profit was further decreased due to carrying costs of $254,000 related to our new water management division and $97,000 of incremental operating costs associated with the dirt hauling project which began in May 2016. For the nine months ended September 30, 2016, gross profit declined $7.7 million, or 97%, to $279,000 during the nine months ended September 30, 2016 as compared to $8.0 million for the same period last year. The decline in gross profits was primarily due to the $11.9 million decline in our higher margin well enhancement services attributable to lower frac water heating services related to the warm weather and reduced service activity discussed above. Also contributing to the decline in gross profit for the nine months ended September 30, 2016, were $1.1 million of carrying costs for our new water management division and $217,000 of startup/incremental costs for the dirt hauling project. Management continues to monitor the carrying costs associated with the new water management division and beginning July 2016 made staff reductions to reduce carrying costs by approximately 50%.

Gross profit as a percentage of revenues was negative 8% and 1% for the three months ended September 30, 2016 and 2015, respectively. Gross profit as a percentage of revenues was 2% and 26% for the nine months ended September 30, 2016 and 2015, respectively. The decrease in gross profit as a percentage of revenues was primarily due to the aforementioned impact from decline in higher margin well enhancement revenues and startup costs for our new water management division and dirt hauling project. Further, gross profits as a percentage of revenue also declined due to the fixed cost components in cost of goods sold such as indirect labor, property and equipment insurance, vehicle registration fees, and site overhead costs which do not fluctuate in proportion to revenues and therefore become a higher percentage of costs of revenues during our seasonal decline in revenues.

Propane Impact Discussion:

In connection with our frac water heating services and hot oil services, the Company provides propane to certain customers on a cost plus basis. 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 impact our revenues, cost of revenues and gross profit percentages. In general, 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 propane revenues and cost of revenue becomes a lower percentage of total revenues. Conversely, increases in propane prices 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 revenues and cost of revenue becomes a higher percentage of total revenues. Propane prices during our first quarter declined approximately 33% from the comparable quarter last year and contributed to the overall decline in revenues, cost of revenues and gross profits discussed above. However, due to the significant decline in frac water heating services, the decline in propane prices, had a relatively minor impact on gross profit as a percentage of revenue.

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 and that more customers may utilize our bi-fuel capabilities.

General and Administrative Expenses:

For the quarter ended September 30, 2016, general and administrative expenses increased $12,000, or 1%, from the comparable quarter last year. Lower personnel costs attributable to reduction in staff and cost reductions from scaled back investor relations expenses and lower corporate travel were mitigated by higher professional fees, office rent, and bad debt expense from the comparable quarter last year.

For the nine months ended September 30, 2016, general and administrative expenses decreased $221,000, or 7%, from the comparable quarter last year primarily due to lower personnel costs attributable to reduction in staff and a $275,000 net decrease due to the timing of an annual bonus paid to management and key employees during the first quarter of 2015. These decreases were partially offset by higher stock based compensation, office rent, and bad debt expense over the comparable period last year. Bad debt expense was higher than the comparable period last year due to a partial write-off of pre-petition receivables from customers that went through Chapter 11 bankruptcy during 2016.

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Patent Litigation and Defense Costs:

Patent litigation and defense costs for the three and nine months ended September 30, 2016 declined $21,000 and $384,000, respectively, from the comparable periods last year. As discussed below in Part II Item 1. –Legal Proceeding, the U.S. District Court for the District of Colorado issued a decision on July 20, 2015 to stay the Company’s case with HOTF pending an appeal of a recent judgement by a North Dakota Court invalidating the ‘993 Patent. As a result of the stay, legal costs have been minimal since July 2015.

Enservco and Heat Waves deny that they are infringing upon any valid, enforceable claim of the asserted HOTF patents, and intend to continue to vigorously defend themselves in the Colorado Case and challenge the validity of these patents should the lawsuit resume. The Company expects associated legal fees to be minimal going forward until or if such time as the Colorado Case is resumed.

Depreciation and Amortization:

Depreciation and amortization expense for the three and nine months ended September 30, 2016 increased $114,000, or 8% and $716,000, or 17%, respectively from the comparable periods last year primarily due to the additional depreciation expense related to the $4.0 million purchase of water transfer assets from WET and HIIT. Depreciation and amortization expense during the third quarter of 2016 was partially offset by a reduction in depreciation expense due to older equipment being fully depreciated during the three months ended September 30, 2016.

Income from operations:

For the nine months ended September 30, 2016, the Company recognized a loss from operations of $7.7 million compared to an income from operations of $106,000 for the same period last year. The loss from operations as compared to the income from operations in the prior period is primarily due to the overall decline in well enhancement revenues and corresponding gross profits discussed above, as well as a $716,000 increase in depreciation and amortization expense related to the acquisition of water transfer assets in January 2016. 

Management believes that the decline in results of operations during 2016, particularly the decline in well enhancement revenues and gross profit, reflects a number of factors including the unseasonably warm weather in the DJ Basin and Marcellus/Utica shale play and decreased drilling, completion and service activity attributable to lower crude oil and natural gas prices should improve over time. We believe that as long as we are able to control our costs and increase our revenues as a result of our expanded fleet and service offerings as well as being able to quickly deploy our equipment from places of lesser utilization to places where they will be better utilized, our financial performance will improve over the long run. 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 three months ended September 30, 2016 increased $193,000, or 53%, to $553,000 as compared to the same quarter last year. The increase was due to several factors including a $200,000 amendment fee charged in connection with the seventh amendment to the PNC credit agreement, an increase in our effective interest rate of 200 basis points due to amendments to our PNC credit facility, and a higher average debt balance from the comparable period last year. These increases were partially offset by a $233,000 reduction in interest expense from the comparable quarter last year related to the fair market adjustment on the PNC interest rate swap agreement.

Interest expense for the nine months ended September 30, 2016 increased $566,000, or 66%, to $1.4 million as compared to $861,000 for the same period last year. The increase in interest expense during the nine months was primarily due to same factors discussed above.

Income Taxes:

For the quarter ended September 30, 2016, the Company recognized an income tax benefit of $1.3 million on pre-tax net loss of approximately $3.6 million as compared to an income tax benefit of $1.2 million on pre-tax net loss of $2.9 million in 2015. The effective tax rate on income from operations was 35% for the quarter ended September 30, 2016 as compared to 43% for the same quarter last year. The difference in effective tax rates was primarily due to permanent tax differences related to stock based compensation.

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For the nine months ended September 30, 2016, the Company recognized an income tax benefit of $3.1 million on pre-tax net loss of approximately $8.9 million as compared to an income tax benefit of $330,000 on pre-tax net loss of $701,000 in 2015. The effective tax rate on income from operations was 34% for the nine months ended September 30, 2016 compared to 47% for the same period last year. The difference in effective tax rates was primarily due to permanent tax differences related to stock based compensation

Adjusted EBITDA*

Management believes that, for the reasons set forth below, Adjusted EBITDA (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 Enservco's industry.

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

	For Three Months Ended September 30,						For Nine Months Ended September 30,
	2016			2015			2016			2015
EBITDA*
Income (Loss)	$	(2,357,824	)	$	(1,648,191	)	$	(5,814,044	)	$	(370,822	)
Add Back (Deduct)
Interest Expense		553,049			360,434			1,426,500			860,865
Provision for income taxes (benefit) expense		(1,251,301	)		(1,234,716	)		(3,060,008	)		(330,162	)
Depreciation and amortization		1,602,901			1,489,352			4,968,493			4,252,124
EBITDA*		(1,453,175	)		(1,033,121	)		(2,479,059	)		4,412,005
Add Back (Deduct)
Stock-based compensation		175,954			170,972			493,458			442,243
Patent litigation and defense costs		33,171			53,844			108,783			493,058
(Gain) Loss on sale and disposal of equipment		-			-			(233,473	)		1,071
Interest and other income		(5,198	)		(22,642	)		(12,204	)		(54,893	)
Adjusted EBITDA*	$	(1,249,248	)	$	(830,947	)	$	(2,122,495	)	$	5,293,484

*Note: See below for discussion of the 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 herein.

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

All of the items included in the reconciliation from net income to EBITDA and from EBITDA to Adjusted EBITDA are either (i) non-cash items (e.g., depreciation, amortization of purchased intangibles, stock-based compensation, warrants issued, etc.) or (ii) items that management does not consider to be useful in assessing the Company’s ongoing operating performance (e.g., income taxes, gain 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.

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We use, and we believe investors benefit from the presentation of, EBITDA and Adjusted EBITDA in evaluating our operating performance because it provides us and our investors with an additional tool to compare our operating performance on a consistent basis by removing the impact of certain items that management believes do not directly reflect our core operations. We believe that EBITDA is useful to investors and other external users of our financial statements in evaluating our operating performance because EBITDA is widely used by investors to measure a company’s operating performance without regard to items such as interest expense, taxes, and depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. Additionally, our leverage and fixed charge ratio covenants associated with our 2014 Credit Agreement require the use of Adjusted EBITDA in specific calculations.

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

Changes in Adjusted EBITDA*

Adjusted EBITDA from operations declined $418,000 to a negative $1.2 million for the quarter ended September 30, 2016 as compared to a negative $831,000 for the same quarter last year. This decrease was primarily due to the $411,000 decline in gross profit discussed above.

Adjusted EBITDA from operations declined $7.4 million to a negative $2.1 million for the nine months ended September 30, 2016 as compared to a positive $5.3 million for the same period last year. This decrease was primarily due to the $7.7 million decline in gross profit discussed above.

LIQUIDITY AND CAPITAL RESOURCES

 The following table summarizes our statements of cash flows for the three and nine months ended September 30, 2016

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2016			2015			2016			2015
Net cash provided by (used in) operating activities	$	(1,634,894	)	$	159,523		$	4,378		$	12,873,736
Net cash provided by (used in) investing activities		(232,010	)		(429,623	)		(4,482,603	)		(3,569,725	)
Net cash provided by (used in) financing activities		2,080,993			257,178			4,454,763			(9,510,569	)
Net Decrease in Cash and Cash Equivalents		214,089			(12,922	)		(23,462	)		(206,558	)
Cash and Cash Equivalents, Beginning of Period		567,186			760,422			804,737			954,058
Cash and Cash Equivalents, End of Period	$	781,275		$	747,500		$	781,275		$	747,500

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The following table sets forth a summary of certain aspects of our balance sheet at September 30, 2016 and December 31, 2015 and (combined with the working capital table and discussion below) is important for understanding our liquidity:

	September 30, 2016		December 31, 2015
Current Assets	$	5,654,933	$	9,445,379
Total Assets		42,352,745		46,421,857
Current Liabilities		3,132,300		3,354,122
Total Liabilities		29,784,801		28,535,041
Stockholders’ equity		12,567,944		17,886,816
Working Capital (Current Assets net of Current Liabilities)		2,522,633		6,091,257
Long-term debt to Equity		2.01 to 1		1.16 to 1

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 September 30, 2016, we had approximately $781,000 of cash and cash equivalents and approximately $1.3 million available under our asset based senior revolving credit facility.

In September 2014, the Company entered into the 2014 Credit Agreement with PNC which provides for a five-year $30 million senior secured revolving credit facility. The facility allows the Company to borrow up to 85% of eligible receivables, up to 85% of the appraised value of trucks and equipment, and 90% of the cost of new equipment. The Company had the option to pay variable interest rate based on (a) 1, 2 or 3 month LIBOR plus applicable margin ranging from 2.75% to 3.75% for LIBOR Rate Loans or (b) interest at PNC Base Rate plus applicable margin of 1.25% to 2.25% for Domestic Rate Loans. As a result of the Sixth Amendment entered into in March 2016, the interest rates we will be paying on our loans for the balance of 2016 and through the end of the term in September 2019 have increased by 1.75%.

The PNC credit facility has certain customary financial covenants which have been amended from time to time and consist of the following as of September 30, 2016 (as described below, effective October 4, 2016, these covenants have changed as a result of a Eighth Amendment to the facility):

(i) a minimum monthly availability requirement for September 2016 of $771,000;

(ii) a minimum fixed charge coverage ratio (as defined, not less than 1.25 to 1.00, measured as of the last day of each fiscal quarter. The fixed charge coverage ratio will based on a building trailing twelve month beginning with the quarter ended December 31, 2015 information.) The fixed charge coverage ratio was a springing covenant through September 30, 2016 and as a result of the Eighth Amendment below will be calculated as of December 31, 2016 and each subsequent quarter thereafter; and,

(iii) a maximum leverage ratio of funded debt to adjusted EBITDA (as defined, not more than 3.50 to 1.0 as of September 30, 2016, measured as of the last day of each fiscal quarter with adjusted EBITDA determined based on trailing twelve month information); The leverage ratio has been converted to a springing covenant as a result of the Sixth Amendment in March 2016 which would only be triggered upon failure to meet the minimum monthly availability covenant or until March 31, 2017.

On August 10, 2016, the Company entered into a Seventh Amendment to the 2014 Credit Agreement that among other things; (i) reset and extended the minimum monthly availability covenant from the date of amendment through September 30, 2017 at amounts ranging from $658,000 to $3.5 million, (ii) extended the period of time that the leverage ratio and fixed charge coverage ratio are springing covenants to July 1, 2017; (iii) provided for a 0.5% monthly reduction in the advance rate on the appraised value of equipment to 80% through February 2017; and (iv) included an amendment fee of $200,000.

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On October 4, 2016, the Company entered into an Eighth Amendment to the 2014 Credit Agreement that among other things; (i) reset the minimum monthly availability covenant to $500,000 from September 1, 2016 through November 30, 2016 and $1 million thereafter; and (ii) reset the leverage ratio for each quarterly period as follows:

Fiscal Quarter Ending:	Maximum Leverage Ratio
March 31, 2017	5.50:1.00
June 30, 2017	4.50:1.00
September 30, 2017	4.50:1.00
December 31, 2017	7.00:1.00
March 31, 2018	5.50:1.00
June 30, 2018	5.00:1.00
September 30, 2018	5.00:1.00
December 31, 2018	5.00:1.00
March 31, 2019	3.50:1.00
June 30, 2019 and each fiscal quarter thereafter	3.50:1.00

As of September 30, 2016, the Company had an outstanding loan balance of $25.3 million and approximately $1.3 million available under the revolving credit facility ($2.0 million gross availability less a minimum monthly availability requirement for September 2016 of $771,000) and was in compliance with applicable terms of the credit facility above. The interest rate at September 30, 2016 was 5.0% for the $25.2 million of outstanding LIBOR Rate Loans and 6.5% for the $68,584 of outstanding Domestic Rate Loans.

The Company intends to continue to use the PNC facility to fund working capital needs and supplement future capital expenditures. The financial covenants outlined above could restrict our ability to secure additional debt financing or access funds under our revolving credit facility.

Working Capital:

As of September 30, 2016, the Company had working capital of approximately $2.5 million, a decrease in working capital of approximately $3.6 million as compared to our 2015 fiscal year end. The decrease in working capital was primarily attributable to a decrease in accounts receivable of $3.7 million, or 52%, related to our seasonal decline in well enhancement revenues, specifically frac water heating revenues.

Cash flow from Operating Activities:

Cash flow used in operating activities during the quarter ended September 30, 2016 was $1.6 million as compared to $160,000 cash inflow during the comparable quarter last year. The decrease in cash flow from operations is primarily attributable to lower cash inflow from accounts receivable.

Cash flow from operating activities during the nine months ended September 30, 2016 was $4,000 as compared to $12.9 million during the comparable period last year. The decrease in cash flow from operations is primarily attributable to the overall decline in revenues and gross profits during the period as discussed above. Additionally, the decrease in cash flow from operations is due to lower cash inflow associated with the collection of accounts receivable.

Cash flow from Investing Activities:

Cash flow used in investing activities during the quarter ended September 30, 2016 was $232,000 as compared to $430,000 during the comparable quarter last year. The cash used in investing activities during the quarters ended September 30, 2016 and 2015 consists primarily of maintenance capital expenditures. Overall the Company has significantly reduced its capital expenditures as a result of lower activity and reduced revenues.

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Cash flow used in investing activities during the nine months ended September 30, 2016 was $4.5 million as compared to $3.6 million during the comparable period last year. The increase in cash used in investing activities was primarily due to the $4.2 million purchase of water transfer assets and patented hydropath technology assets from WET and HIIT. The $3.1 million of capital expenditures for the comparable quarter last year included equipment purchases and payments for trucks in process under the Company’s 2014 CAPEX program and other routine maintenance capital expenditures.

Cash flow from Financing Activities:

Cash provided by financing activities for the quarter ended September 30, 2016 was $2.1 million as compared to $257,000 for the comparable period last year. The change was primarily due to the Company using cash flow in fiscal 2015 to pay down its revolving credit facility with PNC.

Cash provided by financing activities for the nine months ended September 30, 2016 was $4.5 million as compared cash used in financing activities of $9.5 million for the comparable period last year. The change was primarily due to additional borrowings by the Company in January of 2016 to fund the purchase of new water management and patented hydropath technology assets ($4.2 million) as discussed above, whereas during the nine months ended September 30, 2015, the Company utilized cash flow from operations to pay down its revolving credit facility with PNC.

Outlook:

The Company plans to continue to look for opportunities to expand its business operations through organic growth such as geographic expansion and increasing the volume and scope of services offered to our existing customers as capital permits. The Company will also look to expand its business operations through acquisitions. The Company plans to 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 and as a result of the changes negotiated in the Seventh and Eighth Amendments, the Company believes that it will have sufficient capital resources and availability under the PNC revolving credit facility through the remainder of 2016 to fund working capital needs and future capital expenditures. However, the Company’s borrowing availability and ability to meet its debt covenants over the next twelve months will be heavily dependent upon the Company’s ability to generate positive cash flows and EBITDA during the Company’s upcoming heating season which occurs from November 2016 through April 2017. In the event the Company does not generate a sufficient amount of EBITDA to meet its debt covenants, the Company will need to negotiate further amendments to its credit facility and/or raise additional capital resources through debt or equity financing.

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 for the sale of common stock by named selling security holders, and further 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 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 September 30, 2016 consist primarily of scheduled principal payments under certain term loans and operating leases.  The Company does not have any scheduled principal payments under itsfive-year, $30 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 availability and leverage ratios. General terms and conditions for amounts due under these commitments and obligations are summarized in the notes to the financial statements.    

Pursuant to a Sales Agreement with HydroFLOW USA, HWWM has the exclusive right to sell or rent patented hydropath devices in connection with bacteria deactivation and scale treatment services for treating injection and disposal wells, fracking water and recycled water in the oil and gas industry to HWWM customers in the United States. Pursuant to the sales agreement, HWWM is required to pay royalties on certain rental transactions and, in order to maintain the exclusivity provision under the agreement, the Company must purchase approximately $655,000 of equipment per year commencing in 2016 of which $155,000 has been paid as of September 30, 2016. In September 2016, the Company and HydroFLOW USA agreed to allocate $200,000 of the 2016 commitment to 2017, thereby reducing the remaining commitment for 2016 to $280,000.

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OFF-BALANCE SHEET ARRANGEMENTS

Other than the guarantees made by Enservco (as the parent Company) on various loan agreements and operating leases disclosed in Note 8 to the Condensed Consolidated Balance Sheet, the Company had 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 Condensed Consolidated Financial Statements included in this Form 10-Q.

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:

● Collectability of accounts receivable

● Revenue recognition

● Property and equipment as it relates to depreciation and useful lives

● Impairment of long-lived assets

● Valuation allowance of deferred tax assets

● Methodology of the calculation fair value of stock option awards

For a discussion of the Company’s critical accounting policies, please refer to Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Critical Accounting Policies” in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015. There have been no material changes to the Company’s critical accounting policies as disclosed therein.

ITEM 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not applicable.

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

As required by Rule 13a-15 under the Securities Exchange Act of 1934 (the “1934 Act”), as of September 30, 2016, we carried out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures. This evaluation was carried out under the supervision and with the participation of our Chief Executive Officer (our principal executive officer) and our Chief Financial Officer (our principal financial officer). Based upon and as of the date of that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of September 30, 2016.

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 SEC’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 our management, including our principal executive officer and our principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

There were notany changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) promulgated by the SEC under the 1934 Act) during the quarter ended September 30, 2016, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II

ITEM 1. LEGAL PROCEEDINGS

Enservco Corporation (“Enservco”) and its subsidiary Heat Waves Hot Oil Service LLC (“Heat Waves”) are defendants in a civil complaint, Civil Action No. 1:15-cv-00983-RBJ (“Colorado Case”), that alleges that Enservco and Heat Waves, in offering and selling frac water heating services, infringed and induced others to infringe two patents owned by Heat-On-The-Fly, LLC (“HOTF”). The complaint relates to only a portion of the frac water heating services provided by Heat Waves. The Colorado Case is now stayed pending resolution of appeal by HOTF of a North Dakota court’s ruling that the primary patent (“the ‘993 Patent”) in the Colorado Case was invalid. Neither Enservco nor Heat Waves is a party to the North Dakota Case, which involves other energy companies.

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

See disclosure in the Item 3 of our annual Form 10-K for the year ended December 31, 2015, and updates disclosed in our Notes to the Condensed Consolidated Financial Statements of our quarterly report on Form 10-Q for the quarter ended March 31, 2016.

ITEM 1A. RISK FACTORS

See the risk factors set forth in the Company’s annual report on Form 10-K for the year ended December 31, 2015 filed on March 30, 2016, which is incorporated herein by reference. There have been no material changes to the risk factors set forth in that Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

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ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

None.

ITEM 5. OTHER INFORMATION

None

ITEM 6. EXHIBITS

Exhibit No.	Title
3.01	Second Amended and Restated Certificate of Incorporation.(1)
3.02	Certificate of Amendment of Second Amended and Restated Certificate of Incorporation(2)
3.03	Amended and Restated Bylaws.(3)
10.1	Eighth Amendment to Amended and Restated Revolving Credit and Security Agreement dated October 4, 2016,(4)
11.1	Statement of Computation of per share earnings (contained in Note 2 to the Condensed Consolidated Financial Statements).
31.1	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Rick D. Kasch, Principal Executive Officer). Filed herewith.
31.2	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Robert J. Devers, Principal Financial Officer). Filed herewith.
32	Certification Pursuant to 18 U.S.C. §1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Rick D. Kasch, Chief Executive Officer, and Robert J. Devers, 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.
(2)	Incorporated by reference from the Company’s Current Report on Form 8-K dated June 20, 2014, and filed on June 25, 2014.
(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 September 29, 2016, and filed on October 5, 2016.

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SIGNATURES

In accordance with the requirements of the Securities Exchange Act of 1934, we have duly caused this report to be signed on our behalf by the undersigned, thereunto duly authorized.

	ENSERVCO CORPORATION
Date: November 14, 2016		/s/ Rick D. Kasch
		Rick D. Kasch, Principal Executive Officer and Chief Executive Officer
Date: November 14, 2016		/s/ Robert J. Devers
		Robert J. Devers, Principal Financial Officer and Principal Accounting Officer

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