Edgar Filing: NATURAL GAS SERVICES GROUP INC

Document

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 ended September 30, 2017

( ) 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 1-31398

NATURAL GAS SERVICES GROUP, INC.

(Exact name of registrant as specified in its charter)



Colorado		75-2811855
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification No.)

508 W. Wall St., Ste 550

Midland, Texas 79701

(Address of principal executive offices)

(432) 262-2700

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.



Yes x		No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File 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 o

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” and "emerging growth company" in Rule 12b-2 of the Exchange Act.



Large accelerated filer o	Accelerated filer x	Non-accelerated filer o	Smaller reporting company o	Emerging growth company o
		(Do not check if smaller reporting company)

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

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



Yes o		No x

APPLICABLE ONLY TO CORPORATE ISSUERS

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



Class		October 30, 2017
Common Stock, $0.01 par value		12,941,237



Part I - FINANCIAL INFORMATION

Item 1. Consolidated Financial Statements

Unaudited Condensed Consolidated Balance Sheets	Page	1

Unaudited Condensed Consolidated Income Statements	Page	2

Unaudited Condensed Consolidated Statements of Cash Flows	Page	3

Notes to Unaudited Condensed Consolidated Financial Statements	Page	4

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	Page	11

Item 3. Quantitative and Qualitative Disclosures about Market Risk	Page	17

Item 4. Controls and Procedures	Page	17

Part II - OTHER INFORMATION

Item 1. Legal Proceedings	Page	17

Item 1A. Risk Factors	Page	18

Item 6. Exhibits	Page	19

Signatures	Page	21

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements



NATURAL GAS SERVICES GROUP, INC. CONDENSED CONSOLIDATED BALANCE SHEETS (in thousands, except per share amounts) (unaudited)

	September 30,		December 31,
	2017		2016
ASSETS
Current Assets:
Cash and cash equivalents	$	72,924	$	64,094
Trade accounts receivable, net of allowance for doubtful accounts of $634 and $597, respectively	7,163		7,378
Inventory, net	28,379		25,833
Prepaid income taxes	2,339		1,482
Prepaid expenses and other	1,127		972
Total current assets	111,932		99,759
Rental equipment, net of accumulated depreciation of $140,865 and $126,096, respectively	162,137		174,060
Property and equipment, net of accumulated depreciation of $11,486 and $11,267, respectively	8,425		7,753
Goodwill	10,039		10,039
Intangibles, net of accumulated amortization of $1,601 and $1,508, respectively	1,558		1,651
Other assets	895		262
Total assets	$	294,986	$	293,524
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Line of credit	$	—	$	417
Accounts payable	1,830		971
Accrued liabilities	3,955		2,887
Deferred income	185		2,225
Total current liabilities	5,970		6,500
Line of credit, non-current portion	417		—
Deferred income tax liability	50,512		53,745
Other long-term liabilities	880		325
Total liabilities	57,779		60,570
Commitments and contingencies (Note 9)
Stockholders’ Equity:
Preferred stock, 5,000 shares authorized, no shares issued or outstanding	—		—
Common stock, 30,000 shares authorized, par value $0.01; 12,844 and 12,764 shares issued and outstanding, respectively	128		128
Additional paid-in capital	103,916		100,812
Retained earnings	133,163		132,014
Total stockholders' equity	237,207		232,954
Total liabilities and stockholders' equity	$	294,986	$	293,524

See accompanying notes to these unaudited condensed consolidated financial statements.



NATURAL GAS SERVICES GROUP, INC. CONDENSED CONSOLIDATED INCOME STATEMENTS (in thousands, except earnings per share) (unaudited)

	Three months ended						Nine months ended
	September 30,						September 30,
	2017			2016			2017			2016
Revenue:
Rental income	$	11,292		$	13,157		$	34,634		$	44,220
Sales	4,256			2,536			15,300			9,746
Service and maintenance income	365			488			1,099			985
Total revenue	15,913			16,181			51,033			54,951
Operating costs and expenses:
Cost of rentals, exclusive of depreciation stated separately below	4,333			4,513			13,256			15,618
Cost of sales, exclusive of depreciation stated separately below	3,237			2,191			12,405			8,359
Cost of service and maintenance	90			122			288			318
Selling, general and administrative expense	2,340			2,101			7,776			6,822
Depreciation and amortization	5,320			5,431			15,958			16,371
Total operating costs and expenses	15,320			14,358			49,683			47,488
Operating income	593			1,823			1,350			7,463
Other income (expense):
Interest expense	(7		)	(2		)	(11		)	(6		)
Other income (expense), net	(7		)	10			(1		)	22
Total other income (expense), net	(14		)	8			(12		)	16
Income before provision for income taxes	579			1,831			1,338			7,479
Provision for income taxes	57			322			189			2,170
Net income	$	522		$	1,509		$	1,149		$	5,309
Earnings per share:
Basic	$	0.04		$	0.12		$	0.09		$	0.42
Diluted	$	0.04		$	0.12		$	0.09		$	0.41
Weighted average shares outstanding:
Basic	12,838			12,717			12,825			12,691
Diluted	13,117			12,962			13,102			12,913

See accompanying notes to these unaudited condensed consolidated financial statements.



NATURAL GAS SERVICES GROUP, INC. CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands) (unaudited)
	Nine months ended
	September 30,
	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	1,149		$	5,309
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	15,958			16,371
Deferred income taxes	(3,233		)	(1,773		)
Stock-based compensation	3,231			1,739
Bad debt allowance	70			61
Inventory allowance	—			32
Gain on sale of assets	(49		)	(49		)
Gain on company owned life insurance	(35		)	(7		)
Changes in operating assets and liabilities:
Trade accounts receivables	145			3,714
Inventory	(2,535		)	3,556
Prepaid expenses and prepaid income taxes	(1,012		)	(604		)
Accounts payable and accrued liabilities	1,927			(550		)
Deferred income	(2,040		)	1,629
Other	578			133
Tax benefit from equity compensation	—			(51		)
NET CASH PROVIDED BY OPERATING ACTIVITIES	14,154			29,510
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of property and equipment	(4,662		)	(3,359		)
Purchase of company owned life insurance	(571		)	(142		)
Proceeds from sale of property and equipment	49			49
NET CASH USED IN INVESTING ACTIVITIES	(5,184		)	(3,452		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments from other long-term liabilities, net	(13		)	(8		)
Proceeds from exercise of stock options	517			433
Taxes paid related to net share settlement of equity awards	(644		)	(909		)
Tax benefit from equity compensation	—			51
NET CASH USED IN FINANCING ACTIVITIES	(140		)	(433		)
NET CHANGE IN CASH AND CASH EQUIVALENTS	8,830			25,625
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	64,094			35,532
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	72,924		$	61,157
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Interest paid	$	11		$	6
Income taxes paid	$	4,288		$	4,795
NON-CASH TRANSACTIONS
Transfer of rental equipment components to inventory	$	48		$	164

See accompanying notes to these unaudited condensed consolidated financial statements.

Natural Gas Services Group, Inc.

Notes to Condensed Consolidated Financial Statements

(unaudited)

(1) Basis of Presentation and Summary of Significant Accounting Policies

These notes apply to the unaudited condensed consolidated financial statements of Natural Gas Services Group, Inc. a Colorado corporation (the "Company", “NGSG”, "Natural Gas Services Group", "we" or "our").

The accompanying unaudited condensed consolidated financial statements include all adjustments, consisting of only normal recurring adjustments, which are necessary to make our financial position at September 30, 2017 and the results of our operations for the three and nine months ended September 30, 2017 and 2016 not misleading. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying condensed consolidated financial statements do not include all disclosures normally required by generally accepted accounting principles in the United States of America (GAAP). These financial statements should be read in conjunction with the financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2016 on file with the SEC. In our opinion, the condensed consolidated financial statements are a fair presentation of the financial position, results of operations and cash flows for the periods presented.

The results of operations for the three and nine months ended September 30, 2017 are not necessarily indicative of the results of operations to be expected for the full fiscal year ending December 31, 2017.

Revenue Recognition

Revenue from the sales of custom and fabricated compressors, and flare systems is recognized when title passes to the customer, the customer assumes risks and rewards of ownership, collectability is reasonably assured and delivery occurs as directed by our customer. From time to time, we have customers that request units and flares to be built under a bill and hold arrangement. In order to recognize revenue under a bill and hold arrangement the following criteria must be met: risk of ownership was passed to the customer, customer made a fixed commitment to purchase the goods, the customer requested the bill and hold, there was a fixed schedule for delivery, we no longer had any specific performance obligations, the purchase was segregated at our facility and the equipment was complete and ready to ship. For the nine months ended September 30, 2017, we recognized revenue of $5.7 million under these bill and hold arrangements. Exchange and rebuilt compressor revenue is recognized when the replacement compressor has been delivered and the rebuild assessment has been completed. Revenue from compressor service and retrofitting services is recognized upon providing services to the customer. Maintenance agreement revenue is recognized as services are rendered. Rental revenue is recognized over the terms of the respective rental agreements. Deferred income represents payments received before a product is shipped. Revenue from the sale of rental units is included in sales revenue when equipment is shipped or title is transferred to the customer.

Fair Value of Financial Instruments

Our financial instruments consist principally of cash and cash equivalents, accounts receivable, accounts payable, deferred compensation plan (cash portion) and our line of credit. Pursuant to ASC 820 (Accounting Standards Codification), the fair value of our cash equivalents is determined based on “Level 1” inputs, which consist of quoted prices in active markets for identical assets. We believe that the recorded values of all of our other financial instruments approximate their fair values because of their nature and relatively short maturity dates or durations.

Recently Issued Accounting Pronouncements

On February 25, 2016, the Financial Accounting Standards Board ("FASB") issued ASU No. 2016-02, Leases (Topic 842). Under the new guidance, a lessee will be required to recognize assets and liabilities for capital and operating leases with lease terms of more than 12 months. Additionally, this ASU will require disclosures to help investors and other financial statement users better understand the amount, timing, and uncertainty of cash flows arising from leases, including qualitative and quantitative requirements. For public business entities, the amendments are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, with early adoption permitted. The new standard will be effective during our first quarter ending March 31, 2019. We are currently determining the impacts of the new standard on our condensed consolidated financial statements and the additional applicable disclosure requirements.

services. This guidance also requires more detailed disclosures to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In August 2015, the FASB issued an accounting standards update for a one-year deferral of the revenue recognition standard’s effective date for all entities, which changed the effectiveness to interim and annual reporting periods beginning after December 15, 2017. As a result, we expect to adopt this guidance on January 1, 2018. The guidance offers two transition methods: a full retrospective approach to be applied to each prior reporting period presented or a modified retrospective approach where the cumulative effect of initially applying the standard is recognized at the date of initial application. We have preliminarily selected the modified retrospective transition method. We are currently determining the impacts of the new standard on our consolidated financial statements. Our approach includes performing a detailed review of key contracts that are representative of our various revenue streams and comparing our historical accounting policies and practices to the new standard. Our sales and service and maintenance contracts are more short-term in nature or can usually be completed within the same quarter they are started; but, at this stage in our assessment we are still finalizing our evaluation of the extent to which we will have changes, upon adoption. For the impact related to our rental revenues, we are in the final stages of our review and have not concluded as to what impact, if any, there may be to our rental revenues. We also tentatively anticipate a change in our disclosures under the new standard. We expect to complete our review by mid-November 2017.

(2) Stock-Based Compensation

Stock Options:

A summary of option activity under our 1998 Stock Option Plan as of December 31, 2016, and changes during the nine months ended September 30, 2017 is presented below.



	Number of Stock Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Life (years)	Aggregate Intrinsic Value (in thousands)
Outstanding, December 31, 2016	350,186		$	19.45	4.25	$	4,453
Granted	32,750		28.15
Exercised	(25,580	)	20.19			271
Outstanding, September 30, 2017	357,356		$	20.19	4.18	$	3,050
Exercisable, September 30, 2017	307,108		$	19.19	3.44	$	2,946

The following table summarizes information about our stock options outstanding at September 30, 2017:



Range of Exercise Prices	Options Outstanding				Options Exercisable
Range of Exercise Prices	Shares	Weighted Average Remaining Contractual Life (years)	Weighted Average Exercise Price		Shares	Weighted Average Exercise Price
$0.01-15.70	65,852	1.81	$	9.82	65,852	$	9.82
$15.71-17.81	72,750	2.04	17.53		72,750	17.53
$17.82-20.48	86,836	2.59	19.60		86,836	19.60
$20.49-33.36	131,918	7.58	27.23		81,670	27.79
	357,356	4.18	$	20.19	307,108	$	19.19

The summary of the status of our unvested stock options as of December 31, 2016 and changes during the nine months ended September 30, 2017 is presented below.



Unvested stock options:	Shares		Weighted Average Grant Date Fair Value Per Share
Unvested at December 31, 2016	50,833		$	12.67
Granted	32,750		11.93
Vested	(33,335	)	13.80
Unvested at September 30, 2017	50,248		$	11.44

As of September 30, 2017, there was $349,134 of unrecognized compensation cost related to unvested options. Such cost is expected to be recognized over a weighted-average period of two years. Total compensation expense for stock options was $286,500 and $388,732 for the nine months ended September 30, 2017 and 2016, respectively.

Restricted Shares/Units:

In accordance with the Company's employment agreement with Stephen Taylor, the Company's Chief Executive Officer, the Compensation Committee reviewed his performance in determining the issuance of restricted common stock. Based on this review which included consideration of the Company's 2016 performance, Mr. Taylor, was awarded 70,464 restricted shares/units on February 14, 2017, which vest over three years, in equal installments, beginning February 14, 2018. On March 23, 2017, the Compensation Committee awarded 20,000 restricted shares/units to each of G. Larry Lawrence, our CFO, and James Hazlett, our Vice President of Technical Services. The restricted shares to Messrs. Lawrence and Hazlett vest over three years, in equal installments, beginning March 23, 2018. We also awarded and issued 15,968 shares of restricted common stock to our Board of Directors as partial payment for 2017 directors' fees. The restricted stock issued to our directors vests over one year, in quarterly installments, beginning March 31, 2018. Total compensation expense related to restricted awards was $2,945,020 and $1,350,427 for the nine months ended September 30, 2017 and 2016, respectively. As of September 30, 2017, there was a total of $2,114,256 of unrecognized compensation expense related to these shares/units which is expected to be recognized over the next two years.

(3) Inventory

Our inventory, net of allowance for obsolescence of $16,458 and $15,000 at September 30, 2017 and December 31, 2016, respectively, consisted of the following amounts:



	September 30, 2017		December 31, 2016
	(in thousands)
Raw materials	$	20,860	$	18,365
Finished Goods	1,007		2,558
Work in process	6,512		4,910
	$	28,379	$	25,833

During the nine months ended September 30, 2017 and 2016, there were no write-offs of obsolete inventory against the allowance for obsolescence.

(4) Retirement of Long-Lived Assets

During the review of our rental compressor units, management looks for any units that are not of the type, configuration, make or model that our customers are demanding or that were not cost efficient to refurbish, maintain and/or operate. From our review in 2016, we determined 63 units should be retired from our rental fleet with key components from those units being re-utilized in future unit builds and/or repairs. We performed an optimization review and recorded a $545,000 loss on retirement of

rental equipment to reduce the book value of each unit to the estimated fair value of approximately $242,000 for key components being kept. This retirement was recorded in the 2016 consolidated income statement under loss on retirement of rental equipment. No retirements have been made in 2017.

(5) Deferred Compensation Plans

Effective January 1, 2016, the Company established a non-qualified deferred compensation plan for executive officers, directors and certain eligible employees. The assets of the deferred compensation plan are held in a rabbi trust and are subject to additional risk of loss in the event of bankruptcy or insolvency of the Company. The plan allows for deferral of up to 90% of a participant’s base salary, bonus, commissions, director fees and restricted stock unit awards. A Company owned life insurance policy held in a rabbi trust is utilized as a source of funding for the plan. The cash surrender value of the life insurance policy is $814,000 and $149,000 as of September 30, 2017 and 2016, respectively, with a gain related to the policy of approximately $35,000 and $7,000 reported in other income in the condensed consolidated income statement for the nine months ending September 30, 2017 and 2016, respectively.

For deferrals of base salary, bonus, commissions and director fees, settlement payments are made to participants in cash, either in a lump sum or in periodic installments. The obligation to pay the deferred compensation and the deferred director fees is adjusted to reflect the positive or negative performance of investment measurement options selected by each participant and was $779,000 and $151,000 as of September 30, 2017 and 2016, respectively. The deferred obligation is included in other long-term liabilities in the condensed consolidated balance sheet.

For deferrals of restricted stock units, the plan does not allow for diversification, therefore, distributions are paid in shares of common stock and the obligation is carried at grant value. As of September 30, 2017, 97,011 unvested restricted stock units have been deferred.

(6) Credit Facility

We have a senior secured revolving credit agreement the ("Amended Credit Agreement") with JP Morgan Chase Bank, N.A (the "Lender") with an aggregate commitment of $30 million, subject to collateral availability. We also have a right to request from the Lender, on an uncommitted basis, an increase of up to $20 million on the aggregate commitment (which could potentially increase the commitment amount to $50 million). On August 31, 2017, we amended and renewed the Amended Credit Agreement, which was set to expire on December 31, 2017. The Credit Agreement Amendment extends the maturity date to December 31, 2020. No other material revisions were made to the credit facility.

Borrowing Base. At any time before the maturity of the Amended Credit Agreement, we may draw, repay and re-borrow amounts available under the borrowing base up to the maximum aggregate availability discussed above. Generally, the borrowing base equals the sum of (a) 80% of our eligible accounts receivable plus (b) 50% of the book value of our eligible general inventory (not to exceed 50% of the commitment amount at the time) plus (c) 75% of the book value of our eligible equipment inventory. The Lender may adjust the borrowing base components if material deviations in the collateral are discovered in future audits of the collateral. We had $29.5 million borrowing base availability at September 30, 2017 under the terms of our Amended Credit Agreement.

Interest and Fees. Under the terms of the Amended Credit Agreement, we have the option of selecting the applicable variable rate for each revolving loan, or portion thereof, of either (a) LIBOR multiplied by the Statutory Reserve Rate (as defined in the Amended Credit Agreement), with respect to this rate, for Eurocurrency funding, plus the Applicable Margin (“LIBOR-based”), or (b) CB Floating Rate, which is the Lender's Prime Rate less the Applicable Margin; provided, however, that no more than three LIBOR-based borrowings under the agreement may be outstanding at any one time. For purposes of the LIBOR-based interest rate, the Applicable Margin is 1.50%. For purposes of the CB Floating Rate, the Applicable Margin is 1.50%. For the nine month period ended September 30, 2017, our weighted average interest rate was 2.49%.

Accrued interest is payable monthly on outstanding principal amounts, provided that accrued interest on LIBOR-based loans is payable at the end of each interest period, but in no event less frequently than quarterly. In addition, fees and expenses are payable in connection with our requests for letters of credit (generally equal to the Applicable Margin for LIBOR-related borrowings multiplied by the face amount of the requested letter of credit) and administrative and legal costs.

Maturity. The maturity date of the Amended Credit Agreement is December 31, 2020, at which time all amounts borrowed under the agreement will be due and outstanding letters of credit must be cash collateralized. The agreement may be terminated early upon our request or the occurrence of an event of default.

Security. The obligations under the Amended Credit Agreement are secured by a first priority lien on all of our inventory and accounts and leases receivables, along with a first priority lien on a variable number of our leased compressor equipment the book value of which must be maintained at a minimum of 2.00 to 1.00 commitment coverage ratio (such ratio being equal to (i) the amount of the borrowing base as of such date to (ii) the amount of the commitment as of such date.)

Covenants. The Amended Credit Agreement contains customary representations and warranties, as well as covenants which, among other things, limit our ability to incur additional indebtedness and liens; enter into transactions with affiliates; make acquisitions in excess of certain amounts; pay dividends; redeem or repurchase capital stock or senior notes; make investments or loans; make negative pledges; consolidate, merge or effect asset sales; or change the nature of our business. In addition, we also have certain financial covenants that require us to maintain on a consolidated basis a leverage ratio less than or equal to 2.50 to 1.00 as of the last day of each fiscal quarter.

Events of Default and Acceleration. The Amended Credit Agreement contains customary events of default for credit facilities of this size and type, and includes, without limitation, payment defaults; defaults in performance of covenants or other agreements contained in the loan documents; inaccuracies in representations and warranties; certain defaults, termination events or similar events; certain defaults with respect to any other Company indebtedness in excess of $50,000; certain bankruptcy or insolvency events; the rendering of certain judgments in excess of $150,000; certain ERISA events; certain change in control events and the defectiveness of any liens under the secured revolving credit facility. Obligations under the Amended Credit Agreement may be accelerated upon the occurrence of an event of default.

As of September 30, 2017, we were in compliance with all covenants in our Amended Credit Agreement. A default under our Credit Agreement could trigger the acceleration of our bank debt so that it is immediately due and payable. Such default would likely limit our ability to access other credit. At September 30, 2017 and December 31, 2016 our outstanding balance on the line of credit was $417,000.

(7) Earnings per Share

The following table reconciles the numerators and denominators of the basic and diluted earnings per share computation(in thousands, except per share data):



	Three months ended				Nine months ended
	September 30,				September 30,
	2017		2016		2017		2016
Numerator:
Net income	$	522	$	1,509	$	1,149	$	5,309
Denominator for basic net income per common share:
Weighted average common shares outstanding	12,838		12,717		12,825		12,691

Denominator for diluted net income per share:
Weighted average common shares outstanding	12,838		12,717		12,825		12,691
Dilutive effect of stock options and restricted stock	279		245		277		222
Diluted weighted average shares	13,117		12,962		13,102		12,913
Earnings per common share:
Basic	$	0.04	$	0.12	$	0.09	$	0.42
Diluted	$	0.04	$	0.12	$	0.09	$	0.41

In the three and nine months ended September 30, 2017, options to purchase 83,917 shares of common stock with exercise prices ranging from $28.15 to $33.36 were not included in the computation of dilutive income per share, due to their antidilutive effect.

In the three months ended September 30, 2016, options to purchase 52,500 shares of common stock with exercise prices ranging from $30.41 to $33.36 were not included in the computation of dilutive income per share, due to their antidilutive effect.

In the nine months ended September 30, 2016, options to purchase 105,833 shares of common stock with exercise prices ranging from $22.90 to $33.36 were not included in the computation of dilutive income per share, due to their antidilutive effect.

(8) Segment Information

ASC 280-10-50, “Operating Segments", defines the characteristics of an operating segment as: a) being engaged in business activity from which it may earn revenue and incur expenses, b) being reviewed by the Company's chief operating decision maker (CODM) for decisions about resources to be allocated and assess its performance and c) having discrete financial information. Although we look at our products to analyze the nature of our revenue, other financial information, such as certain costs and expenses, net income and EBITDA are not captured or analyzed by these categories. Our CODM does not make resource allocation decisions or access the performance of the business based on these categories, but rather in the aggregate. Based on this, management believes that it operates in one business segment.

In their analysis of product lines as potential operating segments, management also considered ASC 280-10-50-11, “Aggregation Criteria”, which allows for the aggregation of operating segments if the segments have similar economic characteristics and if the segments are similar in each of the following areas:


•	The nature of the products and services;


•	The nature of the production processes;


•	The type or class of customer for their products and services;


•	The methods used to distribute their products or provide their services; and


•	The nature of the regulatory environment, if applicable.

We are engaged in the business of designing and manufacturing compressors and flares. Our compressors and flares are sold and rented to our customers. In addition, we provide service and maintenance on compressors in our fleet and to third parties. These business activities are similar in all geographic areas. Our manufacturing process is essentially the same for the entire Company and is performed in-house at our facilities in Midland, Texas and Tulsa, Oklahoma. Our customers primarily consist of entities in the business of producing natural gas and crude oil. The maintenance and service of our products is consistent across the entire Company and is performed via an internal fleet of vehicles. The regulatory environment is similar in every jurisdiction in that the most impacting regulations and practices are the result of federal energy policy. In addition, the economic characteristics of each customer arrangement are similar in that we maintain policies at the corporate level.



For the three months ended September 30, 2017 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	11,292	$	4,256	$	365	$	—		$	15,913
Operating costs and corporate expenses	4,333		3,237		90		7,660			15,320
Total other expense, net	—		—				(14		)	(14		)
Income before provision for income taxes	$	6,959	$	1,019	$	275	$	(7,674	)	$	579



For the three months ended September 30, 2016 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	13,157	$	2,536	$	488	$	—		$	16,181
Operating costs and corporate expenses	4,513		2,191		122		7,532			14,358
Total other income, net	—		—				8			8
Income before provision for income taxes	$	8,644	$	345	$	366	$	(7,524	)	$	1,831



For the nine months ended September 30, 2017 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	34,634	$	15,300	$	1,099	$	—		$	51,033
Operating costs and expenses	13,256		12,405		288		23,734			$	49,683
Total other expense, net	—		—		—		(12		)	$	(12	)
Income before provision for income taxes	$	21,378	$	2,895	$	811	$	(23,746	)	$	1,338



For the nine months ended September 30, 2016 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	44,220	$	9,746	$	985	$	—		$	54,951
Operating costs and expenses	15,618		8,359		318		23,193			47,488
Total other income, net	—		—		—		16			16
Income before provision for income taxes	$	28,602	$	1,387	$	667	$	(23,177	)	$	7,479

(9) Commitments and Contingencies

From time to time, we are a party to various legal proceedings in the ordinary course of our business. While management is unable to predict the ultimate outcome of these actions, it believes that any ultimate liability arising from these actions will not have a material adverse effect on our financial position, results of operations or cash flow. We are not currently a party to any material legal proceedings, and we are not aware of any threatened material litigation.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The discussion and analysis of our financial condition and results of operations are based on, and should be read in conjunction with, our condensed, consolidated financial statements and the related notes included elsewhere in this report and in our Annual Report on Form 10-K for the year ended December 31, 2016 filed with the SEC.

Overview

We fabricate, manufacture, rent, and sell natural gas compressors and related equipment. Our primary focus is on the rental of natural gas compressors. Our rental contracts generally provide for initial terms of six to 24 months. After the initial term of our rental contracts, many of our customers have continued to rent our compressors on a month-to-month basis. Rental amounts are billed monthly in advance and include maintenance of the rented compressors. As of September 30, 2017, we had 1,251 natural gas compressors totaling 180,433 horsepower rented to 80 customers compared to 1,387 natural gas compressors totaling 196,721 horsepower rented to 79 customers at September 30, 2016.

We also fabricate natural gas compressors for sale to our customers, designing compressors to meet unique specifications dictated by well pressures, production characteristics, and particular applications for which compression is sought. Fabrication of compressors involves our purchase of engines, compressors, coolers, and other components, and our assembling of these components on skids for delivery to customer locations. The major components of our compressors are acquired through periodic purchase orders placed with third-party suppliers on an “as needed” basis, which presently requires a two to three month lead time with delivery dates scheduled to coincide with our estimated production schedules. Although we do not have formal continuing supply contracts with any major supplier, we believe we have adequate alternative sources available. In the past, we have not experienced any sudden and dramatic increases in the prices of the major components for our compressors. However, the occurrence of such an event could have a material adverse effect on the results of our operations and financial condition, particularly if we were unable to increase our rental rates and sales prices proportionate to any such component price increases.

We also manufacture a proprietary line of compressor frames, cylinders and parts, known as our CiP (Cylinder-in-Plane) product line. We use finished CiP component products in the fabrication of compressor units for sale or rental by us or sell the finished component products to other compressor fabricators. We also design, fabricate, sell, install, and service flare stacks and related ignition and control devices for onshore and offshore incineration of gas compounds such as hydrogen sulfide, carbon dioxide, natural gas and liquefied petroleum gases. To provide customer support for our compressor and flare sales businesses, we stock varying levels of replacement parts at our Midland, Texas facility and at field service locations. We also provide an exchange and rebuild program for screw compressors and maintain an inventory of new and used compressors to facilitate this business.

We provide service and maintenance to our customers under written maintenance contracts or on an as-required basis in the absence of a service contract. Maintenance agreements typically have terms of nine months to one year and require payment of a monthly fee.

The oil and natural gas equipment rental and services industry is cyclical in nature. The most critical factor in assessing the outlook for the industry is the worldwide supply and demand for natural gas and crude oil and the corresponding changes in commodity prices. As demand and prices increase, oil and natural gas producers increase their capital expenditures for drilling, development and production activities. Generally, the increased capital expenditures ultimately result in greater revenues and profits for services and equipment companies.

In general, we expect our overall business activity and revenues to track the level of activity in the natural gas industry, with changes in domestic natural gas production and consumption levels and prices more significantly affecting our business than changes in crude oil and condensate production and consumption levels and prices. However, in recent years we have increased our rental and sales in the non-conventional shale plays which are more dependent on crude oil prices. We also believe that demand for compression services and products is driven by declining reservoir pressure in maturing natural gas producing fields and, more recently, by increased focus by producers on non-conventional natural gas production, such as coalbed methane, gas shales and tight gas, which typically requires more compression than production from conventional natural gas reservoirs.

We typically experience a decline in demand during periods of low crude oil and natural gas prices. Low crude oil and natural gas prices experienced throughout 2016 have continued in 2017, with some price movement but no significant sustaining price increases. Through much of this period, producers maintained their focus on non-conventional oil and gas opportunities. The continued inconsistent price environment has caused reduced project spending on both conventional and non-conventional plays. While the timing of a return to aggressive investment in the projects is uncertain, we believe the long-term trend in our

market is favorable. We believe this outlook is supported by our ability to withstand cyclical disruptions and position the Company for the long term.

Results of Operations

Three months ended September 30, 2017, compared to the three months ended September 30, 2016.

The table below shows our revenues and percentage of total revenues of each of our product lines for the three months ended September 30, 2017 and 2016.



	Revenue Three months ended September 30,
	(in thousands)
	2017				2016
Rental	$	11,292	71	%	$	13,157	81	%
Sales	4,256		27	%	2,536		16	%
Service and Maintenance	365		2	%	488		3	%
Total	$	15,913			$	16,181

Total revenue slightly decreased to $15.9 million from $16.2 million, or 2%, for the three months ended September 30, 2017, compared to the same period ended September 30, 2016. The decrease is mainly a result of a drop in rental revenue due to fewer units being rented, offset by increased sales.

Rental revenue decreased to $11.3 million from $13.2 million for the three months ended September 30, 2017, compared to the same period ended September 30, 2016. We ended the quarter with 2,538 compressor packages in our fleet, down from 2,626 units at September 30, 2016. The rental fleet had a utilization of 49.3% as of September 30, 2017 compared to 52.8% utilization as of September 30, 2016. The drop in utilization is mainly the result of compressor rental units being returned due to the continuing depressed oil and natural gas prices. We have experienced some relief in the number of sets versus returns over the past quarter resulting in the smallest decline in our utilization rate since the start of 2015. In the event that oil and natural gas prices increase, we expect to see an increase in the utilization of our fleet.

Sales revenue increased to $4.3 million from $2.5 million for the three months ended September 30, 2017 compared to the same period ended September 30, 2016. This increase is the result of fluctuations in timing of industry activity related to capital projects. We believe this timing is reflective of the typical sales cycle, resulting in fluctuating compressor unit sales to third parties from our Tulsa and Midland operations. We also had an increase in our flares product line during this comparative period, due to customer demand.

Our overall operating income decreased $1.2 million to $593,000 from $1.8 million for the three months ended September 30, 2017 compared to the same period ended September 30, 2016, largely due to the decrease in rental revenue, net of the increase in sales revenue. Operating margin percentage decreased to 4% from 11% for the three months ended September 30, 2017 and September 30, 2016, respectively. The operating margin decreased due to the reduction in rental revenue.

Selling, general, and administrative expense increased to $2.3 million from $2.1 million for the three months ended September 30, 2017, and September 30, 2016, primarily due to an increase in stock compensation expense.

Depreciation and amortization expense decreased to $5.3 million for the three months ended September 30, 2017, compared to $5.4 million for the period ended September 30, 2016. This decrease is the result of fewer units being added to the fleet and older units becoming fully depreciated. We added only 16 units to our fleet over the past 12 months.

Provision for income tax was $57,000 and $322,000 for the three months ended September 30, 2017 and September 30, 2016, respectively. The decrease in the provision is due to a decrease in taxable income and a change in effective tax rate between the two periods.

Nine months ended September 30, 2017, compared to the nine months ended September 30, 2016.

The table below shows our revenues and percentage of total revenues of each of our product lines for the nine months ended September 30, 2017 and 2016.



	Revenue Nine months ended September 30,
	(in thousands)
	2017				2016
Rental	$	34,634	68	%	$	44,220	80	%
Sales	15,300		30	%	9,746		18	%
Service and Maintenance	1,099		2	%	985		2	%
Total	$	51,033			$	54,951

Total revenue decreased to $51.0 million from $55.0 million, or 7.1%, for the nine months ended September 30, 2017, compared to the same period ended September 30, 2016. Comparing the nine months ended September 30, 2017 to the same period in 2016, rental revenue decreased 22% and sales revenue increased 57%.

Rental revenue decreased to $34.6 million from $44.2 million for the nine months ended September 30, 2017, compared to the same period ended September 30, 2016. This decrease is the result of the number of units returned due to low oil and natural gas prices. We ended the quarter with 2,538 compressor packages in our rental fleet down from 2,626 units at September 30, 2016. The rental fleet had a utilization of 49.3%, as of September 30, 2017 compared to 52.8% utilization as of September 30, 2016. We have experienced some relief in the number of sets versus returns over the past quarter resulting in the smallest decline in our utilization rate since the start of 2015. In the event that oil and natural gas prices increase, we should see incremental utilization of our fleet.

Sales revenue increased to $15.3 million from $9.7 million for the nine months ended September 30, 2017, compared to the same period ended September 30, 2016. This increase is the result of the fluctuations in timing of industry activity related to capital projects. We believe this timing is reflective of the typical sales cycle, resulting in fluctuating compressor unit sales to third parties from our Tulsa and Midland operations. There was also an increase in demand for flares during this comparative period, due to customer demand.

Our overall operating income decreased $6.1 million to $1.4 million from $7.5 million for the nine months ended September 30, 2017 compared to the same period ended 2016, largely due to a decrease in rental revenue, offset by the increase in sales revenue and by an increase in stock compensation expense. Operating margin percentage decreased to 3% from 14%, respectively, for the nine months ended September 30, 2017 compared to the same period ended September 30, 2016. Our overall operating income and operating margin decreased due the reduction in rental revenue and an increase in stock compensation expense.

Selling, general, and administrative expense increased to $7.8 million from $6.8 million, for the nine months ended September 30, 2017, as compared to the same period ended September 30, 2016, due to an increase in stock compensation expense offset by a decrease in executive bonus compensation expense.

Depreciation and amortization expense decreased to $16.0 million for the nine months ended September 30, 2017, compared to $16.4 million for the period ended September 30, 2016. This decrease is the result of fewer units being added to the fleet and older units becoming fully depreciated. We added only 16 units to our fleet over the past 12 months.

Provision for income tax decreased to $189,000 from $2.2 million and is the result of the decrease in taxable income and a change in effective tax rate between the two periods.

Liquidity and Capital Resources

Our working capital positions as of September 30, 2017 and December 31, 2016 are set forth below:



	September 30,		December 31,
	2017		2016
	(in thousands)
Current Assets:
Cash and cash equivalents	$	72,924	$	64,094
Trade accounts receivable, net	7,163		7,378
Inventory, net	28,379		25,833
Prepaid income taxes	2,339		1,482
Prepaid expenses and other	1,127		972
Total current assets	111,932		99,759
Current Liabilities:
Line of credit	—		417
Accounts payable	1,830		971
Accrued liabilities	3,955		2,887
Deferred income	185		2,225
Total current liabilities	5,970		6,500
Total working capital	$	105,962	$	93,259

For the nine months ended September 30, 2017, we invested $4.7 million in equipment for our rental fleet and service vehicles. Even though we have idle rental equipment, at times we do not have the specific type of equipment that our customers require, therefore we have to build new equipment to satisfy their needs. We financed this activity with cash flow from operations and cash on hand.

Cash flows

At September 30, 2017, we had cash and cash equivalents of $72.9 million compared to $64.1 million at December 31, 2016. Our cash flow from operations of $14.2 million was offset by capital expenditures of $4.7 million, during the nine months ended September 30, 2017. We had working capital of $106.0 million at September 30, 2017 compared to $93.3 million at December 31, 2016. On September 30, 2017 and December 31, 2016, we had outstanding debt of $417,000, which is all related to our line of credit and is classified as non-current as of September 30, 2017. We had positive net cash flow from operating activities of $14.2 million during the first nine months of 2017 compared to $29.5 million for the first nine months of 2016. The cash flow from operations of $14.2 million was primarily the result of the net income of $1.1 million and the non-cash items of depreciation of $16.0 million, $3.2 million related to the expenses associated with stock-based compensation, a decrease in deferred income taxes of $2.6 million and a decrease in working capital of $3.5 million.

Strategy

For the remainder of the fiscal year 2017 and into 2018, our overall plan is to continue monitoring and holding expenses in line with the anticipated level of activity, fabricate rental fleet equipment only in direct response to market requirements, emphasize marketing of our idle gas compressor units and limit bank borrowing in line with market conditions. For the remainder of 2017, our forecasted capital expenditures will be directly dependent upon our customers’ compression requirements and are not anticipated to exceed our internally generated cash flows and cash on hand. Any required capital will be for additions to our compressor rental fleet and/or addition or replacement of service vehicles. We believe that cash flows from operations, our current cash position and our line of credit will be sufficient to satisfy our capital and liquidity requirements for the foreseeable future. We may require additional capital to fund any unanticipated expenditures, including any acquisitions of other businesses, although that capital, beyond our line of credit, as discussed below may not be available to us when we need it or on acceptable terms.

Bank Borrowings

We have a senior secured revolving credit agreement the ("Amended Credit Agreement") with JP Morgan Chase Bank, N.A. (the "Lender") with an aggregate commitment of $30 million, subject to collateral availability. We also have a right to request from the lender, on an uncommitted basis, an increase of up to $20 million on the aggregate commitment (which could potentially increase the commitment amount to $50 million). On August 31, 2017, we amended and renewed the Amended Credit Agreement, which was set to expire on December 31, 2017. The Credit Agreement Amendment extends the maturity date to December 31, 2020. No other material revisions were made to the credit facility.

Security. The obligations under the Amended Credit Agreement are secured by a first priority lien on all of our inventory and accounts and leases receivables, along with a first priority lien on a variable number of our leased compressor equipment the book value of must be maintained at a minimum of 2.00 to 1.00 commitment coverage ratio (such ratio being equal to (i) the amount of the borrowing base as of such date to (ii) the amount of the commitment as of such date.)

Contractual Obligations and Commitments

We have contractual obligations and commitments that affect the results of operations, financial condition and liquidity. The following table is a summary of our significant cash contractual obligations as of September 30, 2017:



	Obligations Due in Period (in thousands)
Cash Contractual Obligations	2017 ⁽¹⁾		2018		2019		2020		Thereafter		Total
Line of credit (secured)	$	—	$	—	$	—	$	417	$	—	$	417
Interest on line of credit⁽²⁾	4		17		17		17		—		55
Purchase obligations⁽³⁾	80		300		300		300		639		1,619
Other long-term liabilities	—		—		—		—		102		102
Facilities and office leases	104		295		72		9		1		481
Total	$	188	$	612	$	389	$	743	$	742	$	2,674

(1)For the three months remaining in 2017.

(2)Assumes an interest rate of 4.0% and no additional borrowings.

(3)Vendor exclusive purchase agreement related to paint and coatings.

Critical Accounting Policies and Practices

There have been no changes in the critical accounting policies disclosed in the Company's Form 10-K for the year ended December 31, 2016.

Recently Issued Accounting Pronouncements

On May 28, 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606). This update provides a five-step analysis on how an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance also requires more detailed disclosures to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In August 2015, the FASB issued an accounting standards update for a one-year deferral of the revenue recognition standard’s effective date for all entities, which changed the effectiveness to interim and annual reporting periods beginning after December 15, 2017. As a result, we expect to adopt this guidance on January 1, 2018. The guidance offers two transition methods: a full retrospective approach to be applied to each prior reporting period presented or a modified retrospective approach where the cumulative effect of initially applying the standard is recognized at the date of initial application. We have preliminarily selected the modified retrospective transition method. We are currently determining the impacts of the new standard on our consolidated financial statements. Our approach includes performing a detailed review of key contracts that are representative of our various revenue streams and comparing our historical accounting policies and practices to the new standard. Our sales and service and maintenance contracts are more short-term in nature or can usually be completed within the same quarter they are started; but, at this stage in our assessment we are still finalizing our evaluation of the extent to which we will have changes, upon adoption. For the impact related to our rental revenues, we are in the final stages of our review and have not concluded as to what impact, if any, there may be to our rental revenues. We also tentatively anticipate a change in our disclosures under the new standard. We expect to complete our review by mid-November 2017.

Off-Balance Sheet Arrangements

From time-to-time, we enter into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of September 30, 2017, the off-balance sheet arrangements and transactions that we have entered into include operating lease agreements and purchase agreements. We do not believe that these arrangements are reasonably likely to materially affect our liquidity, availability of, or requirements for, capital resources.

Special Note Regarding Forward-Looking Statements

Except for historical information contained herein, the statements in this report are forward-looking and made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Forward-looking statements involve known and unknown risks and uncertainties, which may cause our actual results in future periods to differ materially from forecasted results. Those risks include, among other things, the loss of market share through competition or otherwise; the introduction of competing technologies by other companies; a prolonged, substantial reduction in oil and natural gas prices which could cause a decline in the demand for our products and services; and new governmental safety, health and environmental regulations which could require us to make significant capital expenditures. The forward-looking statements included in this Form 10-Q are only made as of the date of this report, and we undertake no obligation to publicly update such forward-looking statements to reflect subsequent events or circumstances. A discussion of these and other risk factors is included in our Annual Report on Form 10-K for the year ended December 31, 2016 filed with the SEC.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

There have been no changes in the market risks disclosed in the Company's Form 10-K for the year ended December 31, 2016.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures.

An evaluation was carried out under the supervision and with the participation of our management, including our President and Chief Executive Officer and our Vice President and Principal Accounting Officer, of the effectiveness of the design and of our “disclosure controls and procedures” (as such term is defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended or, the “Exchange Act”) as of the end of the period covered by this report pursuant to Exchange Act Rule 13a-15. Based upon that evaluation, the President and Chief Executive Officer and our Vice President and Principal Accounting Officer have concluded that our disclosure controls and procedures as of the end of the period covered by this report were effective to ensure that information required to be disclosed by us in the reports filed or submitted by us under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms. These include controls and procedures designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our principal executive and financial officers as appropriate to allow timely decisions regarding required disclosures. Due to the inherent limitations of control systems, not all misstatements or omissions may be detected. Those inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple errors or mistakes. Additionally, controls could be circumvented by the individual acts of some persons or by collusion of two or more people. Our controls and procedures can only provide reasonable, not absolute, assurance that the above objectives have been met.

Changes in Internal Controls.

There were no changes in our internal control over financial reporting identified in connection with the evaluation required by paragraph (d) of Exchange Act Rules 13a-15 or 15d-15 that occurred during our last quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

From time to time, we are a party to various legal proceedings in the ordinary course of our business. While management is unable to predict the ultimate outcome of these actions, it believes that any ultimate liability arising from these actions will not have a material adverse effect on our financial position, results of operations or cash flow. We are not currently a party to any material legal proceedings and we are not aware of any threatened litigation.

Item 1A. Risk Factors

Please refer to and read “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, 2016 for a discussion of the risks associated with our Company and industry.

Item 6. Exhibits

The following exhibits are filed herewith or incorporated herein by reference, as indicated:



Exhibit No.	Description

3.1	Articles of Incorporation, as amended (Incorporated by reference to Exhibit 3.1 of the 10-QSB filed and dated November 10, 2004)

3.2	Bylaws as amended (Incorporated by reference to Exhibit 3.1 of the Registrant's current report on form 8-K filed with the Securities and Exchange Commission on June 21, 2016.



10.1	Lease Agreement, dated March 26, 2008, between WNB Tower, LTD and Natural Gas Services Group, Inc. (Incorporated by reference to Exhibit 10.15 of the Registrant’s Form 10-K for the fiscal year ended December 31, 2008 and filed with the Securities and Exchange Commission on March 9, 2009)

10.2	2009 Restricted Stock/Unit Plan, as amended (Incorporated by reference to Exhibit 99.1 of the Registrant’s Current Report on Form 8-K dated June 3, 2014 and filed with the Securities and Exchange Commission on June 6, 2014.)

10.3	Stock Option Plan, as amended and restated (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on June 21, 2016.)

10.4	Lease Agreement, dated December 11, 2008, between Klement-Wes Partnership, LTD and Natural Gas Services Group, Inc. and commencing on January 1, 2009

10.5	Credit Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated December 10, 2010 (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on November 24, 2014.)

10.6	Third Amendment of Credit Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated November 19, 2014 (Incorporated by reference to Exhibit 10.1 of the Registrant's Current report on Form 8-K filed with the Securities and Exchange Commission on January 9, 2012.)

10.7	Fifth Amendment of Credit Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated August 31, 2017 (Incorporated by reference to Exhibit 10.2 of the Registrant's Current report on Form 8-K filed with the Securities and Exchange Commission on September 7, 2017.)

10.8	Security Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated December 10, 2010 (Incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on December 16, 2010.)

10.9	Fourth Security Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated August 31, 2017 (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on September 7, 2017.)

10.10	First Amendment of Security Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated December 31, 2011 (Incorporated by reference to Exhibit 10.2 of the Registrant's Current report on Form 8-K filed with the Securities and Exchange Commission on January 9, 2012.)

10.11	Promissory Note in the aggregate amount of $30,000,000 issued to JPMorgan Chase Bank, N.A., dated August 31, 2017, in connection with the revolving credit line under the Credit Agreement with JPMorgan Chase Bank, N.A. (Incorporated by reference to Exhibit 10.3 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on September 7, 2017.)

10.12	Amended and restated Employment Agreement dated April 27, 2015 between Natural Gas Services Group, Inc. and Stephen C. Taylor (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on April 29, 2015.)

10.13	The Executive Nonqualified Excess Plan Adoption Agreement, referred to as the Nonqualified Deferred Compensation Plan (Incorporated by reference to Exhibit 10.11 of the Registrant's Quarterly report on Form 10-Q filed with the Securities and Exchange Commission on May 6, 2016.)



10.14	Annual Incentive Bonus Plan (Incorporated by reference to Exhibit 10.1 of the Registrant's Current Report on Form 8-K filed with the Securities and Exchange Commission December 18, 2012.)

*31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

*31.2	Certification of Principal Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

*32.1	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

*32.2	Certification of Principal Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101.INS	XBRL Instance Document

101.SCH	XBRL Taxonomy Extension Schema Document

101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF	XBRL Taxonomy Extension Definition Linkbase Document

101.LAB	XBRL Taxonomy Extension Label Linkbase Document

101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

	* Filed herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

NATURAL GAS SERVICES GROUP, INC.



/s/ Stephen C. Taylor		/s/ G. Larry Lawrence
Stephen C. Taylor		G. Larry Lawrence
President and Chief Executive Officer		Vice President and Chief Financial Officer
(Principal Executive Officer)		(Principal Accounting Officer)

November 3, 2017