NATURAL GAS SERVICES GROUP INC - FORM 10-Q

Attached files

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EX-32.2 - EXHIBIT 32.2 - NATURAL GAS SERVICES GROUP INC	ngs-33117xex322.htm
EX-32.1 - EXHIBIT 32.1 - NATURAL GAS SERVICES GROUP INC	ngs-33117xex321.htm
EX-31.2 - EXHIBIT 31.2 - NATURAL GAS SERVICES GROUP INC	ngs-33117xex312.htm
EX-31.1 - EXHIBIT 31.1 - NATURAL GAS SERVICES GROUP INC	ngs-33117xex311.htm

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 March 31, 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		May 1, 2017
Common Stock, $0.01 par value		12,937,363



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	10

Item 3. Quantitative and Qualitative Disclosures about Market Risk	Page	15

Item 4. Controls and Procedures	Page	15

Part II - OTHER INFORMATION

Item 1. Legal Proceedings	Page	16

Item 1A. Risk Factors	Page	16

Item 6. Exhibits	Page	17

Signatures	Page	19

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements



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

	March 31,		December 31,
	2017		2016
ASSETS
Current Assets:
Cash and cash equivalents	$	74,370	$	64,094
Trade accounts receivable, net of allowance for doubtful accounts of $646 and $597, respectively	4,681		7,378
Inventory, net	23,900		25,833
Prepaid income taxes	123		1,482
Prepaid expenses and other	401		972
Total current assets	103,475		99,759
Rental equipment, net of accumulated depreciation of $130,990 and $126,096, respectively	169,500		174,060
Property and equipment, net of accumulated depreciation of $11,248 and $11,267 respectively	7,432		7,753
Goodwill	10,039		10,039
Intangibles, net of accumulated amortization of $1,539 and $1,508, respectively	1,620		1,651
Other assets	375		262
Total assets	$	292,441	$	293,524
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Line of credit	$	417	$	417
Accounts payable	496		971
Accrued liabilities	3,430		2,887
Deferred income	484		2,225
Total current liabilities	4,827		6,500
Deferred income tax liability	52,479		53,745
Other long-term liabilities	372		325
Total liabilities	57,678		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; 12,818 and 12,764 shares issued and outstanding, respectively	128		128
Additional paid-in capital	102,369		100,812
Retained earnings	132,266		132,014
Total stockholders' equity	234,763		232,954
Total liabilities and stockholders' equity	$	292,441	$	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
	March 31,
	2017			2016
Revenue:
Rental income	$	11,922		$	16,408
Sales	6,637			4,910
Service and maintenance income	343			258
Total revenue	18,902			21,576
Operating costs and expenses:
Cost of rentals, exclusive of depreciation stated separately below	4,668			5,694
Cost of sales, exclusive of depreciation stated separately below	5,423			3,932
Cost of service and maintenance	94			111
Selling, general and administrative expense	3,046			2,569
Depreciation and amortization	5,328			5,503
Total operating costs and expenses	18,559			17,809
Operating income	343			3,767
Other income (expense):
Interest expense	(2		)	(2		)
Other income	3			19
Total other income, net	1			17
Income before provision for income taxes	344			3,784
Provision for income taxes	92			1,243
Net income	$	252		$	2,541
Earnings per share:
Basic	$	0.02		$	0.20
Diluted	$	0.02		$	0.20
Weighted average shares outstanding:
Basic	12,804			12,648
Diluted	13,056			12,838

See accompanying notes to these unaudited condensed consolidated financial statements.



NATURAL GAS SERVICES GROUP, INC. CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands) (unaudited)
	Three months ended
	March 31,
	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	252		$	2,541
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	5,328			5,503
Deferred income taxes	(1,266		)	135
Stock-based compensation	1,532			648
Bad debt allowance	60			29
Gain on sale of assets	(27		)	(25		)
Gain on company owned life insurance	(12		)	(3		)
Changes in operating assets and liabilities:
Trade accounts receivables	2,637			(1,769		)
Inventory	1,981			2,791
Prepaid expenses	1,930			165
Accounts payable and accrued liabilities	68			68
Deferred income	(1,741		)	(86		)
Other	43			51
Tax benefit from equity compensation	—			(15		)
NET CASH PROVIDED BY OPERATING ACTIVITIES	10,785			10,033
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of property and equipment	(464		)	(1,942		)
Purchase of company owned life insurance	(93		)	(48		)
Proceeds from sale of property and equipment	27			25
NET CASH USED IN INVESTING ACTIVITIES	(530		)	(1,965		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments from other long-term liabilities, net	(4		)	(3		)
Proceeds from exercise of stock options	517			352
Taxes paid related to net share settlement of equity awards	(492		)	(909		)
Tax benefit from equity compensation	—			15
NET CASH PROVIDED BY/(USED IN) FINANCING ACTIVITIES	21			(545		)
NET CHANGE IN CASH AND CASH EQUIVALENTS	10,276			7,523
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	64,094			35,532
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	74,370		$	43,055
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Interest paid	$	2		$	2
Income taxes paid	$	—		$	1,550
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 March 31, 2017 and the results of our operations for the three months ended March 31, 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 months ended March 31, 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 three months ended March 31, 2017, we recognized revenue of $837,000 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 January 1, 2017, we adopted Accounting Standards Update (“ASU”) No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The ASU simplifies several aspects of accounting for share-based payment transactions, including the income tax impact, classification of awards as equity or liabilities, classifications on the statement of cash flows and forfeitures. The section of the update that will have the most impact on our financial statements will be how the excess tax benefits and tax deficiencies on stock-based compensation awards are recorded. These items are now included in our tax provision within our condensed consolidated statement of operations as discrete items in the reporting period in which they occur, rather than in previous accounting of being recorded in additional paid-in capital on our condensed consolidated balance sheets. We have also elected to continue our current policy of estimating forfeitures of stock-based compensation awards at the time of grant and revising in subsequent periods to reflect actual forfeitures. We applied the update prospectively beginning January 1, 2017, and the adoption did not have a material impact on our condensed consolidated financial statements.

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.

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. This standard is required to be applied either retrospectively to each prior reporting period presented or retrospectively with the cumulative effect of initially applying it recognized at the date of initial application. We have not yet selected the 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 representative of our revenue units and comparing historical accounting policies and practices to the new standard. A majority of our revenue transactions are short-term in nature, and our assessment at this stage is that we do not expect the new revenue recognition standard will have a material impact on our financial position or results of operations upon adoption.

(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 three months ended March 31, 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
Canceled/Forfeited	—		—
Outstanding, March 31, 2017	357,356		$	20.19	4.68	$	2,399
Exercisable, March 31, 2017	305,441		$	19.11	3.92	$	2,345

The following table summarizes information about our stock options outstanding at March 31, 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	2.31	$	9.82	65,852	$	9.82
$15.71-17.81	72,750	2.54	17.53		72,750	17.53
$17.82-20.48	86,836	3.09	19.60		86,836	19.60
$20.49-33.36	131,918	8.09	27.23		80,003	27.67
	357,356	4.68	$	20.19	305,441	$	19.11

The summary of the status of our unvested stock options as of December 31, 2016 and changes during the three months ended March 31, 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	(31,668	)	13.56
Canceled/Forfeited	—		—
Unvested at March 31, 2017	51,915		$	11.66

As of March 31, 2017, there was $491,128 of unrecognized compensation cost related to unvested options. Such cost is expected to be recognized over a weighted-average period of three years. Total compensation expense for stock options was $124,331 and $166,523 for the three months ended March 31, 2017 and 2016, respectively.

Restricted Stock:

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 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 shares of restricted common stock to each of G. Larry Lawrence, our CFO, and James Hazlett, our Vice President of Technical Services. The restricted shares to Messrs. Hazlett and Lawrence 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 stock awards was $1,408,265 and $481,753 for the three months ended March 31, 2017 and 2016, respectively. As of March 31, 2017, there was a total of $3,649,957 of unrecognized compensation expense related to these shares 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 March 31, 2017 and December 31, 2016, respectively, consisted of the following amounts:



	March 31, 2017		December 31, 2016
	(in thousands)
Raw materials	$	18,183	$	18,365
Finished Goods	1,008		2,558
Work in process	4,709		4,910
	$	23,900	$	25,833

During the three months ended March 31, 2017 and 2016, there were no write-offs of obsolete inventory against the allowance for obsolescence.

(4) Retirement of Long-Lived Assets

During the annual 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 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 $312,000 and $51,000 as of March 31, 2017 and 2016, respectively, with a gain related to the policy of approximately $12,000 and $3,000 reported in other income in the condensed consolidated income statement for the three months ending March 31, 2017and 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 $261,000 and $51,000 as of March 31, 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, 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 March 31, 2017, 97,011 unvested shares 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).

(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 March 31, 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 three month period ended March 31, 2017, our weighted average interest rate was 2.24%.

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, 2017, 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 March 31, 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 March 31, 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
	March 31,
	2017		2016
Numerator:
Net income	$	252	$	2,541
Denominator for basic net income per common share:
Weighted average common shares outstanding	12,804		12,648

Denominator for diluted net income per share:
Weighted average common shares outstanding	12,804		12,648
Dilutive effect of stock options and restricted stock	252		190
Diluted weighted average shares	13,056		12,838
Earnings per common share:
Basic	$	0.02	$	0.20
Diluted	$	0.02	$	0.20

In the three months ended March 31, 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 March 31, 2016, options to purchase 187,500 shares of common stock with exercise prices ranging from $19.61 to $33.46 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 March 31, 2017 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	11,922	$	6,637	$	343	$	—		$	18,902
Operating costs and corporate expenses	4,668		5,423		94		8,374			18,559
Total other expense, net	—		—				1			1
Income before provision for income taxes	$	7,254	$	1,214	$	249	$	(8,373	)	$	344



For the three months ended March 31, 2016 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	16,408	$	4,910	$	258	$	—		$	21,576
Operating costs and corporate expenses	5,694		3,932		111		8,072			17,809
Total other income, net	—		—				17			17
Income before provision for income taxes	$	10,714	$	978	$	147	$	(8,055	)	$	3,784

(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, most 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 March 31, 2017, we had 1,261 natural gas compressors totaling 180,594 horsepower rented to 75 customers compared to 1,610 natural gas compressors totaling 230,170 horsepower rented to 84 customers at March 31, 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.

Demand for our products and services have been generally strong. However, 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 the first three months of 2017, with some price movement but no significant sustaining price increases. Through much of this period, producers maintained their focus on non-conventional 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 temporary disruptions and position the Company for the long term.

Results of Operations

Three months ended March 31, 2017, compared to the three months ended March 31, 2016.

The table below shows our revenues and percentage of total revenues of each of our product lines for the three months ended March 31, 2017 and 2016.



	Revenue Three months ended March 31,
	(in thousands)
	2017				2016
Rental	$	11,922	63	%	$	16,408	76	%
Sales	6,637		35	%	4,910		23	%
Service and Maintenance	343		2	%	258		1	%
Total	$	18,902			$	21,576

Total revenue decreased to $18.9 million from $21.6 million, or 12%, for the three months ended March 31, 2017, compared to the same period ended March 31, 2016. The decrease is mainly a result of the $4.5 million drop in rental revenue due to the number of units being rented, as the oil and natural gas price environment persists at levels below that which promotes increased developments.

Rental revenue decreased to $11.9 million from $16.4 million for the three months ended March 31, 2017, compared to the same period ended March 31, 2016. We ended the quarter with 2,531 compressor packages in our fleet, down from 2,627 units at March 31, 2016. The rental fleet had a utilization of 49.8% as of March 31, 2017 compared to 61.3% utilization as of March 31, 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. In the event that oil and natural gas prices increase, we should see an increase in the utilization of our fleet.

Sales revenue increased to $6.6 million from $4.9 million for the three months ended March 31, 2017 compared to the same period ended March 31, 2016. We had an increase in our sales of compressors product line offset by a decrease in our sales of flares during this comparative period.

Our overall operating income decreased $3.4 million to $343,000 from $3.8 million for the three months ended March 31, 2017 compared to the same period ended March 31, 2016, due to a decrease in rental revenue and an increase in stock compensation expense. Operating margin percentage decreased to 2% from 17% for the three months ended March 31, 2017 and March 31, 2016, respectively. The operating margin decreased due the reduction in rental revenue and an increase in stock compensation expense.

Selling, general, and administrative expense increased to $3.0 million from $2.6 million for the three months ended March 31, 2017, and March 31, 2016, primarily due to an increase in stock compensation expense.

Depreciation and amortization expense decreased to $5.3 million for the three months ended March 31, 2017, compared to $5.5 million for the period ended March 31, 2016. This decrease is the result of fewer units being added to the fleet and older units becoming fully depreciated. We added only 15 units over the past 12 months to our fleet.

Provision for income tax was $92,000 and $1.2 million for the three months ended March 31, 2017 and March 31, 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.

Liquidity and Capital Resources

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



	March 31,		December 31,
	2017		2016
	(in thousands)
Current Assets:
Cash and cash equivalents	$	74,370	$	64,094
Trade accounts receivable, net	4,681		7,378
Inventory, net	23,900		25,833
Prepaid income taxes	123		1,482
Prepaid expenses and other	401		972
Total current assets	103,475		99,759
Current Liabilities:
Line of credit	417		417
Accounts payable	496		971
Accrued liabilities	3,430		2,887
Deferred income	484		2,225
Total current liabilities	4,827		6,500
Total working capital	$	98,648	$	93,259

For the three months ended March 31, 2017, we invested $464,000 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 March 31, 2017, we had cash and cash equivalents of $74.4 million compared to $64.1 million at December 31, 2016. Our cash flow from operations of $10.8 million was offset by capital expenditures of $464,000, during the three months ended March 31, 2017. We had working capital of $98.6 million at March 31, 2017 compared to $93.3 million at December 31, 2016. On March 31, 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 current. We had positive net cash flow from operating activities of $10.8 million during the first three months of 2017 compared to $10.0 million for the first three months of 2016. The cash flow from operations of $10.8 million was primarily the result of the net income of $252,000 and the non-cash items of depreciation of $5.3 million, $1.5 million related to the expenses associated with stock options and restricted shares, an increase in working capital of $5.0 million and a decrease in deferred income taxes of $1.3 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).

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 March 31, 2017, under the terms of our Amended Credit Agreement.

Maturity. The maturity date of the Amended Credit Agreement is December 31, 2017, 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 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 March 31, 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⁾	13		—		—		—		—		13
Purchase obligations⁽³⁾	247		300		300		300		639		1,786
Other long-term liabilities	—		—		—		—		112		112
Facilities and office leases	330		284		59		—		—		673
Total	$	1,007	$	584	$	359	$	300	$	751	$	3,001

(1)For the nine 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

update prospectively beginning January 1, 2017, and the adoption did not have a material impact on our condensed consolidated financial statements.

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 March 31, 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 (Incorporated by reference to Exhibit 3.4 of the Registrant's Registration Statement on Form SB-2, No. 333-88314)

4.1	Non-Statutory Stock Option Agreement (Incorporated by reference to Exhibit 10.2 to Form 8-K filed with the SEC on August 30, 2005)



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	1998 Stock Option Plan, as amended (Incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K dated September 18, 2009 and filed with the Securities and Exchange Commission on September 18, 2009.)

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	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, 2011.)

10.8	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.)

10.9	Promissory Note in the aggregate amount of $30,000,000 issued to JPMorgan Chase Bank, N.A., dated December 31, 2014, in connection with the revolving credit line under the Credit Agreement with JPMorgan Chase Bank, N.A. (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 November 24, 2014.)

10.10	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.)

10.11	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.)

10.12	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 8, 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)

May 5, 2017

INDEX TO 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 (Incorporated by reference to Exhibit 3.4 of the Registrant's Registration Statement on Form SB-2, No. 333-88314)

4.1	Non-Statutory Stock Option Agreement (Incorporated by reference to Exhibit 10.2 to Form 8-K filed with the SEC on August 30, 2005)



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	1998 Stock Option Plan, as amended (Incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K dated September 18, 2009 and filed with the Securities and Exchange Commission on September 18, 2009.)

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	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, 2011.)

10.8	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.)

10.9	Promissory Note in the aggregate amount of $30,000,000 issued to JPMorgan Chase Bank, N.A., dated December 31, 2014, in connection with the revolving credit line under the Credit Agreement with JPMorgan Chase Bank, N.A. (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 November 24, 2014.)

10.10	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.)

10.11	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.)



10.12	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 8, 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.

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