NATURAL GAS SERVICES GROUP INC - Quarter Report: 2014 June (Form 10-Q)

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 June 30, 2014

( ) 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” in Rule 12b-2 of the Exchange Act.



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

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		August 4, 2014
Common Stock, $0.01 par value		12,519,405



Part I - FINANCIAL INFORMATION

Item 1. Financial Statements

Unaudited Condensed Balance Sheets	Page	1

Unaudited Condensed Income Statements	Page	2

Unaudited Condensed Statements of Cash Flows	Page	3

Notes to Unaudited Condensed 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	17

Item 4. Controls and Procedures	Page	18

Part II - OTHER INFORMATION

Item 1. Legal Proceedings	Page	18

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 BALANCE SHEETS (in thousands, except per share amounts) (unaudited)

	June 30,		December 31,
	2014		2013
ASSETS
Current Assets:
Cash and cash equivalents	$	14,439	$	24,443
Trade accounts receivable, net of allowance for doubtful accounts of $447 and $436, respectively	7,113		6,750
Inventory, net	28,302		26,832
Prepaid income taxes	2,969		2,281
Prepaid expenses and other	886		339
Total current assets	53,709		60,645
Rental equipment, net of accumulated depreciation of $95,937 and $86,533, respectively	194,775		176,420
Property and equipment, net of accumulated depreciation of $10,221 and $9,692, respectively	7,293		7,429
Goodwill	10,039		10,039
Intangibles, net of accumulated amortization of $2,253 and $2,191, respectively	1,965		2,027
Other assets	37		29
Total assets	$	267,818	$	256,589
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Line of credit	$	437	$	577
Accounts payable	2,289		3,904
Accrued liabilities	8,826		6,487
Current income tax liability	2,937		350
Deferred income	639		873
Total current liabilities	15,128		12,191
Deferred income tax liability	51,550		51,464
Other long-term liabilities	176		197
Total liabilities	66,854		63,852
Commitments and contingencies (Note 7)
Stockholders’ Equity:
Preferred stock, 5,000 shares authorized, no shares issued or outstanding	—		—
Common stock, 30,000 shares authorized, par value $0.01; 12,461 and 12,366 shares issued and outstanding, respectively	125		123
Additional paid-in capital	93,328		91,344
Retained earnings	107,511		101,270
Total stockholders' equity	200,964		192,737
Total liabilities and stockholders' equity	$	267,818	$	256,589

See accompanying notes to these unaudited condensed financial statements.



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

	Three months ended						Six months ended
	June 30,						June 30,
	2014			2013			2014			2013
Revenue:
Rental income	$	19,465		$	16,721		$	38,254		$	32,728
Sales, net	2,275			3,329			5,613			11,164
Service and maintenance income	212			208			407			349
Total revenue	21,952			20,258			44,274			44,241
Operating costs and expenses:
Cost of rentals, exclusive of depreciation stated separately below	7,749			6,258			15,705			13,070
Cost of sales, exclusive of depreciation stated separately below	1,098			1,600			3,333			6,482
Cost of service and maintenance, exclusive of depreciation and amortization stated separately below	84			85			168			153
Selling, general, and administrative expense	2,690			2,035			5,333			3,881
Depreciation and amortization	5,246			4,436			10,288			8,674
Total operating costs and expenses	16,867			14,414			34,827			32,260
Operating income	5,085			5,844			9,447			11,981
Other income (expense):
Interest expense	(3		)	(11		)	(5		)	(42		)
Other income (expense)	47			(68		)	52			268
Total other income (expense), net	44			(79		)	47			226
Income before provision for income taxes	5,129			5,765			9,494			12,207
Provision for income taxes	1,744			1,921			3,253			4,369
Net income	$	3,385		$	3,844		$	6,241		$	7,838
Earnings per share:
Basic	$	0.27		$	0.31		$	0.50		$	0.64
Diluted	$	0.27		$	0.31		$	0.49		$	0.63
Weighted average shares outstanding:
Basic	12,436			12,316			12,405			12,299
Diluted	12,752			12,518			12,722			12,447

See accompanying notes to these unaudited condensed financial statements.



NATURAL GAS SERVICES GROUP, INC. CONDENSED STATEMENTS OF CASH FLOWS (in thousands) (unaudited)

	Six months ended
	June 30,
	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	6,241		$	7,838
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	10,288			8,674
Deferred income taxes	86			4,067
Stock based compensation	1,638			598
Gain on disposal of assets	(40		)	—
Gain on extinguishment of liability	—			(223		)
Changes in current assets and liabilities:
Trade accounts receivables	(363		)	374
Inventory	(1,453		)	306
Prepaid expenses	(936		)	(1,323		)
Accounts payable and accrued liabilities	425			(1,479		)
Current income tax liability	2,874			302
Deferred income	(234		)	285
Other	(8		)	—
Tax benefit from equity compensation	(287		)	—
NET CASH PROVIDED BY OPERATING ACTIVITIES	18,231			19,419
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of property and equipment	(28,462		)	(18,429		)
Proceeds from sale of property and equipment	40			—
NET CASH USED IN INVESTING ACTIVITIES	(28,422		)	(18,429		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayments from other long-term liabilities, net	(21		)	(64		)
Repayments of line of credit	(140		)	(50		)
Proceeds from exercise of stock options	61			368
Tax benefit from equity compensation	287			—
NET CASH PROVIDED BY FINANCING ACTIVITIES	187			254
NET CHANGE IN CASH AND CASH EQUIVALENTS	(10,004		)	1,244
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	24,443			28,086
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	14,439		$	29,330
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Interest paid	$	5		$	42
Income taxes paid	$	981		$	1,801
NON-CASH TRANSACTIONS
Transfer of rental equipment to inventory	$	53		$	57

See accompanying notes to these unaudited condensed financial statements.

Natural Gas Services Group, Inc.

Notes to Condensed Financial Statements

(unaudited)

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

These notes apply to the unaudited condensed 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 financial statements include all adjustments, consisting of only normal recurring adjustments, which are necessary to make our financial position at June 30, 2014 and the results of our operations for the three and six months ended June 30, 2014 and 2013 not misleading. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying condensed 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, 2013 on file with the SEC. In our opinion, the condensed 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 six months ended June 30, 2014 are not necessarily indicative of the results of operations to be expected for the full fiscal year ending December 31, 2014.

Revenue Recognition

Revenue from the sales of custom and fabricated compressors, and flare systems is recognized upon shipment of the equipment to customers or when all conditions have been met and title is transferred to the customer. Exchange and rebuild compressor revenue is recognized when both the replacement compressor has been delivered and the rebuild assessment has been completed. Revenue from compressor 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 based upon the classification of the rental agreement. 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 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 May 28, 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers (Topic 606), as part of a joint project with the International Accounting Standards Board (IASB)
to clarify revenue-recognizing principles and develop a common revenue standard for U.S. GAAP and International Financial Reporting Standards (IFRS). ASU No. 2014-09 finalizes Proposed ASU Nos. 1820-100, 2011-230 and 2011-250 is expected, among other things, to remove inconsistencies and weaknesses in revenue requirements and improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets. In particular, the amendments in this ASU will be added to the FASB Accounting Standards Codification (FASB ASC) as Topic 606, Revenue from Contracts with Customers, and will supersede the revenue recognition requirements in FASB ASC 605, Revenue Recognition, as well as some cost guidance in FASB ASC Subtopic 605-35, Revenue Recognition-Construction-Type and Production-Type Contracts. The core principle of this ASU is that 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. To achieve this core principle, the guidance provides that an entity should apply the following steps: (1) identify the contract(s) with a customer; (2) identify the performance obligation in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when, or as, the entity satisfies a performance obligation. For public entities, the amendments in ASU No. 2014-09 are effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, and early application is prohibited. Additionally, an entity should apply the amendments either retrospectively to each prior reporting period presented or retrospectively with the cumulative effect

of initially applying this ASU recognized at the date of initial application. If an entity elects the latter, transition method, then it must also provide the additional disclosures in reporting periods that include the date of initial application of (1) the amount by which each financial statement line item is affected in the current reporting period, as compared to the guidance that was in effect before the change, and (2) an explanation of the reasons for significant changes. The new standard will be effective during our first quarter ending March 31, 2017. We are currently evaluating the new standard to determine which reporting option allows us to report the most meaningful information and are still evaluating the potential impact this new standard will have on our financial statements.

(2) Stock-Based Compensation

Stock Options:

A summary of option activity under our 1998 Stock Option Plan as of December 31, 2013, and changes during the six months ended June 30, 2014 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, 2013	378,852		$	15.61	5.23	$	4,533
Granted	50,000		30.41		—	—
Exercised	(3,500	)	17.13		—	48
Canceled/Forfeited	(1,333	)	17.99		—	16
Outstanding, June 30, 2014	424,019		$	17.33	5.30	$	6,669
Exercisable, June 30, 2014	341,185		$	15.34	4.34	$	6,045

The following table summarizes information about our stock options outstanding at June 30, 2014:



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
$0.01-9.43	71,352	2.47	$	8.72	71,352	$	8.72
$9.44-15.60	70,000	4.56	12.51		64,166	12.30
$15.61-30.41	282,667	6.20	20.70		205,667	18.59
	424,019	5.30	$	17.33	341,185	$	15.34

The summary of the status of our unvested stock options as of December 31, 2013 and changes during the six months ended June 30, 2014 is presented below.



Unvested stock options:	Shares		Weighted Average Grant Date Fair Value
Unvested at December 31, 2013	63,082		$	9.87
Granted	50,000		16.78
Vested	(28,915	)	9.80
Canceled/Forfeited	(1,333	)	9.82
Unvested at June 30, 2014	82,834		$	14.06

As of June 30, 2014, there was $895,174 of unrecognized compensation cost related to unvested options. Such cost is expected to be recognized over a weighted-average period of 2.38 years. Total compensation expense for stock options was $174,270 and $57,144 for the six months ended June 30, 2014 and 2013, 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 2013 performance, Mr. Taylor, was awarded 49,420 restricted shares on January 23, 2014, which vest one year from the date of grant. On March 20, 2014, the Compensation Committee awarded 15,000 shares of restricted common stock to each of G. Larry Lawrence, our CFO, and James Hazlett our Vice President of Technical Services, subject to the approval at our June 2014 annual meeting of shareholders of a proposal to increase the number of shares reserved for issuance under our 2009 restricted Stock\Unit Plan. As the proposal was approved by shareholders at the 2014 annual meeting, we issued the restricted shares to Messrs. Hazlett and Lawrence which vest one year from the grant date. We also awarded and issued 13,152 shares of restricted common stock to our Board of Directors as partial payment for 2014 Directors' fees. The restricted stock vests in quarterly installments beginning March 31, 2015. Total compensation expense related to restricted stock awards was $1,463,733 and $540,703 for the six months ended June 30, 2014 and 2013, respectively. As of June 30, 2014, there was a total of $1,956,752 of unrecognized compensation expenses related to these shares which is expected to be recognized over the next eighteen months.

(3) Inventory

Our inventory, net of allowance for obsolescence of $128,000 at June 30, 2014 and December 31, 2013, consisted of the following amounts:



	June 30, 2014		December 31, 2013
	(in thousands)
Raw materials	$	22,381	$	20,524
Work in process	5,921		6,308
	$	28,302	$	26,832

During the six months ended June 30, 2014 and 2013, there were no write offs of obsolete inventory against the allowance for obsolescence.

(4) Credit Facility

We have a senior secured revolving credit agreement with JP Morgan Chase Bank, N.A (the "Amended Credit Agreement") aggregate commitment $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. JPMorgan Chase Bank (the “Lender”) may adjust the borrowing base components if material deviations in the collateral are discovered in future audits of the collateral. We had $29.4 million borrowing base availability at June 30, 2014 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 1.25%. For the six month period ended June 30, 2014, our weighted average interest rate was 1.40%.

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, 2014, 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 June 30, 2014, 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 June 30, 2014 and December 31, 2013, our outstanding balance on the line of credit was $437,000 and $577,000, respectively.

(5) 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				Six months ended
	June 30,				June 30,
	2014		2013		2014		2013
Numerator:
Net income	$	3,385	$	3,844	$	6,241	$	7,838
Denominator for basic net income per common share:
Weighted average common shares outstanding	12,436		12,316		12,405		12,299

Denominator for diluted net income per share:
Weighted average common shares outstanding	12,436		12,316		12,405		12,299
Dilutive effect of stock options and restricted stock	316		202		317		148
Diluted weighted average shares	12,752		12,518		12,722		12,447
Earnings per common share:
Basic	$	0.27	$	0.31	$	0.50	$	0.64
Diluted	$	0.27	$	0.31	$	0.49	$	0.63

(6) 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 to assess its performance and c) having discrete financial information. Although we indeed look at our product lines 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. Therefore discrete financial information is not available by product line and our CODM does not make resource allocation decisions or assess 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 June 30, 2014 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	19,465	$	2,275	$	212	$	—		$	21,952
Operating costs and expenses	7,749		1,098		84		7,936			16,867
Other income, net	—		—		—		44			44
Income before provision for income taxes	$	11,716	$	1,177	$	128	$	(7,892	)	$	5,129



For the three months ended June 30, 2013 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	16,721	$	3,329	$	208	$	—		$	20,258
Operating costs and expenses	6,258		1,600		85		6,471			14,414
Other expense, net	—		—		—		79			79
Income before provision for income taxes	$	10,463	$	1,729	$	123	$	(6,550	)	$	5,765




For the six months ended June 30, 2014 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	38,254	$	5,613	$	407	$	—		$	44,274
Operating costs and expenses	15,705		3,333		168		15,621			34,827
Other income (expense)	—		—		—		47			47
Income before provision for income taxes	$	22,549	$	2,280	$	239	$	(15,574	)	$	9,494




For the six months ended June, 2013 (in thousands):
	Rental		Sales		Service & Maintenance		Corporate			Total
Revenue	$	32,728	$	11,164	$	349	$	—		$	44,241
Operating costs and expenses	13,070		6,482		153		12,555			32,260
Other income (expense)	—		—		—		226			226
Income before provision for income taxes	$	19,658	$	4,682	$	196	$	(12,329	)	$	12,207

(7) 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 other 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 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, 2013 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 June 30, 2014, we had 2,142 natural gas compressors totaling 295,803 horsepower rented to 97 third parties compared to 1,889 natural gas compressors totaling 264,150 horsepower rented to 99 third parties at June 30, 2013.

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 six 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, 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 historically strong, but in 2009 and early 2010 the demand declined due to lower natural gas prices, decreased demand for natural gas and the economic recession. This began to show signs of easing during the latter part of 2010 and through 2013. However, natural gas prices have had only slight movements up followed by downward movements. Meanwhile, opportunities have developed in non-conventional shale plays. While shale plays continued to offer opportunities, natural gas prices have not surged, leaving demand for compression in conventional areas uncertain.

Natural gas prices continue at levels that do not encourage energy companies to invest capital in natural gas projects. In addition, the domestic economy has not fully recovered. Notwithstanding the continuing uncertain economy and financial markets, we believe the long-term trend in our market is favorable. We believe this outlook is supported by the growth in our revenue in 2012, 2013 and our continued stable results in the first six months of 2014.

Results of Operations

Three months ended June 30, 2014, compared to the three months ended June 30, 2013.

The table below shows our revenues and percentage of total revenues of each of our product lines for the three months ended June 30, 2014 and 2013.



	Revenue Three months ended June 30,
	(in thousands)
	2014				2013
Rental	$	19,465	89	%	$	16,721	83	%
Sales	2,275		10	%	3,329		16	%
Service and Maintenance	212		1	%	208		1	%
Total	$	21,952			$	20,258

Total revenue increased to $22.0 million from $20.3 million, or 8%, for the three months ended June 30, 2014, compared to the same period ended June 30, 2013. The $1.7 million increase in revenue was due to an increase in rental revenue of $2.7 million offset by a decrease in sales revenue of $1.0 million. Comparing the three months ended June 30, 2014 to the same period in 2013, rental revenue increased 16% and sales revenue decreased 32%.

Rental revenue increased to $19.5 million from $16.7 million for the three months ended June 30, 2014, compared to the same period ended June 30, 2013. This increase is the result of higher oil and natural gas industry drilling and demand for low to mid horsepower compression. We ended the quarter with 2,732 compressor packages in our rental fleet, up from 2,392 units at June 30, 2013. The rental fleet had a utilization of 78.4% as of June 30, 2014 compared to 79.0% utilization as of June 30, 2013. This steady utilization is mainly the result of a consistently high number of compressor rental units in our inventory being matched to customer requirements and being returned to service in comparison to units being returned from operation. In the event that natural gas prices increase, we should see additional utilization of our fleet due to a possible leveling of returns related to dry gas.

Sales revenue decreased to $2.3 million from $3.3 million for the three months ended June 30, 2014, compared to the same period ended June 30, 2013. This decrease is the result of timing of industry activity related to the completion of capital projects. We believe this timing is reflective of the typical sales cycle, resulting in inconsistent compressor units sales to third parties from our Tulsa and Midland operations. There was also a decrease in demand for flares during this comparative period.

Our overall operating income decreased $700,000 from $5.8 million to $5.1 million with the margin percentage decreasing to 23% from 29% for the three months ended June 30, 2014 compared to the same period ended June 30, 2013. The operating margin decrease is mainly the result of depreciation associated with additions to our rentals fleet and, to a lesser extent, increases in administrative expenses.

Selling, general, and administrative expense increased to $2.7 million from $2.0 million, for the three months ended June 30, 2014, as compared to the same period ended June 30, 2013, due to increases in equity compensation expense.

Depreciation and amortization expense increased to $5.2 million for the three months ended June 30, 2014, compared to $4.4 million for the period ended June 30, 2013. This was the result of new gas compressor rental units being added to the rental fleet from June 30, 2013 to June 30, 2014. We added a net of 89 compressors to our rental fleet during the three month period ending June 30, 2014.

Provision for income tax was $1.7 million and $1.9 million for the three months ended June 30, 2014 and June 30, 2013, respectively. The provision is the result of a decrease in taxable income for the three months ended June 30, 2014 compared to the three months ended June 30, 2013 and in addition we experienced a slightly lower effective tax rate.

Six months ended June 30, 2014, compared to the six months ended June 30, 2013.

The table below shows our revenues and percentage of total revenues of each of our product lines for the six months ended June 30, 2014 and 2013.



	Revenue Six months ended June 30,
	(in thousands)
	2014				2013
Rental	$	38,254	86	%	$	32,728	74	%
Sales	5,613		13	%	11,164		25	%
Service and Maintenance	407		1	%	349		1	%
Total	$	44,274			$	44,241

Total revenue increased to $44.3 million from $44.2 million, or 0.1%, for the six months ended June 30, 2014, compared to the same period ended June 30, 2013. Comparing the six months ended June 30, 2014 to the same period in 2013, rental revenue increased 17% and sales revenue decreased 50%.

Rental revenue increased to $38.3 million from $32.7 million for the six months ended June 30, 2014, compared to the same period ended June 30, 2013. This increase is the result of higher oil and natural gas industry drilling and demand for low to mid horsepower compression. We ended the quarter with 2,732 compressor packages in our rental fleet, up from 2,392 units at June 30, 2013. The rental fleet had a utilization of 78.4% as of June 30, 2014 compared to 79.0% utilization as of June 30, 2013. This utilization decrease is mainly the result of more compressor rental units in our inventory being matched to customer requirements and being returned to service as well as fewer units being returned from operation. In the event that natural gas prices increase, we should see incremental utilization of our fleet.

Sales revenue decreased to $5.6 million from $11.2 million for the six months ended June 30, 2014, compared to the same period ended June 30, 2013. This decrease is the result of timing of industry activity related to capital projects. We believe this timing is reflective of the typical sales cycle, resulting in inconsistent compressor units sales to third parties from our Tulsa and Midland operations. There was a slight increase in demand for flares during this comparative period.

Our overall operating income decreased $2.6 million from $12.0 million to $9.4 million with the margin percentage decreasing to 21% from 27% for the six months ended June 30, 2014 compared to the same period ended June 30, 2013. The operating margin decrease is mainly the result of depreciation associated with additions to our rentals fleet and, to a lesser extent, increases in administrative expenses.

Selling, general, and administrative expense increased to $5.3 million from $3.9 million, for the six months ended June 30, 2014, as compared to the same period ended June 30, 2013, due to increases in equity compensation expense.

Depreciation and amortization expense increased to $10.3 million for the six months ended June 30, 2014, compared to $8.7 million for the period ended June 30, 2013. This was the result of new gas compressor rental units being added to the rental fleet from June 30, 2013 to June 30, 2014. We added a net of 341 compressors to our rental fleet during the twelve month period ending June 30, 2014.

Provision for income tax decreased to $3.3 million from $4.4 million, or 25.0%, and is the result of the decrease in taxable income and a change in effective tax rate between the two periods. We had an effective tax rate of 34.3% in the six months ended June 30, 2014 and 35.8% in the six months ended June 30, 2013.

Liquidity and Capital Resources

Our working capital positions as of June 30, 2014 and December 31, 2013 are set forth below:



	June 30,		December 31,
	2014		2013
	(in thousands)
Current Assets:
Cash and cash equivalents	$	14,439	$	24,443
Trade accounts receivable, net	7,113		6,750
Inventory, net	28,302		26,832
Prepaid income taxes	2,969		2,281
Prepaid expenses and other	886		339
Total current assets	53,709		60,645
Current Liabilities:
Line of credit	437		577
Accounts payable	2,289		3,904
Accrued liabilities	8,826		6,487
Current portion of tax liability	2,937		350
Deferred income	639		873
Total current liabilities	15,128		12,191
Total working capital	$	38,581	$	48,454

For the six months ended June 30, 2014, we invested $28.5 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 June 30, 2014, we had cash and cash equivalents of $14.4 million compared to $24.4 million at December 31, 2013. Our cash flow from operations of $18.2 million was offset by capital expenditures of $28.5 million, during the six months ended June 30, 2014. We had working capital of $38.6 million at June 30, 2014 compared to $48.5 million at December 31, 2013. At June 30, 2014 and December 31, 2013, we had outstanding debt of $437,000 and $577,000, respectively, which is all related to our line of credit and classified as current. We had positive net cash flow from operating activities of $18.2 million during the first six months of 2014 compared to $19.4 million for the first six months of 2013. The cash flow from operations of $18.2 million was primarily the result of the net income of $6.2 million and the non-cash items of depreciation of $10.3 million and $1.6 million related to the expensing associated with stock options and restricted shares.

Strategy

For the remainder of the fiscal year 2014 and into 2015, our overall plan is to continue monitoring 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 2014, 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 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. Capital expenditures for the year ending December 31, 2014 are not anticipated to exceed our internal cash generating capacity. We may require additional capital to fund any unanticipated expenditures, including any acquisitions of other businesses.

Bank Borrowings

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. JPMorgan Chase Bank (the “Lender”) may adjust the borrowing base components if material deviations in the collateral are discovered in future audits of the collateral. We had $29.4 million million borrowing base availability at June 30, 2014, under the terms of our Amended Credit Agreement.

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, 2014, 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:



	Obligations Due in Period (in thousands)
Cash Contractual Obligations	2014 ⁽¹⁾		2015		2016		2017		Thereafter		Total
Line of credit (secured)	$	437	$	—	$	—	$	—	$	—	$	437
Interest on line of credit⁽²⁾	9		—		—		—		—		9
Purchase obligations	143		478		478		478		1,231		2,808
Other long-term liabilities	—		—		—		—		176		176
Facilities and office leases	143		288		261		241		130		1,063
Equipment leases	6		13		7		2		—		28
Vehicle leases	26		—		—				—		26
Total	$	764	$	779	$	746	$	721	$	1,537	$	4,547

(1)For the six months remaining in 2014.

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

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, 2013.

Recently Issued Accounting Pronouncements

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 June 30, 2014, 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 risk factors is included in our Annual Report on Form 10-K for the year ended December 31, 2013 filed with the Securities and Exchange Commission.

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, 2013.

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 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 other 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, 2013 for a discussion of the risk 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)

4.2	Form of Senior Indenture (Incorporated by reference to Exhibit 4.1 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.3	Form of Senior Note (Incorporated by reference to Exhibit 4.2 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.4	Form of Subordinated Indenture (Incorporated by reference to Exhibit 4.3 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.5	Form of Subordinated Note (Incorporated by reference to Exhibit 4.4 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.6	Form of Deposit Agreement, including Form of Depositary Share (Incorporated by reference to Exhibit 4.5 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.7	Form of Warrant Agreement, including Form of Warrant Certificate (Incorporated by reference to Exhibit 4.6 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.8	Form of Unit Agreement (Incorporated by reference to Exhibit 4.7 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.9	Form of Preferred Stock Certificate (Incorporated by reference to Exhibit 4.8 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.10	Form of Certificate of Designation with respect to Preferred Stock (Incorporated by reference to Exhibit 4.9 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.11	Form of Rights Agreement, including Form of Rights Certificate (Incorporated by reference to Exhibit 4.10 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)



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 Appendix A of the Registrant's definitive proxy statement on schedule 14A filed April 22, 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 December 16, 2010.)

10.6	First Amendment of Credit Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated December 31, 2011 (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, 2010.)

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, 2011, 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 January 16, 2011.)

10.10	Employment Agreement between Natural Gas Services Group, Inc. and Stephen C. Taylor dated October 23, 2013 (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 October 25, 2013)

*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)

August 8, 2014

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)

4.2	Form of Senior Indenture (Incorporated by reference to Exhibit 4.1 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.3	Form of Senior Note (Incorporated by reference to Exhibit 4.2 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.4	Form of Subordinated Indenture (Incorporated by reference to Exhibit 4.3 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.5	Form of Subordinated Note (Incorporated by reference to Exhibit 4.4 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.6	Form of Deposit Agreement, including Form of Depositary Share (Incorporated by reference to Exhibit 4.5 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.7	Form of Warrant Agreement, including Form of Warrant Certificate (Incorporated by reference to Exhibit 4.6 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.8	Form of Unit Agreement (Incorporated by reference to Exhibit 4.7 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.9	Form of Preferred Stock Certificate (Incorporated by reference to Exhibit 4.8 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.10	Form of Certificate of Designation with respect to Preferred Stock (Incorporated by reference to Exhibit 4.9 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)

4.11	Form of Rights Agreement, including Form of Rights Certificate (Incorporated by reference to Exhibit 4.10 of the Registrant’s Registration Statement on Form S-3 (No. 333-161346) and filed on August 14, 2009)



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 Appendix A of the Registrant's definitive proxy statement on schedule 14A filed April 22, 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 December 16, 2010.)

10.6	First Amendment of Credit Agreement between Natural Gas Services Group, Inc. and JPMorgan Chase Bank, N.A., dated December 31, 2011 (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, 2010.)

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, 2011, 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 January 16, 2011.)

10.10	Employment Agreement between Natural Gas Services Group, Inc. and Stephen C. Taylor dated October 23, 2013 (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 October 25, 2013)

*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.