Edgar Filing: NATURAL GAS SERVICES GROUP INC

NGS-2013.9.30-10Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2013

( ) 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		Outstanding at November 4, 2013
Common Stock, $0.01 par value		12,404,803



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	16

Item 4. Controls and Procedures	Page	17

Part II - OTHER INFORMATION

Item 1. Legal Proceedings	Page	17

Item 1A. Risk Factors	Page	17

Item 6. Exhibits	Page	18

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)

	September 30,		December 31,
	2013		2012
ASSETS
Current Assets:
Cash and cash equivalents	$	27,727	$	28,086
Trade accounts receivable, net of allowance for doubtful accounts of $401 and $437, respectively	5,377		6,691
Inventory, net	27,545		26,509
Prepaid income taxes	2,271		275
Prepaid expenses and other	416		475
Total current assets	63,336		62,036
Rental equipment, net of accumulated depreciation of $82,259 and $70,266, respectively	167,247		151,015
Property and equipment, net of accumulated depreciation of $9,250 and $8,441 respectively	7,190		7,475
Goodwill	10,039		10,039
Intangibles, net of accumulated amortization of $2,159 and $2,060, respectively	2,059		2,157
Other assets	29		29
Total assets	$	249,900	$	232,751
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable	$	1,599	$	3,420
Accrued liabilities	6,903		5,817
Current income tax liability	931		522
Deferred income	1,203		2,027
Total current liabilities	10,636		11,786
Line of credit, non-current portion	747		897
Deferred income tax liability	49,477		43,741
Other long-term liabilities	206		502
Total liabilities	61,066		56,926
Commitments and contingencies (Note 8)
Stockholders’ Equity:
Preferred stock, 5,000 shares authorized, no shares issued or outstanding	—		—
Common stock, 30,000 shares authorized, par value $0.01; 12,352 and 12,241 shares issued and outstanding, respectively	123		122
Additional paid-in capital	90,598		88,823
Retained earnings	98,113		86,880
Total stockholders' equity	188,834		175,825
Total liabilities and stockholders' equity	$	249,900	$	232,751

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						Nine months ended
	September 30,						September 30,
	2013			2012			2013			2012
Revenue:
Sales, net	$	3,893		$	4,935		$	15,057		$	28,015
Rental income	17,805			14,120			50,533			41,529
Service and maintenance income	167			235			516			630
Total revenue	21,865			19,290			66,106			70,174
Operating costs and expenses:
Cost of sales, exclusive of depreciation stated separately below	2,454			3,126			8,935			20,244
Cost of rentals, exclusive of depreciation stated separately below	7,449			5,896			20,519			17,279
Cost of service and maintenance, exclusive of depreciation stated separately below	80			88			233			279
Selling, general, and administrative expense	2,142			1,958			6,023			6,116
Depreciation and amortization	4,652			3,980			13,326			11,564
Total operating costs and expenses	16,777			15,048			49,036			55,482
Operating income	5,088			4,242			17,070			14,692
Other income (expense):
Interest expense	(3		)	(8		)	(45		)	(13		)
Other income (expense)	125			(37		)	393			62
Total other income (expense), net	122			(45		)	348			49
Income before provision for income taxes	5,210			4,197			17,418			14,741
Provision for income taxes	1,816			1,591			6,185			5,627
Net income	$	3,394		$	2,606		$	11,233		$	9,114
Earnings per share:
Basic	$	0.28		$	0.21		$	0.91		$	0.75
Diluted	$	0.27		$	0.21		$	0.90		$	0.74
Weighted average shares outstanding:
Basic	12,339			12,230			12,313			12,214
Diluted	12,600			12,331			12,504			12,312

See accompanying notes to these unaudited condensed financial statements.



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

	Nine months ended
	September 30,
	2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	11,233		$	9,114
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	13,326			11,564
Deferred income taxes	5,736			5,627
Stock based compensation	1,134			1,058
Gain on extinguishment of liability	(223		)	—
Changes in current assets and liabilities:
Trade accounts receivables	1,314			1,948
Inventory	(1,036		)	312
Prepaid expenses	(1,937		)	(178		)
Accounts payable and accrued liabilities	(735		)	3,460
Current income tax liability	409			—
Deferred income	(824		)	(1,359		)
NET CASH PROVIDED BY OPERATING ACTIVITIES	28,397			31,546
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of property and equipment	(29,175		)	(17,074		)
NET CASH USED IN INVESTING ACTIVITIES	(29,175		)	(17,074		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from other long-term liabilities, net	(73		)	(16		)
Repayments of line of credit	(150		)	(90		)
Proceeds from exercise of stock options	642			168
NET CASH PROVIDED BY FINANCING ACTIVITIES	419			62
NET CHANGE IN CASH AND CASH EQUIVALENTS	(359		)	14,534
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	28,086			16,390
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	27,727		$	30,924
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Interest paid	$	45		$	13
Income taxes paid	$	2,036		$	—
NON-CASH TRANSACTIONS
Transfer of rental equipment to inventory	$	207		$	8,690

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 September 30, 2013 and the results of our operations for the three and nine months ended September 30, 2013 and 2012 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 accounting principles generally accepted 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, 2012 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 nine months ended September 30, 2013 are not necessarily indicative of the results of operations to be expected for the full fiscal year ending December 31, 2013.

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

At this time, there are no recently issued pronouncements that affect the Company.

(2) Stock-Based Compensation

Stock Options:

A summary of option activity under our 1998 Stock Option plan for the nine months ended September 30, 2013 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, 2012	394,322		$	15.30
Granted	47,000		18.75
Exercised	(41,637	)	15.38
Canceled/Forfeited	(9,833	)	17.68
Expired	—		—
Outstanding, September 30, 2013	389,852		$	15.65	5.49	$	4,355
Exercisable, September 30, 2013	326,770		$	15.22	4.82	$	3,790

The following table summarizes information about our stock options outstanding at September 30, 2013:



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	3.22	$	8.72	71,352	$	8.72
$9.44-15.60	73,500	5.27	12.66		61,834	12.23
$15.61-20.48	245,000	6.21	18.57		193,584	18.57
	389,852	5.49	$	15.65	326,770	$	15.22

The summary of the status of our unvested stock options as of December 31, 2012 and changes during the nine months ended September 30, 2013 is presented below.



Unvested stock options:	Shares		Weighted Average Grant Date Fair Value
Unvested at December 31, 2012	49,334		$	9.01
Granted	47,000		10.30
Vested	(26,335	)	9.05
Canceled/Forfeited	(6,917	)	9.79
Unvested at September 30, 2013	63,082		$	9.87

As of September 30, 2013, there was $399,828 of unrecognized compensation cost related to unvested options. Such cost is expected to be recognized over a weighted-average period of 2.14 years. Total compensation expense for stock options was $122,702 and $330,000 for the nine months ended September 30, 2013 and 2012, respectively.

Restricted Stock:

On March 21, 2013, the Compensation Committee awarded 20,000 shares of restricted common stock to two of our three named executive officers. The restricted shares issued to Messrs. Hazlett and Lawrence vest one year from the grant date. We also awarded and issued 10,000 shares of restricted stock to each member of our Board of Directors as partial payment for 2013 Directors' fees. The restricted stock vests in quarterly installments beginning March 31, 2014. In accordance with Mr. Taylor's employment agreement, 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 2012 performance, Mr. Taylor, our Chief Executive Officer, was awarded 56,950 restricted shares on April 30, 2013, which vest one year from the date of grant. Total compensation expense related to restricted stock awards was $1,011,727 and $727,658 for the nine months ended September 30, 2013 and 2012, respectively. As of September 30, 2013, there was a total of $1,188,685 of unrecognized compensation expenses related to these shares which is expected to be recognized in 0.9 years.

(3) Inventory

Our inventory, net of allowance for obsolescence of $258,000 at September 30, 2013 and $211,000 at December 31, 2012, consisted of the following amounts:



	September 30, 2013		December 31, 2012
	(in thousands)
Raw materials	$	22,705	$	19,654
Work in process	4,840		6,855
	$	27,545	$	26,509

During the nine months ended September 30, 2013 and 2012 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 $28.9 million borrowing base availability at September 30, 2013 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 nine month period ended September 30, 2013, our weighted average interest rate was 1.44%.

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 which must be maintained at a minimum of 2.00 to 1.00 commitment coverage ratio (such ratio being equal to (i) the amount of the borrowing base as of such date to (ii) the amount of the commitment as of such date.)

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

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

As of September 30, 2013 we were in compliance with all covenants in our Amended Credit Agreement. A default under our Credit Agreement could trigger the acceleration of our bank debt so that it is immediately due and payable. Such default would likely limit our ability to access other credit. At September 30, 2013 and December 31, 2012 our outstanding balance on the line of credit was $747,000 and $897,000, respectively.

(5) Other Long-Term Liabilities

As of December 31, 2012, we had a long-term liability of $275,000 to Midland Development Corporation. The liability was fully satisfied during the quarter ended March 31, 2013. As a result of our performance under the agreement, a payment to Midland Development Corporation of $52,000 was made to settle the liability, resulting in a gain of $223,000, which is included in our condensed income statement. In addition, we entered into a purchase agreement with a vendor on July 30, 2008 pursuant to which we agreed to purchase up to $4.8 million of our paint and coating requirements exclusively from the vendor. In connection with the execution of the agreement, the vendor paid us a $300,000 fee which is considered to be a discount toward future purchases from the vendor. The $300,000 payment we received is recorded as a long-term liability and will decrease as the purchase commitment is fulfilled. The long-term liability remaining as of September 30, 2013 and December 31, 2012 was $206,000 and $227,000, respectively.

(6) Earnings per Share

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



	Three months ended				Nine months ended
	September 30,				September 30,
	2013		2012		2013		2012
Numerator:
Net income	$	3,394	$	2,606	$	11,233	$	9,114
Denominator for basic net income per common share:
Weighted average common shares outstanding	12,339		12,230		12,313		12,214

Denominator for diluted net income per share:
Weighted average common shares outstanding	12,339		12,230		12,313		12,214
Dilutive effect of stock options and restricted stock	261		101		191		98
Diluted weighted average shares	12,600		12,331		12,504		12,312
Earnings per common share:
Basic	$	0.28	$	0.21	$	0.91	$	0.75
Diluted	$	0.27	$	0.21	$	0.90	$	0.74

(7) 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 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 September 30, 2013 (in thousands):
	Sales		Rental		Service & Maintenance		Corporate			Total
Revenue	$	3,893	$	17,805	$	167	$	—		$	21,865
Operating costs and expenses	2,454		7,449		80		6,794			16,777
Other income (expense)	—		—		—		122			122
Income before provision for income taxes	$	1,439	$	10,356	$	87	$	(6,672	)	$	5,210



For the three months ended September 30, 2012 (in thousands):
	Sales		Rental		Service & Maintenance		Corporate			Total
Revenue	$	4,935	$	14,120	$	235	$	—		$	19,290
Operating costs and expenses	3,126		5,896		88		5,938			15,048
Other income (expense)	—		—		—		(45		)	(45		)
Income before provision for income taxes	$	1,809	$	8,224	$	147	$	(5,983	)	$	4,197



For the nine months ended September 30, 2013 (in thousands):
	Sales		Rental		Service & Maintenance		Corporate			Total
Revenue	$	15,057	$	50,533	$	516	$	—		$	66,106
Operating costs and expenses	8,935		20,519		233		19,349			49,036
Other income (expense)	—		—		—		348			348
Income before provision for income taxes	$	6,122	$	30,014	$	283	$	(19,001	)	$	17,418



For the nine months ended September 30, 2012 (in thousands):
	Sales		Rental		Service & Maintenance		Corporate			Total
Revenue	$	28,015	$	41,529	$	630	$	—		$	70,174
Operating costs and expenses	20,244		17,279		279		17,680			55,482
Other income (expense)	—		—		—		49			49
Income before provision for income taxes	$	7,771	$	24,250	$	351	$	(17,631	)	$	14,741

(8) 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, 2012 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 September 30, 2013, we had 1,986 natural gas compressors totaling 277,073 horsepower rented to 101 third parties compared to 1,680 natural gas compressors totaling 233,241 horsepower rented to 99 third parties at September 30, 2012.

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 weak economy and financial uncertainty, 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 and our continued strong results in the first nine months of 2013.

Results of Operations

Three months ended September 30, 2013, compared to the three months ended September 30, 2012.

The table below shows our revenues and percentage of total revenues of each of our product lines for the three months ended September 30, 2013 and 2012.



	Revenue Three months ended September 30,
	( dollars in thousands)
	2013				2012
Sales	$	3,893	18	%	$	4,935	26	%
Rental	17,805		81	%	14,120		73	%
Service and Maintenance	167		1	%	235		1	%
Total	$	21,865			$	19,290

Total revenue increased to $21.9 million from $19.3 million, or 13%, for the three months ended September 30, 2013, compared to the same period ended September 30, 2012. The $2.6 million increase in revenue was due to a increase in rental revenue of $3.7 million, offset by an decrease in sales revenue of $1.0 million. Comparing the three months ended September 30, 2013 to the same period in 2012, sales revenue decreased 21% and rental revenue increased 26%.

Sales revenue decreased to $3.9 million from $4.9 million for the three months ended September 30, 2013, compared to the same period ended September 30, 2012. 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.

Rental revenue increased to $17.8 million from $14.1 million for the three months ended September 30, 2013, compared to the same period ended September 30, 2012. 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 2,466 compressor packages in our rental fleet, up from 2,236 units at September 30, 2012. The rental fleet had a utilization of 80.5% as of September 30, 2013 compared to 75.1% utilization as of September 30, 2012. This utilization increase 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 be able to see additional utilization of our fleet.

Our overall operating income margin percentage increased to 23% from 22% for the three months ended September 30, 2013 compared to the same period ended September 30, 2012. The margin increase is mainly the result of our ability to hold the line on costs related to compressor sales, and a shift in revenues toward rentals, which typically has a higher margin, from sales.

Selling, general, and administrative expense increased slightly to $2.1 million from $2.0 million, for the three months ended September 30, 2013, as compared to the same period ended September 30, 2012.

Depreciation and amortization expense increased to $4.7 million for the three months ended September 30, 2013, compared to $4.0 million for the period ended September 30, 2012. This was the result of new gas compressor rental units being added to the rental fleet from September 30, 2012 to September 30, 2013. We added a net of 230 compressors to our rental fleet during the twelve month period ending September 30, 2013.

Provision for income tax was $1.8 million and $1.6 million for the three months ended September 30, 2013 and September 30, 2012, respectively. The provision is the result of an increase in taxable income for the three months ended September 30, 2013 compared to the three months ended September 30, 2012 offset by a slightly lower effective tax rate.

Nine months ended September 30, 2013, compared to the nine months ended September 30, 2012.

The table below shows our revenues and percentage of total revenues of each of our product lines for the nine months ended September 30, 2013 and 2012.



	Revenue Nine months ended September 30,
	(dollars in thousands)
	2013				2012
Sales	$	15,057	23	%	$	28,015	40	%
Rental	50,533		76	%	41,529		59	%
Service and Maintenance	516		1	%	630		1	%
Total	$	66,106			$	70,174

Total revenue decreased to $66.1 million from $70.2 million, or 5.8%, for the nine months ended September 30, 2013, compared to the same period ended September 30, 2012. The $4.1 million decrease in revenue was due to a decrease in sales revenue to $15.1 million, offset by an increase in rental revenue to $50.5 million. Comparing the nine months ended September 30, 2013 to the same period in 2012, sales revenue decreased 46.3% and rental revenue increased 21.7%.

Sales revenue decreased to $15.1 million from $28.0 million for the nine months ended September 30, 2013, compared to the same period ended September 30, 2012. This decrease is the result of timing of industry activity related to capital projects and a large one-time sale to a single customer from our fleet in the nine months ended September 30, 2012. 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.

Rental revenue increased to $50.5 million from $41.5 million for the nine months ended September 30, 2013, compared to the same period ended September 30, 2012. 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 2,466 compressor packages in our rental fleet, up from 2,236 units at September 30, 2012. The rental fleet had a utilization of 80.5% as of September 30, 2013 compared to 75.1% utilization as of September 30, 2012. This utilization increase 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 be able to see incremental utilization of our fleet.

Our overall operating income margin percentage increased to 26% from 21% for the nine months ended September 30, 2013 compared to the same period ended September 30, 2012. The margin increase is mainly the result of our ability to hold the line on costs related to compressor sales, and a shift in revenues toward rentals, which typically has a higher margin, from sales.

Selling, general, and administrative expense decreased slightly to $6.0 million from $6.1 million, for the nine months ended September 30, 2013, as compared to the same period ended September 30, 2012.

Depreciation and amortization expense increased to $13.3 million for the nine months ended September 30, 2013, compared to $11.6 million for the period ended September 30, 2012. This was the result of new gas compressor rental units being added to the rental fleet from September 30, 2012 to September 30, 2013. We added a net of 230 compressors to our rental fleet during the twelve month period ending September 30, 2013.

Provision for income tax increased to $6.2 million from $5.6 million, or 10.7%, and is the result of the increase in taxable income and a change in effective tax rate between the two periods. We had an effective tax rate of 35.5% in the nine months ended September 30, 2013 and 38% in the nine months ended September 30, 2012.

Liquidity and Capital Resources

Our working capital positions as of September 30, 2013 and December 31, 2012 are set forth below:



	September 30,		December 31,
	2013		2012
	(in thousands)
Current Assets:
Cash and cash equivalents	$	27,727	$	28,086
Trade accounts receivable, net	5,377		6,691
Inventory, net	27,545		26,509
Prepaid income taxes	2,271		275
Prepaid expenses and other	416		475
Total current assets	63,336		62,036
Current Liabilities:
Accounts payable	1,599		3,420
Accrued liabilities	6,903		5,817
Current portion of tax liability	931		522
Deferred income	1,203		2,027
Total current liabilities	10,636		11,786
Total working capital	$	52,700	$	50,250

Historically, we have funded our operations through public and private offerings of our equity securities, subordinated debt, bank borrowings and cash flow from operations. Proceeds from these sources were primarily used to pay debt and to fund the manufacture and fabrication of additional units for our rental fleet of natural gas compressors.

For the nine months ended September 30, 2013, we invested $29.2 million in equipment for our rental fleet and service vehicles. Even though we have idle rental equipment, at times we do not have the specific type of equipment that our customers require, therefore we have to build new equipment to satisfy their needs. We financed this activity with cash flow from operations and cash on hand.

Cash flows

At September 30, 2013, we had cash and cash equivalents of $27.7 million compared to $28.1 million at December 31, 2012. Our cash flow from operations of $28.4 million was offset by capital expenditures of $29.2 million, during the nine months ended September 30, 2013. We had working capital of $52.7 million at September 30, 2013 compared to $50.3 million at December 31, 2012. At September 30, 2013 and December 31, 2012, we had total debt of $747,000 and $897,000, respectively, which is all related to our line of credit and classified as long term. We had positive net cash flow from operating activities of $28.4 million during the first nine months of 2013 compared to $31.5 million for the first nine months of 2012. The cash flow from operations of $28.4 million was primarily the result of the net income of $11.2 million and the non-cash items of depreciation of $13.3 million, and an increase in deferred taxes of $5.7 million.

Strategy

For the remainder of the fiscal year 2013 and into 2014, 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 2013, 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 may not be available to us when we need it or on acceptable terms. Capital expenditures for the year ended December 31, 2013 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 $28.9 million million borrowing base availability at September 30, 2013, under the terms of our Amended Credit Agreement.

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.)

As of September 30, 2013, we were in compliance with all covenants in our Amended Credit Agreement. A default under our Credit Agreement could trigger the acceleration of our bank debt so that it is immediately due and payable. Such default would likely limit our ability to access other credit. At September 30, 2013 our balance on the line of credit was $747,000.

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 of dollars)
Cash Contractual Obligations	2013⁽¹⁾		2014		2015		2016		Thereafter		Total
Line of credit (secured)	$	—	$	747	$	—	$	—	$	—	$	747
Interest on line of credit⁽²⁾	7		30		—		—		—		37
Purchase obligations	148		330		330		330		2,288		3,426
Other long-term liabilities	—		—		—		—		206		206
Facilities and office leases	86		262		255		228		284		1,115
Equipment Leases	3		12		12		6		1		34
Vehicle Leases	21		67		—		—		—		88
Total	$	265	$	1,448	$	597	$	564	$	2,779	$	5,653


(1)	For the three months remaining in 2013.


(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, 2012.

Recently Issued Accounting Pronouncements

At this time, there are no recently issued pronouncements that affect the Company.

Off-Balance Sheet Arrangements

From time-to-time, we enter into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of September 30, 2013, 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.

We entered into a purchase agreement with a vendor on July 30, 2008 pursuant to which we agreed to purchase up to $4.8 million of our paint and coating requirements exclusively from the vendor. In connection with the execution of the agreement, the vendor paid us a $300,000 fee which is considered to be a discount toward future purchases from the vendor. The $300,000 payment received by the Company is recorded as a long-term liability and will decrease as the purchase commitment is fulfilled. This long-term liability remaining as of September 30, 2013 was $206,000. (See Note 5)

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, 2012 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, 2012.

Item 4. Controls and Procedures

(a) 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 Principal Accounting Officer and Treasurer, 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 Principal Accounting Officer and Treasurer 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 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.

(b) 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, 2012 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 (Incorporated by reference to Exhibit 10.1 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.)



10.3	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)

November 8, 2013

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 (Incorporated by reference to Exhibit 10.1 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.)

10.3	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.