Summary of Significant Accounting Policies

Organization and Principles of Consolidation

These notes apply to the financial statements of Natural Gas Services Group, Inc. (the "Company", “NGSG”, "Natural Gas Services Group", "we" or "our") (a Colorado corporation). Natural Gas Services Group, Inc. was formed on December 17, 1998 for the purposes of combining the operations of certain manufacturing, service and leasing entities.

Nature of Operations

Natural Gas Services Group, Inc. is a leading provider of small to medium horsepower compression equipment to the natural gas industry. We focus primarily on the non-conventional natural gas production business in the United States (such as coal bed methane, gas shale, tight gas and oil shale). We manufacture, fabricate and rent natural gas compressors that enhance the production of natural gas wells. NGSG provides maintenance services for its natural gas compressors. In addition, we sell custom fabricated natural gas compressors to meet customer specifications dictated by well pressures, production characteristics and particular applications. We also manufacture and sell flare systems for oil and natural gas plant and production facilities.

Use of Estimates

The preparation of our financial statements in conformity with accounting principles generally accepted in the United States of America requires our management to make estimates and assumptions that affect the amounts reported in these financial statements and accompanying notes. Actual results could differ from those estimates. Significant estimates include fixed asset lives, bad debt allowance and the allowance for inventory obsolescence. It is at least reasonably possible these estimates could be revised in the near term and the revisions could be material.

Cash Equivalents

For purposes of reporting cash flows, we consider all short-term investments with an original maturity of three months or less to be cash equivalents.

Accounts Receivable

Our trade receivables consist of customer obligations for the sale of compressors and flare systems due under normal trade terms, and operating leases for the use of our natural gas compressors. The receivables are not collateralized except as provided for under lease agreements. However, we typically require deposits of as much as 50% for large custom contracts. We extend credit based on management's assessment of the customer's financial condition, receivable aging, customer disputes and general business and economic conditions. The allowance for doubtful accounts was $507,000 and $436,000 at December 31, 2014 and 2013, respectively. Management believes that the allowance is adequate; however, actual write-offs may exceed the recorded allowance.

Revenue Recognition

Revenue from the sales of custom and fabricated compressors, and flare systems is recognized when title passes to the customer, the customer assumes risks and rewards of ownership, collectability is reasonably assured and delivery occurs as directed by our customer. Exchange and rebuilt compressor revenue is recognized when both the replacement compressor has been delivered and the rebuild assessment has been completed. Revenue from compressor service and retrofitting services is recognized upon providing services to the customer. Maintenance agreement revenue is recognized as services are rendered. Rental revenue is recognized over the terms of the respective rental agreements. Deferred income represents payments received before a product is shipped. Revenue from the sale of rental units is included in sales revenue when equipment is shipped or title is transferred to the customer.

Major Customers and Concentration of Credit Risk

Sales and rental income to Devon Energy Production, Inc. ("Devon") and EOG Resources, Inc. ("EOG") in 2014 amounted to 18% and 15% of revenue, respectively. Sales and rental income to EOG and Devon in 2013 amounted to 18% and 15% of revenue, respectively. Sales and rental income to EOG and Devon in 2012 amounted to 32% and 12% of revenue. No other single customer accounted for more than 10% of our revenues in 2014, 2013 or 2012. EOG, Promatcon and Oxy amounted to 20%, 18% and 14% of our accounts receivable as of December 31, 2014. EOG and Devon amounted to 18% and 14% of our accounts receivable as of December 31, 2013, respectively. No other customers amounted to more than 10% of our accounts receivable as of December 31, 2014 and 2013.

Inventory

Inventory is valued at the lower of cost or market. The cost of inventories is determined by the weighted average method. A reserve is recorded against inventory balances for estimated obsolescence. This reserve is based on specific identification and historical experience and totaled $225,000 and $128,000 at December 31, 2014 and 2013, respectively. There were no new completed compressor units at December 31, 2014 or at December 31, 2013 available for sale or for use in our rental fleet. At December 31, 2014 and 2013, inventory consisted of the following (in thousands):



	2014		2013
Raw materials	$	25,984	$	20,524
Work in process	6,640		6,308
Total	$	32,624	$	26,832

Property and Equipment

Property and equipment is recorded at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful lives of the assets, which range from three to forty years. Rental equipment has an estimated useful life of fifteen years.

Gains and losses resulting from sales and dispositions of property and equipment are included in current operations. Maintenance and repairs are charged to operations as incurred.

Goodwill

Goodwill represents the cost in excess of fair value of the identifiable net assets acquired. Goodwill is tested for impairment annually or whenever events indicate impairment may have occurred. The annual goodwill impairment test is performed in the fourth quarter of each year. We experienced no impairment of goodwill at December 31, 2014 and 2013.

Intangibles

At December 31, 2014, NGSG had intangible assets, which relate to developed technology and a trade name. The carrying amount net of accumulated amortization at December 31, 2014 and 2013 was $1.9 million and $2.0 million respectively. Developed technology is amortized on a straight-line basis with a useful life of 20 years, with a weighted average remaining life of approximately ten years as of December 31, 2014. Amortization expense recognized in each of the years ending December 31, 2014, 2013, and 2012 was $125,000, $130,000 and $125,000 respectively. Estimated amortization expense for the years 2015-2024 is $125,000 per year. NGSG has an intangible asset with a gross carrying value of $654,000 at December 31, 2014 related to the trade name of SCS which was acquired in our acquisition of Screw Compression Systems in January 2005. This asset is not being amortized as it has been deemed to have an indefinite life.

The following table represents the identified intangible assets by major asset class (in thousands):



		December 31, 2014						December 31, 2013

	Useful Life (years)	Gross Carrying Value		Accumulated Amortization		Net Book Value		Gross Carrying Value		Accumulated Amortization		Net Book Value
Developed Technology	20	2,505		1,257		1,248		2,505		1,132		1,373
Trade Name	Indefinite	654		—		654		654		—		654
Total		$	3,159	$	1,257	$	1,902	$	3,159	$	1,132	$	2,027

Our policy is to periodically review intangibles for impairment through an assessment of the estimated future cash flows related to such assets. In the event that assets are found to be carried at amounts in excess of estimated undiscounted future cash flows, then the assets will be adjusted for impairment to a level commensurate with a discounted cash flow analysis of the underlying assets. Based upon our analysis, we experienced no impairment of intangible assets at December 31, 2014 or 2013.

Warranty

We accrue amounts for estimated warranty claims based upon current and historical product warranty costs and any other related information known. The warranty reserve was $0 and $28,000 for December 31, 2014 and 2013, respectively, and is included in accrued liabilities on the balance sheet.

Financial Instruments and Concentrations of Credit Risk

We invest our cash primarily in deposits and money market funds with commercial banks. At times, cash balances at banks and financial institutions may exceed federally insured amounts.

Per Share Data

Basic earnings per common share is computed using the weighted average number of common shares outstanding during the period. Diluted earnings per common share is computed using the weighted average number of common stock and common stock equivalent shares outstanding during the period. There were no an anti-dilutive securities in 2014, 2013, and 2012.

The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share amounts):



	Year Ended December 31,
	2014		2013		2012
Numerator:
Net income	$	14,128	$	14,390	$	12,685
Denominator for basic net income per common share:
Weighted average common shares outstanding	12,434		12,324		12,220
Denominator for diluted net income per share:
Weighted average common shares outstanding	12,434		12,324		12,220
Dilutive effect of stock options and restricted shares	287		226		100
Diluted weighted average shares	12,721		12,550		12,320
Earnings per common share:
Basic	$	1.14	$	1.17	$	1.04
Diluted	$	1.11	$	1.15	$	1.03

Income Taxes

Deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of assets and liabilities and their respective tax bases, and operating losses and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled.

ASC Topic 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. In order to record any financial statement benefit, we are required to determine, based on technical merits of the position, whether it is more likely than not (a likelihood of more than 50 percent) that a tax position will be sustained upon examination, including resolution of any related appeals or litigation processes. If that step is satisfied, then we must measure the tax position to determine the amount of benefit to recognize in the financial statements. The tax position is measured at the largest amount of the benefit that is greater than 50 percent likely of being realized upon ultimate settlement. We have no uncertain tax positions as of December 31, 2014 or 2013.

Fair Value Measurement

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date under current market conditions. Topic 820 established a fair value hierarchy, which requires an entity to maximize the use of observable inputs when measuring fair value. These inputs are categorized as follows:

Level 1- quoted prices in an active market for identical assets or liabilities;

Level 2- quoted prices in an active market for similar assets or liabilities, inputs other than quoted prices that are observable for similar assets or liabilities, inputs derived principally from or corroborated by observable market data by correlation or other means; and

Level 3- valuation methodology with unobservable inputs that are significant to the fair value measurement.

Management believes that the fair value of our cash and cash equivalents, trade receivables, accounts payable and line of credit at December 31, 2014 and 2013 approximate their carrying values due to the short-term nature of the instruments or the use of prevailing market interest rates.

Segments and Related Information

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

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


•	The nature of the products and services;


•	The nature of the production processes;


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


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


•	The nature of the regulatory environment, if applicable.

We are engaged in the business of designing and manufacturing compressors and flares. Our compressors and flares are sold and rented to our customers. In addition, we provide service and maintenance on compressors in our fleet and to third parties.These business activities are similar in all geographic areas. Our manufacturing process is essentially the same for the entire Company and is performed in house at our facilities in Midland, Texas and Tulsa, Oklahoma. Our customers primarily consist of entities in the business of producing natural gas. 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.

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 and 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 may have on our financial statements.