Gas Natural Inactive 10-K31 Mar 142013 FY Annual reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
Document and Entity Information (USD $)	Dec. 31, 2013	Mar. 14, 2014	Jun. 30, 2013
Document And Entity Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Trading Symbol	'EGAS	'	'
Entity Registrant Name	'Gas Natural Inc.	'	'
Entity Central Index Key	'0000043350	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Filer Category	'Smaller Reporting Company	'	'
Entity Common Stock, Shares Outstanding	'	10,451,678	'
Entity Public Float	'	'	$73,575,528

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS	'	'
Cash and cash equivalents	$13,147,381	$3,435,117
Marketable securities	406,134	344,346
Accounts receivable	'	'
Trade, less allowance for doubtful accounts of $1,986,531 and $1,350,338, respectively	13,440,565	11,406,807
Related parties	146,225	522,557
Unbilled gas	7,729,560	4,612,258
Note receivable - related parties, current portion	1,938	10,998
Inventory	'	'
Natural gas	5,464,744	4,938,078
Materials and supplies	2,413,745	1,779,944
Prepaid income taxes	727,427	501,763
Prepayments and other	1,064,845	2,153,922
Recoverable cost of gas purchases	1,298,299	2,329,524
Deferred tax asset	1,225,032	813,846
Discontinued operations	34,151	3,117,349
Total current assets	47,100,046	35,966,509
PROPERTY, PLANT, & EQUIPMENT, NET	133,520,286	116,429,042
OTHER ASSETS	'	'
Notes receivable - related parties, less current portion	93,727	24,411
Regulatory assets	'	'
Property taxes	25,000	307,732
Income taxes	452,645	452,645
Rate case costs	130,228	176,250
Debt issuance costs, net of amortization	1,388,124	1,798,720
Goodwill	16,267,377	14,891,377
Customer relationships, net of amortization	3,230,333	616,500
Investment in unconsolidated affiliate	351,724	321,731
Restricted cash	1,137,442	3,150,847
Other assets	46,683	327,695
Total other assets	23,123,283	22,067,908
TOTAL ASSETS	203,743,615	174,463,459
CURRENT LIABILITIES	'	'
Checks in excess of amounts on deposit	843,634	720,340
Line of credit	24,529,799	23,859,755
Accounts payable	'	'
Trade	12,418,701	8,982,051
Related parties	559,933	47,929
Notes payable, current portion	3,502,190	633,498
Contingent consideration, current portion	671,638	'
Accrued liabilities	'	'
Taxes other than income	3,173,640	2,528,940
Vacation	95,806	115,956
Employee benefit plans	178,789	145,496
Interest	169,581	191,263
Deferred payments received from levelized billing	2,469,665	2,633,220
Customer deposits	761,022	744,974
Related parties	'	595,240
Obligation under capital lease, current portion	177,570	167,518
Over-recovered gas purchases	793,184	1,185,034
Other current liabilities	1,482,375	690,511
Discontinued operations	45,855	1,420,897
Total current liabilities	51,873,382	44,662,622
LONG-TERM LIABILITIES	'	'
Deferred investment tax credits	134,255	155,317
Deferred tax liability	9,055,166	4,895,135
Asset retirement obligation	2,026,353	1,850,379
Customer advances for construction	1,016,671	1,009,232
Regulatory liability for income taxes	83,161	83,161
Regulatory liability for gas costs	'	20,745
Obligation under capital lease, less current portion	1,862,938	2,040,508
Contingent consideration, less current portion	13,362	'
Total long-term liabilities	14,191,906	9,755,971
NOTES PAYABLE, less current portion	40,198,552	43,700,742
COMMITMENTS AND CONTINGENCIES (see Note 17)	'	'
STOCKHOLDERS' EQUITY	'	'
Preferred stock; $0.15 par value, 1,500,000 shares authorized, no shares issued or outstanding	'	'
Common stock; $0.15 par value, 15,000,000 shares authorized, 10,451,678 and 8,369,752 shares issued and outstanding, respectively	1,567,752	1,255,463
Capital in excess of par value	63,468,969	44,256,493
Accumulated other comprehensive income	104,909	65,789
Retained earnings	32,338,145	30,766,379
Total stockholders' equity	97,479,775	76,344,124
TOTAL CAPITALIZATION	137,678,327	120,044,866
TOTAL LIABILITIES AND CAPITALIZATION	$203,743,615	$174,463,459

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Statement Of Financial Position [Abstract]	'	'
Allowance for doubtful accounts	$1,986,531	$1,350,338
Preferred stock, par value	$0.15	$0.15
Preferred stock, shares authorized	1,500,000	1,500,000
Preferred stock, shares issued	'	'
Preferred stock, shares outstanding	'	'
Common stock, par value	$0.15	$0.15
Common stock, shares authorized	15,000,000	15,000,000
Common stock, shares issued	10,451,678	8,369,752
Common stock, shares outstanding	10,451,678	8,369,752

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
Consolidated Statements of Comprehensive Income (USD $)	Dec. 31, 2013	Dec. 31, 2012
REVENUES	'	'
Natural gas operations	$106,264,609	$81,305,951
Marketing and production	12,167,241	7,493,361
Pipeline operations	402,914	401,933
Total revenues	118,834,764	89,201,245
COST OF SALES	'	'
Natural gas purchased	61,236,772	42,485,803
Marketing and production	10,052,865	5,953,156
Total cost of sales	71,289,637	48,438,959
GROSS MARGIN	47,545,127	40,762,286
OPERATING EXPENSES	'	'
Distribution, general, and administrative	23,477,984	20,815,855
Maintenance	1,317,792	1,191,038
Depreciation and amortization	6,135,160	5,026,142
Accretion	175,974	161,298
Contingent consideration gain	-1,565,000	'
Goodwill impairment	725,744	'
Taxes other than income	4,003,468	3,478,897
Total operating expenses	34,271,122	30,673,230
OPERATING INCOME	13,274,005	10,089,056
Loss from unconsolidated affiliate	-5,007	-8,620
Other income, net	924,586	424,221
Acquisition expense	-272,094	-959,267
Stock sale expense	-309,432	-274,213
Interest expense	-3,178,606	-2,700,193
Income (loss) before taxes	10,433,452	6,570,984
Income tax expense	-3,391,898	-2,650,569
INCOME FROM CONTINUING OPERATIONS	7,041,554	3,920,415
Discontinued operations, net of income taxes (See Note 4)	-370,275	-201,098
NET INCOME	6,671,279	3,719,317
BASIC & DILUTED EARNINGS (LOSS) PER SHARE:	'	'
Continuing operations	$0.75	$0.48
Discontinued operations	($0.04)	($0.02)
Net income per share	$0.71	$0.46
Weighted average dividends declared per common share	$0.55	$0.54
COMPREHENSIVE INCOME:	'	'
Net income	6,671,279	3,719,317
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX	'	'
Unrealized gain (loss) on available for sale securities, net of tax of $22,951 and $8,913, respectively	39,120	-14,616
COMPREHENSIVE INCOME	$6,710,399	$3,704,701

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Statement [Abstract]	'	'
Unrealized gain (loss) on available for sale securities, tax portion	$22,951	$8,913

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Stockholders Equity (USD $)	Total	Common Stock [Member]	Capital In Excess Of Par Value [Member]	Accumulated Other Comprehensive Income [Member]	Retained Earnings [Member]
BEGINNING BALANCE at Dec. 31, 2011	$74,772,027	$1,223,145	$41,978,799	$80,405	$31,489,678
BEGINNING BALANCE, Shares at Dec. 31, 2011	'	8,154,301	'	'	'
Net income	3,719,317	'	'	'	3,719,317
Other comprehensive Income (Loss), net	-14,616	'	'	-14,616	'
Stock issued for services	50,602	675	49,927	'	'
Stock issued for services, shares	'	4,500	'	'	'
Stock based compensation	9,406	'	9,406	'	'
Purchase of Loring Pipeline	2,250,004	31,643	2,218,361	'	'
Purchase of Loring Pipeline, Shares	'	210,951	'	'	'
Dividends declared	-4,442,616	'	'	'	-4,442,616
ENDING BALANCE at Dec. 31, 2012	76,344,124	1,255,463	44,256,493	65,789	30,766,379
ENDING BALANCE, Shares at Dec. 31, 2012	8,369,752	8,369,752	'	'	'
Net income	6,671,279	'	'	'	6,671,279
Other comprehensive Income (Loss), net	39,120	'	'	39,120	'
Exercise of stock options	159,500	3,000	156,500	'	'
Exercise of stock options, Shares	20,000	20,000	'	'	'
Stock based compensation	2,962	'	2,962	'	'
Purchase of JDOG Marketing	2,641,199	38,539	2,602,660	'	'
Purchase of JDOG Marketing, Shares	'	256,926	'	'	'
Common stock issued	16,721,104	270,750	16,450,354	'	'
Common stock issued, Shares	'	1,805,000	'	'	'
Dividends declared	-5,099,513	'	'	'	-5,099,513
ENDING BALANCE at Dec. 31, 2013	$97,479,775	$1,567,752	$63,468,969	$104,909	$32,338,145
ENDING BALANCE, Shares at Dec. 31, 2013	10,451,678	10,451,678	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
Consolidated Statements of Cash Flows (USD $)	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES	'	'
Net income	$6,671,279	$3,719,317
Less loss from discontinued operations	-370,275	-201,098
INCOME FROM CONTINUING OPERATIONS	7,041,554	3,920,415
Adjustments to reconcile income from continuing operations to net cash provided by operating activities:	'	'
Depreciation and amortization	6,135,160	5,026,142
Accretion	175,974	161,298
Amortization of debt issuance costs	418,204	275,858
Stock based compensation	2,962	60,009
(Gain) loss on sale of assets	-158,321	54,154
Loss from unconsolidated affiliate	5,007	8,620
Unrealized holding loss on contingent consideration	-1,565,000	'
Goodwill impairment	725,744	'
Investment tax credit	-21,062	-21,062
Deferred income taxes	4,024,683	2,261,345
Changes in assets and liabilities	'	'
Accounts receivable, including related parties	-1,757,282	-2,555,988
Unbilled gas	-3,117,302	-379,404
Natural gas inventory	-526,666	1,810,861
Accounts payable, including related parties	3,101,920	896,823
Recoverable/refundable cost of gas purchases	639,375	-834,814
Prepayments and other	1,086,478	-1,432,597
Other assets	-431,153	1,051,267
Other liabilities	876,068	-1,163,368
Net cash (used in) provided by operating activities	16,656,343	9,139,559
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Capital expenditures	-24,103,789	-20,654,184
Proceeds from sale of fixed assets	968,772	48,485
Proceeds from related party notes receivable	8,681	10,255
Purchase of Public Gas Company, Inc.	'	-1,551,477
Cash acquired in acquisition	'	502
Investment in unconsolidated affiliate	-35,000	'
Restricted cash - capital expenditures fund	1,264,624	-1,322,065
Customer advances for construction	23,802	128,381
Contributions in aid of construction	1,105,973	134,076
Net cash (used in) provided by investing activities	-20,766,937	-23,206,027
CASH FLOWS FROM FINANCING ACTIVITIES	'	'
Proceeds from lines of credit	22,519,000	51,390,754
Repayments of lines of credit	-21,848,956	-50,690,999
Proceeds from notes payable	'	12,989,552
Repayments of notes payable	-633,498	-7,920
Payments of capital lease obligations	-167,518	'
Debt issuance costs	-7,607	-1,204,987
Proceeds from issuance of common shares	16,721,104	'
Exercise of stock options	159,500	'
Restricted cash - debt service fund	748,781	-878,875
Dividends paid	-5,005,827	-4,432,920
Net cash (used in) provided by financing activities	12,484,979	7,164,605
DISCONTINUED OPERATIONS	'	'
Operating cash flows	-394,427	-522,559
Investing cash flows	2,345,993	-46,306
Financing cash flows	-613,687	401,000
Net cash provided by discontinued operations	1,337,879	-167,865
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	9,712,264	-7,069,728
Cash and cash equivalents, beginning of period	3,435,117	10,504,845
CASH AND CASH EQUIVALENTS, END OF PERIOD	13,147,381	3,435,117
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION	'	'
Cash paid for interest	2,806,051	2,286,902
Cash refunded for income taxes, net	-4,050	-989,503
NONCASH INVESTING AND FINANCING ACTIVITIES	'	'
Shares issued to purchase JDOG Marketing	2,641,199	'
Contingent consideration issued to purchase JDOG Marketing	2,250,000	'
Plant, property and equipment acquired from JDOG Marketing purchase	21,600	'
Customer relationships acquired from JDOG Marketing purchase	2,800,000	'
Goodwill acquired from JDOG Marketing purchase	2,101,744	'
Note receivable effectively settled in JDOG Marketing acquisition	32,145	'
Capital expenditures included in accounts payable	1,798,014	745,402
Shares issued to purchase Loring Pipeline	'	2,250,004
Capital assets exchanged to settle payables	82,584	'
Capital assets acquired through trade-in	23,500	'
Accrued dividends	470,326	376,639
Capitalized interest	15,226	21,147
Customer advances for construction moved to contribution in aid of construction	$16,364	'

Financial_Statement_Schedule

Financial Statement Schedule	12 Months Ended
Financial Statement Schedule	Dec. 31, 2013
Condensed Financial Information Of Parent Company Only Disclosure [Abstract]	'
Financial Statement Schedule	'
	Gas Natural Inc. (Parent Company Only)
	Condensed Financial Statements


			December 31,
			2013			2012
	BALANCE SHEETS
	ASSETS
	Current assets		$	8,376,229		$	235,519
	Investments			89,104,692			75,417,951
	Accounts receivable			250,000
	Property, plant, & equipment, net			306,738			611,575
	Deferred tax asset, less current portion			435,983			278,469
	Restricted cash			-			750,939
	Prepayments			179,598
	Other assets			840			-

	Total assets		$	98,654,080		$	77,294,453

	LIABILITIES AND CAPITALIZATION
	Current liabilities		$	694,217		$	654,764
	Intercompany payable, net			480,088			295,565
	Stockholders’ equity			97,479,775			76,344,124

	Total liabilities and capitalization		$	98,654,080		$	77,294,453


			Year Ended December 31,
			2013			2012
	STATEMENT OF COMPREHENSIVE INCOME
	Operating expenses		$	946,222		$	250,045

	Operating loss			(946,222)			(250,045)
	Other income (expense)			(523,990)			(804,775)
	Interest expense			-			-

	Income before income taxes and income from unconsolidated subsidiaries			(1,470,212)			(1,054,820)
	Income from unconsolidated subsidiaries			7,738,256			4,377,406
	Income tax benefit (expense)			403,235			396,731

	Net income		$	6,671,279		$	3,719,317
	Other comprehensive income, net of tax of $22,951 and 8,913, respectively			39,120			(14,616)

	Comprehensive income		$	6,710,399		$	3,704,701


	Gas Natural Inc. (Parent Company Only)
	Condensed Financial Statements, continued


			Year Ended December 31,
			2013			2012
	STATEMENTS OF CASH FLOWS
	CASH FLOWS FROM OPERATING ACTIVITIES
	Net income		$	6,671,279		$	3,719,317
	Income from unconsolidated subsidiaries			(7,738,256)			(4,377,406)
	Depreciation expense			12,670			3,931
	Stock based compensation			2,962			60,009
	Deferred income taxes			(158,629)			(256,291)
	Other assets			(62,122)			7,245
	Other liabilities			108,736			432,430

	Net cash used in operating activities			(1,163,360)			(410,765)
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures			(75,309)			(615,506)
Purchase of marketable securities			-			-
Repayment of intercompany loans			-			-
Investment in subsidiaries			(6,845,497)			(1,887,288)
Dividends received from subsidiaries			3,600,000			4,485,892

Net cash (used in) provided by investing activities			(3,320,806)			1,983,098
CASH FLOWS FROM FINANCING ACTIVITIES
Debt issuance costs			(840)			-
Restricted cash – debt service			750,939			(750,939)
Exercise of stock options			159,500			-
Proceeds from issuance of common stock			16,721,104			-
Dividends paid			(5,005,827)			(4,432,920)

Net cash (used in) provided by financing activities			12,624,876			(5,183,859)
Net increase (decrease) in cash and cash equivalents			8,140,710			(3,611,526)
Cash and cash equivalents, beginning of period			235,519			3,847,045

Cash and cash equivalents, end of period		$	8,376,229		$	235,519

Basis of Presentation
Pursuant to rules and regulations of the SEC, the unconsolidated condensed financial statements of Gas Natural Inc. do not reflect all of the information and notes normally included with financial statements prepared in accordance with accounting principles generally accepted in the United States of America. Therefore, these condensed financial statements should be read in conjunction with the consolidated financial statements and related notes included in this Form 10-K.
Gas Natural Inc. has accounted for the earnings of its subsidiaries under the equity method in these unconsolidated condensed financial statements.
Common Dividends from Subsidiaries
Common stock cash dividends paid to Gas Natural Inc. by its subsidiaries were as follows:


		Years Ended December 31,
		2013			2012
Energy West, Inc.		$	3,600,000		$	4,350,000
Great Plains Natural Gas Company			-			98,759
Lightning Piepeline Company, Inc.			-			37,133

Total		$	3,600,000		$	4,485,892

Summary_of_Business

Summary of Business	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Business	'
	Note 1 – Summary of Business
	Nature of Business
	Gas Natural Inc. (the “Company”) is the parent company of Brainard, Energy West, GNR, Independence, GNSC, Great Plains, Lightning Pipeline and PGC. Brainard is a natural gas utility company with operations in Ohio. Energy West is the parent company of multiple entities that are natural gas utility companies with regulated operations in Maine, Montana, North Carolina and Wyoming as well as non-regulated operations in Maine, Montana and Wyoming. GNR is a natural gas marketing company that markets gas in Ohio and Pennsylvania. GNSC manages gas procurement, transportation, and storage for Brainard and subsidiaries of Lightning Pipeline and Great Plains. Great Plains is the parent company of NEO, a regulated natural gas distribution company with operations in Ohio. NEO is the parent company of 8500 Station Street, a property management company responsible for the Company’s headquarters building, and Kidron, a small natural gas well company in Ohio. Lightning Pipeline is the parent company of Orwell, a regulated natural gas distribution company with operations in Ohio, and Spelman, a natural gas pipeline company in Ohio and Kentucky. Clarion River and Walker Gas are divisions of Orwell and are regulated natural gas distribution companies with operations in Pennsylvania. PGC is a regulated natural gas distribution company in Kentucky. The Company currently has four reporting segments:


	• Natural Gas Operations	Annually distribute approximately 36 Bcf of natural gas to approximately 72,000 customers through regulated utilities operating in Kentucky, Maine, Montana, North Carolina, Ohio, Pennsylvania and Wyoming.

	• Marketing and Production Operations	Annually markets approximately 1.5 Bcf of natural gas to commercial and industrial customers in Montana, Wyoming, Ohio, and Pennsylvania through our EWR and GNR subsidiaries. Our EWR subsidiary also manages midstream supply and production assets for transportation customers and utilities. EWR owns an average 51% gross working interest (average 43% net revenue interest) in 160 natural gas producing wells and gas gathering assets located in Glacier and Toole Counties in Montana.

	• Pipeline Operations	The Shoshone interstate and Glacier gathering natural gas pipelines located in Montana and Wyoming are owned through the subsidiary, EWD. Certain natural gas producing wells owned by EWD are being managed and reported under the marketing and production operations.

	• Corporate and Other	Encompasses costs associated with business development and acquisitions, dispositions of subsidiary entities, results of discontinued operations, dividend income, recognized gains or losses from the sale of marketable securities, and activity from Lone Wolfe which serves as an insurance agent for the Company and other businesses in the energy industry.

	Energy West was originally incorporated in Montana in 1909 and was reorganized as a holding company in 2009 to facilitate future acquisitions and corporate-level financing to support the Company’s growth strategy. On July 9, 2010, the Company changed its name to Gas Natural Inc. and reincorporated from Montana to Ohio. Moving the incorporation to Ohio enhances the Company’s flexibility and provides a more efficient platform from which to operate and grow.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
Significant Accounting Policies	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	Note 2 – Significant Accounting Policies
	Basis of Presentation
	The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States. These principles are set by the FASB. The FASB sets GAAP to ensure the consistent reporting of the Company’s financial condition, results of operations and cash flows. References to GAAP issued by the FASB in these footnotes are to the FASB Accounting Standards Codification, sometimes referred to as the Codification or ASC.
	Principles of Consolidation
	The consolidated financial statements include the accounts and transactions of the Company and its wholly-owned subsidiaries as well as the proportionate share of assets, liabilities, revenues, and expenses of certain producing natural gas properties. All intercompany transactions and balances have been eliminated.
	Reclassifications
	Certain reclassifications of prior year reported amounts have been made for comparative purposes. Such reclassifications are not considered material and had no effect on net income.
	Effects of Regulation
	The Company follows the provisions of ASC 980—Regulated Operations and the accompanying financial statements reflect the effects of the different rate-making principles followed by the various jurisdictions regulating the Company. The economic effects of regulation can result in regulated companies recording costs that have been, or are expected to be, allowed in the rate-making process in a period different from the period in which the costs would be charged to expense by an unregulated enterprise. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses in the periods when those same amounts are reflected in rates. Additionally, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for amounts that are expected to be refunded to customers which are recorded as liabilities in the balance sheet (regulatory liabilities).
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.
	The Company has used estimates in measuring certain deferred charges and deferred credits related to items subject to approval of the various public service commissions with jurisdiction over the Company. Estimates are also used in determining amounts for the Company’s allowances for doubtful accounts, unbilled gas, asset retirement obligations, contingent consideration liability, and determination of depreciable lives of utility plant. The deferred tax asset and valuation allowance require a significant amount of judgment and are significant estimates. The estimates are based on projected future tax deductions, future taxable income, estimated limitations under the Internal Revenue Code, and other assumptions.
	The Company makes acquisitions which involve combining the assets and liabilities of the acquired company with our Company. The assets and liabilities acquired are reported at their fair value at the date of acquisition. Measuring this fair value may require the use of estimates.
	Such estimates could change in the near term and could significantly impact the Company’s results of operations and financial position.
	Fair Value Measurements
	For assets and liabilities measured at fair value, fair value is 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. Measuring fair value requires the use of market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, corroborated by market data, or generally unobservable. Valuation techniques are required to maximize the use of observable inputs and minimize the use of unobservable inputs.
	Leases
	Leases are categorized as either operating or capital leases at inception. Operating lease costs are recognized on a straight-line basis over the term of the lease. For capital leases, an asset and a corresponding liability are established for the present value at the beginning of the lease term of minimum lease payments during the lease term, excluding any executory costs. If the present value of the minimum lease payments exceeds the fair value of the leased property at lease inception, the amount measured initially as the asset and obligation shall be the fair value. The capital lease obligation is amortized over the life of the lease.
	Revenue Recognition
	Revenues are recognized in the period that services are provided or products are delivered. The Company records gas distribution revenues for gas delivered to residential and commercial customers but not billed at the end of the accounting period. The Company periodically collects revenues subject to possible refunds pending final orders from regulatory agencies. When this occurs, appropriate liabilities for such revenues collected subject to refund are established.
	Stock-Based Compensation
	The Company accounts for stock-based compensation arrangements by recognizing compensation costs for all stock-based awards over the respective service period for employee services received in exchange for an award of equity or equity-based compensation. The compensation cost is based on the fair value of the award on the date it was granted.
	Income Taxes
	The Company files its income tax returns on a consolidated basis. Rate-regulated operations record cumulative increases in deferred taxes as income taxes recoverable from customers. The Company uses the deferral method to account for investment tax credits as required by regulatory commissions. Deferred income taxes are determined using the asset and liability method, under which deferred tax assets and liabilities are measured based upon the temporary differences between the financial statement and income tax bases of assets and liabilities, using current tax rates.
	Tax positions must meet a more-likely-than-not recognition threshold to be recognized. The Company has no unrecognized tax benefits that would have a material impact to the Company’s financial statements for any open tax years. No adjustments were recognized for uncertain tax positions for the years ended December 31, 2013 and 2012.
	The Company recognizes interest and penalties related to unrecognized tax benefits in operating expense. As of December 31, 2013 and 2012, there were no unrecognized tax benefits nor interest or penalties accrued related to unrecognized tax benefits. For the years ended December 31, 2013 and 2012, the Company did not recognize interest or penalties.
	The Company, or one or more of its subsidiaries, files income tax returns in the U.S. federal jurisdiction and various state jurisdictions. The tax years after 2009 for federal and state returns remain open to examination by the major taxing jurisdictions in which we operate.
	Comprehensive Income
	Comprehensive income includes net income and other comprehensive income (loss), which for the Company is primarily comprised of unrealized holding gains or losses on available-for-sale securities. These gains or losses are excluded from the computing of net income and reported separately in shareholders’ equity as Accumulated other comprehensive income.
	Earnings per Share
	Basic earnings per share are computed by dividing net income by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution from the exercise or conversion of outstanding stock options and restricted stock awards into common stock.
	Cash and Cash Equivalents
	The Company considers all highly liquid investments with original maturities of three months or less, at the date of acquisition, to be cash equivalents. The Company maintains, at various financial institutions, cash and cash equivalents which may exceed federally insurable limits and which may, at times, significantly exceed balance sheet amounts.
	Marketable Securities
	Securities investments that the Company has the positive intent and ability to hold to maturity are classified as held-to-maturity securities and recorded at amortized cost. Securities investments bought expressly for the purpose of selling in the near term are classified as trading securities and are measured at fair value with unrealized gains and losses reported in earnings. Securities investments not classified as either held-to-maturity or trading securities are classified as available-for-sale securities. Available-for-sale securities are recorded at fair value in marketable securities in the accompanying Consolidated Balance Sheets, with the change in fair value during the period excluded from earnings and recorded net of tax as a component of other comprehensive income. Realized gains and losses, and declines in value judged to be other than temporary, are recorded in the accompanying Consolidated Statement of Comprehensive Income.

	Receivables
	The accounts receivable are generated from sales and delivery of natural gas and propane as measured by inputs from meter reading devices. Trade accounts receivable are carried at the expected net realizable value. There is credit risk associated with the collection of these receivables. As such, a provision is recorded for the receivables considered to be uncollectible. The provision is based on management’s assessment of the collectability of specific customer accounts, the aging of the accounts receivable and historical write-off amounts. The underlying assumptions used for the provision can change from period to period and the provision could potentially cause a negative material impact to the income statement and working capital.
	Two of the Company’s utilities in Ohio, Orwell and NEO collect from their customers, through rates, an amount to provide an allowance for doubtful accounts. As accounts are identified as uncollectible, they are written off against this allowance for doubtful accounts with no income statement impact. In effect, all bad debt expense is funded by the customer base. The total amount collected from customers and the amounts written off are reviewed annually by the PUCO and the rate per Mcf is adjusted as necessary.
	The Company’s bad debt expense for the years ended December 31, 2013 and 2012 was $797,867 and $958,561, respectively. The Company wrote-off $161,674 and $213,855 for the years ended December 31, 2013 and 2012, respectively.
	Natural Gas Inventory
	Natural gas inventory is stated at the lower of weighted average cost or net realizable value except for Energy West Montana – Great Falls, which is stated at the rate approved by the MPSC, which includes transportation and storage costs.
	Recoverable/Refundable Costs of Gas Purchases
	The Company accounts for purchased gas costs in accordance with procedures authorized by the utility commissions in the states in which it operates. Purchased gas costs that are different from those provided for in present rates, and approved by the respective commission, are accumulated and recovered or credited through future rate changes. The gas cost recoveries are monitored closely by the regulatory commissions in all of the states in which the Company operates and are subject to periodic audits or other review processes.
	Property, Plant and Equipment
	Property, plant and equipment are recorded at original cost when placed in service. Depreciation and amortization on assets are generally recorded on a straight-line basis over the estimated useful lives, as applicable, at various rates. These assets are depreciated and amortized over three to forty years.
	EWR owns an interest in certain producing natural gas reserves on properties located in northern Montana. EWD also owns an interest in certain natural gas producing properties located in northern Montana. The Company is depleting these reserves using the units-of-production method. The production activities are being accounted for using the successful efforts method. The Company is not the operator of any of the natural gas producing wells on these properties and the Company is not regarded as having significant oil- and gas-producing activities as defined by ASC 932 – Extractive Activities – Oil and Gas. Therefore, the disclosures defined in ASC 932 have been omitted.
	Contributions in Aid of and Advances Received for Construction
	Contributions in aid of construction are contributions received from customers for construction that are not refundable and are amortized over the life of the assets. Customer advances for construction includes advances received from customers for construction that are to be refunded wholly or in part.

	Goodwill and Other Intangible Assets
	Goodwill represents the excess of the purchase price over the fair value of identifiable net tangible and intangible assets acquired in a business combination. Goodwill is not amortized, rather, the goodwill is required to be tested for impairment annually, which the Company performs in the fourth quarter, or if events or changes in circumstances indicate that goodwill may be impaired. The Company tests for goodwill impairment using a two-step approach. A recoverability test at the reporting unit level must be performed during the first step. If the asset is not recoverable, the second step calculates the impairment loss, if any.
	The Company recognizes an acquired intangible apart from goodwill whenever the intangible arises from contractual or other legal rights, or whenever it can be separated or divided from the acquired entity and sold, transferred, licensed, rented or exchanged, either individually or in combination with a related contract, asset or liability. Such intangibles are amortized on a straight-line basis over their estimated useful lives unless the estimated useful life is determined to be indefinite. Accumulated amortization for Customer relationships was approximately $254,667 at December 31, 2013. Amortization expense for Customer relationships for the year ended December 31, 2013 was approximately $186,167.
	Regulatory Assets and Liabilities
	The regulatory asset for property tax is recovered in rates over a ten-year period starting January 1, 2004. The income taxes earn a return equal to that of the Company’s rate base. The rate case costs do not earn a return. Regulatory assets will be recovered over a period of approximately three to twenty years. Regulatory liabilities will be refunded over a period of approximately five to twenty years.
	Debt Issuance Costs
	Debt issuance costs are fees and other direct incremental costs incurred by the Company in obtaining debt financing and are recognized as assets and amortized as interest expense over the term of the related debt.
	Investment in Unconsolidated Affiliate
	EWR owns a 24.5% interest in Kykuit, a developer and operator of oil, gas and mineral leasehold estates located in Montana. The Company is accounting for the investment in Kykuit using the equity method. The Company has invested approximately $2.2 million in Kykuit and may invest additional funds in the future as Kykuit could provide a supply of natural gas in close proximity to our natural gas operations in Montana. However, our obligations to make additional investments in Kykuit are limited under our agreement with the other Kykuit investors. At December 31, 2013, we are obligated to invest no more than an additional $0.1 million over the life of the venture. Other investors in Kykuit include our chairman and chief executive officer, Richard M. Osborne, and John D. Oil and Gas Company, a publicly held gas exploration company, which is also the managing member of Kykuit. Additional investors include Thomas J. Smith, a director and our chief financial officer, and a director of John D. Oil and Gas Company, and Gregory J. Osborne, a director and chief operating officer and former president and director of John D. Oil and Gas Company.
	Impairment of Long-Lived Assets
	The Company evaluates its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets or intangibles may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to future undiscounted net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment loss to be recognized is measured as the amount by which the carrying value of the assets exceeds their fair value. As of December 31, 2013 and 2012, management does not consider the value of any of its long-lived assets to be impaired.
	Asset Retirement Obligations
	The Company records the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it was incurred or acquired. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement cost is included in “Property, plant and equipment, net” in the accompanying Consolidated Balance Sheets. The Company amortizes the amount added to property, plant, and equipment, net. The accretion of the asset retirement liability is allocated to operating expense using a systematic and rational method.
Derivatives and Hedging Activities
In order to mitigate the risk of natural gas market price volatility related to firm commitments to purchase or sell natural gas, from time to time the Company and its subsidiaries have entered into fixed contracts. Such arrangements may be used to protect profit margins on future obligations to deliver gas at a fixed price, or to protect against adverse effects of potential market price declines on future obligations to purchase gas at fixed prices.
The Company accounts for these contracts in accordance with ASC 815, Derivatives and Hedging which states that unless these contracts qualify for treatment as a “normal purchase or normal sale,” they are to be reflected in the balance sheet as assets or liabilities at fair value as of the balance sheet date. Changes in these fair values are reported in the Consolidated Statement of Comprehensive Income.
For the years ended December 31, 2013 and 2012, all of the Company’s fixed contracts for purchase or sale of gas at fixed prices and volumes qualified for treatment as a “normal purchase” or “normal sale”.
Recently Adopted Accounting Pronouncements
ASU No. 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities”
In January 2013, the FASB issued ASU 2013-01, which clarifies which instruments and transactions are subject to the offsetting disclosure requirements established by ASU 2011-11. The new ASU addresses preparer concerns that the scope of the disclosure requirements under ASU 2011-11 was overly broad and imposed unintended costs that were not commensurate with estimated benefits to financial statement users. In choosing to narrow the scope of the offsetting disclosures, the FASB determined that it could make them more operable and cost effective for preparers while still giving financial statement users sufficient information to analyze the most significant presentation differences between financial statements prepared in accordance with U.S. GAAP and those prepared under IFRSs. ASU 2013-01 became effective for fiscal years beginning on or after January 1, 2013. The adoption of this ASU did not have a material impact on the accompanying financial statements.
ASU 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”
In February 2013, the FASB issued ASU 2013-02 to amend the guidance in the FASB ASC Topic 220, entitled Comprehensive Income. The goal behind development of the ASU 2013-02 amendments is to improve the transparency of reporting reclassifications out of accumulated other comprehensive income. Other comprehensive income includes gains and losses that are initially excluded from net income for an accounting period. Those gains and losses are later reclassified out of accumulated other comprehensive income into net income when realized. The amendments to FASB ASC 220 do not change current requirements for reporting net income or other comprehensive income in the financial statements. Essentially, all of the information required to be displayed or disclosed in financial statements already are required to be disclosed in the financial statements. The adoption of this ASU did not have a material impact on the accompanying financial statements, but did require additional disclosure.

Acquisitions

Acquisitions	12 Months Ended
Acquisitions	Dec. 31, 2013
Business Combinations [Abstract]	'
Acquisitions	'
	Note 3 – Acquisitions
	Acquisition of Public Gas Company, Inc.
	On April 1, 2012 the Company purchased 100% of the stock of PGC from Kentucky Energy Development, LLC for the price of $1.6 million. PGC is a regulated natural gas distribution company serving approximately 1,600 customers in the State of Kentucky in the counties of Breathitt, Jackson, Johnson, Lawrence, Lee, Magoffin, Morgan and Wolf. The costs related to the transaction were $51,187 and were expensed during 2012. The Company completed the transaction as it provided the opportunity to expand its presence into Kentucky.
	The Company applied the acquisition method to the business combination and valued each of the assets acquired (cash, accounts receivable, and property, plant and equipment) and liabilities assumed (accounts payable) at fair value as of the acquisition date. The cash, accounts receivable and accounts payable were deemed to be recorded at fair value as of the acquisition date. The Company determined the fair value of property, plant and equipment to be historical book value which is the rate base as PGC is a regulated natural gas distribution company and is required to report to the KPSC. The Company also recorded deferred taxes based on the timing difference related to depreciation. As a result of the purchase, $142,971 was allocated to goodwill. During 2012, this amount was adjusted to $283,425 resulting from adjustments to deferred income taxes and deferred gas cost existing at the time of acquisition. This is reported in the Natural Gas Operations segment. The Company expects none of the goodwill to be deductible for tax purposes.
	The estimated fair value of the assets acquired and liabilities assumed is reflected in the following table at the date of acquisition.


			Fair Value at
			April 1, 2012
	Current assets		$	69,634
	Property, plant and equipment			1,577,592
	Goodwill			283,425

	Total assets acquired			1,930,651
	Current liabilities			184,770
	Long-term liabilities			194,403

	Total liabilities assumed			379,173

	Net assets acquired		$	1,551,478

	Acquisition of Loring Pipeline lease and related property
	On April 17, 2012, the Company entered into an agreement with United States Power Fund, L.P. (“USPF”) to place a bid at a public auction on certain assets that were being foreclosed upon by USPF. Those assets included various parcels of land as well as a leasehold interest in a pipeline corridor easement running from Searsport to Limestone, Maine. The assets were owned by Loring BioEnergy, LLC (“LBE”) and were being foreclosed upon by USPF due to LBE’s default on a loan that it had obtained from USPF. On June 4, 2012 the Company attended the public foreclosure auction and was the successful bidder with a bid of $4.5 million. The transaction closed on September 25, 2012. At that time, the Company issued 210,951 shares of its common stock in addition to transferring $2,250,000 of cash it had placed into escrow prior to the auction to USPF. The lease agreement calls for lease payments of $300,000 per year for the next ten years, an annual service fee of $120,000 and a charge of $0.0125 per Mcf moved on the pipeline.
	In accordance with U.S. GAAP, the assets acquired do not constitute a business and the Company has accounted for the transaction as a group of assets which included both fixed assets and leased fixed assets. The purchase price was allocated to the assets purchased based on the relative fair value of each asset (including the leased assets) to the total fair value of all the assets. Land, buildings, generators and equipment purchased totaled $605,352. Leased pipeline and leased pipeline easements acquired totaled $6,320,000. The Company has determined that the fixed asset lease is a capital lease because the present value of the lease payments, discounted at an appropriate discount rate, exceeded 90% of the fair market value of the assets. The lease obligation for the $300,000 per year was recorded at the present value of the minimum lease payments of $2,208,026.
	Acquisition of 8500 Station Street
	On March 5, 2013, the Company purchased the Matchworks Building in Mentor, Ohio for $1.9 million from McKay Real Estate Corporation, Matchworks, LLC, and Nathan Properties, LLC (collectively, the “Sellers”) by and through Mark E. Dottore as Receiver in the United States District Court. The Sellers are entities owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer. The acquisition of the Matchworks Building was approved by the independent members of the Company’s board of directors. A subsidiary of Gas Natural, 8500 Station Street, was formed to operate the property. The Company accounted for the transaction as an asset purchase and as such recorded the land and building purchased as Property, plant and equipment on its Consolidated Balance Sheets in the amounts of $244,859 and $1,607,915, respectively. These amounts were allocated based on the assets’ relative fair values.
	Acquisition of John D. Oil and Gas Marketing
	On June 1, 2013, the Company and its wholly-owned Ohio subsidiary, GNR, completed the acquisition of substantially all of the assets and certain liabilities of JDOG Marketing, an Ohio company engaged in the marketing of natural gas. The Osborne Trust is the majority owner of JDOG Marketing. Richard M. Osborne, the Company’s chairman and chief executive officer, is the sole trustee of the Osborne Trust. The Company believes the natural gas marketing business complements its existing natural gas distribution business in Ohio. In addition, it currently conducts natural gas marketing in Montana and Wyoming, which the Company believes allows it to integrate the Ohio marketing operations into Gas Natural with minimal increases in staff or overhead. Costs related to this acquisition totaled $0.6 million and were expensed as incurred.
	Pursuant to the terms of the purchase agreement, the consummation of the transaction depended upon the satisfaction or waiver of a number of certain customary closing conditions, the receipt of regulatory approvals and the consent of certain of Gas Natural’s lenders. In addition, the transaction was subject to the approval of Gas Natural’s shareholders, and the receipt of a fairness opinion by an independent investment banking firm. All of these conditions were satisfied and the acquisition was completed on June 1, 2013. In accordance with U.S. GAAP, the consideration given, assets received, and liabilities assumed by the Company were recorded at their fair market value as of this date.

	The following table shows the estimated fair values of the assets acquired and liabilities assumed at the date of acquisition.


			Fair Value at
			June 1, 2013
	Assets acquired:
	Property, plant and equipment		$	21,600
	Customer relationships			2,800,000
	Goodwill			2,101,744

	Total assets acquired			4,923,344

	Less liabilities assumed:
	Current liabilities			669,396
	Long-term liabilities			1,580,604

	Total liabilities assumed			2,250,000

	Less effective settlement of pre-existing relationships:
	Settlement of note receivable			32,145

	Net assets acquired from John D Marketing acquisition		$	2,641,199

	Under the purchase agreement, Gas Natural issued to JDOG Marketing 256,926 shares of the Company’s common stock. These shares had an acquisition date fair value of $2,641,199. There were no underwriting discounts or commissions in connection with the issuance, as no underwriters were used to facilitate the acquisition. The shares were not registered under the Securities Act of 1933, as amended (the “Act”), in reliance on the exemption from registration provided by Section 4(2) of the Act.
	In addition, the purchase agreement provides for contingent “earn-out” payments for a period of five years after the closing of the transaction if the acquired business achieves an annual EBITDA target in the amount of $810,432, which was JDOG Marketing’s EBITDA for the year ended December 31, 2011. If JDOG Marketing’s actual EBITDA for a given year is less than the target EBITDA, then no earn-out payment will be due and payable for that particular period. If JDOG Marketing’s actual EBITDA for a given year meets or exceeds the target EBITDA, then an earn-out payment in an amount equal to actual EBITDA divided by target EBITDA times $575,000 will have been earned for that year. Due to the earn-out structure, the maximum amount that could be earned over the five year period is unlimited.
	Earn-out payments are to be settled annually in validly issued, fully paid and non-assessable shares of the Company’s common stock. The share price to be used to determine the number of shares to be issued for each earn-out payment will be the average closing price of Gas Natural’s common stock for the 20 trading days preceding issuance of Gas Natural’s common stock for such earn-out payment. The Company estimated the acquisition date fair value of this liability to be $2,250,000, of which $669,396 was classified as current. The fair value of this liability is remeasured on a recurring basis. See Note 7 – Fair Value Measurements for details regarding this valuation.
	The Company has calculated the earn-out payment for the year ended December 31, 2013 as $671,638. This earn-out amount is included in the Contingent consideration, current portion line of the Company’s Consolidated Balance Sheet and is expected to be settled in the second quarter of 2014.
	The Company applied the acquisition method to the business combination and valued each of the assets acquired (property, plant and equipment and customer relationships) and liabilities assumed (earn-out liability) at fair value as of the acquisition date. The Company used the net book value of property, plant, and equipment received as this closely approximated the fair value. The Company used the present value of expected net cash flows associated with the acquired customer contracts to approximate the assets’ fair values. These customer contracts represent established and ongoing contracts to provide natural gas to the former customers of JDOG Marketing acquired by the Company as part of the acquisition. These customer contracts will be fully amortized over their 10 year estimated useful lives. The Company recorded the fair value of the earn-out liability as the present value of estimated future earn-out payments as of the acquisition date. In addition to the assets acquired and liabilities assumed in the transaction, the Company also effectively settled a note due from JDOG Marketing. As a result of the purchase, $2,101,744 was allocated to goodwill. The Company expects none of the goodwill to be deductible for tax purposes.
	The results of JDOG Marketing are included in the Company’s Marketing and Production Operations reporting segment. For the year ended December 31, 2013, JDOG Marketing contributed $1,946,745 to the Company’s revenues and $764,568 to the Company’s net income.
	The following unaudited information is provided to present a summary of the combined results of the Company’s operations with JDOG Marketing as if the acquisition had been completed as of the beginning of the reporting periods. Adjustments were made to eliminate any inter-company transactions in the periods presented.


			Years ended December 31,
		2013			2012
		(Pro Forma)			(Pro Forma)
Revenues		$	120,326,778		$	98,233,417

Net income		$	7,082,270		$	4,996,567

Basic and diluted earnings (loss) per share		$	0.76		$	0.61

Historically, the Company has been a party to transactions with JDOG Marketing primarily for the purchase of natural gas. In addition to these purchases, the Company also had a note receivable outstanding from JDOG Marketing included in the Notes receivable – related parties line items on the Consolidated Balance Sheets and an operating lease agreement the cost of which was included in the Distribution, general, and administrative line of the Consolidated Statement of Comprehensive Income. Both of these relationships were effectively settled with the completion of the transaction. See Note 15 – Related Party Transactions for more information regarding all of the Company’s transactions with JDOG Marketing prior to the acquisition.

Discontinued_Operations

Discontinued Operations	12 Months Ended
Discontinued Operations	Dec. 31, 2013
Discontinued Operations And Disposal Groups [Abstract]	'
Discontinued Operations	'
	Note 4 – Discontinued Operations
	On November 6, 2013, the Company closed on the sale of Independence to Blue Ridge Energies, LLC (“Blue Ridge”) for a total of $2.3 million. This sale resulted in the Company recording a loss on sale of approximately $8,000 in the fourth quarter of 2013. This amount is included in the Discontinued operations line of the Company’s Consolidated Statement of Comprehensive Income. The results of operations and financial position for Independence have been reclassified to the discontinued operations sections of the Company’s consolidated financial statements. Independence was the Company’s only subsidiary included in its Propane Operations reporting segment. As a result of it being classified as discontinued operations, it results have been included in Corporate and Other operating segment for all periods presented. The remaining assets and liabilities associated with Independence on the Company’s books at December 31, 2013 include various prepaid expenses, accounts payable, and accrued liabilities. The Company expects each of these items to be settled in the near term. The Company has no material continuing cash flows or other contractual obligations associated with this sales transaction.

	The following table details the revenue and loss from discontinued operations associated with Independence for the years ended December 31, 2013 and 2012.


		Year Ended December 31,
		2013		2012
	Independence revenues	$	3,696,143	$	4,614,915

	Independence pretax loss	$	(514,634)	$	(494,541)
	Independence income tax benefit		144,359		293,443

	Loss from discontinued operations	$	(370,275)	$	(201,098)

	Basic and diluted loss from discontinued operations per share	$	(0.04)	$	(0.02)

Goodwill

Goodwill	12 Months Ended
Goodwill	Dec. 31, 2013
Goodwill And Intangible Assets Disclosure [Abstract]	'
Goodwill	'
	Note 5 – Goodwill
	In June 2013, the Company finalized its purchase of substantially all the assets and certain liabilities of JDOG Marketing. The Company accounted for this transaction as a business combination and as a result recognized $2.1 million of goodwill. See Note 3 – Acquisitions for more information regarding this transaction. The Company used many estimates in the determination of the acquisition date fair value of JDOG Marketing. One of these estimates was related to future sales between GNR, the Company’s subsidiary absorbing JDOG Marketing in the business combination, and two of the Company’s Ohio natural gas utility subsidiaries, NEO and Orwell.
	In November 2013, the PUCO released its Opinion and Order related to the 2012 NEO and Orwell GCR audits. See Note 17 – Commitments and Contingencies for more information regarding these GCR audits. This Opinion and Order, amongst other things, fined the Company’s NEO and Orwell subsidiaries for failure to terminate natural gas purchase agreements with JDOG Marketing as previously ordered. As a result of these fines, the Company has ceased all future purchases by NEO and Orwell of natural gas from GNR. The Company is unsure if it will be able to replace these lost sales volumes with sales to other sources. This change in forecast negatively affected the calculated enterprise value of GNR and has led to a goodwill impairment charge for a portion of the goodwill previously recorded. This impairment charge was calculated using both a Discounted Cash Flow method and a Guideline Public Company method.
	The schedule below describes the changes in carrying amount of goodwill for the years 2013 and 2012:


		Natural Gas		Marketing &		Total
		Operations		Production
				Operations
	Balance as of January 1, 2012	$	14,607,952	$	-	$	14,607,952
	Acquisition of PGC		283,425		-		283,425

	Balance as of December 31, 2012	$	14,891,377	$	-	$	14,891,377

	Balance as of January 1, 2013	$	14,891,377	$	-	$	14,891,377
	Acquisition of JDOG Marketing		-		2,101,744		2,101,744
	GNR Impairment loss		-		(725,744)		(725,744)

	Balance as of December 31, 2013	$	14,891,377	$	1,376,000	$	16,267,377

Marketable_Securities

Marketable Securities

12 Months Ended

Dec. 31, 2013

Investments Debt And Equity Securities [Abstract]

Marketable Securities

Note 6 – Marketable Securities

The Company’s marketable securities as of December 31, 2013 and 2012 consisted solely of common stock classified as available-for-sale securities. The Company did not hold any held-to-maturity or trading securities as of December 31, 2013 or 2012. As of December 31, 2013 and 2012, the Company did not hold any securities in an unrealized loss position.

The following is a summary of available-for-sale securities at December 31, 2013 and 2012.

December 31, 2013

Investment

Unrealized

Estimated

at cost

gains

losses

fair value

Common stock

238,504

167,630

406,134

31-Dec-12

Investment

Unrealized

Estimated

at cost

gains

losses

fair value

Common stock

238,504

105,842

344,346

The Company did not sell any of its marketable securities and there were no gross realized gains or losses for the years ended December 31, 2013 and 2012.

Fair_Value_Measurements

Fair Value Measurements

12 Months Ended

Dec. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value Measurements

Note 7 – Fair Value Measurements

The Company follows a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to measurements involving unobservable inputs (Level 3). The three levels of the fair value hierarchy are as follows:

Level 1 inputs – observable inputs that reflect quoted prices (unadjusted) for identical assets or liabilities in active markets.

Level 2 inputs – other inputs that are directly or indirectly observable in the marketplace.

Level 3 inputs – unobservable inputs which are supported by little or no market activity.

The level in the fair value hierarchy within which a fair value measurement falls is based on the lowest level input that is significant to the fair value measurement in its entirety.

The following table shows the amount and level in the fair value hierarchy of each of the Company’s assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012.

December 31, 2013

Level 1

Level 2

Level 3

TOTAL

ASSETS:

Available-for-sale securities

406,134

LIABILITIES:

Contingent consideration

685,000

31-Dec-12

Level 1

Level 2

Level 3

TOTAL

ASSETS:

Available-for-sale securities

344,346

The fair value of financial instruments including cash and cash equivalents, notes and accounts receivable and notes and accounts payable are not materially different from their carrying amounts. The fair values of marketable securities are estimated based on closing share price on the quoted market price for those investments. Cost basis is determined by specific identification of securities sold. Under the fair value hierarchy, the fair value of cash and cash equivalents is classified as a Level 1 measurement and the fair value of notes payable are classified as Level 2 measurements.

The contingent consideration liability categorized in level 3 of the fair value hierarchy arose as a result of the JDOG Marketing acquisition. See Note 3 – Acquisitions for more information regarding this transaction.

Valuation of the contingent consideration liability categorized under level 3 of the fair value hierarchy was conducted by an independent third-party valuation firm. Inputs and assumptions used in the valuation were reviewed for reasonableness by the Company in the course of the valuation process and have been updated to reflect changes in the Company’s business environment.

The following table reconciles the beginning and ending balances of the contingent consideration liability categorized under level 3 of the fair value hierarchy.

Fair Value Measurements Using Significant Unobservable Inputs (Level 3)

Contingent

Consideration

Opening balance December 31, 2012

Transfers into level 3

Transfers out of level 3

Total (gains) losses for period:

Included in net income

(1,565,000)

Included in other comprehensive income

Purchases

Sales

Settlements

Issuances

2,250,000

Closing balance December 31, 2013

685,000

The gain included as a part of net income in the table above is included in the Contingent consideration gain line of the Company’s Consolidated Statement of Comprehensive Income and is the result of an unrealized holding gain associated with the change in the fair value of the Company’s contingent consideration liability.

The following table summarizes quantitative information used in determining the fair value of the Company’s liabilities categorized in level 3 of the fair value hierarchy.

Quantitative Information about Level 3 Fair Value Measures

Fair Value at

Valuation

Unobservable Input

Range

December 31,

Techniques

2013

Contingent Consideration

685,000

Monte Carlo analysis

Forecasted annual EBITDA

$0.4 - $0.6 million

Weighted avg cost of capital

15.0% - 15.0%

U.S. Treasury yields

0.1% - 1.3%

Discounted cash flow

U.S. Treasury yields

0.1% - 1.3%

Credit spread

1.3% - 3.3%

The significant unobservable inputs used in the fair value measure of the Company’s contingent consideration liability are its weighted average cost of capital, various U.S. Treasury yields, and the Company’s credit spread above the risk free rate. Significant increases (decreases) in any of these inputs in isolation would result in a significantly lower (higher) fair value measure. An additional significant unobservable input for this fair value measure is the Company’s forecasted annual EBITDA related to its GNR subsidiary. A significant increase (decrease) in this input would result in a significant increase (decrease) in the fair value measure.

Earnings_per_Share

Earnings per Share	12 Months Ended
Earnings per Share	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings per Share	'
	Note 8 – Earnings per Share


		Year Ended December 31,
		2013		2012
	Numerator:
	Income from continuing operations	$	7,041,554	$	3,920,415
	Income (loss) from discontinued operations		(370,275)		(201,098)

	Net income	$	6,671,279	$	3,719,317

	Denominator:
	Basic weighted average common shares outstanding		9,339,002		8,163,814
	Dilutive effect of stock options		720		5,865

	Diluted weighted average common shares outstanding		9,339,722		8,169,679

	Basic & diluted earnings (loss) per share of common stock:
	Continuing operations	$	0.75	$	0.48
	Discontinued operations		(0.04)		(0.02)

	Net income	$	0.71	$	0.46

	There were no shares or share equivalents that would have been anti-dilutive and therefore excluded in the calculation of diluted earnings per share for the years ended December 31, 2013 and 2012.

Property_Plant_Equipment

Property Plant & Equipment	12 Months Ended
Property Plant & Equipment	Dec. 31, 2013
Property Plant And Equipment [Abstract]	'
Property Plant & Equipment	'

	Note 9 – Property Plant & Equipment

	Components of property, plant, and equipment were as follows:



		December 31,
		2013		2012
	Gas transmission & distribution facilities	$	138,815,764	$	125,067,279
	Land		3,773,998		3,530,639
	Buildings & leasehold improvements		11,241,104		9,029,773
	Transportation equipment		3,449,615		3,311,769
	Computer equipment		3,844,776		3,589,035
	Other equipment		10,065,908		8,751,626
	Construction work in progress		10,762,534		8,470,638
	Producing natural gas properties		3,896,817		3,911,404

	Property, plant & equipment		185,850,516		165,662,163
	Accumulated depreciation, depletion & amortization		(52,301,885)		(47,034,673)

			133,548,631		118,627,490
	Discontinued operations		(28,345)		(2,198,448)

	Property, plant & equipment, net	$	133,520,286	$	116,429,042


	Producing Natural Gas Properties

	In order to provide a stable source of natural gas for a portion of its requirements, EWR and EWD own two natural gas production properties and three gathering systems located in north central Montana. The Company is depleting the cost of the gas properties using the units-of-production method. As of December 31, 2013 and 2012, management of the Company, considering reserve estimates provided by an independent reservoir engineer, estimated the net gas reserves at 2.3 Bcf (unaudited) and 2.1 Bcf (unaudited), respectively, and with net present values of $2,090,000 and $1,419,000, respectively, after applying a 10% discount (unaudited). The net book value of the gas properties totals $1,003,340 and $1,289,160 at December 31, 2013 and 2012, respectively.

	The wells are depleted based upon production at approximately 10% and 10% per year as of December 31, 2013 and 2012, respectively. For the years ended December 31, 2013 and 2012, EWR’s portion of the daily gas production was 422 Mcf and 461 Mcf per day, or 19.0% and 15.5% of EWR’s volume requirements, respectively.

	EWD owns working interests in a group of approximately 50 producing natural gas properties and a 75% ownership interest in a gathering system located in northern Montana. For the years ended December 31, 2013 and 2012, EWD’s portion of the daily gas production was 129 Mcf and 132 Mcf per day, or 5.8% and 4.4% of EWR’s volume requirements, respectively.

	For the years ended December 31, 2013 and 2012, EWR and EWD’s combined portion of the estimated daily gas production from the reserves was 550 Mcf and 593 Mcf, or 25.0% and 19.9% of our volume requirements in our Montana market, respectively. The wells are operated by an independent third party operator who also has an ownership interest in the properties.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	Note 10 – Asset Retirement Obligations
	The Company, excluding Orwell and Brainard, has identified but not recognized ARO liabilities related to gas transmission and distribution assets resulting from easements over property not owned by the Company. These easements are generally perpetual and only require retirement action upon abandonment or cessation of use of the property for the specified purpose. The ARO liability is not estimable for such easements as the Company intends to utilize these properties indefinitely. In the event the Company decides to abandon or cease the use of a particular easement, an ARO liability would be recorded at that time.
	As a result of regulatory action by the PUCO related to prior audits, Orwell and Brainard accrue an estimated liability for removing gas mains, meter and regulator station equipment, and service lines at the end of their useful lives. The liability is equal to a percent of the asset cost according to the following table:


		Percent of Asset Cost
		Orwell		Brainard
	Mains		15%		20%
	Meter/regulator stations		10%		10%
	Service lines		75%		75%
	The Company has no assets legally restricted for purposes of settling its asset retirement obligations. The schedule below is a reconciliation of the Company’s liability for the years ended December 31:


		2013		2012
	Balance, beginning of period	$	1,850,379	$	1,689,081
	Accretion expense		175,974		161,298


	Balance, end of period	$	2,026,353	$	1,850,379

	As of December 31, 2013 and 2012, the Company had capitalized ARO costs included in property, plant and equipment of $86,415 and $156,816, respectively.

Credit_Facilities_and_LongTerm

Credit Facilities and Long-Term Debt	12 Months Ended
Credit Facilities and Long-Term Debt	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Credit Facilities and Long-Term Debt	'

	Note 11 – Credit Facilities and Long-Term Debt

	Lines of Credit

	Bank of America

	The Company has a revolving credit facility with the Bank of America with a maximum borrowing capacity of $30.0 million due April 1, 2017. This revolving credit facility includes an annual commitment fee ranging from 25 to 45 basis points of the unused portion of the facility and interest on the amounts outstanding at LIBOR plus 175 to 225 basis points. The Company had outstanding borrowings under this facility of $24.5 million and $23.9 million at December 31, 2013 and 2012, respectively. For the year ended December 31, 2013, the weighted average borrowing outstanding on the revolving line of credit was $19.0 million. For the years ended December 31, 2013 and 2012, the weighted average interest rate on the revolving credit facility was 2.42% and 3.33%, respectively.

	Yadkin Valley

	The Company had a $500,000 revolving credit facility with Yadkin Valley Bank with an interest rate based on the prime rate, with a floor of 4.5% and cap of 16.0% per annum. The debt was secured by a blanket lien on all assets owned or acquired by Independence. In November 2013, as part of the sale of Independence, the Company paid off this line of credit to remove the liens on the assets owned by the subsidiary. The Company had outstanding borrowings under this facility of $0.0 million and $0.4 million at December 31, 2013 and 2012, respectively. These amounts were included in the Discontinued operations line on the Company’s Consolidated Balance Sheets. For the years ended December 31, 2013 and 2012, the weighted average borrowing outstanding on the revolving line of credit was $0.3 million and $0.4 million, respectively. The weighted average interest rate on the facility was 4.5% and 4.5% for the years ended December 31, 2013 and 2012, respectively.

	Notes Payable

	The following table details the Company’s outstanding long-term debt balances at December 31, 2013 and 2012.



		December 31,
		2013		2012
	LIBOR plus 1.75 to 2.25%, Bank of America amortizing term loan, due April 1, 2017	$	9,375,000	$	10,000,000
	6.16%, Allstate/CUNA Senior unsecured note, due June 29, 2017		13,000,000		13,000,000
	5.38%, Sun Life fixed rate note, due June 1, 2017		15,334,000		15,334,000
	LIBOR plus 3.85%, Sun Life floating rate note, due May 3, 2014		3,000,000		3,000,000
	4.15% Sun Life senior secured guaranteed note, due June 1, 2017		2,989,552		2,989,552
	Vehicle loan		2,190		10,688

	Total notes payable		43,700,742		44,334,240
	Less: current portion		3,502,190		633,498

	Notes payable, less current portion	$	40,198,552	$	43,700,742


	Bank of America

	The Bank of America amortizing term loan is an obligation of Energy West. The term loan contains an interest rate swap provision that allows for the interest rate to be fixed in the future. The term loan is amortized at a rate of $125,000 per quarter, with the first principal payment having come due on December 31, 2012. As of December 31, 2013, the Company had not exercised the interest rate swap provision for the fixed interest rate. For the years ended December 31, 2013 and 2012, the weighted average interest rate on the term loan was 2.19% and 2.14% respectively resulting in $215,593 and $56,226 of interest expense.

	Allstate/CUNA

	The Allstate/CUNA senior unsecured note is an obligation of Energy West. Interest expense from the senior unsecured note was $800,800 for the years ended December 31, 2013 and 2012, respectively.

	Sun Life

	The Sun Life fixed rate note is a joint obligation of the Company, NEO, Orwell and Brainard, and is guaranteed by the Company, Lightning Pipeline and Great Plains. This note received approval from the PUCO on March 30, 2011. The note is governed by a note purchase agreement. Prepayment of this note prior to maturity is subject to a 50 basis point make-whole premium. For the years ended December 31, 2013 and 2012, interest expense related to the fixed rate note was $824,969 for each year.

	The Sun Life floating rate note is an obligation of Great Plains and is guaranteed by the Company. Pricing for this note will reset on a quarterly basis to the then current yield of three month Libor. Prepayment of this note prior to maturity is at par. For the years ended December 31, 2013 and 2012, the weighted average interest rate on the floating rate note was 4.13% and 4.31% respectively resulting in $123,850 and $129,200 of interest expense.



	The Sun Life senior secured guaranteed note is a joint obligation of NEO, Orwell, and Brainard and is guaranteed by the Company’s non-regulated Ohio subsidiaries. For the years ended December 31, 2013 and 2012, interest expense from the senior secured guaranteed note was $123,007 and $23,576, respectively.

	The following table shows the aggregate future maturities of the Company’s notes payable.



	Years Ending
	2014	$	3,502,190
	2015		500,000
	2016		500,000
	2017		39,198,552
	2018		-
	Thereafter		-

Total		43,700,742


Debt Covenants

Bank of America

The Bank of America revolving credit agreement and term loan contain various covenants, which requires that Energy West and its subsidiaries maintain compliance with a number of financial covenants, including a limitation on investments in another entity by acquisition of any debt or equity securities or assets or by making loans or advances to such entity. In addition, Energy West must maintain a total debt to total capital ratio of not more than .55-to-1.00 and an interest coverage ratio of no less than 2.0-to-1.0. The credit facility restricted Energy West’s ability to create, incur or assume indebtedness except (i) indebtedness under the credit facility (ii) indebtedness incurred under certain capitalized leases including the capital lease related to the Loring pipeline, and purchase money obligations not to exceed $500,000, (iii) certain indebtedness of Energy West’s subsidiaries, (iv) certain subordinated indebtedness, (v) certain hedging obligations and (vi) other indebtedness not to exceed $1.0 million.

In addition, the Bank of America revolving credit agreement and term loan also restricts Energy West’s ability to pay dividends and make distributions, redemptions and repurchases of stock during any 60-month period to 80% of its net income over that period. In addition, no event of default may exist at the time such dividend, distribution, redemption or repurchase is made. Energy West is also prohibited from consummating a merger or consolidation or selling all or substantially all of its assets or stock except for (i) any merger consolidation or sale by or with certain of its subsidiaries, (ii) any such purchase or other acquisition by Energy West or certain of its subsidiaries and (iii) sales and dispositions of assets for at least fair market value so long as the net book value of all assets sold or otherwise disposed of in any fiscal year does not exceed 5% of the net book value of Energy West’s assets as of the last day of the preceding fiscal year.

Allstate/CUNA

The Allstate/CUNA senior unsecured notes contain various covenants, including a limitation on Energy West’s total dividends and distributions made in the immediately preceding 60-month period to 100% of aggregate consolidated net income for such period. The notes restrict Energy West from incurring additional senior indebtedness in excess of 65% of capitalization at any time and require Energy West to maintain an interest coverage ratio of more than 150% of the pro forma annual interest charges on a consolidated basis in two of the three preceding fiscal years.



Sun Life

The Sun Life covenants restrict certain cash balances and require two main types of debt service reserve accounts to be maintained to cover approximately one year of interest payments. The total balance in the debt service reserve accounts was $1.1 million and $1.1 million at December 31, 2013 and 2012, respectively, and is included in restricted cash on the Company’s Consolidated Balance Sheets. The debt service reserve accounts cannot be used for operating cash needs. In addition, the Company was required to maintain a $750,000 reserve account where Sun Life was the beneficiary. In July 2013, this additional reserve account requirement was lifted and the cash became unrestricted.

The covenants also provide that any cash dividends, distributions, redemptions or repurchases of common stock may be made by the obligors to the holding company only if (i) the aggregate amount of all such dividends, distributions, redemptions and repurchases for the fiscal year do not exceed 70% of net income of the obligors for the four fiscal quarters then ending determined as of the end of each fiscal quarter, and (ii) there exists no other event of default at the time the dividend, distribution, redemption or repurchase is made. The inability of the obligors to pay a dividend to the holding company may impact the Company’s ability to pay a dividend to shareholders.

The obligors are also prohibited from creating, assuming or incurring additional indebtedness except for (i) obligations under certain financing agreements, (ii) indebtedness incurred under certain capitalized leases and purchase money obligations not to exceed $500,000 at any one time outstanding, (iii) indebtedness outstanding as of March 31, 2011, (iv) certain unsecured intercompany indebtedness and (v) certain other indebtedness permitted under the notes.

The covenants require, on a consolidated basis, an interest coverage ratio of at least 2.0 to 1.0, measured quarterly on a trailing four quarter basis. The notes generally define the interest coverage ratio as the ratio of EBITDA to gross interest expense. The note defines EBITDA as net income plus the sum of interest expense, any provision for federal, state, and local taxes, depreciation, and amortization determined on a consolidated basis in accordance with GAAP, but excluding any extraordinary non-operating income or loss and any gain or loss from non-operating transactions. The interest coverage ratio is measured with respect to the Obligors on a consolidated basis and also with respect to the Company and all of its subsidiaries on a consolidated basis. The notes also require that the Company does not permit indebtedness to exceed 60% of capitalization at any time. Like the interest coverage ratio, the ratio of debt to capitalization is measured on a consolidated basis for the Obligors and again on a consolidated basis with respect to the Company and all of its subsidiaries.

The notes prohibit the Company from selling or otherwise transferring assets except in the ordinary course of business and to the extent such sales or transfers, in the aggregate, over each rolling twelve month period, do not exceed 1% of our total assets. The Company received consent from Sun Life, under its covenant restrictions, approving the sale of Independence prior to the finalization of the transaction. Generally, the Company may consummate a merger or consolidation if there is no event of default and the provisions of the notes are assumed by the surviving or continuing corporation. The Company is also generally limited in making acquisitions in excess of 10% of our total assets.

An event of default, if not cured or waived, would require the Company to immediately pay the outstanding principal balance of the notes as well as any and all interest and other payments due. An event of default would also entitle Sun Life to exercise certain rights with respect to any collateral that secures the indebtedness incurred under the notes.

The Company believes it is in compliance with all of the covenants under its debt agreements.

Stockholders_Equity

Stockholders' Equity

12 Months Ended

Dec. 31, 2013

Equity [Abstract]

Stockholders' Equity

Note 12 – Stockholders’ Equity

Share Repurchase Plan

The Company’s common stock trades on the NYSE Amex Equities under the symbol “EGAS.”

The Board of Directors approved a stock repurchase plan whereby the Company has the ability to buy back up to 448,500 shares of the Company’s common stock. There was no share repurchase activity during the years ended December 31, 2013 and 2012.

Stock Compensation

2002 Stock Option Plan

The Energy West Incorporated 2002 Stock Option Plan expired on October 4, 2012 and provided for the issuance of up to 300,000 options to purchase the Company’s common stock to be issued to certain key employees. As of December 31, 2013 and 2012, there were 5,000 and 35,000 options outstanding, respectively. Pursuant to the plan, the options vest over four to five years and are exercisable over a five to ten-year period from date of issuance.

The fair value of each option grant was estimated on the grant date using the Black-Scholes option pricing model. No options were granted under this plan during the years ended December 31, 2013 and 2012.

2012 Incentive and Equity Award Plan

The 2012 Incentive and Equity Award Plan provides for the grant of options, restricted stock, performance awards, other stock-based awards and cash awards to certain eligible employees. The number of shares authorized for issuance under the plan is 500,000. Under the plan, the option price may not be less than 100% of the fair market value on the date of grant and the options may be exercisable up to a ten year period after the date of grant (five years in the case of an incentive stock option granted to a holder of 10% of the Company’s shares of common stock). Under the plan, awards tied to performance goals will be subject to a one-year minimum performance measurement period. As of December 31, 2013, no awards had been granted under the plan.

2012 Non-Employee Director Stock Award Plan

The 2012 Non-Employee Director Stock Award Plan allows each non-employee director to receive his or her fees in shares of the Company’s common stock by providing written notice to the Company. Under the plan, the election to participate will remain in effect until it is revoked or modified in writing by the director. The number of shares authorized for issuance under the plan is 250,000. As of December 31, 2013, no awards had been granted under the plan.

A summary of the status of the outstanding stock options is as follows:

Number of

Weighted

Aggregate

Average

Intrinsic

Exercise Price

Value

Outstanding December 31, 2011

35,000

8.66

Granted

Exercised

Expired

Outstanding December 31, 2012

35,000

8.66

31,550

Granted

Exercised

(20,000)

7.98

Expired

(10,000)

10.15

Outstanding December 31, 2013

5,000

8.44

Exerciseable December 31, 2013

5,000

8.44

During the year ended December 31, 2013, 20,000 stock options were exercised in the amount of $159,500.

The following information applies to options outstanding at December 31, 2013:

Grant

Exercise

Number

Weighted

Number

Weighted

Date

Price

Outstanding

Average

Exercisable

Average

Exercise

Remaining

Exercise

Price

Contractual

Price

Life

(Years)

6/3/09

$8.44

5,000

$8.44

0.42

5,000

$8.44

5,000

During the years ended December 31, 2013 and 2012, the Company recorded $3,231 and $9,406, respectively ($2,032 and $5,832, net of tax, respectively), of stock-based compensation expense. As of December 31, 2013 and 2012, there was $0 and $3,231 of total unrecognized compensation cost related to stock-based compensation, respectively.

Restrictions on Dividends

The Company’s subsidiaries are subject to several restrictions on the amounts that they can distribute to the holding company. In addition to the debt covenants discussed in Note 11 – Credit Facilities and Long-Term Debt, each of the Maine Public Service Commission, the Montana Public Service Commission, the North Carolina Utilities Commission and the Wyoming Public Service Commission have ring fencing provisions over the subsidiary companies in their jurisdiction. The ring fencing provisions and debt covenants act to limit the dividends and distributions of the various subsidiaries to the holding company, which limit the funds available to be paid as dividends to the Company’s shareholders.

The most limiting of the restrictions placed on the Company’s subsidiaries is the Sun Life debt covenant restriction on distributions which limits distributions to the Company to 70% of net income of the obligors for the four fiscal quarters then ending.

The total restricted net assets of consolidated subsidiaries related to the Company’s debt covenants and ring fencing restrictions is $80,331,499, which accounts for 82.4% of Gas Natural Inc.’s net assets of $97,479,775 at December 31, 2013.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
Employee Benefit Plans	Dec. 31, 2013
Compensation And Retirement Disclosure [Abstract]	'
Employee Benefit Plans	'
	Note 13 – Employee Benefit Plans
	The Company has a defined contribution plan (the “401k Plan”) which covers substantially all of its employees. The plan provides for an annual contribution of 3% of salaries, with a discretionary contribution of up to an additional 3%. The expense related to the 401k Plan for the years ended December 31, 2013 and 2012 was $382,400 and $362,160, respectively.
	The Company makes matching contributions in the form of Company common stock equal to 10% of each participant’s elective deferrals in the 401k Plan. The Company contributed shares of common stock valued at $57,590 and $52,719 for the years ended December 31, 2013 and 2012, respectively. In addition, a portion of the 401k Plan consists of an Employee Stock Ownership Plan (“ESOP”) that covers most employees. The ESOP receives contributions of common stock from the Company each year as determined by the Board of Directors. The contribution is recorded based on the current market price of the Company’s common stock. The Company made no contributions for the years ended December 31, 2013 and 2012.
	The Company has sponsored a defined postretirement health benefit plan (the “Retiree Health Plan”) providing health and life insurance benefits to eligible retirees. The Plan pays eligible retirees (post-65 years of age) up to $125 per month in lieu of contracting for health and life insurance benefits. The amount of this payment is fixed and will not increase with medical trends or inflation. In addition, the Retiree Health Plan allows retirees between the ages of 60 and 65 and their spouses to remain on the same medical plan as active employees by contributing 125% of the current COBRA rate to retain this coverage. The amounts paid in excess of the current COBRA rate is held in a VEBA trust account, and benefits for this plan are paid from assets held in the VEBA Trust account. The Company discontinued contributions in 2006 and is no longer required to fund the Retiree Health Plan. As of December 31, 2013 and 2012, the value of plan assets was $155,750 and $163,313, respectively. The assets remaining in the trust will be used to fund the plan until these assets are exhausted.

Income_Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'

	Note 14 – Income Taxes

	Significant components of the deferred tax assets and liabilities are as follows:



			December 31,
			2013					2012
			Current			Long-term		Current		Long-term
	Deferred tax assets:
	Allowance for doubtful accounts		$	724,534		$	-	$	524,677	$	-
	Contributions in aid of construction			-			1,652,760		-		742,152
	Other nondeductible accruals			47,484			-		66,278		-
	Recoverable purchase gas costs			60,903			-		434,995		-
	Net operating loss carryforwards			-			7,733,763		-		5,439,748
	Property tax			154,146			-		-		153,967
	Other			754,235			-		709,778		595,918


	Total deferred tax assets			1,741,302			9,386,523		1,735,728		6,931,785

	Deferred tax liabilities:
	Recoverable purchase gas costs			454,795			-		867,075		-
	Property, plant and equipment			-			11,402,464		-		6,962,154
	Unrealized gain on securities available for sale			61,475			-		39,923		-
	Amortization of intangibles			-			539,498		-		418,181
	Other			-			800,698		-		519,814


	Total deferred tax liabilities			516,270			12,742,660		906,998		7,900,149


	Net deferred tax asset (liability) before valuation allowance			1,225,032			(3,356,137)		828,730		(968,930)
	Less: valuation allowance			-			(5,699,029)		-		(4,175,072)


	Total deferred tax asset (liability)			1,225,032			(9,055,166)		828,730		(5,144,002)
	Discontinued operations			-			-		(14,884)		547,373

	Net deferred tax asset (liability), continuing operations		$	1,225,032		$	(9,055,166)	$	813,846	$	(4,596,629)


	Income tax expense from continuing operations consists of the following:



			Year Ended December 31,
			2013			2012
	Current income tax expense (benefit):
	Federal		$	(344,342)		$	(150,224)
	State			120,753			245,483


	Total current income tax expense (benefit)			(223,589)			95,259

	Deferred income tax expense:
	Federal			3,692,413			2,030,525
	State			(200,217)			252,403


	Total deferred income tax expense			3,492,196			2,282,928


Total income taxes before credits			3,268,607			2,378,187
Investment tax credit, net			(21,062)			(21,062)

Total income tax expense			3,247,545			2,357,125
Discontinued operations			144,353			293,444


Income tax expense from continuing operations		$	3,391,898		$	2,650,569




Income tax position differs from the amount computed by applying the Federal statutory rate to pre-tax income from continuing operations as demonstrated in the table below:



		Year Ended December 31,
		2013			2012
Tax expense at statutory rate of 34%		$	3,372,404		$	2,065,991
State income tax, net of federal tax expense			348,151			228,051
Amortization of deferred investment tax credits			(21,062)			(21,062)
Change in valuation allowance			(237,557)			(262,343)
Permanent differences			134,583			140,211
State rate change			(346,149)			-
Other			(2,825)			206,277


Total income tax expense			3,247,545			2,357,125
Discontinued operations			144,353			293,444


Income tax expense from continuing operations		$	3,391,898		$	2,650,569


In 2013, due to the increasing disparity between the tax rates and rules for state income taxes in the states in which the Company operates, the Company changed from using a blended effective tax rate for all its subsidiaries to calculating an effective tax rate for each subsidiary based on each subsidiary’s taxable income and the applicable state tax. This resulted in a decrease in the state effective rate for most subsidiaries offset by an increased effective rate for subsidiaries with operations in North Carolina and Kentucky, with the resulting tax benefit of $336,007 as noted on the “State rate change” line item above. The Company’s Frontier Utilities subsidiary operates in North Carolina and had gross deferred tax assets and net operating losses from the acquisition of Frontier Utilities in 2007 totaling $98.0 million, offset by a 100% valuation allowance of equal amount. Applying the increased effective rate for North Carolina caused an increase in deferred tax assets of $1,970,586 offset by an increase in the corresponding valuation allowance of the same amount. After including the effect of offsetting decreases from other states, the net increase to expense from applying the separate subsidiary effective rates to the valuation allowance is $1,761,514. Combining the ($237,557) from the “Change in valuation allowance” line item above, results in total expense from the change in valuation allowance of $1,523,957.

The Company has approximately $10.2 million in federal net operating loss carryovers as of December 31, 2013. The net operating losses begin to expire in 2024. Due to acquisitions and changes in ownership, these net operating loss carryovers are subject to Section 382 of the Internal Revenue Code. The Company has placed a valuation allowance of $96,000 on the portion relating to its acquisition of Cut Bank Gas in 2009. The Company has approximately $66.8 million of state net operating loss carryovers as of December 31, 2013. The Company has recorded a state deferred tax asset valuation allowance of $3.9 million against the state net operating loss carryover. In addition, the Company has approximately $26.8 million of carryover tax basis as of December 31, 2013. The Company has recorded a state deferred tax asset valuation allowance of $1.7 million related to the carryover tax basis of the subsidiaries, since the carryover tax basis is subject to Section 382 of the Internal Revenue Code. Management has concluded that the realization of these state deferred tax assets do not meet the “more-likely-than-not” requirements of ASC 740.

In assessing the ability to realize the deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future results of operations, and tax planning strategies in making this assessment.



The Company adopted the applicable provisions of ASC 740 to recognize, measure, and disclose uncertain tax positions in the financial statements. Under ASC 740, tax positions must meet a “more-likely-than-not” recognition threshold at the effective date to be recognized upon the adoption and in subsequent periods. During the years ended December 31, 2013 and 2012, no adjustments were recognized for uncertain tax benefits.

The tax years after 2009 remain open to examination by the major taxing jurisdictions in which the Company operates, although no material changes to unrecognized tax positions are expected within the next twelve months.

During 2012, the Company filed Form 3115 with the Internal Revenue Service for an application for change in accounting method for customer recoveries in Ohio due to rate changes. This application has subsequently been approved by the IRS. Under the Company’s prior method of accounting for customer recoveries in Ohio, income was recognized before the “all events test” for income had been satisfied. At the point at which we were recognizing such income, we did not have a fixed right to such income. In our application, we proposed to apply the “all events test” for income to customer recoveries, such that income will now be recognized in connection with such item only when it has a fixed right to receive such income, and the amount can be determined with reasonable accuracy.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'

	Note 15 – Related Party Transactions

	The Company is party to certain agreements and transactions with Richard M. Osborne, the Company’s chairman and chief executive officer; companies owned or controlled by Richard M. Osborne; and other members of the Company’s management.

	Acquisition of 8500 Station Street

	On March 5, 2013, the Company purchased the Matchworks building in Mentor, Ohio for $1.9 million from McKay Real Estate Corporation, Matchworks, LLC, and Nathan Properties, LLC (collectively, the “Sellers”) by and through Mark E. Dottore as Receiver in the United States District Court. The Sellers are entities owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer. The acquisition of the Matchworks Building was approved by the independent members of the Company’s board of directors. See Note 3 – Acquisitions for details regarding this transaction.

	Acquisition of John D. Oil and Gas Marketing

	On June 1, 2013, the Company and its wholly-owned Ohio subsidiary, GNR, completed the acquisition of substantially all of the assets and certain liabilities of JDOG Marketing, an Ohio company engaged in the marketing of natural gas. The Osborne Trust is the majority owner of JDOG Marketing. Richard M. Osborne, the Company’s chairman and chief executive officer, is the sole trustee of the Osborne Trust. The acquisition of JDOG Marketing was approved by the independent members of the Company’s board of directors and the Company’s shareholders. See Note 3 – Acquisitions for details regarding this transaction.

	Notes Receivable

	The Company had a note receivable due from JDOG Marketing, a company controlled by Richard M. Osborne, the Company’s chairman and chief executive officer. In connection with the acquisition of JDOG Marketing, the Company assumed the corresponding liability of this note, effectively settling the note at the close of the acquisition. The balance due at December 31, 2012 related to this note was $35,409, of which $10,998 was due within one year. See Note 3 – Acquisitions for details regarding the JDOG Marketing acquisition.



	The Company has a note receivable from one of its employees with an annual interest rate of 4%. Monthly payments are based on a 30 year amortization schedule with a balloon payment no later than December 1, 2017. As of December 31, 2013, the principal balance due was $95,665 of which $1,938 is due within one year.

	Lease Agreements

	The Company had an agreement to lease a pipeline from JDOG Marketing through December 31, 2016. This pipeline and corresponding lease were acquired by the Company in the acquisition of JDOG Marketing. Lease expense resulting from this agreement was $5,500 and $13,200 for the years ended December 31, 2013 and 2012, respectively. These amounts are included in the Natural Gas Purchased column below. There was no balance due at December 31, 2013 or 2012 to JDOG Marketing related to these lease payments. See Note 3 – Acquisitions for details regarding the JDOG Marketing acquisition.

	On October 7, 2013, 8500 Station Street entered into a lease agreement with OsAir, Inc. (“OsAir”), an entity owned and controlled by Richard M. Osborne, the Company’s chairman and chief executive officer. Pursuant to the agreement, 8500 Station Street leases to OsAir approximately 6,472 square feet of office space located at 8500 Station Street, Mentor, Ohio 44060, at a rent of $5,500 per month for a period of three years starting from March 1, 2013. The lease agreement is not subject to renewal following the end of the term.

	On December 18, 2013, Orwell entered into a lease agreement with Cobra Pipeline Co., LLC (“Cobra”), an entity owned and controlled by Richard M. Osborne, the Company’s chairman and chief executive officer. Pursuant to the lease agreement, Cobra leases to Orwell approximately 2,400 square feet of warehouse space located at 2412 Newton Falls Rd., Newton Falls, OH 44444, at a rent of $2,000 per month for the time period commencing on December 18, 2013 and ending on February 29, 2016. Following the end of the initial term, the lease agreement will continue on a month-to-month basis until either party decides to terminate it upon 30 days’ advance written notice to the other party.

	Accounts Receivable and Accounts Payable

	The table below details amounts due from and due to related parties, including companies owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, at December 31, 2013 and 2012.



			Accounts Receivable						Accounts Payable
			December 31, 2013			December 31, 2012			December 31, 2013			December 31, 2012
	John D. Oil and Gas Marketing		$	-		$	3,282		$	-		$	40,518
	Cobra Pipeline			131,208			21,698			76,909			-
	Orwell Trumbell Pipeline			-			90,385			122,693			-
	Great Plains Exploration			7,033			142,740			73,983			9
	Big Oats Oil Field Supply			4,945			769			179,447			11,270
	Kykuit Resources			-			98,037			-			-
	John D. Oil and Gas Company			91			-			82,188			-
	Sleepy Hollow Oil & Gas			-			143,697			-			-
	Other			2,948			21,949			24,713			-

	Total related party balances			146,225			522,557			559,933			51,797
	Less amounts included in discontinued operations			-			-			-			3,868

	Total related party balances included in continuing operations		$	146,225		$	522,557		$	559,933		$	47,929




	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, for the year ended December 31, 2013:



			Year Ended December 31, 2013
			Natural Gas			Pipeline			Rent, Supplies,			Natural Gas			Rental Income
			Purchases			Construction			Consulting and			Sales			and Other
						Purchases			Other Purchases						Sales
John D. Oil and Gas Marketing		$	951,120		$	-		$	16,599		$	5,470		$	-
Cobra Pipeline			842,620			263,574			20,000			157,834			381
Orwell Trumbell Pipeline			795,190			-			-			1,260			33,911
Great Plains Exploration			856,696			854			1,341			9,310			47,640
Big Oats Oil Field Supply			-			2,967,705			624,147			3,996			5,125
John D. Oil and Gas Company			911,507			5,975			-			572			29,356
OsAir			241,693			13,200			91,850			4,866			72,787
Other			86,987			853			44,334			20,054			45,299

Total		$	4,685,813		$	3,252,161		$	798,271		$	203,362		$	234,499


The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, for the year ended December 31, 2012:



		Year Ended December 31, 2012
		Natural Gas			Pipeline			Rent, Supplies,			Natural Gas			Rental Income
		Purchases			Construction			Consulting and			Sales			and Other
					Purchases			Other Purchases						Sales
John D. Oil and Gas Marketing		$	2,405,158		$	9,870		$	58,043		$	-		$	13,128
Cobra Pipeline			389,233			5,390			5,104			-			23,210
Orwell Trumbell Pipeline			526,785			132			19,547			26,519			4,785
Great Plains Exploration			506,503			-			-			7,068			10,643
Big Oats Oil Field Supply			-			1,231,921			256,607			2,131			7,068
John D. Oil and Gas Company			502,897			-			-			575			-
Sleepy Hollow Oil & Gas			-			-			-			-			5,113
OsAir			248,588			-			196,451			2,479			306
Other			135,927			-			127,171			28,777			411

Total		$	4,715,091		$	1,247,313		$	662,923		$	67,549		$	64,664


The Company also accrued a liability of $0 and $595,240 due to companies controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, for natural gas used through December 31, 2013 and 2012, respectively, which had not yet been invoiced. The related expense is included in the gas purchased line item in the accompanying statements of comprehensive income.

Richard M. Osborne, the Company’s chairman and chief executive officer, sold shares of common stock in which the Company incurred expenses of $309,432 and $274,213 for the years ended December 31, 2013 and 2012, respectively. These expenses are recorded in the accompanying income statement as stock sale expense.

Segments_of_Operations

Segments of Operations	12 Months Ended
Segments of Operations	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segments of Operations	'
	Note 16 – Segments of Operations
	The Company classifies its segments to provide investors with a view of the business through management’s eyes. The Company primarily separates its state regulated utility businesses from the non-regulated marketing and production business, and federally regulated pipeline business. See Note 4 – Discontinued Operations for more information regarding the Company’s previously reported Propane Operations segment. The Company has regulated utility businesses in the states of Kentucky, Maine, Montana, North Carolina, Ohio, Pennsylvania and Wyoming and these businesses are aggregated together to form the natural gas operations. Transactions between reportable segments are accounted for on an accrual basis, and eliminated prior to external financial reporting. Inter-company eliminations between segments consist primarily of gas sales from the marketing and production operations to the natural gas operations, inter-company accounts receivable and payable, equity, and subsidiary investments.

	The following tables set forth summarized financial information for the Company’s Natural Gas, Marketing and Production, Pipeline, and Corporate and Other operating segments.


	Year Ended December 31,
	2013
			Natural Gas			Marketing &			Pipeline			Corporate &			Consolidated
			Operations			Production			Operations			Other
						Operations						Operations

	OPERATING REVENUES		$	106,590,940		$	20,260,001		$	402,914		$	-		$	127,253,855
	Intersegment eliminations			(326,331)			(8,092,760)			-			-			(8,419,091)

	Total operating revenue			106,264,609			12,167,241			402,914			-			118,834,764

	COST OF SALES			61,563,103			18,145,625			-			-			79,708,728
	Intersegment eliminations			(326,331)			(8,092,760)			-			-			(8,419,091)

	Total cost of sales			61,236,772			10,052,865			-			-			71,289,637


	GROSS MARGIN			45,027,837			2,114,376			402,914			-			47,545,127

	OPERATING EXPENSES
	Distribution, general and administrative			21,476,833			801,305			105,249			1,192,431			23,575,818
	Maintenance			1,305,897			2,765			9,130			-			1,317,792
	Depreciation and amortization			5,603,639			456,790			62,061			12,670			6,135,160
	Accretion			125,130			50,844			-			-			175,974
	Unrealized holding gain			-			(1,565,000)			-			-			(1,565,000)
	Goodwill impairment			-			725,744			-			-			725,744
	Taxes other than income			3,910,335			28,113			40,507			24,513			4,003,468
	Intersegment eliminations			(13,744)			-			-			(84,090)			(97,834)

	Total operating expenses			32,408,090			500,561			216,947			1,145,524			34,271,122


	OPERATING INCOME (LOSS)			12,619,747			1,613,815			185,967			(1,145,524)			13,274,005

	Other income (expense)			804,989			151,168			-			(618,104)			338,053
	Interest expense			(2,881,218)			(142,031)			(25,877)			(129,480)			(3,178,606)

	Income (loss) before taxes			10,543,518			1,622,952			160,090			(1,893,108)			10,433,452

	Income tax benefit (expense)			(3,346,726)			(586,326)			(39,161)			580,315			(3,391,898)


	INCOME (LOSS) FROM CONTINUING OPERATIONS			7,196,792			1,036,626			120,929			(1,312,793)			7,041,554
	Discontinued operations, net of income tax			-			-			-			(370,275)			(370,275)


	NET INCOME (LOSS)		$	7,196,792		$	1,036,626		$	120,929		$	(1,683,068)		$	6,671,279


	Capital expenditures		$	23,825,593		$	217,201		$	3,186		$	57,809		$	24,103,789


	As of December 31, 2013
	Investment in unconsolidated affiliate		$	-		$	351,724		$	-		$	-		$	351,724


	Total assets		$	195,219,938		$	11,633,544		$	685,760		$	83,173,644		$	290,712,886
Intersegment eliminations			(53,670,915)			(3,678,311)			(28,100)			(29,591,945)			(86,969,271)

Total assets		$	141,549,023		$	7,955,233		$	657,660		$	53,581,699		$	203,743,615



Year Ended December 31, 2012
		Natural Gas			Marketing &			Pipeline			Corporate &			Consolidated
		Operations			Production			Operations			Other
					Operations						Operations
OPERATING REVENUES		$	81,630,788		$	13,417,723		$	401,933		$	-		$	95,450,444
Intersegment eliminations			(324,837)			(5,924,362)			-			-			(6,249,199)

Total operating revenue			81,305,951			7,493,361			401,933			-			89,201,245

COST OF SALES			42,810,640			11,877,518			-			-			54,688,158
Intersegment eliminations			(324,837)			(5,924,362)			-			-			(6,249,199)

Total cost of sales			42,485,803			5,953,156			-			-			48,438,959


GROSS MARGIN		$	38,820,148		$	1,540,205		$	401,933		$	-		$	40,762,286

OPERATING EXPENSES
Distribution, general and administrative			19,806,389			449,665			87,640			472,161			20,815,855
Maintenance			1,176,189			1,014			13,835			-			1,191,038
Depreciation and amortization			4,662,313			268,202			61,085			34,542			5,026,142
Accretion			113,106			48,192			-			-			161,298
Taxes other than income			3,366,238			38,052			35,497			39,110			3,478,897

Total operating expenses			29,124,235			805,125			198,057			545,813			30,673,230


OPERATING INCOME (LOSS)		$	9,695,913		$	735,080		$	203,876		$	(545,813)		$	10,089,056

Other income (expense)			418,822			(6,051)			-			(1,230,650)			(817,879)
Interest expense			(2,512,444)			(133,440)			(13,528)			(40,781)			(2,700,193)

Income (loss) before taxes			7,602,291			595,589			190,348			(1,817,244)			6,570,984

Income tax benefit (expense)			(3,135,445)			4,542			(97,523)			577,857			(2,650,569)


INCOME (LOSS) FROM CONTINUING OPERATIONS		$	4,466,846		$	600,131		$	92,825		$	(1,239,387)		$	3,920,415

Discontinued operations, net of income tax			-			-			-			(201,098)			(201,098)


NET INCOME (LOSS)		$	4,466,846		$	600,131		$	92,825		$	(1,440,485)		$	3,719,317


Capital expenditures		$	18,381,644		$	1,393,040		$	23,141		$	856,359		$	20,654,184

As of December 31, 2012
Investment in unconsolidated affiliate		$	-		$	321,731		$	-		$	-		$	321,731

Total assets		$	169,616,395		$	8,786,247		$	632,466		$	68,443,708		$	247,478,816
Intersegment eliminations			(46,338,335)			(447,549)			(16,073)			(26,213,400)			(73,015,357)

Total assets		$	123,278,060		$	8,338,698		$	616,393		$	42,230,308		$	174,463,459

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
Commitments and Contingencies	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Note 17 – Commitments and Contingencies
	Lease Commitments
	The following schedule presents the future minimum lease payments under the Company’s lease agreements as of December 31, 2013.
	Future Minimum Lease Payments


		Operating Leases		Capital Leases
	2014	$	253,833	$	300,000
	2015		229,711		300,000
	2016		125,906		300,000
	2017		121,080		300,000
	2018		120,633		300,000
	Thereafter		537,392		1,200,000

	Total minimum lease payments required	$	1,388,555		2,700,000

	Less: Interest portion				(659,492)

	Liability			$	2,040,508

	Operating Leases
	The Company leases certain properties including land, office buildings, and other equipment under non-cancelable operating leases. Lease expense resulting from operating leases for the years ended December 31, 2013 and 2012, totaled $304,783 and $537,097, respectively.
	Capital Leases
	During 2012, the Company entered into an agreement with USPF whereby it is leasing certain pipeline and pipeline easement assets. The agreement contains an initial term of sixteen years, with the option to renew for two additional sixteen year terms. The lease calls for future lease payments of $300,000 per year through 2022. The first annual installment is due and payable within a 30 day period beginning on the first anniversary of the commencement date, and each subsequent annual installment is due and payable within the applicable 30 day period commencing on each subsequent anniversary, subject to the right of the Company to defer a portion of each annual installment if chosen.
	The agreement calls for a $120,000 facility service fee to be paid by the Company each year within a 30 day period beginning on the first anniversary of the commencement date, as long as the leased assets remain in place on the property. Also included in the agreement is a throughput charge of $0.0125 per Mcf moved through the leased pipeline. There were no throughput charge payments made during 2013 or 2012. There was no facility service fees paid in 2013 or 2012.
	The cost basis and accumulated depreciation of assets recorded under capital leases, which are included in Property, Plant, and Equipment on the Consolidated Balance Sheets are as follows as of December 31, 2013 and 2012:


		December 31,
		2013		2012
	Gas transmission & distribution facilities		6,320,000		6,320,000

	Capital lease assets, gross		6,320,000		6,320,000
	Accumulated depreciation		(501,587)		(100,317)

	Capital lease assets, net		5,818,413		6,219,683


	Depreciation expense recorded in connection with assets under capital leases was $401,270 and $100,317 for the years ended December 31, 2013 and 2012, respectively.
	Long-term Contracts
	The Company has a long-term contract with Northwestern Energy for pipeline and storage capacity which commits the Company to purchase certain blocks of pipeline capacity through 2018 at the interconnect with the TransCanada pipeline. The Company has a companion contract with TransCanada for pipeline capacity of equal quantities and terms. These agreements are based on current tariff prices as specified in the contracts. Neither of these contracts have been recognized on the Company’s Consolidated Balance Sheets.
	The Company’s subsidiary, Bangor Gas, entered into an agreement with Maritimes and Northeast Pipeline for the transportation and storage of natural gas. This agreement has not been recognized on the Company’s Consolidated Balance Sheets.
	The Company guarantees the gas supply obligations of its subsidiaries for up to $6.0 million of amounts purchased.
	The future obligations under these pipeline, storage and gas purchase agreements at December 31, 2013 are as follows:
	Future Minimum Long-term Contract Obligations


		Northwestern		Trans-Canada		Maritimes and
		Energy		Trans-Canada		Northeast Pipeline
	2014	$	1,517,892	$	921,977	$	575,622
	2015		1,434,680		829,775		357,042
	2016		519,356		368,768		357,042
	2017		519,356		368,768		357,042
	2018		476,076		338,036		357,042
	Thereafter		-		-		357,042

	Total	$	4,467,360	$	2,827,324	$	2,360,832

	Environmental Contingency
	Included as part of our acquisition of Independence in 2011, the Company identified a piece of property that encountered a diesel fuel spill and required environmental cleanup. This property is currently used as a storage facility for the diesel fuel and propane that is utilized in daily operations. The Company has completed the voluntary remediation of the soil contaminants at the property and continues to monitor the site for additional contamination.
	Approximately $24,000 and $25,000 was voluntarily incurred to evaluate and remediate the site during 2013 and 2012, respectively. The Company expects on-going monitoring and monitoring system removal costs for 2014 of approximately $7,000 if the site tests negative for further contaminants. If the property test positive for contamination, further voluntary remediation in 2014 could cost the Company up to a total of approximately $23,000. The Company will expense these voluntary remediation costs as incurred.
	Legal Proceedings
	From time to time, the Company is involved in lawsuits that have arisen in the ordinary course of business. The Company is contesting each of these lawsuits vigorously and believes it has defenses to the allegations that have been made.

Shareholder Suits
Beginning on December 10, 2013, five putative shareholder derivative lawsuits were filed by five different individuals, in their capacity as shareholders of Gas Natural, in the United States District Court for the Northern District of Ohio, purportedly on behalf of Gas Natural and naming certain of our current and former executive officers and directors as individual defendants. These five shareholder lawsuits are captioned as follows: (1) Richard J. Wickham v. Richard M. Osborne, et al., (Case No. 1:13-cv-02718-LW); (2) John Durgerian v. Richard M. Osborne, et al., (Case No. 1:13-cv-02805-LW); (3) Joseph Ferrigno v. Richard M. Osborne, et al., (Case No. 1:13-cv-02822-LW); (4) Kyle Warner v. Richard M. Osborne, et al., (Case No. 1:14-cv-00007-LW) and (5) Gary F. Peters v. Richard M. Osborne, (Case No. 1:14-cv-0026-CAB).
Each lawsuit contains claims against various current or former directors or officers of the Company alleging, among other things, violations of federal securities laws, breaches of fiduciary duty, waste of corporate assets, unjust enrichment and insider selling arising primarily out of the Company’s acquisition of the Ohio utilities, services provided by JDOG Marketing and the acquisition of JDOG Marketing and the sale of the Company’s common stock by Richard M. Osborne, the Company’s chairman and chief executive officer, and Thomas J. Smith, our chief financial officer. The suits seek the recovery of unspecified damages allegedly sustained by Gas Natural, which is named as a nominal defendant, corporate reforms, disgorgement, restitution, the recovery of plaintiffs’ attorney’s fees, rescission of the acquisition of the Ohio utilities and John D. Marketing and other relief.
On February 6, 2014, the five lawsuits were consolidated solely for purposes of conducting limited pretrial discovery, and on February 21, 2014, the Court appointed lead counsel for all five lawsuits. No formal discovery has been conducted to date.
At this time the Company is unable to provide an estimate of any possible future losses that it may incur in connection to this suit. The Company carries insurance that it believes will cover any negative outcome associated with this case. This insurance carries a $250,000 deductible which the Company will be responsible for paying before any losses will be covered.
Harrington Employment Suit
On February 25, 2013, one of the Company’s former officers, Jonathan Harrington, filed a lawsuit captioned “Jonathan Harrington v. Energy West, Inc. and Does 1-4,” Case No. DDV-13-159 in the Montana Eighth Judicial District Court, Cascade County. Mr. Harrington claims that he was terminated in violation of Montana statute requiring just cause for termination. In addition, he alleges claims for negligent infliction of emotional distress and negligent slander. Mr. Harrington is seeking relief for economic loss, including lost wages and fringe benefits for a period of at least four years from the date of discharge, together with interest. Mr. Harrington is an Ohio resident and was employed in the Company’s Ohio corporate offices. On March 20, 2013, the Company filed a motion to dismiss the lawsuit on the basis that Mr. Harrington was an Ohio employee, not a Montana employee, and therefore the statute does not apply. The motion has been fully briefed but has not been ruled on by the Court. Likewise, Mr. Harrington has requested oral argument but the Court has not indicated whether such request will be granted. The Company believes his claims under Montana law are without merit, and intends to vigorously defend this case on all grounds.
PUCO Audits
The Company accounts for purchased gas costs in accordance with procedures authorized by the utility commissions in the states in which it operates. Purchased gas costs that are different from those provided for in present rates, and approved by the respective commission, are accumulated and recovered or credited through future rate changes. The GCRs are monitored closely by the regulatory commissions in all of the states in which the Company operates and are subject to periodic audits or other review processes. The PUCO retrospectively audits the Ohio utility companies’ purchases of natural gas on an annual basis. The purpose of this GCR audit is to reconcile the differences, if any, between the amount the companies paid for natural gas and the amount the companies’ customers paid for natural gas.
2010 NEO & Orwell Audits
During the year ended December 31, 2010, the PUCO conducted audits of NEO and Orwell’s GCRs as filed from September 2007 through August 2009 and January 2008 through June 2010, respectively. In connection with the audits, the PUCO found that NEO had under-recovered gas costs of approximately $1.1 million and Orwell had over-recovered gas costs of approximately $1.0 million. The collection and repayment of the under-recovery and over-recovery for NEO and Orwell began in February, 2012, respectively. These adjustments appeared on the accompanying Consolidated Balance Sheets as part of “recoverable cost of gas purchases” and “over-recovered gas purchases.” The remaining balance in NEO’s recoverable cost of gas purchases was $234,253.42 and $707,002 at December 31, 2013 and 2012, respectively. The remaining balance in Orwell’s over-recovered gas purchases was $0 and $237,175 at December 31, 2013 and 2012, respectively.
2011 Brainard Audit
During the year ended December 31, 2011, the PUCO conducted an audit of Brainard’s rates as filed from July 2009 through June 2011. The PUCO issued an order requiring that Brainard refund approximately $104,000 with interest over twelve months to its customers. The Company initiated the refund commencing in October 2012. These adjustments appear on the accompanying Consolidated Balance Sheets as part of “over-recovered gas purchases.” The remaining balance in Brainard’s over-recovered gas purchases are $0 and $99,479 at December 31, 2013 and 2012, respectively.
2012 NEO & Orwell Audits
On January 23, 2012, the PUCO directed its staff to examine the compliance of NEO and Orwell under the GCR mechanism. In a non-binding report to the PUCO in February 2013, its staff asserted that NEO could have purchased natural gas from local producers for less and recommended an adjustment to the GCR calculations that would result in a liability for NEO and Orwell to its customers.
In July 2013, after a hearing with the PUCO and its staff, the Company determined it was probable that the GCR adjustments recommended by the staff would be adopted by the PUCO and as a result the Company recorded these liabilities in its financial statements for the period ended June 30, 2013. Based on the PUCO staff’s calculations and management’s assessment, a $943,550 liability to its customers was recorded as the Company’s best estimate of the required adjustment to NEO’s GCR and a liability for Orwell to its customers of $251,081.
On November 13, 2013, the PUCO issued an Opinion and Order in the NEO and Orwell GCR cases; case numbers 12-209-GA-GCR and 12-212-GA-GCR. The Order concluded that adjustments to NEO and Orwell’s GCRs were appropriate in the amounts of $0.8 million and $0.2 million, respectively. These adjustments represent disallowed agent fees paid by NEO and Orwell to JDOG Marketing for natural gas procurement, disallowed processing and compression fees paid by NEO to Cobra for NEO’s natural gas supply being delivered through Cobra’s pipeline, and certain excess costs associated with local production gas purchased by NEO and Orwell from JDOG Marketing. Both JDOG Marketing and Cobra were companies controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, during the periods covered by these audits. The Company examined NEO and Orwell’s GCRs for the periods immediately following the companies’ audit periods through December 31, 2013. As a result, the Company calculates that a total liability to its NEO and Orwell customers to be in the range of $1.5 million to $1.9 million. As a result, the Company has accrued an additional $0.3 million to increase its initial estimated liability to $1.5 million. New information may cause the Company to materially change this estimate in future periods. This accrual is included on the accompanying Consolidated Statement of Comprehensive Income for the year-ended 2013 as part of the Cost of goods sold – Natural gas purchased line item and as a reduction of the Recoverable cost of gas purchases line item on the accompanying December 31, 2013 Consolidated Balance Sheet.
In addition to the GCR adjustments, the PUCO’s Opinion and Order concluded that an investigative audit of NEO, Orwell and all affiliated and related companies should be undertaken by an outside auditor. The costs associated with these audits will be the responsibility of the Company. The costs associated with such an audit cannot be estimated at this time and as such no amount has been accrued. These costs may prove to be material once known.
The Opinion and Order also imposed civil forfeitures of $26,000 and $50,000 for NEO and Orwell, respectively. These civil forfeitures were due to failure to terminate purchase contracts between JDOG Marketing and the companies as ordered by the PUCO in a 2010 order and for Orwell’s failure to have appropriate tariffs on file for services provided.
Trade Receivables
Included in the accounts receivable, trade line item on the accompanying Consolidated Balance Sheets are $1,059,224 and $1,139,778, net of allowance for doubtful accounts of $1,421,000 and $774,000 at December 31, 2013 and December 31, 2012, respectively, for amounts due to the Company by a large industrial customer that is currently under Chapter 11 bankruptcy protection. All but $178,546 of the amounts were incurred after the customer’s petition for bankruptcy was filed and the Company believes it will ultimately receive payment as the customer emerges from bankruptcy protection.

Subsequent_Events

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Note 18 – Subsequent Events
	The Company declared a dividend of $0.045 per share on January 30, 2014 that is payable to shareholders of record on February 14, 2014. There were 10,451,678 shares outstanding on February 14, 2014 resulting in a total dividend of $470,326 which was paid to shareholders on February 28, 2014.
	The Company declared a dividend of $0.045 per share on February 28, 2014 that is payable to shareholders of record on March 14, 2014. There were 10,451,678 shares outstanding on March 14, 2014 resulting in a total dividend of $470,326 which was paid to shareholders on March 31, 2014.
	The Company declared a dividend of $0.045 per share on March 26, 2014 that is payable to shareholders of record on April 15, 2014. There were 10,451,678 shares outstanding on April 15, 2014 resulting in a total dividend of $470,326 which will be paid to shareholders on April 30, 2014.

Summary_of_Business_Policies

Summary of Business (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Nature of Business	'
	Nature of Business
	Gas Natural Inc. (the “Company”) is the parent company of Brainard, Energy West, GNR, Independence, GNSC, Great Plains, Lightning Pipeline and PGC. Brainard is a natural gas utility company with operations in Ohio. Energy West is the parent company of multiple entities that are natural gas utility companies with regulated operations in Maine, Montana, North Carolina and Wyoming as well as non-regulated operations in Maine, Montana and Wyoming. GNR is a natural gas marketing company that markets gas in Ohio and Pennsylvania. GNSC manages gas procurement, transportation, and storage for Brainard and subsidiaries of Lightning Pipeline and Great Plains. Great Plains is the parent company of NEO, a regulated natural gas distribution company with operations in Ohio. NEO is the parent company of 8500 Station Street, a property management company responsible for the Company’s headquarters building, and Kidron, a small natural gas well company in Ohio. Lightning Pipeline is the parent company of Orwell, a regulated natural gas distribution company with operations in Ohio, and Spelman, a natural gas pipeline company in Ohio and Kentucky. Clarion River and Walker Gas are divisions of Orwell and are regulated natural gas distribution companies with operations in Pennsylvania. PGC is a regulated natural gas distribution company in Kentucky. The Company currently has four reporting segments:


	• Natural Gas Operations	Annually distribute approximately 36 Bcf of natural gas to approximately 72,000 customers through regulated utilities operating in Kentucky, Maine, Montana, North Carolina, Ohio, Pennsylvania and Wyoming.

	• Marketing and Production Operations	Annually markets approximately 1.5 Bcf of natural gas to commercial and industrial customers in Montana, Wyoming, Ohio, and Pennsylvania through our EWR and GNR subsidiaries. Our EWR subsidiary also manages midstream supply and production assets for transportation customers and utilities. EWR owns an average 51% gross working interest (average 43% net revenue interest) in 160 natural gas producing wells and gas gathering assets located in Glacier and Toole Counties in Montana.

	• Pipeline Operations	The Shoshone interstate and Glacier gathering natural gas pipelines located in Montana and Wyoming are owned through the subsidiary, EWD. Certain natural gas producing wells owned by EWD are being managed and reported under the marketing and production operations.

	• Corporate and Other	Encompasses costs associated with business development and acquisitions, dispositions of subsidiary entities, results of discontinued operations, dividend income, recognized gains or losses from the sale of marketable securities, and activity from Lone Wolfe which serves as an insurance agent for the Company and other businesses in the energy industry.

	Energy West was originally incorporated in Montana in 1909 and was reorganized as a holding company in 2009 to facilitate future acquisitions and corporate-level financing to support the Company’s growth strategy. On July 9, 2010, the Company changed its name to Gas Natural Inc. and reincorporated from Montana to Ohio. Moving the incorporation to Ohio enhances the Company’s flexibility and provides a more efficient platform from which to operate and grow.
Basis of Presentation	'
	Basis of Presentation
	The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States. These principles are set by the FASB. The FASB sets GAAP to ensure the consistent reporting of the Company’s financial condition, results of operations and cash flows. References to GAAP issued by the FASB in these footnotes are to the FASB Accounting Standards Codification, sometimes referred to as the Codification or ASC.
Principles of Consolidation	'
	Principles of Consolidation
	The consolidated financial statements include the accounts and transactions of the Company and its wholly-owned subsidiaries as well as the proportionate share of assets, liabilities, revenues, and expenses of certain producing natural gas properties. All intercompany transactions and balances have been eliminated.
Reclassifications	'
	Reclassifications
	Certain reclassifications of prior year reported amounts have been made for comparative purposes. Such reclassifications are not considered material and had no effect on net income.
Effects of Regulation	'
	Effects of Regulation
	The Company follows the provisions of ASC 980—Regulated Operations and the accompanying financial statements reflect the effects of the different rate-making principles followed by the various jurisdictions regulating the Company. The economic effects of regulation can result in regulated companies recording costs that have been, or are expected to be, allowed in the rate-making process in a period different from the period in which the costs would be charged to expense by an unregulated enterprise. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses in the periods when those same amounts are reflected in rates. Additionally, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for amounts that are expected to be refunded to customers which are recorded as liabilities in the balance sheet (regulatory liabilities).
Use of Estimates	'
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.
	The Company has used estimates in measuring certain deferred charges and deferred credits related to items subject to approval of the various public service commissions with jurisdiction over the Company. Estimates are also used in determining amounts for the Company’s allowances for doubtful accounts, unbilled gas, asset retirement obligations, contingent consideration liability, and determination of depreciable lives of utility plant. The deferred tax asset and valuation allowance require a significant amount of judgment and are significant estimates. The estimates are based on projected future tax deductions, future taxable income, estimated limitations under the Internal Revenue Code, and other assumptions.
	The Company makes acquisitions which involve combining the assets and liabilities of the acquired company with our Company. The assets and liabilities acquired are reported at their fair value at the date of acquisition. Measuring this fair value may require the use of estimates.
	Such estimates could change in the near term and could significantly impact the Company’s results of operations and financial position.
Fair Value Measurements	'
	Fair Value Measurements
	For assets and liabilities measured at fair value, fair value is 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. Measuring fair value requires the use of market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, corroborated by market data, or generally unobservable. Valuation techniques are required to maximize the use of observable inputs and minimize the use of unobservable inputs.
Leases	'
	Leases
	Leases are categorized as either operating or capital leases at inception. Operating lease costs are recognized on a straight-line basis over the term of the lease. For capital leases, an asset and a corresponding liability are established for the present value at the beginning of the lease term of minimum lease payments during the lease term, excluding any executory costs. If the present value of the minimum lease payments exceeds the fair value of the leased property at lease inception, the amount measured initially as the asset and obligation shall be the fair value. The capital lease obligation is amortized over the life of the lease.
Revenue Recognition	'
	Revenue Recognition
	Revenues are recognized in the period that services are provided or products are delivered. The Company records gas distribution revenues for gas delivered to residential and commercial customers but not billed at the end of the accounting period. The Company periodically collects revenues subject to possible refunds pending final orders from regulatory agencies. When this occurs, appropriate liabilities for such revenues collected subject to refund are established.
Stock-Based Compensation	'
	Stock-Based Compensation
	The Company accounts for stock-based compensation arrangements by recognizing compensation costs for all stock-based awards over the respective service period for employee services received in exchange for an award of equity or equity-based compensation. The compensation cost is based on the fair value of the award on the date it was granted.
Income Taxes	'
	Income Taxes
	The Company files its income tax returns on a consolidated basis. Rate-regulated operations record cumulative increases in deferred taxes as income taxes recoverable from customers. The Company uses the deferral method to account for investment tax credits as required by regulatory commissions. Deferred income taxes are determined using the asset and liability method, under which deferred tax assets and liabilities are measured based upon the temporary differences between the financial statement and income tax bases of assets and liabilities, using current tax rates.
	Tax positions must meet a more-likely-than-not recognition threshold to be recognized. The Company has no unrecognized tax benefits that would have a material impact to the Company’s financial statements for any open tax years. No adjustments were recognized for uncertain tax positions for the years ended December 31, 2013 and 2012.
	The Company recognizes interest and penalties related to unrecognized tax benefits in operating expense. As of December 31, 2013 and 2012, there were no unrecognized tax benefits nor interest or penalties accrued related to unrecognized tax benefits. For the years ended December 31, 2013 and 2012, the Company did not recognize interest or penalties.
	The Company, or one or more of its subsidiaries, files income tax returns in the U.S. federal jurisdiction and various state jurisdictions. The tax years after 2009 for federal and state returns remain open to examination by the major taxing jurisdictions in which we operate.
Comprehensive Income	'
	Comprehensive Income
	Comprehensive income includes net income and other comprehensive income (loss), which for the Company is primarily comprised of unrealized holding gains or losses on available-for-sale securities. These gains or losses are excluded from the computing of net income and reported separately in shareholders’ equity as Accumulated other comprehensive income.
Earnings per Share	'
	Earnings per Share
	Basic earnings per share are computed by dividing net income by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the potential dilution from the exercise or conversion of outstanding stock options and restricted stock awards into common stock.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	The Company considers all highly liquid investments with original maturities of three months or less, at the date of acquisition, to be cash equivalents. The Company maintains, at various financial institutions, cash and cash equivalents which may exceed federally insurable limits and which may, at times, significantly exceed balance sheet amounts.
Marketable Securities	'
	Marketable Securities
	Securities investments that the Company has the positive intent and ability to hold to maturity are classified as held-to-maturity securities and recorded at amortized cost. Securities investments bought expressly for the purpose of selling in the near term are classified as trading securities and are measured at fair value with unrealized gains and losses reported in earnings. Securities investments not classified as either held-to-maturity or trading securities are classified as available-for-sale securities. Available-for-sale securities are recorded at fair value in marketable securities in the accompanying Consolidated Balance Sheets, with the change in fair value during the period excluded from earnings and recorded net of tax as a component of other comprehensive income. Realized gains and losses, and declines in value judged to be other than temporary, are recorded in the accompanying Consolidated Statement of Comprehensive Income.
Receivables	'
	Receivables
	The accounts receivable are generated from sales and delivery of natural gas and propane as measured by inputs from meter reading devices. Trade accounts receivable are carried at the expected net realizable value. There is credit risk associated with the collection of these receivables. As such, a provision is recorded for the receivables considered to be uncollectible. The provision is based on management’s assessment of the collectability of specific customer accounts, the aging of the accounts receivable and historical write-off amounts. The underlying assumptions used for the provision can change from period to period and the provision could potentially cause a negative material impact to the income statement and working capital.
	Two of the Company’s utilities in Ohio, Orwell and NEO collect from their customers, through rates, an amount to provide an allowance for doubtful accounts. As accounts are identified as uncollectible, they are written off against this allowance for doubtful accounts with no income statement impact. In effect, all bad debt expense is funded by the customer base. The total amount collected from customers and the amounts written off are reviewed annually by the PUCO and the rate per Mcf is adjusted as necessary.
	The Company’s bad debt expense for the years ended December 31, 2013 and 2012 was $797,867 and $958,561, respectively. The Company wrote-off $161,674 and $213,855 for the years ended December 31, 2013 and 2012, respectively.
Natural Gas Inventory	'
	Natural Gas Inventory
	Natural gas inventory is stated at the lower of weighted average cost or net realizable value except for Energy West Montana – Great Falls, which is stated at the rate approved by the MPSC, which includes transportation and storage costs.
Recoverable/Refundable Costs of Gas Purchases	'
	Recoverable/Refundable Costs of Gas Purchases
	The Company accounts for purchased gas costs in accordance with procedures authorized by the utility commissions in the states in which it operates. Purchased gas costs that are different from those provided for in present rates, and approved by the respective commission, are accumulated and recovered or credited through future rate changes. The gas cost recoveries are monitored closely by the regulatory commissions in all of the states in which the Company operates and are subject to periodic audits or other review processes.
Property, Plant and Equipment	'
	Property, Plant and Equipment
	Property, plant and equipment are recorded at original cost when placed in service. Depreciation and amortization on assets are generally recorded on a straight-line basis over the estimated useful lives, as applicable, at various rates. These assets are depreciated and amortized over three to forty years.
	EWR owns an interest in certain producing natural gas reserves on properties located in northern Montana. EWD also owns an interest in certain natural gas producing properties located in northern Montana. The Company is depleting these reserves using the units-of-production method. The production activities are being accounted for using the successful efforts method. The Company is not the operator of any of the natural gas producing wells on these properties and the Company is not regarded as having significant oil- and gas-producing activities as defined by ASC 932 – Extractive Activities – Oil and Gas. Therefore, the disclosures defined in ASC 932 have been omitted.
Contributions in Aid of and Advances Received for Construction	'
	Contributions in Aid of and Advances Received for Construction
	Contributions in aid of construction are contributions received from customers for construction that are not refundable and are amortized over the life of the assets. Customer advances for construction includes advances received from customers for construction that are to be refunded wholly or in part.
Goodwill and Other Intangible Assets	'
	Goodwill and Other Intangible Assets
	Goodwill represents the excess of the purchase price over the fair value of identifiable net tangible and intangible assets acquired in a business combination. Goodwill is not amortized, rather, the goodwill is required to be tested for impairment annually, which the Company performs in the fourth quarter, or if events or changes in circumstances indicate that goodwill may be impaired. The Company tests for goodwill impairment using a two-step approach. A recoverability test at the reporting unit level must be performed during the first step. If the asset is not recoverable, the second step calculates the impairment loss, if any.
	The Company recognizes an acquired intangible apart from goodwill whenever the intangible arises from contractual or other legal rights, or whenever it can be separated or divided from the acquired entity and sold, transferred, licensed, rented or exchanged, either individually or in combination with a related contract, asset or liability. Such intangibles are amortized on a straight-line basis over their estimated useful lives unless the estimated useful life is determined to be indefinite. Accumulated amortization for Customer relationships was approximately $254,667 at December 31, 2013. Amortization expense for Customer relationships for the year ended December 31, 2013 was approximately $186,167.
Regulatory Assets and Liabilities	'
	Regulatory Assets and Liabilities
	The regulatory asset for property tax is recovered in rates over a ten-year period starting January 1, 2004. The income taxes earn a return equal to that of the Company’s rate base. The rate case costs do not earn a return. Regulatory assets will be recovered over a period of approximately three to twenty years. Regulatory liabilities will be refunded over a period of approximately five to twenty years.
Debt Issuance Costs	'
	Debt Issuance Costs
	Debt issuance costs are fees and other direct incremental costs incurred by the Company in obtaining debt financing and are recognized as assets and amortized as interest expense over the term of the related debt.
Investment in Unconsolidated Affiliate	'
	Investment in Unconsolidated Affiliate
	EWR owns a 24.5% interest in Kykuit, a developer and operator of oil, gas and mineral leasehold estates located in Montana. The Company is accounting for the investment in Kykuit using the equity method. The Company has invested approximately $2.2 million in Kykuit and may invest additional funds in the future as Kykuit could provide a supply of natural gas in close proximity to our natural gas operations in Montana. However, our obligations to make additional investments in Kykuit are limited under our agreement with the other Kykuit investors. At December 31, 2013, we are obligated to invest no more than an additional $0.1 million over the life of the venture. Other investors in Kykuit include our chairman and chief executive officer, Richard M. Osborne, and John D. Oil and Gas Company, a publicly held gas exploration company, which is also the managing member of Kykuit. Additional investors include Thomas J. Smith, a director and our chief financial officer, and a director of John D. Oil and Gas Company, and Gregory J. Osborne, a director and chief operating officer and former president and director of John D. Oil and Gas Company.
Impairment of Long-Lived Assets	'
	Impairment of Long-Lived Assets
	The Company evaluates its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets or intangibles may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to future undiscounted net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment loss to be recognized is measured as the amount by which the carrying value of the assets exceeds their fair value. As of December 31, 2013 and 2012, management does not consider the value of any of its long-lived assets to be impaired.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	The Company records the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it was incurred or acquired. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement cost is included in “Property, plant and equipment, net” in the accompanying Consolidated Balance Sheets. The Company amortizes the amount added to property, plant, and equipment, net. The accretion of the asset retirement liability is allocated to operating expense using a systematic and rational method.
Derivatives and Hedging Activities	'
	Derivatives and Hedging Activities
	In order to mitigate the risk of natural gas market price volatility related to firm commitments to purchase or sell natural gas, from time to time the Company and its subsidiaries have entered into fixed contracts. Such arrangements may be used to protect profit margins on future obligations to deliver gas at a fixed price, or to protect against adverse effects of potential market price declines on future obligations to purchase gas at fixed prices.
	The Company accounts for these contracts in accordance with ASC 815, Derivatives and Hedging which states that unless these contracts qualify for treatment as a “normal purchase or normal sale,” they are to be reflected in the balance sheet as assets or liabilities at fair value as of the balance sheet date. Changes in these fair values are reported in the Consolidated Statement of Comprehensive Income.
	For the years ended December 31, 2013 and 2012, all of the Company’s fixed contracts for purchase or sale of gas at fixed prices and volumes qualified for treatment as a “normal purchase” or “normal sale”.
Recently Adopted Accounting Pronouncements	'
	Recently Adopted Accounting Pronouncements
	ASU No. 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities”
	In January 2013, the FASB issued ASU 2013-01, which clarifies which instruments and transactions are subject to the offsetting disclosure requirements established by ASU 2011-11. The new ASU addresses preparer concerns that the scope of the disclosure requirements under ASU 2011-11 was overly broad and imposed unintended costs that were not commensurate with estimated benefits to financial statement users. In choosing to narrow the scope of the offsetting disclosures, the FASB determined that it could make them more operable and cost effective for preparers while still giving financial statement users sufficient information to analyze the most significant presentation differences between financial statements prepared in accordance with U.S. GAAP and those prepared under IFRSs. ASU 2013-01 became effective for fiscal years beginning on or after January 1, 2013. The adoption of this ASU did not have a material impact on the accompanying financial statements.
	ASU 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”
	In February 2013, the FASB issued ASU 2013-02 to amend the guidance in the FASB ASC Topic 220, entitled Comprehensive Income. The goal behind development of the ASU 2013-02 amendments is to improve the transparency of reporting reclassifications out of accumulated other comprehensive income. Other comprehensive income includes gains and losses that are initially excluded from net income for an accounting period. Those gains and losses are later reclassified out of accumulated other comprehensive income into net income when realized. The amendments to FASB ASC 220 do not change current requirements for reporting net income or other comprehensive income in the financial statements. Essentially, all of the information required to be displayed or disclosed in financial statements already are required to be disclosed in the financial statements. The adoption of this ASU did not have a material impact on the accompanying financial statements, but did require additional disclosure.

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
Acquisitions (Tables)	Dec. 31, 2013
Financial Information of Company for Acquisition	'
	The following unaudited information is provided to present a summary of the combined results of the Company’s operations with JDOG Marketing as if the acquisition had been completed as of the beginning of the reporting periods. Adjustments were made to eliminate any inter-company transactions in the periods presented.


		Years ended December 31,
		2013		2012
		(Pro Forma)		(Pro Forma)
	Revenues	$	120,326,778	$	98,233,417

	Net income	$	7,082,270	$	4,996,567

	Basic and diluted earnings (loss) per share	$	0.76	$	0.61

Public Gas Company, Inc. [Member]	'
Estimated Fair Value of Assets Acquired and Liabilities Assumed	'
	The estimated fair value of the assets acquired and liabilities assumed is reflected in the following table at the date of acquisition.


		Fair Value at
		April 1, 2012
	Current assets	$	69,634
	Property, plant and equipment		1,577,592
	Goodwill		283,425

	Total assets acquired		1,930,651
	Current liabilities		184,770
	Long-term liabilities		194,403

	Total liabilities assumed		379,173

	Net assets acquired	$	1,551,478

John D. Oil and Gas Marketing [Member]	'
Estimated Fair Value of Assets Acquired and Liabilities Assumed	'
	The following table shows the estimated fair values of the assets acquired and liabilities assumed at the date of acquisition.


		Fair Value at
		June 1, 2013
	Assets acquired:
	Property, plant and equipment	$	21,600
	Customer relationships		2,800,000
	Goodwill		2,101,744

	Total assets acquired		4,923,344

	Less liabilities assumed:
	Current liabilities		669,396
	Long-term liabilities		1,580,604

	Total liabilities assumed		2,250,000

	Less effective settlement of pre-existing relationships:
	Settlement of note receivable		32,145

	Net assets acquired from John D Marketing acquisition	$	2,641,199

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
Discontinued Operations (Tables)	Dec. 31, 2013
Discontinued Operations And Disposal Groups [Abstract]	'
Schedule of Revenue and Loss from Discontinued Operations Associated with Independence	'
	The following table details the revenue and loss from discontinued operations associated with Independence for the years ended December 31, 2013 and 2012.


		Year Ended December 31,
		2013		2012
	Independence revenues	$	3,696,143	$	4,614,915

	Independence pretax loss	$	(514,634)	$	(494,541)
	Independence income tax benefit		144,359		293,443

	Loss from discontinued operations	$	(370,275)	$	(201,098)

	Basic and diluted loss from discontinued operations per share	$	(0.04)	$	(0.02)

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
Goodwill (Tables)	Dec. 31, 2013
Goodwill And Intangible Assets Disclosure [Abstract]	'
Change in Carrying Amount of Goodwill	'
	The schedule below describes the changes in carrying amount of goodwill for the years 2013 and 2012:


		Natural Gas		Marketing &		Total
		Operations		Production
				Operations
	Balance as of January 1, 2012	$	14,607,952	$	-	$	14,607,952
	Acquisition of PGC		283,425		-		283,425

	Balance as of December 31, 2012	$	14,891,377	$	-	$	14,891,377

	Balance as of January 1, 2013	$	14,891,377	$	-	$	14,891,377
	Acquisition of JDOG Marketing		-		2,101,744		2,101,744
	GNR Impairment loss		-		(725,744)		(725,744)

	Balance as of December 31, 2013	$	14,891,377	$	1,376,000	$	16,267,377

Marketable_Securities_Tables

Marketable Securities (Tables)

12 Months Ended

Dec. 31, 2013

Investments Debt And Equity Securities [Abstract]

Summary of Available-For-Sale Securities

The following is a summary of available-for-sale securities at December 31, 2013 and 2012.

December 31, 2013

Investment

Unrealized

Estimated

at cost

gains

losses

fair value

Common stock

238,504

167,630

406,134

31-Dec-12

Investment

Unrealized

Estimated

at cost

gains

losses

fair value

Common stock

238,504

105,842

344,346

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
Fair Value Measurements (Tables)	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Hierarchy of Assets and Liabilities Measured at Fair Value on Recurring Basis	'
	The following table shows the amount and level in the fair value hierarchy of each of the Company’s assets and liabilities measured at fair value on a recurring basis as of December 31, 2013 and 2012.


		December 31, 2013
		Level 1		Level 2			Level 3		TOTAL
	ASSETS:
	Available-for-sale securities	$	406,134	$	-		$	-	$	406,134

	LIABILITIES:
	Contingent consideration	$	-	$	-		$	685,000	$	685,000



		31-Dec-12
		Level 1		Level 2			Level 3		TOTAL
	ASSETS:
	Available-for-sale securities	$	344,346	$	-		$	-	$	344,346

Reconciliation of Beginning and Ending Balances of Contingent Consideration Liability Categorized Under Level 3 of Fair Value	'
	The following table reconciles the beginning and ending balances of the contingent consideration liability categorized under level 3 of the fair value hierarchy.
	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)


		Contingent
		Consideration
	Opening balance December 31, 2012	$	-

	Transfers into level 3		-
	Transfers out of level 3		-
	Total (gains) losses for period:
	Included in net income		(1,565,000)
	Included in other comprehensive income		-
	Purchases		-
	Sales		-
	Settlements		-
	Issuances		2,250,000


	Closing balance December 31, 2013	$	685,000

Quantitative Information about Level 3 Fair Value Measures	'
	The following table summarizes quantitative information used in determining the fair value of the Company’s liabilities categorized in level 3 of the fair value hierarchy.
	Quantitative Information about Level 3 Fair Value Measures


		Fair Value at		Valuation		Unobservable Input	Range
		December 31,		Techniques
		2013
	Contingent Consideration	$	685,000	Monte Carlo analysis		Forecasted annual EBITDA	$0.4 - $0.6 million
						Weighted avg cost of capital	15.0% - 15.0%
						U.S. Treasury yields	0.1% - 1.3%

				Discounted cash flow		U.S. Treasury yields	0.1% - 1.3%
						Credit spread	1.3% - 3.3%

Earnings_per_Share_Tables

Earnings per Share (Tables)	12 Months Ended
Earnings per Share (Tables)	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Summary of Earnings Per Share	'

		Year Ended December 31,
		2013		2012
	Numerator:
	Income from continuing operations	$	7,041,554	$	3,920,415
	Income (loss) from discontinued operations		(370,275)		(201,098)

	Net income	$	6,671,279	$	3,719,317

	Denominator:
	Basic weighted average common shares outstanding		9,339,002		8,163,814
	Dilutive effect of stock options		720		5,865

	Diluted weighted average common shares outstanding		9,339,722		8,169,679

	Basic & diluted earnings (loss) per share of common stock:
	Continuing operations	$	0.75	$	0.48
	Discontinued operations		(0.04)		(0.02)

	Net income	$	0.71	$	0.46

Property_Plant_Equipment_Table

Property Plant & Equipment (Tables)	12 Months Ended
Property Plant & Equipment (Tables)	Dec. 31, 2013
Property Plant And Equipment [Abstract]	'
Components of Property Plant and Equipment	'

	Components of property, plant, and equipment were as follows:



		December 31,
		2013		2012
	Gas transmission & distribution facilities	$	138,815,764	$	125,067,279
	Land		3,773,998		3,530,639
	Buildings & leasehold improvements		11,241,104		9,029,773
	Transportation equipment		3,449,615		3,311,769
	Computer equipment		3,844,776		3,589,035
	Other equipment		10,065,908		8,751,626
	Construction work in progress		10,762,534		8,470,638
	Producing natural gas properties		3,896,817		3,911,404

	Property, plant & equipment		185,850,516		165,662,163
	Accumulated depreciation, depletion & amortization		(52,301,885)		(47,034,673)

			133,548,631		118,627,490
	Discontinued operations		(28,345)		(2,198,448)

	Property, plant & equipment, net	$	133,520,286	$	116,429,042

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Liability is Equal to Percent of Asset Cost	'
	The liability is equal to a percent of the asset cost according to the following table:


		Percent of Asset Cost
		Orwell		Brainard
	Mains		15%		20%
	Meter/regulator stations		10%		10%
	Service lines		75%		75%
Reconciliation of Company's Liability	'
	The schedule below is a reconciliation of the Company’s liability for the years ended December 31:


		2013		2012
	Balance, beginning of period	$	1,850,379	$	1,689,081
	Accretion expense		175,974		161,298


	Balance, end of period	$	2,026,353	$	1,850,379

Credit_Facilities_and_LongTerm1

Credit Facilities and Long-Term Debt (Tables)	12 Months Ended
Credit Facilities and Long-Term Debt (Tables)	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Summary of Outstanding Long-Term Debt Balances	'
	The following table details the Company’s outstanding long-term debt balances at December 31, 2013 and 2012.


		December 31,
		2013		2012
	LIBOR plus 1.75 to 2.25%, Bank of America amortizing term loan, due April 1, 2017	$	9,375,000	$	10,000,000
	6.16%, Allstate/CUNA Senior unsecured note, due June 29, 2017		13,000,000		13,000,000
	5.38%, Sun Life fixed rate note, due June 1, 2017		15,334,000		15,334,000
	LIBOR plus 3.85%, Sun Life floating rate note, due May 3, 2014		3,000,000		3,000,000
	4.15% Sun Life senior secured guaranteed note, due June 1, 2017		2,989,552		2,989,552
	Vehicle loan		2,190		10,688

	Total notes payable		43,700,742		44,334,240
	Less: current portion		3,502,190		633,498

	Notes payable, less current portion	$	40,198,552	$	43,700,742

Schedule of Aggregate Future Maturities of Notes Payable	'
	The following table shows the aggregate future maturities of the Company’s notes payable.


	Years Ending
	2014	$	3,502,190
	2015		500,000
	2016		500,000
	2017		39,198,552
	2018		-
	Thereafter		-

	Total		43,700,742

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	12 Months Ended
Stockholders' Equity (Tables)	Dec. 31, 2013
Equity [Abstract]	'
Summary of Status of Outstanding Stock Options	'

	A summary of the status of the outstanding stock options is as follows:



		Number of				Weighted			Aggregate
		Shares				Average			Intrinsic
						Exercise Price			Value

	Outstanding December 31, 2011		35,000			$	8.66
	Granted		-			$	-
	Exercised		-			$	-
	Expired		-			$	-


	Outstanding December 31, 2012		35,000			$	8.66		$	31,550
	Granted		-			$-
	Exercised		(20,000)			$	7.98
	Expired		(10,000)			$	10.15


	Outstanding December 31, 2013		5,000			$	8.44		$	0


	Exerciseable December 31, 2013		5,000			$	8.44		$	0

Summary of Status of Options Outstanding	'
	The following information applies to options outstanding at December 31, 2013:


	Grant	Exercise		Number				Weighted	Weighted		Number		Weighted
	Date	Price		Outstanding				Average	Average		Exercisable		Average
								Exercise	Remaining				Exercise
								Price	Contractual				Price
									Life
									(Years)

	6/3/09	$8.44			5,000			$8.44	0.42			5,000	$8.44

					5,000							5,000

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Summary of Significant Components of Deferred Tax Assets and Liabilities	'
	Significant components of the deferred tax assets and liabilities are as follows:


		December 31,
		2013				2012
		Current		Long-term		Current		Long-term
	Deferred tax assets:
	Allowance for doubtful accounts	$	724,534	$	-	$	524,677	$	-
	Contributions in aid of construction		-		1,652,760		-		742,152
	Other nondeductible accruals		47,484		-		66,278		-
	Recoverable purchase gas costs		60,903		-		434,995		-
	Net operating loss carryforwards		-		7,733,763		-		5,439,748
	Property tax		154,146		-		-		153,967
	Other		754,235		-		709,778		595,918


	Total deferred tax assets		1,741,302		9,386,523		1,735,728		6,931,785

	Deferred tax liabilities:
	Recoverable purchase gas costs		454,795		-		867,075		-
	Property, plant and equipment		-		11,402,464		-		6,962,154
	Unrealized gain on securities available for sale		61,475		-		39,923		-
	Amortization of intangibles		-		539,498		-		418,181
	Other		-		800,698		-		519,814


	Total deferred tax liabilities		516,270		12,742,660		906,998		7,900,149


	Net deferred tax asset (liability) before valuation allowance		1,225,032		(3,356,137)		828,730		(968,930)
	Less: valuation allowance		-		(5,699,029)		-		(4,175,072)


	Total deferred tax asset (liability)		1,225,032		(9,055,166)		828,730		(5,144,002)
	Discontinued operations		-		-		(14,884)		547,373

	Net deferred tax asset (liability), continuing operations	$	1,225,032	$	(9,055,166)	$	813,846	$	(4,596,629)

Summary of Income Tax Expense from Continuing Operations	'
	Income tax expense from continuing operations consists of the following:


		Year Ended December 31,
		2013		2012
	Current income tax expense (benefit):
	Federal	$	(344,342)	$	(150,224)
	State		120,753		245,483


	Total current income tax expense (benefit)		(223,589)		95,259

	Deferred income tax expense:
	Federal		3,692,413		2,030,525
	State		(200,217)		252,403


	Total deferred income tax expense		3,492,196		2,282,928


	Total income taxes before credits		3,268,607		2,378,187
	Investment tax credit, net		(21,062)		(21,062)
	Total income tax expense		3,247,545		2,357,125
	Discontinued operations		144,353		293,444

	Income tax expense from continuing operations	$	3,391,898	$	2,650,569

Federal Statutory Rate to Pre-Tax Income from Continuing Operations	'
	Income tax position differs from the amount computed by applying the Federal statutory rate to pre-tax income from continuing operations as demonstrated in the table below:


		Year Ended December 31,
		2013		2012
	Tax expense at statutory rate of 34%	$	3,372,404	$	2,065,991
	State income tax, net of federal tax expense		348,151		228,051
	Amortization of deferred investment tax credits		(21,062)		(21,062)
	Change in valuation allowance		(237,557)		(262,343)
	Permanent differences		134,583		140,211
	State rate change		(346,149)		-
	Other		(2,825)		206,277


	Total income tax expense		3,247,545		2,357,125
	Discontinued operations		144,353		293,444


	Income tax expense from continuing operations	$	3,391,898	$	2,650,569

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
Related Party Transactions (Tables)	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Amounts Due from and Due to Related Parties	'
	The table below details amounts due from and due to related parties, including companies owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, at December 31, 2013 and 2012.


		Accounts Receivable				Accounts Payable
		December 31, 2013		December 31, 2012		December 31, 2013		December 31, 2012
	John D. Oil and Gas Marketing	$	-	$	3,282	$	-	$	40,518
	Cobra Pipeline		131,208		21,698		76,909		-
	Orwell Trumbell Pipeline		-		90,385		122,693		-
	Great Plains Exploration		7,033		142,740		73,983		9
	Big Oats Oil Field Supply		4,945		769		179,447		11,270
	Kykuit Resources		-		98,037		-		-
	John D. Oil and Gas Company		91		-		82,188		-
	Sleepy Hollow Oil & Gas		-		143,697		-		-
	Other		2,948		21,949		24,713		-

	Total related party balances		146,225		522,557		559,933		51,797
	Less amounts included in discontinued operations		-		-		-		3,868

	Total related party balances included in continuing operations	$	146,225	$	522,557	$	559,933	$	47,929

Summary of Related Parties Transactions	'

	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, for the year ended December 31, 2013:



		Year Ended December 31, 2013
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas		Rental Income
		Purchases		Construction		Consulting and		Sales		and Other
				Purchases		Other Purchases				Sales
	John D. Oil and Gas Marketing	$	951,120	$	-	$	16,599	$	5,470	$	-
	Cobra Pipeline		842,620		263,574		20,000		157,834		381
	Orwell Trumbell Pipeline		795,190		-		-		1,260		33,911
	Great Plains Exploration		856,696		854		1,341		9,310		47,640
	Big Oats Oil Field Supply		-		2,967,705		624,147		3,996		5,125
	John D. Oil and Gas Company		911,507		5,975		-		572		29,356
	OsAir		241,693		13,200		91,850		4,866		72,787
	Other		86,987		853		44,334		20,054		45,299

	Total	$	4,685,813	$	3,252,161	$	798,271	$	203,362	$	234,499


	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, the Company’s chairman and chief executive officer, for the year ended December 31, 2012:



		Year Ended December 31, 2012
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas		Rental Income
		Purchases		Construction		Consulting and		Sales		and Other
				Purchases		Other Purchases				Sales
	John D. Oil and Gas Marketing	$	2,405,158	$	9,870	$	58,043	$	-	$	13,128
	Cobra Pipeline		389,233		5,390		5,104		-		23,210
	Orwell Trumbell Pipeline		526,785		132		19,547		26,519		4,785
	Great Plains Exploration		506,503		-		-		7,068		10,643
	Big Oats Oil Field Supply		-		1,231,921		256,607		2,131		7,068
	John D. Oil and Gas Company		502,897		-		-		575		-
	Sleepy Hollow Oil & Gas		-		-		-		-		5,113
	OsAir		248,588		-		196,451		2,479		306
	Other		135,927		-		127,171		28,777		411

	Total	$	4,715,091	$	1,247,313	$	662,923	$	67,549	$	64,664

Segments_of_Operations_Tables

Segments of Operations (Tables)	12 Months Ended
Segments of Operations (Tables)	Dec. 31, 2013
Segment Reporting [Abstract]	'
Summary of Financial Information for Operating Segments	'
	The following tables set forth summarized financial information for the Company’s Natural Gas, Marketing and Production, Pipeline, and Corporate and Other operating segments.


	Year Ended December 31,
	2013
			Natural Gas			Marketing &			Pipeline			Corporate &			Consolidated
			Operations			Production			Operations			Other
						Operations						Operations

	OPERATING REVENUES		$	106,590,940		$	20,260,001		$	402,914		$	-		$	127,253,855
	Intersegment eliminations			(326,331)			(8,092,760)			-			-			(8,419,091)

	Total operating revenue			106,264,609			12,167,241			402,914			-			118,834,764

	COST OF SALES			61,563,103			18,145,625			-			-			79,708,728
	Intersegment eliminations			(326,331)			(8,092,760)			-			-			(8,419,091)

	Total cost of sales			61,236,772			10,052,865			-			-			71,289,637


	GROSS MARGIN			45,027,837			2,114,376			402,914			-			47,545,127

	OPERATING EXPENSES
	Distribution, general and administrative			21,476,833			801,305			105,249			1,192,431			23,575,818
	Maintenance			1,305,897			2,765			9,130			-			1,317,792
	Depreciation and amortization			5,603,639			456,790			62,061			12,670			6,135,160
	Accretion			125,130			50,844			-			-			175,974
	Unrealized holding gain			-			(1,565,000)			-			-			(1,565,000)
	Goodwill impairment			-			725,744			-			-			725,744
	Taxes other than income			3,910,335			28,113			40,507			24,513			4,003,468
	Intersegment eliminations			(13,744)			-			-			(84,090)			(97,834)

	Total operating expenses			32,408,090			500,561			216,947			1,145,524			34,271,122


	OPERATING INCOME (LOSS)			12,619,747			1,613,815			185,967			(1,145,524)			13,274,005

	Other income (expense)			804,989			151,168			-			(618,104)			338,053
	Interest expense			(2,881,218)			(142,031)			(25,877)			(129,480)			(3,178,606)

	Income (loss) before taxes			10,543,518			1,622,952			160,090			(1,893,108)			10,433,452

	Income tax benefit (expense)			(3,346,726)			(586,326)			(39,161)			580,315			(3,391,898)


	INCOME (LOSS) FROM CONTINUING OPERATIONS			7,196,792			1,036,626			120,929			(1,312,793)			7,041,554
	Discontinued operations, net of income tax			-			-			-			(370,275)			(370,275)


	NET INCOME (LOSS)		$	7,196,792		$	1,036,626		$	120,929		$	(1,683,068)		$	6,671,279


	Capital expenditures		$	23,825,593		$	217,201		$	3,186		$	57,809		$	24,103,789


	As of December 31, 2013
	Investment in unconsolidated affiliate		$	-		$	351,724		$	-		$	-		$	351,724


	Total assets		$	195,219,938		$	11,633,544		$	685,760		$	83,173,644		$	290,712,886
	Intersegment eliminations			(53,670,915)			(3,678,311)			(28,100)			(29,591,945)			(86,969,271)

	Total assets		$	141,549,023		$	7,955,233		$	657,660		$	53,581,699		$	203,743,615



Year Ended December 31, 2012
		Natural Gas			Marketing &			Pipeline			Corporate &			Consolidated
		Operations			Production			Operations			Other
					Operations						Operations
OPERATING REVENUES		$	81,630,788		$	13,417,723		$	401,933		$	-		$	95,450,444
Intersegment eliminations			(324,837)			(5,924,362)			-			-			(6,249,199)

Total operating revenue			81,305,951			7,493,361			401,933			-			89,201,245

COST OF SALES			42,810,640			11,877,518			-			-			54,688,158
Intersegment eliminations			(324,837)			(5,924,362)			-			-			(6,249,199)

Total cost of sales			42,485,803			5,953,156			-			-			48,438,959


GROSS MARGIN		$	38,820,148		$	1,540,205		$	401,933		$	-		$	40,762,286

OPERATING EXPENSES
Distribution, general and administrative			19,806,389			449,665			87,640			472,161			20,815,855
Maintenance			1,176,189			1,014			13,835			-			1,191,038
Depreciation and amortization			4,662,313			268,202			61,085			34,542			5,026,142
Accretion			113,106			48,192			-			-			161,298
Taxes other than income			3,366,238			38,052			35,497			39,110			3,478,897

Total operating expenses			29,124,235			805,125			198,057			545,813			30,673,230


OPERATING INCOME (LOSS)		$	9,695,913		$	735,080		$	203,876		$	(545,813)		$	10,089,056

Other income (expense)			418,822			(6,051)			-			(1,230,650)			(817,879)
Interest expense			(2,512,444)			(133,440)			(13,528)			(40,781)			(2,700,193)

Income (loss) before taxes			7,602,291			595,589			190,348			(1,817,244)			6,570,984

Income tax benefit (expense)			(3,135,445)			4,542			(97,523)			577,857			(2,650,569)


INCOME (LOSS) FROM CONTINUING OPERATIONS		$	4,466,846		$	600,131		$	92,825		$	(1,239,387)		$	3,920,415

Discontinued operations, net of income tax			-			-			-			(201,098)			(201,098)


NET INCOME (LOSS)		$	4,466,846		$	600,131		$	92,825		$	(1,440,485)		$	3,719,317


Capital expenditures		$	18,381,644		$	1,393,040		$	23,141		$	856,359		$	20,654,184

As of December 31, 2012
Investment in unconsolidated affiliate		$	-		$	321,731		$	-		$	-		$	321,731

Total assets		$	169,616,395		$	8,786,247		$	632,466		$	68,443,708		$	247,478,816
Intersegment eliminations			(46,338,335)			(447,549)			(16,073)			(26,213,400)			(73,015,357)

Total assets		$	123,278,060		$	8,338,698		$	616,393		$	42,230,308		$	174,463,459

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
Commitments and Contingencies (Tables)	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'
Schedule of Future Minimum Lease Payments	'
	The following schedule presents the future minimum lease payments under the Company’s lease agreements as of December 31, 2013.
	Future Minimum Lease Payments


		Operating Leases		Capital Leases
	2014	$	253,833	$	300,000
	2015		229,711		300,000
	2016		125,906		300,000
	2017		121,080		300,000
	2018		120,633		300,000
	Thereafter		537,392		1,200,000

	Total minimum lease payments required	$	1,388,555		2,700,000

	Less: Interest portion				(659,492)

	Liability			$	2,040,508

Schedule of Future Minimum Lease Payments	'
	The following schedule presents the future minimum lease payments under the Company’s lease agreements as of December 31, 2013.
	Future Minimum Lease Payments


		Operating Leases		Capital Leases
	2014	$	253,833	$	300,000
	2015		229,711		300,000
	2016		125,906		300,000
	2017		121,080		300,000
	2018		120,633		300,000
	Thereafter		537,392		1,200,000

	Total minimum lease payments required	$	1,388,555		2,700,000

	Less: Interest portion				(659,492)

	Liability			$	2,040,508

Summary of Cost Basis and Accumulated Depreciation of Assets Recorded under Capital Leases	'
	The cost basis and accumulated depreciation of assets recorded under capital leases, which are included in Property, Plant, and Equipment on the Consolidated Balance Sheets are as follows as of December 31, 2013 and 2012:


		December 31,
		2013		2012
	Gas transmission & distribution facilities		6,320,000		6,320,000

	Capital lease assets, gross		6,320,000		6,320,000
	Accumulated depreciation		(501,587)		(100,317)

	Capital lease assets, net		5,818,413		6,219,683

Summary of Future Minimum Long-term Contract Obligations	'
	The future obligations under these pipeline, storage and gas purchase agreements at December 31, 2013 are as follows:
	Future Minimum Long-term Contract Obligations


		Northwestern		Trans-Canada		Maritimes and
		Energy		Trans-Canada		Northeast Pipeline
	2014	$	1,517,892	$	921,977	$	575,622
	2015		1,434,680		829,775		357,042
	2016		519,356		368,768		357,042
	2017		519,356		368,768		357,042
	2018		476,076		338,036		357,042
	Thereafter		-		-		357,042

	Total	$	4,467,360	$	2,827,324	$	2,360,832

Schedule_1_Condensed_Financial

Schedule 1 - Condensed Financial Statements (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
ASSETS	'	'	'
Current assets	$47,100,046	$35,966,509	'
Investments	351,724	321,731	'
PROPERTY, PLANT, & EQUIPMENT, NET	133,520,286	116,429,042	'
Deferred tax asset, less current portion	1,225,032	813,846	'
Restricted cash	1,137,442	3,150,847	'
Prepayments	1,064,845	2,153,922	'
Other assets	23,123,283	22,067,908	'
TOTAL ASSETS	203,743,615	174,463,459	'
LIABILITIES AND CAPITALIZATION	'	'	'
Current liabilities	51,873,382	44,662,622	'
Stockholders' equity	97,479,775	76,344,124	74,772,027
TOTAL LIABILITIES AND CAPITALIZATION	203,743,615	174,463,459	'
Operating expenses	34,271,122	30,673,230	'
Operating loss	13,274,005	10,089,056	'
Other income (expense)	924,586	424,221	'
Interest expense	-3,178,606	-2,700,193	'
Income (loss) before taxes	10,433,452	6,570,984	'
Income from unconsolidated subsidiaries	-5,007	-8,620	'
Income tax benefit (expense)	-3,391,898	-2,650,569	'
NET INCOME	6,671,279	3,719,317	'
Other comprehensive income, net of tax of $22,951 and 8,913, respectively	39,120	-14,616	'
Comprehensive income	6,710,399	3,704,701	'
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	6,671,279	3,719,317	'
Income from unconsolidated subsidiaries	5,007	8,620	'
Stock based compensation	2,962	60,009	'
Deferred income taxes	4,024,683	2,261,345	'
Other assets	-431,153	1,051,267	'
Other liabilities	876,068	-1,163,368	'
Net cash (used in) provided by operating activities	16,656,343	9,139,559	'
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures	-24,103,789	-20,654,184	'
Net cash (used in) provided by investing activities	-20,766,937	-23,206,027	'
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Debt issuance costs	-7,607	-1,204,987	'
Restricted cash - debt service	748,781	-878,875	'
Exercise of stock options	159,500	'	'
Proceeds from issuance of common stock	16,721,104	'	'
Dividends paid	-5,005,827	-4,432,920	'
Net cash (used in) provided by financing activities	12,484,979	7,164,605	'
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	9,712,264	-7,069,728	'
Cash and cash equivalents, beginning of period	3,435,117	10,504,845	'
CASH AND CASH EQUIVALENTS, END OF PERIOD	13,147,381	3,435,117	'
Total	3,600,000	4,485,892	'
Gas Natural Inc.[Member]	'	'	'
ASSETS	'	'	'
Current assets	8,376,229	235,519	'
Investments	89,104,692	75,417,951	'
Accounts receivable	250,000	'	'
PROPERTY, PLANT, & EQUIPMENT, NET	306,738	611,575	'
Deferred tax asset, less current portion	435,983	278,469	'
Restricted cash	'	750,939	'
Prepayments	179,598	'	'
Other assets	840	'	'
TOTAL ASSETS	98,654,080	77,294,453	'
LIABILITIES AND CAPITALIZATION	'	'	'
Current liabilities	694,217	654,764	'
Intercompany payable, net	480,088	295,565	'
Stockholders' equity	97,479,775	76,344,124	'
TOTAL LIABILITIES AND CAPITALIZATION	98,654,080	77,294,453	'
Operating expenses	946,222	250,045	'
Operating loss	-946,222	-250,045	'
Other income (expense)	-523,990	-804,775	'
Interest expense	'	'	'
Income (loss) before taxes	-1,470,212	-1,054,820	'
Income from unconsolidated subsidiaries	7,738,256	4,377,406	'
Income tax benefit (expense)	403,235	396,731	'
NET INCOME	6,671,279	3,719,317	'
Other comprehensive income, net of tax of $22,951 and 8,913, respectively	39,120	-14,616	'
Comprehensive income	6,710,399	3,704,701	'
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	6,671,279	3,719,317	'
Income from unconsolidated subsidiaries	-7,738,256	-4,377,406	'
Depreciation expense	12,670	3,931	'
Stock based compensation	2,962	60,009	'
Deferred income taxes	-158,629	-256,291	'
Other assets	-62,122	7,245	'
Other liabilities	108,736	432,430	'
Net cash (used in) provided by operating activities	-1,163,360	-410,765	'
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures	-75,309	-615,506	'
Purchase of marketable securities	'	'	'
Repayment of intercompany loans	'	'	'
Investment in subsidiaries	-6,845,497	-1,887,288	'
Dividends received from subsidiaries	3,600,000	4,485,892	'
Net cash (used in) provided by investing activities	-3,320,806	1,983,098	'
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Debt issuance costs	-840	'	'
Restricted cash - debt service	750,939	-750,939	'
Exercise of stock options	159,500	'	'
Proceeds from issuance of common stock	16,721,104	'	'
Dividends paid	-5,005,827	-4,432,920	'
Net cash (used in) provided by financing activities	12,624,876	-5,183,859	'
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	8,140,710	-3,611,526	'
Cash and cash equivalents, beginning of period	235,519	3,847,045	'
CASH AND CASH EQUIVALENTS, END OF PERIOD	8,376,229	235,519	'
Energy West, Inc. [Member]	'	'	'
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Total	3,600,000	4,350,000	'
Great Plains Natural Gas Company [Member]	'	'	'
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Total	'	98,759	'
Lightning Pipeline Company, Inc. [Member]	'	'	'
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Total	'	$37,133	'

Schedule_1_Condensed_Financial1

Schedule 1 - Condensed Financial Statements (Parenthetical) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Condensed Balance Sheet Statements, Captions [Line Items]	'	'
Other comprehensive income, tax portion	$22,951	$8,913
Gas Natural Inc.[Member]	'	'
Condensed Balance Sheet Statements, Captions [Line Items]	'	'
Other comprehensive income, tax portion	$22,951	$8,913

Summary_of_Business_Additional

Summary of Business - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2013
	Wells
	Segment
Summary Of Business And Accounting Policies [Line Items]	'
Number of reporting segments	4
Number of natural gas producing wells and gas gathering assets	160
EWR Subsidiary [Member]	'
Summary Of Business And Accounting Policies [Line Items]	'
Gross percentage of working interest	51.00%
Average net revenue interest, percentage	43.00%
Natural Gas Operations [Member]	'
Summary Of Business And Accounting Policies [Line Items]	'
Annual distribution of natural gas	36,000
Natural gas customers	72,000
Marketing & Production Operations [Member]	'
Summary Of Business And Accounting Policies [Line Items]	'
Annually market of natural gas	1,500

Significant_Accounting_Policie1

Significant Accounting Policies - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Summary Of Business And Accounting Policies [Line Items]	'	'
Bad debt expense	$797,867	$958,561
Bad debt write-off	161,674	213,855
Additional investments	351,724	321,731
Kykuit Resources [Member]	'	'
Summary Of Business And Accounting Policies [Line Items]	'	'
Ownership interest in Kykuit	24.50%	'
Additional investments	2,200,000	'
Customer Relationships [Member]	'	'
Summary Of Business And Accounting Policies [Line Items]	'	'
Accumulated amortization	254,667	'
Amortization expense	186,167	'
Maximum [Member]	'	'
Summary Of Business And Accounting Policies [Line Items]	'	'
Depreciation and amortization period	'40 years	'
Regulatory asset for property tax recovery period	'10 years	'
Regulatory assets recovery period	'20 years	'
Regulatory liabilities refunding period	'20 years	'
Maximum [Member] \| Kykuit Resources [Member]	'	'
Summary Of Business And Accounting Policies [Line Items]	'	'
Additional investments	$100,000	'
Minimum [Member]	'	'
Summary Of Business And Accounting Policies [Line Items]	'	'
Depreciation and amortization period	'3 years	'
Regulatory assets recovery period	'3 years	'
Regulatory liabilities refunding period	'5 years	'

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail) (USD $)

0 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Mar. 05, 2013

Sep. 25, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2013

Apr. 01, 2012

Dec. 31, 2011

Apr. 01, 2012

Apr. 30, 2012

Dec. 31, 2012

Apr. 01, 2012

Dec. 31, 2013

Jun. 04, 2012

Dec. 31, 2013

Jun. 01, 2013

Dec. 31, 2013

Public Gas Company, Inc. [Member]

Loring Pipeline Lease and Related Property [Member]

Leased Pipeline and Leased Pipeline Easements [Member]

John D. Oil and Gas Marketing [Member]

Station Street 8500 [Member]

Kentucky [Member]

Underwriter

Building [Member]

Land [Member]

Customer

Business Acquisition [Line Items]

Percentage of stock purchased

100.00%

Cash purchase price of pipeline and rights-of-way assets

$1,600,000

Product delivered to number of customers

1,600

Costs related to the transaction

51,187

Amount allocated to Goodwill

142,971

Goodwill adjusted

16,267,377

14,891,377

2,100,000

283,425

14,607,952

283,425

2,101,744

Expected goodwill to be deductible for tax purpose

Public foreclosure auction amount

4,500,000

Shares issued to purchase Loring Pipeline

2,250,004

2,250,000

Lease payments per year

300,000

Duration of lease payments

'10 years

Annual service fee

120,000

Annual service fee charge

0.0125

Additional shares of common stock

210,951

Total fair value of all the assets

605,352

6,320,000

Discount rate of present value of the lease payments

90.00%

Present value of the minimum lease payment

2,208,026

Purchase of Matchworks Building in Mentor, Ohio

1,900,000

Property, plant and equipment amounts

1,607,915

244,859

Acquisition cost

600,000

Number of shares issued for payment

256,926

Purchase consideration paid

2,641,199

Underwriting discounts or commissions in connection with the issuance

Number of underwriters facilitating acquisition

Contingent earn out payment period

'5 years

Targeted EBITDA amount for contingent earn out payments

810,432

Earn out payment in case actual EBITDA remain less than target EBITDA

Earn out payment in case actual EBITDA meets or exceeds target EBITDA

'575000

Trading days used to calculate earn out payments

'20 days

Fair value of earn-out provision

2,250,000

Business combination estimated current liability for earn out payment

669,396

Earn out payment calculated

671,638

customer contracts amortized estimated useful lives.

Amount allocated to goodwill

2,101,744

Amount contributed to the Company's revenues

12,167,241

7,493,361

1,946,745

Amount contributed to the company's net income

$6,671,279

$3,719,317

$764,568

Acquisitions_Estimated_Fair_Va

Acquisitions - Estimated Fair Value of Assets Acquired and Liabilities Assumed (Detail) (USD $)	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012	Apr. 01, 2012	Dec. 31, 2011	Apr. 01, 2012	Jun. 01, 2013	Jun. 01, 2013
						Public Gas Company, Inc. [Member]	John D. Oil and Gas Marketing [Member]	John D. Oil and Gas Marketing [Member]
								Customer Relationships [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'
Current assets	'	'	'	'	'	$69,634	'	'
Property, plant and equipment	'	'	'	'	'	1,577,592	21,600	'
Customer relationships	'	'	'	'	'	'	'	2,800,000
Goodwill	16,267,377	2,100,000	14,891,377	283,425	14,607,952	283,425	2,101,744	'
Total assets acquired	'	'	'	'	'	1,930,651	4,923,344	'
Current liabilities	'	'	'	'	'	184,770	669,396	'
Long-term liabilities	'	'	'	'	'	194,403	1,580,604	'
Total liabilities assumed	'	'	'	'	'	379,173	2,250,000	'
Less effective settlement of pre-existing relationships, Settlement of note receivable	'	'	'	'	'	'	32,145	'
Net assets acquired	'	'	'	'	'	$1,551,478	$2,641,199	'

Acquisitions_Financial_Informa

Acquisitions - Financial Information of Company for Acquisition (Detail) (John D. Oil and Gas Marketing [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
John D. Oil and Gas Marketing [Member]	'	'
Business Acquisition [Line Items]	'	'
Revenues	$120,326,778	$98,233,417
Net income	$7,082,270	$4,996,567
Basic and diluted earnings (loss) per share	$0.76	$0.61

Discontinued_Operations_Additi

Discontinued Operations - Additional Information (Detail) (Blue Ridge Energies LLC [Member], USD $)	0 Months Ended	3 Months Ended
	Nov. 06, 2013	Dec. 31, 2013
Blue Ridge Energies LLC [Member]	'	'
Schedule Of Discontinued Operations [Line Items]	'	'
Amount of sale	$2,300,000	'
Loss on sale of a discontinued operation	'	$8,000

Discontinued_Operations_Schedu

Discontinued Operations - Schedule of Revenue and Loss from Discontinued Operations Associated with Independence (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'
Loss from discontinued operations	($370,275)	($201,098)
Basic and diluted loss from discontinued operations per share	($0.04)	($0.02)
Independence [Member]	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'
Independence revenues	3,696,143	4,614,915
Independence pretax loss	-514,634	-494,541
Independence income tax benefit	144,359	293,443
Loss from discontinued operations	($370,275)	($201,098)
Basic and diluted loss from discontinued operations per share	($0.04)	($0.02)

Goodwill_Additional_Informatio

Goodwill - Additional Information (Detail) (USD $)	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012	Apr. 01, 2012	Dec. 31, 2011
Intangible Liability Disclosure [Abstract]	'	'	'	'	'
Business combination goodwill recognized	$16,267,377	$2,100,000	$14,891,377	$283,425	$14,607,952

Goodwill_Changes_in_Carrying_A

Goodwill - Changes in Carrying Amount of Goodwill (Detail) (USD $)

12 Months Ended

Dec. 31, 2013

Jun. 30, 2013

Apr. 01, 2012

Dec. 31, 2011

Dec. 31, 2012

Apr. 01, 2012

Dec. 31, 2013

Jun. 01, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Public Gas Company, Inc. [Member]

John D. Oil and Gas Marketing [Member]

Natural Gas Operations [Member]

Marketing & Production Operations [Member]

Public Gas Company, Inc. [Member]

John D. Oil and Gas Marketing [Member]

Public Gas Company, Inc. [Member]

John D. Oil and Gas Marketing [Member]

Goodwill [Line Items]

Beginning balance

$14,891,377

$2,100,000

$283,425

$14,607,952

$283,425

$2,101,744

$14,891,377

$14,607,952

Acquisition

283,425

2,101,744

283,425

2,101,744

GNR Impairment loss

-725,744

Ending balance

$16,267,377

$2,100,000

$283,425

$14,607,952

$283,425

$2,101,744

$14,891,377

$14,607,952

$1,376,000

Marketable_Securities_Addition

Marketable Securities - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Amortized Cost And Fair Value Debt Securities [Abstract]	'	'
Held-to-maturity securities	$0	'
Trading securities	'	0
Securities in an unrealized position	0	0
Gross realized gains or losses	$0	$0

Marketable_Securities_Summary_

Marketable Securities - Summary of Available-For-Sale Securities (Detail) (Common Stock [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
Common Stock [Member]	'	'
Schedule of Available-for-sale Securities [Line Items]	'	'
Investment at cost	$238,504	$238,504
Unrealized gains	167,630	105,842
Unrealized losses	'	'
Estimated fair value	$406,134	$344,346

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Value Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
ASSETS	'	'
Available-for-sale securities	$406,134	$344,346
LIABILITIES	'	'
Contingent consideration	685,000	'
Level 1 [Member]	'	'
ASSETS	'	'
Available-for-sale securities	406,134	344,346
LIABILITIES	'	'
Contingent consideration	'	'
Level 2 [Member]	'	'
ASSETS	'	'
Available-for-sale securities	'	'
LIABILITIES	'	'
Contingent consideration	'	'
Level 3 [Member]	'	'
ASSETS	'	'
Available-for-sale securities	'	'
LIABILITIES	'	'
Contingent consideration	$685,000	'

Fair_Value_Measurements_Reconc

Fair Value Measurements - Reconciliation of Beginning and Ending Balances of Contingent Consideration Liability Categorized Under Level 3 of Fair Value (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'
Total (gains) losses for period: Included in net income	($1,565,000)
Contingent Consideration [Member]	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'
Opening balance	'
Transfers into level 3	'
Transfers out of level 3	'
Total (gains) losses for period: Included in net income	-1,565,000
Total gains or losses for period Included in other comprehensive income	'
Purchases	'
Sales	'
Settlements	'
Issuances	2,250,000
Closing balance	$685,000

Fair_Value_Measurements_Quanti

Fair Value Measurements - Quantitative Information about Level 3 Fair Value Measures (Detail) (Contingent Consideration [Member], Level 3 [Member], USD $)	12 Months Ended
	Dec. 31, 2013
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Fair Value	$685,000
Monte Carlo Analysis [Member] \| Minimum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Forecasted annual EBITDA	400,000
Weighted average cost of capital	15.00%
U.S. Treasury yields	0.10%
Monte Carlo Analysis [Member] \| Maximum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Forecasted annual EBITDA	$600,000
Weighted average cost of capital	15.00%
U.S. Treasury yields	1.30%
Discounted Cash Flow [Member] \| Minimum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
U.S. Treasury yields	0.10%
Credit spread	1.30%
Discounted Cash Flow [Member] \| Maximum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
U.S. Treasury yields	1.30%
Credit spread	3.30%

Earnings_Per_Share_Summary_of_

Earnings Per Share - Summary of Earnings Per Share (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]	'	'
Income from continuing operations	$7,041,554	$3,920,415
Income (loss) from discontinued operations	-370,275	-201,098
Net income	$6,671,279	$3,719,317
Basic weighted average common shares outstanding	9,339,002	8,163,814
Dilutive effect of stock options	720	5,865
Diluted weighted average common shares outstanding	9,339,722	8,169,679
Basic & diluted earnings (loss) per share of common stock:	'	'
Continuing operations	$0.75	$0.48
Discontinued operations	($0.04)	($0.02)
Net income	$0.71	$0.46

Earning_Per_Share_Additional_I

Earning Per Share - Additional Information (Detail)	12 Months Ended
Earning Per Share - Additional Information (Detail)	Dec. 31, 2013
Earnings Per Share [Abstract]	'
No of shares or share equivalents excluded the from calculation of diluted earning per share	0

Property_Plant_Equipment_Compo

Property Plant & Equipment - Components of Property Plant and Equipment (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	$185,850,516	$165,662,163
Accumulated depreciation, depletion & amortization	-52,301,885	-47,034,673
Property, plant & equipment including discontinued operation	133,548,631	118,627,490
Discontinued operations	-28,345	-2,198,448
Property, plant & equipment, net	133,520,286	116,429,042
Gas, Transmission & Distribution Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	138,815,764	125,067,279
Land [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	3,773,998	3,530,639
Buildings & Leasehold Improvements [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	11,241,104	9,029,773
Transportation Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	3,449,615	3,311,769
Computer Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	3,844,776	3,589,035
Other Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	10,065,908	8,751,626
Construction Work in Progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	10,762,534	8,470,638
Producing Natural Gas Properties [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant & equipment, gross	3,896,817	3,911,404
Property, plant & equipment, net	$1,003,340	$1,289,160

Property_Plant_Equipment_Addit

Property Plant & Equipment - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
	Property	Mcf
	Mcf
Property, Plant and Equipment [Line Items]	'	'
Net book value of gas reserves	$133,520,286	$116,429,042
Number of natural gas production properties	2	'
Number of Gathering systems	3	'
Net present value of gas reserves	2,090,000	1,419,000
Portion of daily gas production	550	593
Volume requirements	25.00%	19.90%
EWR Subsidiary [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Portion of daily gas production	422	461
Volume requirements	19.00%	15.50%
EWD Subsidiary [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Number of natural gas production properties	50	'
Portion of daily gas production	129	132
Volume requirements	5.80%	4.40%
EWD's ownership interest in gathering system	75.00%	'
Natural Gas [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Discount on gas reserves	10.00%	10.00%
Estimated net gas reserves	2.3	2.1
Depletion of wells	10.00%	10.00%
Producing Natural Gas Properties [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Net book value of gas reserves	$1,003,340	$1,289,160

Asset_Retirement_Obligations_L

Asset Retirement Obligations - Liability is Equal to Percent of Asset Cost (Detail)	12 Months Ended
	Dec. 31, 2013
Mains [Member] \| Orwell [Member]	'
Asset Retirement Obligations [Line Items]	'
Regulatory actions estimated useful life percentage of asset cost estimated liability	15.00%
Meter/regulator stations [Member] \| Orwell [Member]	'
Asset Retirement Obligations [Line Items]	'
Regulatory actions estimated useful life percentage of asset cost estimated liability	10.00%
Service lines [Member] \| Orwell [Member]	'
Asset Retirement Obligations [Line Items]	'
Regulatory actions estimated useful life percentage of asset cost estimated liability	75.00%
Brainard [Member] \| Mains [Member]	'
Asset Retirement Obligations [Line Items]	'
Regulatory actions estimated useful life percentage of asset cost estimated liability	20.00%
Brainard [Member] \| Meter/regulator stations [Member]	'
Asset Retirement Obligations [Line Items]	'
Regulatory actions estimated useful life percentage of asset cost estimated liability	10.00%
Brainard [Member] \| Service lines [Member]	'
Asset Retirement Obligations [Line Items]	'
Regulatory actions estimated useful life percentage of asset cost estimated liability	75.00%

Asset_Retirement_Obligations_R

Asset Retirement Obligations - Reconciliation of Company's Liability (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation Disclosure [Abstract]	'	'
Balance, beginning of period	$1,850,379	$1,689,081
Accretion expense	175,974	161,298
Balance, end of period	$2,026,353	$1,850,379

Asset_Retirement_Obligations_A

Asset Retirement Obligations - Additional Information (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation Disclosure [Abstract]	'	'
Capitalized ARO costs included in property, plant and equipment	$86,415	$156,816

Credit_Facilities_and_LongTerm2

Credit Facilities and Long-Term Debt - Lines of Credit - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Bank of America [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Interest on amount outstanding	'LIBOR plus 175 to 225 basis points	'
Yadkin Valley Bank [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Outstanding borrowings	$0	$400,000
Debt instrument, interest rate, effective percentage rate range, minimum	4.50%	'
Debt instrument, interest rate, effective percentage rate range, maximum	16.00%	'
Revolving Credit Facility [Member] \| Bank of America [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Maximum borrowing credit facility	30,000,000	'
Line of credit maturity date	1-Apr-17	'
Outstanding borrowings	24,500,000	23,900,000
Weighted average borrowing outstanding	19,000,000	'
Weighted average interest rate on the revolving credit facility	2.42%	3.33%
Revolving Credit Facility [Member] \| Bank of America [Member] \| Minimum [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Annual commitment fee	25.00%	'
Changes in interest rate on amount outstanding	175.00%	'
Revolving Credit Facility [Member] \| Bank of America [Member] \| Maximum [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Annual commitment fee	45.00%	'
Changes in interest rate on amount outstanding	225.00%	'
Revolving Credit Facility [Member] \| Yadkin Valley Bank [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Weighted average borrowing outstanding	300,000	400,000
Weighted average interest rate on the revolving credit facility	4.50%	4.50%
Revolving credit facility short term debt	$500,000	'

Credit_Facilities_and_LongTerm3

Credit Facilities and Long-Term Debt - Summary of Outstanding Long-Term Debt Balances (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Summary of outstanding long-term debt balances	'	'
Total notes payable	$43,700,742	$44,334,240
Less: current portion	3,502,190	633,498
NOTES PAYABLE, less current portion	40,198,552	43,700,742
LIBOR Plus 1.75 to 2.25%, Bank of America Amortizing Term Loan, Due April 1, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Total notes payable	9,375,000	10,000,000
6.16%, Allstate/ CUNA Senior Unsecured Notes, Due June 29, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Total notes payable	13,000,000	13,000,000
5.38%, Sun Life Fixed Rate Note, Due June 1, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Total notes payable	15,334,000	15,334,000
LIBOR Plus 3.85%, Sun Life Floating Rate Note, Due May 3, 2014 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Total notes payable	3,000,000	3,000,000
4.15% Sun Life Senior Secured Guaranteed Note, Due June 1, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Total notes payable	2,989,552	2,989,552
Vehicle Loan [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Total notes payable	$2,190	$10,688

Credit_Facilities_and_LongTerm4

Credit Facilities and Long-Term Debt - Summary of Outstanding Long-Term Debt Balances (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
LIBOR Plus 1.75 to 2.25%, Bank of America Amortizing Term Loan, Due April 1, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Notes payable, maturity date	1-Apr-17	1-Apr-17
LIBOR Plus 1.75 to 2.25%, Bank of America Amortizing Term Loan, Due April 1, 2017 [Member] \| Minimum [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Changes in interest rate on amount outstanding	1.75%	1.75%
LIBOR Plus 1.75 to 2.25%, Bank of America Amortizing Term Loan, Due April 1, 2017 [Member] \| Maximum [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Changes in interest rate on amount outstanding	2.25%	2.25%
6.16%, Allstate/ CUNA Senior Unsecured Notes, Due June 29, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Changes in interest rate, percentage	6.16%	6.16%
Notes payable, maturity date	29-Jun-17	29-Jun-17
5.38%, Sun Life Fixed Rate Note, Due June 1, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Changes in interest rate, percentage	5.38%	5.38%
Notes payable, maturity date	1-Jun-17	1-Jun-17
LIBOR Plus 3.85%, Sun Life Floating Rate Note, Due May 3, 2014 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Changes in interest rate on amount outstanding	3.85%	3.85%
Notes payable, maturity date	3-May-14	3-May-14
4.15% Sun Life Senior Secured Guaranteed Note, Due June 1, 2017 [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Changes in interest rate, percentage	4.15%	4.15%
Notes payable, maturity date	1-Jun-17	1-Jun-17

Credit_Facilities_and_LongTerm5

Credit Facilities and Long-Term Debt - Notes Payable - Additional Information (Detail) (Note Payable [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Bank of America [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Term loan amortized per quarter	'	$125,000
Weighted average interest rate on term loan	2.19%	2.14%
Interest expense	215,593	56,226
Allstate/CUNA [Member] \| Senior Unsecured Note [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Interest expense	800,800	800,800
Sun Life Assurance Company of Canada [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Interest expense	824,969	824,969
Sun Life Assurance Company of Canada [Member] \| Senior Secured Guaranteed Floating Rate [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Interest expense	123,850	129,200
Weighted average interest rate	4.13%	4.31%
Sun Life Assurance Company of Canada [Member] \| Senior Secured Guaranteed Note [Member]	'	'
Summary of outstanding long-term debt balances	'	'
Interest expense	$123,007	$23,576

Credit_Facilities_and_LongTerm6

Credit Facilities and Long-Term Debt - Schedule of Aggregate Future Maturities of Notes Payable (Detail) (USD $)	Dec. 31, 2013
Long Term Debt By Maturity [Abstract]	'
2014	$3,502,190
2015	500,000
2016	500,000
2017	39,198,552
2018	'
Thereafter	'
Total	$43,700,742

Credit_Facilities_and_LongTerm7

Credit Facilities and Long-Term Debt - Debt Covenants - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2011
	DebtServiceAccounts	Dec. 31, 2012	Mar. 31, 2011
Sun Life Assurance Company of Canada [Member]	'	'	'
Summary of outstanding long-term debt balances	'	'	'
Number of debt service reserve accounts	2	'	'
Interest payment period	'1 year	'	'
Debt service reserve account	$1,100,000	$1,100,000	'
Irrevocable letter of credit	750,000	'	'
Maximum percentage of dividend distribution redemptions of net income	70.00%	'	'
Maximum capitalized leases and purchase money obligations	'	'	500,000
Maximum limit for sale or transfer of assets	1.00%	'	'
Percentage of maximum limit of making acquisition	10.00%	'	'
Sun Life Assurance Company of Canada [Member] \| Maximum [Member]	'	'	'
Summary of outstanding long-term debt balances	'	'	'
Debt to capitalization rate	60.00%	'	'
Interest coverage ratio	2	'	'
Sun Life Assurance Company of Canada [Member] \| Minimum [Member]	'	'	'
Summary of outstanding long-term debt balances	'	'	'
Interest coverage ratio	1	'	'
Bank of America [Member]	'	'	'
Summary of outstanding long-term debt balances	'	'	'
Maximum debt to capital ratio	0.55	'	'
Interest coverage ratio	2	'	'
Maximum capital lease borrowing obligation	500,000	'	'
Maximum other borrowing obligation	$1,000,000	'	'
Period consider for distribution and redemption restriction	'60 months	'	'
Percent of net income consider for distribution and redemption restriction	80.00%	'	'
Maximum percent of assets disposal restriction in fiscal year	5.00%	'	'
Allstate/CUNA [Member]	'	'	'
Summary of outstanding long-term debt balances	'	'	'
Total dividends and distributions made in the immediately preceding period	'60 months	'	'
Allstate/CUNA [Member] \| Maximum [Member]	'	'	'
Summary of outstanding long-term debt balances	'	'	'
Aggregate consolidated net income	100.00%	'	'
Debt to capitalization rate	65.00%	'	'
Interest coverage ratio	150.00%	'	'

Stockholders_Equity_Additional

Stockholders' Equity - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Maximum shares buy back ability	448,500	'	'
Shares repurchased	0	0	'
Options outstanding	5,000	35,000	35,000
Number of options granted during period	'	'	'
Number of stock options exercised	20,000	'	'
Exercise of stock options	$159,500	'	'
Compensation expense for stock option	3,231	9,406	'
Compensation expense for stock option net of tax	2,032	5,832	'
Total unrecognized compensation cost	0	3,231	'
Gas Natural Inc.[Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Exercise of stock options	159,500	'	'
Restricted net assets	97,479,775	'	'
Sun Life Assurance Company of Canada [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Maximum percentage of dividend distribution redemptions of net income	70.00%	'	'
Restricted net assets	80,331,499	'	'
Percentage of investment in restricted net assets	82.40%	'	'
Two Thousand Two Stock Option Plan [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Stock option expired	4-Oct-12	'	'
Number of common shares issued subject to adjustment	'	300,000	'
Options outstanding	5,000	35,000	'
Number of options granted during period	0	0	'
Number of stock options exercised	20,000	'	'
Exercise of stock options	$159,500	'	'
2012 Incentive and Equity Award Plan [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Number of common shares issued subject to adjustment	500,000	'	'
Number of options granted during period	0	'	'
Option price fair value for common stock percentage	100.00%	'	'
Period of stock option granted	'5 years	'	'
Stock option granted, shares of common stock	10.00%	'	'
Performance measurement period	'1 year	'	'
2012 Non-Employee Director Stock Award Plan [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Number of common shares issued subject to adjustment	250,000	'	'
Number of options granted during period	0	'	'
Maximum [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Options vest period	'5 years	'	'
Options exercisable period	'10 years	'	'
Maximum [Member] \| 2012 Incentive and Equity Award Plan [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Common stock exercise term	'10 years	'	'
Minimum [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Options vest period	'4 years	'	'
Options exercisable period	'5 years	'	'

Stockholders_Equity_Summary_of

Stockholders' Equity - Summary of Status of Outstanding Stock Options (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Share Based Compensation Arrangement By Share Based Payment Award Options Outstanding [Roll Forward]	'	'
Number of Shares Outstanding, Beginning Balance	35,000	35,000
Granted, Number of Shares	'	'
Exercised, Number of Shares	-20,000	'
Expired, Number of Shares	-10,000	'
Number of Shares Outstanding, Ending Balance	5,000	35,000
Weighted Average Exercise Price Outstanding, Beginning Balance	$8.66	$8.66
Exercisable, Number of Shares Outstanding	5,000	'
Granted, Weighted Average Exercise Price	'	'
Exercised, Weighted Average Exercise Price	$7.98	'
Expired, Weighted Average Exercise Price	$10.15	'
Weighted Average Exercise Price Outstanding, Ending Balance	$8.44	$8.66
Aggregate Intrinsic Value Outstanding, Beginning Balance	$31,550	'
Exercisable, Weighted Average Exercise Price	$8.44	'
Aggregate Intrinsic Value Outstanding, Ending Balance	0	31,550
Exercisable, Aggregate Intrinsic Value	$0	'

Stockholders_Equity_Summary_of1

Stockholders' Equity - Summary of Status of Options Outstanding (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	6/3/2009 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Grant Date	'	'	'	6-Mar-09
Exercise Price	'	'	'	$8.44
Number Outstanding	5,000	35,000	35,000	5,000
Weighted Average Exercise Price	$8.44	$8.66	$8.66	$8.44
Weighted Average Remaining Contractual Life (Years)	'	'	'	'5 months 1 day
Number Exercisable	5,000	'	'	5,000
Weighted Average Exercise Price	'	'	'	$8.44

Employee_Benefit_Plans_Additio

Employee Benefit Plans - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Compensation And Retirement Disclosure [Abstract]	'	'
Annual contribution of employees salaries	3.00%	'
Discretionary contributions made by an employer to a defined contribution plan	3.00%	'
Expense related to plan	$382,400	$362,160
Company makes matching contributions in form of common stock, percent	10.00%	'
Company makes matching contributions in form of common stock	57,590	52,719
Contribution to ESOP by company	0	0
Maximum age criteria for retirees to remain on the same medical plan to retain coverage	'65 years	'
Defined postretirement health benefit plan	125	'
Minimum age criteria for retirees to remain on the same medical plan to retain coverage	'60 years	'
Percentage rate of contribution retirees health plan	125.00%	'
Value of plan assets	$155,750	$163,313

Income_Taxes_Summary_of_Signif

Income Taxes - Summary of Significant Components of Deferred Tax Assets and Liabilities (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Deferred Tax Assets Liabilities Net [Abstract]	'	'
Allowance for doubtful accounts (current)	$724,534	$524,677
Contributions in aid of construction (current)	'	'
Other nondeductible accruals (current)	47,484	66,278
Recoverable purchase gas costs (current)	60,903	434,995
Net operating loss carryforwards (current)	'	'
Property tax (current)	154,146	'
Other (current)	754,235	709,778
Total deferred tax assets (current)	1,741,302	1,735,728
Recoverable purchase gas costs (current)	454,795	867,075
Property, plant and equipment (current)	'	'
Unrealized gain on securities available for sale (current)	61,475	39,923
Amortization of intangibles (current)	'	'
Other (current)	'	'
Total deferred tax liabilities (current)	516,270	906,998
Net deferred tax asset (liability) before valuation allowance (current)	1,225,032	828,730
Less: valuation allowance (current)	'	'
Total deferred tax asset (liability)	1,225,032	828,730
Discontinued operations	'	-14,884
Net deferred tax asset (liability), continuing operations	1,225,032	813,846
Allowance for doubtful accounts (non current)	'	'
Contributions in aid of construction (non current)	1,652,760	742,152
Other nondeductible accruals (non current)	'	'
Recoverable purchase gas costs (non current)	'	'
Net operating loss carryforwards (non current)	7,733,763	5,439,748
Property tax (non current)	'	153,967
Other (non current)	'	595,918
Total deferred tax assets (non current)	9,386,523	6,587,382
Recoverable purchase gas costs (non current)	'	'
Property, plant and equipment (non current)	11,402,464	6,369,450
Unrealized gain on securities available for sale (non current)	'	'
Amortization of intangibles (non current)	539,498	418,181
Other (non current)	800,698	519,814
Total deferred tax liabilities (non current)	12,742,660	7,307,445
Net deferred tax asset (liability) before valuation allowance (non current)	-3,356,137	-720,063
Less: valuation allowance (non current)	-5,699,029	-4,175,072
Total deferred tax asset (liability)	-9,055,166	-5,144,002
Discontinued operations	'	547,373
Net deferred tax asset (liability), continuing operations	($9,055,166)	($4,596,629)

Income_Taxes_Summary_of_Income

Income Taxes - Summary of Income Tax Expense from Continuing Operations (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Current income tax expense (benefit):	'	'
Federal	($344,342)	($150,224)
State	120,753	245,483
Total current income tax expense (benefit)	-223,589	95,259
Deferred income tax expense:	'	'
Federal	3,692,413	2,030,525
State	-200,217	252,403
Total deferred income tax expense	3,492,196	2,282,928
Total income taxes before credits	3,268,607	2,378,187
Investment tax credit, net	-21,062	-21,062
Total income tax expense	3,247,545	2,357,125
Discontinued operations	144,353	293,444
Income tax expense from continuing operations	$3,391,898	$2,650,569

Income_Taxes_Federal_Statutory

Income Taxes - Federal Statutory Rate to Pre-Tax Income from Continuing Operations (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation [Abstract]	'	'
Tax expense at statutory rate of 34%	$372,404	$2,065,991
State income tax, net of federal tax expense	348,151	228,051
Amortization of deferred investment tax credits	-21,062	-21,062
Change in valuation allowance	-237,557	-262,343
Permanent differences	134,583	140,211
State rate change	-346,149	'
Other	-2,825	206,277
Total income tax expense	3,247,545	2,357,125
Discontinued operations	144,353	293,444
Income tax expense from continuing operations	$3,391,898	$2,650,569

Income_Taxes_Federal_Statutory1

Income Taxes - Federal Statutory Rate to Pre-Tax Income from Continuing Operations (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation [Abstract]	'	'
Statutory income tax rate	34.00%	34.00%

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	12 Months Ended
Income Taxes - Additional Information (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Income Tax [Line Items]	'	'
State rate change	($346,149)	'
Change in valuation allowance	-237,557	-262,343
Net operating losses expiration date	'Net operating losses begin to expire in 2024	'
Valuation Allowance	96,000	'
Carryover tax basis amount	26,800,000	'
Adjustments recognized for uncertain tax benefits	0	0
Duration for which no material changes to unrecognized tax positions are expected	'12 months	'
North Carolina and Kentucky [Member]	'	'
Income Tax [Line Items]	'	'
State rate change	336,007	'
Frontier Utilities [Member]	'	'
Income Tax [Line Items]	'	'
Gross deferred tax assets and net operating losses from acquisition	98,000,000	'
Valuation allowance	100.00%	'
Net increase to valuation allowance	1,761,514	'
Change in valuation allowance	237,557	'
Total expense from the change in valuation allowance	1,523,957	'
Frontier Utilities [Member] \| NORTH CAROLINA	'	'
Income Tax [Line Items]	'	'
Increase in deferred tax asset allowance	1,970,586	'
Domestic Tax Authority [Member]	'	'
Income Tax [Line Items]	'	'
Net operating loss carryover	10,200,000	'
State and Local Jurisdiction [Member]	'	'
Income Tax [Line Items]	'	'
Net operating loss carryover	66,800,000	'
State deferred tax asset valuation allowance, against the state net operating loss carryover	3,900,000	'
State deferred tax asset valuation allowance on the carryover tax basis of the subsidiaries	$1,700,000	'

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

Mar. 05, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Oct. 07, 2013

Dec. 31, 2013

Dec. 18, 2013

Dec. 31, 2013

Dec. 31, 2012

Mar. 05, 2013

John D. Oil and Gas Marketing [Member]

Employee [Member]

OsAir [Member]

Cobra Pipeline [Member]

Affiliated Entity [Member]

8500 Station Street [Member]

sqft

Related Party Transaction [Line Items]

Purchase of Matchworks Building in Mentor, Ohio

$1,900,000

Principal balance due

35,409

95,665

Balance due within one year

1,938

10,998

1,938

Annual interest rate

4.00%

Amortization schedule for payments

'30 years

Maturity date of note receivable

1-Dec-17

Agreement date to lease pipeline from John D. Oil and Gas Marketing

31-Dec-16

Lease expense

5,500

13,200

Office space in square feet

6,472

Monthly lease rental payments

5,500

2,000

Lessee arrangements term of contract

'3 years

Description of lessee arrangement

'Pursuant to the agreement, 8500 Station Street leases to OsAir approximately 6,472 square feet of office space located at 8500 Station Street, Mentor, Ohio 44060, at a rent of $5,500 per month for a period of three years starting from March 1, 2013. The lease agreement is not subject to renewal following the end of the term.

'Pursuant to the lease agreement, Cobra leases to Orwell approximately 2,400 square feet of warehouse space located at 2412 Newton Falls Rd., Newton Falls, OH 44444, at a rent of $2,000 per month for the time period commencing on December 18, 2013 and ending on February 29, 2016. Following the end of the initial term, the lease agreement will continue on a month-to-month basis until either party decides to terminate it upon 30 days' advance written notice to the other party.

Warehouse space in square feet

2,400

Accrued liability, related parties

595,240

Stock sale expense

$309,432

$274,213

$309,432

$274,213

Related_Party_Transactions_Amo

Related Party Transactions - Amounts Due from and Due to Related Parties (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	$146,225	$522,557
Accounts Payable, Total	559,933	47,929
Amounts included in discontinued operations [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	'	'
Accounts Payable, Total	'	3,868
Amounts included in continuing operations [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	146,225	522,557
Accounts Payable, Total	559,933	47,929
John D. Oil and Gas Marketing [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	'	3,282
Accounts Payable, Total	'	40,518
Cobra Pipeline [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	131,208	21,698
Accounts Payable, Total	76,909	'
Orwell Trumbell Pipeline [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	'	90,385
Accounts Payable, Total	122,693	'
Great Plains Exploration [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	7,033	142,740
Accounts Payable, Total	73,983	9
Big Oats Oil Field Supply [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	4,945	769
Accounts Payable, Total	179,447	11,270
Kykuit Resources [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	'	98,037
Accounts Payable, Total	'	'
John D. Oil and Gas Company [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	91	'
Accounts Payable, Total	82,188	'
Sleepy Hollow Oil & Gas [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	'	143,697
Accounts Payable, Total	'	'
Other [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	2,948	21,949
Accounts Payable, Total	24,713	'
Total related party balances [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts Receivable, Total	146,225	522,557
Accounts Payable, Total	$559,933	$51,797

Related_Party_Transactions_Sum

Related Party Transactions - Summary of Related Party Transactions (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	$4,685,813	$4,715,091
Pipeline Construction Purchases	3,252,161	1,247,313
Rent, Supplies, Consulting and Other Purchases	798,271	662,923
Natural Gas Sales	203,362	67,549
Rental Income and Other Sales	234,499	64,664
Cobra Pipeline [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	842,620	389,233
Pipeline Construction Purchases	263,574	5,390
Rent, Supplies, Consulting and Other Purchases	20,000	5,104
Natural Gas Sales	157,834	'
Rental Income and Other Sales	381	23,210
Orwell Trumbell Pipeline [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	795,190	526,785
Pipeline Construction Purchases	'	132
Rent, Supplies, Consulting and Other Purchases	'	19,547
Natural Gas Sales	1,260	26,519
Rental Income and Other Sales	33,911	4,785
Great Plains Exploration [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	856,696	506,503
Pipeline Construction Purchases	854	'
Rent, Supplies, Consulting and Other Purchases	1,341	'
Natural Gas Sales	9,310	7,068
Rental Income and Other Sales	47,640	10,643
Big Oats Oil Field Supply [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	'	'
Pipeline Construction Purchases	2,967,705	1,231,921
Rent, Supplies, Consulting and Other Purchases	624,147	256,607
Natural Gas Sales	3,996	2,131
Rental Income and Other Sales	5,125	7,068
John D. Oil and Gas Company [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	911,507	502,897
Pipeline Construction Purchases	5,975	'
Rent, Supplies, Consulting and Other Purchases	'	'
Natural Gas Sales	572	575
Rental Income and Other Sales	29,356	'
Sleepy Hollow Oil & Gas [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	'	'
Pipeline Construction Purchases	'	'
Rent, Supplies, Consulting and Other Purchases	'	'
Natural Gas Sales	'	'
Rental Income and Other Sales	'	5,113
OsAir [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	241,693	248,588
Pipeline Construction Purchases	13,200	'
Rent, Supplies, Consulting and Other Purchases	91,850	196,451
Natural Gas Sales	4,866	2,479
Rental Income and Other Sales	72,787	306
Other [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	86,987	135,927
Pipeline Construction Purchases	853	'
Rent, Supplies, Consulting and Other Purchases	44,334	127,171
Natural Gas Sales	20,054	28,777
Rental Income and Other Sales	45,299	411
John D. Oil and Gas Marketing [Member]	'	'
Related Party Transaction [Line Items]	'	'
Natural Gas Purchases	951,120	2,405,158
Pipeline Construction Purchases	'	9,870
Rent, Supplies, Consulting and Other Purchases	16,599	58,043
Natural Gas Sales	5,470	'
Rental Income and Other Sales	'	$13,128

Segments_of_Operations_Summary

Segments of Operations - Summary of Financial Information for Operating Segments (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]	'	'
Total cost of sales	$71,289,637	$48,438,959
GROSS MARGIN	47,545,127	40,762,286
Distribution, general and administrative	23,575,818	20,815,855
Maintenance	1,317,792	1,191,038
Depreciation and amortization	6,135,160	5,026,142
Accretion	175,974	161,298
Unrealized holding gain	-1,565,000	'
Goodwill impairment	725,744	'
Taxes other than income	4,003,468	3,478,897
Total operating expenses	34,271,122	30,673,230
OPERATING INCOME (LOSS)	13,274,005	10,089,056
Other income (expense)	338,053	-817,879
Interest expense	-3,178,606	-2,700,193
Income (loss) before taxes	10,433,452	6,570,984
Income tax benefit (expense)	-3,391,898	-2,650,569
INCOME (LOSS) FROM CONTINUING OPERATIONS	7,041,554	3,920,415
Discontinued operations, net of income tax	-370,275	-201,098
NET INCOME (LOSS)	6,671,279	3,719,317
Capital expenditures	24,103,789	20,654,184
Total operating revenue	118,834,764	89,201,245
Investment in unconsolidated affiliate	351,724	321,731
Total assets	203,743,615	174,463,459
Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	79,708,728	54,688,158
Total operating revenue	127,253,855	95,450,444
Investment in unconsolidated affiliate	351,724	321,731
Total assets	290,712,886	247,478,816
Intersegment Elimination [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	-8,419,091	-6,249,199
Total operating expenses	-97,834	'
Interest expense	-3,178,606	'
Total operating revenue	-8,419,091	-6,249,199
Total assets	-86,969,271	-73,015,357
Natural Gas Operations [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	61,236,772	42,485,803
GROSS MARGIN	45,027,837	38,820,148
Distribution, general and administrative	21,476,833	19,806,389
Maintenance	1,305,897	1,176,189
Depreciation and amortization	5,603,639	4,662,313
Accretion	125,130	113,106
Taxes other than income	3,910,335	3,366,238
Total operating expenses	32,408,090	29,124,235
OPERATING INCOME (LOSS)	12,619,747	9,695,913
Other income (expense)	804,989	418,822
Interest expense	'	-2,512,444
Income (loss) before taxes	10,543,518	7,602,291
Income tax benefit (expense)	-3,346,726	-3,135,445
INCOME (LOSS) FROM CONTINUING OPERATIONS	7,196,792	4,466,846
NET INCOME (LOSS)	7,196,792	4,466,846
Capital expenditures	23,825,593	18,381,644
Total operating revenue	106,264,609	81,305,951
Total assets	141,549,023	123,278,060
Natural Gas Operations [Member] \| Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	61,563,103	42,810,640
Total operating revenue	106,590,940	81,630,788
Total assets	195,219,938	169,616,395
Natural Gas Operations [Member] \| Intersegment Elimination [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	-326,331	-324,837
Total operating expenses	-13,744	'
Interest expense	-2,881,218	'
Total operating revenue	-326,331	-324,837
Total assets	-53,670,915	-46,338,335
Marketing and Production [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	10,052,865	5,953,156
GROSS MARGIN	2,114,376	1,540,205
Distribution, general and administrative	801,305	449,665
Maintenance	2,765	1,014
Depreciation and amortization	456,790	268,202
Accretion	50,844	48,192
Unrealized holding gain	-1,565,000	'
Goodwill impairment	725,744	'
Taxes other than income	28,113	38,052
Total operating expenses	500,561	805,125
OPERATING INCOME (LOSS)	1,613,815	735,080
Other income (expense)	151,168	-6,051
Interest expense	'	-133,440
Income (loss) before taxes	1,622,952	595,589
Income tax benefit (expense)	-586,326	4,542
INCOME (LOSS) FROM CONTINUING OPERATIONS	1,036,626	600,131
NET INCOME (LOSS)	1,036,626	600,131
Capital expenditures	217,201	1,393,040
Total operating revenue	12,167,241	7,493,361
Total assets	7,955,233	8,338,698
Marketing and Production [Member] \| Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	18,145,625	11,877,518
Total operating revenue	20,260,001	13,417,723
Investment in unconsolidated affiliate	351,724	321,731
Total assets	11,633,544	8,786,247
Marketing and Production [Member] \| Intersegment Elimination [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total cost of sales	-8,092,760	-5,924,362
Interest expense	-142,031	'
Total operating revenue	-8,092,760	-5,924,362
Total assets	-3,678,311	-447,549
Pipeline Operations [Member]	'	'
Segment Reporting Information [Line Items]	'	'
GROSS MARGIN	402,914	401,933
Distribution, general and administrative	105,249	87,640
Maintenance	9,130	13,835
Depreciation and amortization	62,061	61,085
Taxes other than income	40,507	35,497
Total operating expenses	216,947	198,057
OPERATING INCOME (LOSS)	185,967	203,876
Interest expense	'	-13,528
Income (loss) before taxes	160,090	190,348
Income tax benefit (expense)	-39,161	-97,523
INCOME (LOSS) FROM CONTINUING OPERATIONS	120,929	92,825
NET INCOME (LOSS)	120,929	92,825
Capital expenditures	3,186	23,141
Total operating revenue	402,914	401,933
Total assets	657,660	616,393
Pipeline Operations [Member] \| Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total operating revenue	402,914	401,933
Total assets	685,760	632,466
Pipeline Operations [Member] \| Intersegment Elimination [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Interest expense	-25,877	'
Total assets	-28,100	-16,073
Corporate and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Distribution, general and administrative	1,192,431	472,161
Depreciation and amortization	12,670	34,542
Taxes other than income	24,513	39,110
Total operating expenses	1,145,524	545,813
OPERATING INCOME (LOSS)	-1,145,524	-545,813
Other income (expense)	-618,104	-1,230,650
Interest expense	'	-40,781
Income (loss) before taxes	-1,893,108	-1,817,244
Income tax benefit (expense)	580,315	577,857
INCOME (LOSS) FROM CONTINUING OPERATIONS	-1,312,793	-1,239,387
Discontinued operations, net of income tax	-370,275	-201,098
NET INCOME (LOSS)	-1,683,068	-1,440,485
Capital expenditures	57,809	856,359
Total assets	53,581,699	42,230,308
Corporate and Other [Member] \| Operating Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total assets	83,173,644	68,443,708
Corporate and Other [Member] \| Intersegment Elimination [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Total operating expenses	-84,090	'
Interest expense	-129,480	'
Total assets	($29,591,945)	($26,213,400)

Commitments_and_Contingencies_1

Commitments and Contingencies - Schedule of Future Minimum Lease Payments (Detail) (USD $)	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'
2014	$253,833
2015	229,711
2016	125,906
2017	121,080
2018	120,633
Thereafter	537,392
Total minimum lease payments required	1,388,555
2014	300,000
2015	300,000
2016	300,000
2017	300,000
2018	300,000
Thereafter	1,200,000
Total minimum lease payments required	2,700,000
Less: Interest portion	-659,492
Liability	$2,040,508

Commitments_and_Contingencies_2

Commitments and Contingencies - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010	Jun. 30, 2013
Commitments Contingencies And Litigation [Line Items]	'	'	'	'
Lease expense resulting from operating leases	$304,783	$537,097	'	'
Future lease payment, per year	300,000	'	'	'
Due period of first annual installment payment beginning from first anniversary of commencement date	'30 days	'	'	'
Due period of subsequent annual installment payments beginning from each subsequent anniversary of commencement date	'30 days	'	'	'
Initial term of agreement	'16 years	'	'	'
Option to renew of agreement term	2	'	'	'
Additional term of agreement	'16 years	'	'	'
Facility service fee to be paid each year	0	0	'	'
Due period of facility service fee payment beginning from first anniversary of commencement date	'30 days	'	'	'
Throughput charge	0.0125	'	'	'
Throughput charge payments during period	0	0	'	'
Amortization of leased assets	401,270	100,317	'	'
Cost of evaluation and remediation	24,000	25,000	'	'
Insurance premium paid before any losses covered	250,000	'	'	'
Minimum period of relief for economic loss	'4 years	'	'	'
Over (Under) Recovered Gas Costs	-639,375	834,814	'	'
Accounts receivable trade from large industrial customer under chapter 11 bankruptcy protection	1,059,224	1,139,778	'	'
Allowance for doubtful accounts receivable for large industrial customer covered under bankruptcy protection act	1,421,000	774,000	'	'
Accounts receivable from customer under bankruptcy protection	178,546	'	'	'
NEO [Member]	'	'	'	'
Commitments Contingencies And Litigation [Line Items]	'	'	'	'
Over (Under) Recovered Gas Costs	'	'	-1,100,000	'
Unrecovered costs for purchased gas amount for audit adjustment	234,253.42	707,002	'	'
Liability of customers	'	'	'	943,550
Valuation adjustments	800,000	'	'	'
Increase in initial estimated liability	300,000	'	'	'
Civil forfeitures imposed for NEO and Orwell	26,000	'	'	'
Orwell [Member]	'	'	'	'
Commitments Contingencies And Litigation [Line Items]	'	'	'	'
Over (Under) Recovered Gas Costs	'	'	1,000,000	'
Refundable gas costs for audit adjustment	0	237,175	'	'
Liability of customers	'	'	'	251,081
Valuation adjustments	200,000	'	'	'
Civil forfeitures imposed for NEO and Orwell	50,000	'	'	'
Brainard [Member]	'	'	'	'
Commitments Contingencies And Litigation [Line Items]	'	'	'	'
Refundable gas costs for audit adjustment	104,000	'	'	'
Recoverable refundable gas costs	0	99,479	'	'
Minimum [Member]	'	'	'	'
Commitments Contingencies And Litigation [Line Items]	'	'	'	'
Expected future cost of services environmental remediation for 2014	7,000	'	'	'
Liability of customers	1,500,000	'	'	'
Increase in initial estimated liability	300,000	'	'	'
Maximum [Member]	'	'	'	'
Commitments Contingencies And Litigation [Line Items]	'	'	'	'
Maximum guarantee obligation for gas supply	6,000,000	'	'	'
Expected future cost of services environmental remediation for 2014	23,000	'	'	'
Liability of customers	1,900,000	'	'	'
Increase in initial estimated liability	$1,500,000	'	'	'

Commitments_and_Contingencies_3

Commitments and Contingencies - Summary of Cost Basis and Accumulated Depreciation of Assets Recorded under Capital Leases (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Capital Leased Assets [Line Items]	'	'
Capital lease assets, gross	$6,320,000	$6,320,000
Accumulated depreciation	-501,587	-100,317
Capital lease assets, net	5,818,413	6,219,683
Gas, Transmission & Distribution Equipment [Member]	'	'
Capital Leased Assets [Line Items]	'	'
Capital lease assets, gross	$6,320,000	$6,320,000

Commitments_and_Contingencies_4

Commitments and Contingencies - Summary of Future Minimum Long-term Contract Obligations (Detail) (USD $)	Dec. 31, 2013
Northwestern Energy [Member]	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'
2014	$1,517,892
2015	1,434,680
2016	519,356
2017	519,356
2018	476,076
Thereafter	'
Total	4,467,360
Trans-Canada [Member]	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'
2014	921,977
2015	829,775
2016	368,768
2017	368,768
2018	338,036
Thereafter	'
Total	2,827,324
Maritimes and Northeast Pipeline [Member]	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'
2014	575,622
2015	357,042
2016	357,042
2017	357,042
2018	357,042
Thereafter	357,042
Total	$2,360,832

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	12 Months Ended		0 Months Ended			1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Mar. 26, 2014	Feb. 28, 2014	Jan. 30, 2014	Apr. 30, 2014	Mar. 31, 2014	Feb. 28, 2014	Apr. 15, 2014	Mar. 14, 2014	Feb. 14, 2014
	Dec. 31, 2013	Dec. 31, 2012	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Dividend declared per share	'	'	$0.05	$0.05	$0.05	'	'	$0.05	'	'	'
Shares outstanding	10,451,678	8,369,752	'	'	'	'	'	'	10,451,678	10,451,678	10,451,678
Dividend paid	$5,005,827	$4,432,920	'	'	'	$470,326	$470,326	$470,326	'	'	'
Dividend payable record date	'	'	15-Apr-14	14-Mar-14	14-Feb-14	'	'	'	'	'	'