Gas Natural 10-K 12 Mar 15 2014 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Mar. 06, 2015	Jun. 30, 2014
Document Information [Line Items]
Entity Registrant Name	Gas Natural Inc.
Entity Central Index Key	43350
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Trading Symbol	EGAS
Entity Common Stock, Shares Outstanding		10,451,678
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2014
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$106,590,580

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
CURRENT ASSETS
Cash and cash equivalents	$1,585,926	$12,741,197
Marketable securities	0	406,134
Accounts receivable
Trade, less allowance for doubtful accounts of $370,909 and $1,978,358, respectively	12,111,026	12,305,657
Related parties	234,610	146,225
Unbilled gas	7,630,852	7,172,062
Note receivable, current portion	2,070	1,938
Inventory
Natural gas	5,301,895	4,996,065
Materials and supplies	2,300,990	2,285,722
Prepaid income taxes	431,681	727,427
Prepayments and other	986,941	970,574
Regulatory assets, current	4,097,822	1,209,982
Deferred tax asset	635,195	1,225,032
Assets held for sale	802,436	0
Discontinued operations	11,653,934	12,032,203
Total current assets	47,775,378	56,220,218
PROPERTY, PLANT, & EQUIPMENT, NET	142,011,085	124,587,645
OTHER ASSETS
Notes receivable, less current portion	90,345	93,727
Regulatory assets, non-current	2,055,404	452,047
Debt issuance costs, net of amortization	1,079,447	1,388,124
Goodwill	16,155,672	16,267,377
Customer relationships, net of amortization	2,927,500	3,230,333
Investment in unconsolidated affiliate	0	351,724
Restricted cash	1,897,677	1,137,442
Other assets	11,404	3,160
Total other assets	24,217,449	22,923,934
TOTAL ASSETS	214,003,912	203,731,797
CURRENT LIABILITIES
Checks in excess of amounts on deposit	194,524	842,443
Line of credit	28,760,799	24,529,799
Accounts payable
Trade	14,115,367	12,355,605
Related parties	170,319	559,933
Notes payable, current portion	542,201	3,502,190
Contingent consideration, current	671,638	671,638
Derivative instruments	3,023,271	0
Accrued liabilities	4,860,663	5,751,594
Accrued liabilities - related parties	111,133	0
Customer deposits, current	634,090	667,479
Obligation under capital lease, current	188,224	177,570
Regulatory liability, current	925,175	793,184
Build-to-suit liability	5,597,287	0
Other current liabilities	940,643	1,464,646
Liabilities held for sale	61,416	0
Discontinued operations	544,432	574,889
Total current liabilities	61,341,182	51,890,970
LONG-TERM LIABILITIES
Deferred investment tax credits	113,193	134,255
Deferred tax liability	10,538,394	9,055,166
Asset retirement obligation	1,196,518	1,145,052
Customer advances for construction	993,681	987,265
Regulatory liability, non-current	1,089,850	964,462
Customer deposits	949,540	0
Obligation under capital lease, less current	1,674,714	1,862,938
Contingent consideration, less current	75,362	13,362
Total long-term liabilities	16,631,252	14,162,500
NOTES PAYABLE, less current portion	39,720,860	40,198,552
COMMITMENTS AND CONTINGENCIES (see Note 24)
STOCKHOLDERS' EQUITY
Preferred stock; $0.15 par value; 1,500,000 shares authorized, no shares issued or outstanding	0	0
Common stock; $0.15 par value; Authorized: 30,000,000 and 15,000,000 shares, respectively; Issued: 10,487,511 and 10,451,678 shares, respectively; Outstanding: 10,487,511 and 10,451,678 shares, respectively	1,573,127	1,567,752
Capital in excess of par value	63,826,341	63,468,969
Accumulated other comprehensive income	0	104,909
Retained earnings	30,911,150	32,338,145
Total stockholders' equity	96,310,618	97,479,775
TOTAL CAPITALIZATION	136,031,478	137,678,327
TOTAL LIABILITIES AND CAPITALIZATION	$214,003,912	$203,731,797

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets [Parenthetical] (USD $)	Dec. 31, 2014	Dec. 31, 2013
Allowance for doubtful accounts	$370,909	$1,978,358
Preferred stock, par value (in dollars per share)	$0.15	$0.15
Preferred stock, shares authorized	1,500,000	1,500,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value (in dollars per share)	$0.15	$0.15
Common stock, shares authorized	30,000,000	15,000,000
Common stock, shares issued	10,487,511	10,451,678
Common stock, shares outstanding	10,487,511	10,451,678

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
REVENUES
Natural gas operations	$123,052,554	$97,233,112	$73,900,481
Marketing and production	9,517,287	12,167,241	7,493,361
Total revenues	132,569,841	109,400,353	81,393,842
COST OF SALES
Natural gas purchased	79,096,553	55,977,154	38,552,607
Marketing and production	8,620,826	10,052,865	5,953,156
Total cost of sales	87,717,379	66,030,019	44,505,763
GROSS MARGIN	44,852,462	43,370,334	36,888,079
OPERATING EXPENSES
Distribution, general, and administrative	24,769,623	21,308,592	18,512,126
Maintenance	1,225,491	1,142,261	995,072
Depreciation and amortization	6,604,569	5,550,753	4,337,196
Accretion	51,466	57,912	161,298
Taxes other than income	3,928,018	3,671,930	3,188,071
Provision for doubtful accounts	1,112,115	726,434	951,655
Contingent consideration loss (gain)	62,000	-1,565,000	0
Goodwill impairment	0	725,744	0
Total operating expenses	37,753,282	31,618,626	28,145,418
OPERATING INCOME	7,099,180	11,751,708	8,742,661
Loss from unconsolidated affiliate	-351,724	-5,007	-8,620
Gain on sale of marketable securities	183,371	0	0
Acquisition expense	-7,197	-272,094	-959,267
Stock sale expense	0	-309,432	-274,213
Other income, net	579,214	886,832	351,446
Interest expense	-3,226,096	-3,176,155	-2,699,720
Income before income taxes	4,276,748	8,875,852	5,152,287
Income tax expense	-1,547,582	-3,023,711	-1,956,799
INCOME FROM CONTINUING OPERATIONS	2,729,166	5,852,141	3,195,488
Discontinued operations, net of income taxes (See Note 4)	1,032,611	819,138	523,829
NET INCOME	3,761,777	6,671,279	3,719,317
BASIC & DILUTED EARNINGS (LOSS) PER SHARE:
Continuing operations (in dollars per share)	$0.26	$0.63	$0.39
Discontinued operations (in dollars per share)	$0.10	$0.08	$0.07
Net income per share (in dollars per share)	$0.36	$0.71	$0.46
Weighted average dividends declared per common share (in dollars per share)	$0.50	$0.55	$0.54
COMPREHENSIVE INCOME:
Net income	3,761,777	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 $7,689, $22,951 and $8,913, respectively	14,811	39,120	-14,616
Accumulated unrealized gain on available for sale securities transferred to earnings, net of tax of $63,651	-119,720	0	0
Other comprehensive income (loss), net of tax	-104,909	39,120	-14,616
COMPREHENSIVE INCOME	$3,656,868	$6,710,399	$3,704,701

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income [Parenthetical] (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Unrealized gain (loss) on available for sale securities, tax portion	$7,689	$22,951	$8,913
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI for Sale of Securities, Tax	$63,651

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 (in shares) at Dec. 31, 2011		8,154,301
Net income	3,719,317	0	0	0	3,719,317
Other comprehensive income (loss), net	-14,616	0	0	-14,616	0
Stock issued for services	50,602	675	49,927	0	0
Stock issued for services (in shares)		4,500
Stock compensation	9,406	0	9,406	0	0
Purchase of Loring Pipeline	2,250,004	31,643	2,218,361	0	0
Purchase of Loring Pipeline (in shares)		210,951
Dividends declared	-4,442,616	0	0	0	-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 (in shares) at Dec. 31, 2012		8,369,752
Net income	6,671,279	0	0	0	6,671,279
Other comprehensive income (loss), net	39,120	0	0	39,120	0
Exercise of stock options	159,500	3,000	156,500	0	0
Exercise of stock options (in shares)		20,000
Stock compensation	2,962	0	2,962	0	0
Purchase of JDOG Marketing	2,641,199	38,539	2,602,660	0	0
Purchase of JDOG Marketing (in shares)		256,926
Common stock issued	16,721,104	270,750	16,450,354	0	0
Common stock issued (in shares)		1,805,000
Dividends declared	-5,099,513	0	0	0	-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 (in shares) at Dec. 31, 2013	10,451,678	10,451,678
Net income	3,761,777	0	0	0	3,761,777
Other comprehensive income (loss), net	-104,909	0	0	-104,909	0
Exercise of stock options	45,762	750	45,012	0	0
Exercise of stock options (in shares)		5,000
Stock compensation	316,985	4,625	312,360	0	0
Stock compensation (in shares)		30,833
Dividends declared	-5,188,772	0	0	0	-5,188,772
ENDING BALANCE at Dec. 31, 2014	$96,310,618	$1,573,127	$63,826,341	$0	$30,911,150
ENDING BALANCE (in shares) at Dec. 31, 2014	10,487,511	10,487,511

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$3,761,777	$6,671,279	$3,719,317
Less income from discontinued operations	1,032,611	819,138	523,829
Income from continuing operations	2,729,166	5,852,141	3,195,488
Adjustments to reconcile income from continuing operations to net cash provided by operating activities:
Depreciation and amortization	6,604,569	5,550,753	4,337,196
Accretion	51,466	57,912	161,298
Amortization of debt issuance costs	419,953	418,204	275,858
Provision for doubtful accounts	1,112,115	726,434	951,655
Stock based compensation	316,985	2,962	60,009
Gain on sale of marketable securities	-183,371	0	0
Loss (gain) on sale of assets	-28,293	-158,320	61,495
Loss from unconsolidated affiliate	351,724	5,007	8,620
Unrealized holding loss (gain) on contingent consideration	62,000	-1,565,000	0
Change in fair value of derivative financial instruments	150,885	0	0
Investment tax credit	-21,062	-21,062	-21,062
Deferred income taxes	2,135,786	4,024,683	2,261,345
Goodwill impairment	0	725,744	0
Changes in assets and liabilities
Accounts receivable, including related parties	-891,338	-2,187,452	-3,667,888
Unbilled gas	-480,942	-3,009,029	-569,950
Natural gas inventory	-457,611	-388,858	1,700,367
Accounts payable, including related parties	1,817,098	3,111,116	907,843
Regulatory assets & liabilities	-1,938,386	1,039,063	-258,212
Prepayments and other	-24,243	1,076,550	-1,372,244
Other assets	234,751	-464,339	1,006,239
Other liabilities	-815,380	642,788	-1,435,500
Net cash provided by operating activities of continuing operations	11,145,872	15,439,297	7,602,557
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	-21,612,680	-23,516,923	-19,935,982
Proceeds from sale of fixed assets	172,142	968,772	39,485
Proceeds from sale of marketable securities	421,875	0	0
Proceeds from note receivable	3,250	8,681	10,255
Purchase of Public Gas Company, Inc.	0	0	-1,551,477
Cash acquired in acquisition	0	0	502
Investment in unconsolidated affiliate	0	-35,000	0
Restricted cash - capital expenditures fund	57,441	1,264,624	-1,322,065
Customer advances for construction	16,900	12,028	150,920
Contributions in aid of construction	2,262,047	1,105,974	54,532
Net cash used in investing activities of continuing operations	-18,679,025	-20,191,844	-22,553,830
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from lines of credit	24,850,000	22,519,000	51,390,754
Repayments of lines of credit	-20,619,000	-21,848,956	-50,690,999
Proceeds from notes payable	102,000	0	12,989,552
Repayments of notes payable	-3,565,224	-633,498	-7,920
Payments of capital lease obligations	-177,570	-167,518	0
Debt issuance costs	-111,275	-7,607	-1,204,987
Proceeds from issuance of common shares	0	16,721,104	0
Exercise of stock options	45,762	159,500	0
Restricted cash - debt service fund	131,864	748,781	-878,875
Dividends paid	-5,659,098	-5,005,827	-4,432,920
Net cash provided by (used in) financing activities of continuing operations	-5,002,541	12,484,979	7,164,605
DISCONTINUED OPERATIONS
Operating cash flows	1,924,330	658,105	883,724
Investing cash flows	-511,434	1,738,076	-698,503
Financing cash flows	-32,473	-590,059	401,000
Net cash provided by discontinued operations	1,380,423	1,806,122	586,221
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-11,155,271	9,538,554	-7,200,447
Cash and cash equivalents, beginning of period	12,741,197	3,202,643	10,403,090
CASH AND CASH EQUIVALENTS, END OF PERIOD	1,585,926	12,741,197	3,202,643
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest	2,730,385	2,806,051	2,286,902
Cash refunded for income taxes, net	-233,740	-4,050	-989,503
NONCASH INVESTING AND FINANCING ACTIVITIES
Assets acquired under build-to-suit agreement	5,597,314	0	0
Capital expenditures included in accounts payable	1,047,211	1,798,014	745,402
Restricted cash received from customer as security deposit	949,540	0	0
Capital assets exchanged to settle payables	321,971	82,584	0
Capital assets acquired through trade-in	103,154	23,500	0
Capital additions acquired through debt	25,543
Capitalized interest	24,965	6,003	21,147
Customer advances for construction moved to contribution in aid of construction	10,483	16,364	0
Customer relationships acquired from JDOG Marketing purchase	0	2,800,000	0
Contingent consideration issued to purchase JDOG Marketing	0	2,250,000	0
Goodwill acquired from JDOG Marketing purchase	0	2,101,744	0
Accrued dividends	0	470,326	376,639
Note receivable effectively settled in JDOG Marketing acquisition	0	32,145	0
Plant, property and equipment acquired from JDOG Marketing purchase	0	21,600	0
John D. Oil And Gas Marketing [Member]
NONCASH INVESTING AND FINANCING ACTIVITIES
Shares issued to purchase	0	2,641,199	0
Loring Pipeline [Member]
NONCASH INVESTING AND FINANCING ACTIVITIES
Shares issued to purchase	$0	$0	$2,250,004

Summary_of_Business

Summary of Business	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Business and Basis of Presentation	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, Lone Wolfe, 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, and North Carolina as well as non-regulated operations in Maine and Montana. GNR is a natural gas marketing company that markets gas in Ohio and Pennsylvania. 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, 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. 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 three reporting segments:
	⋅	Natural Gas Operations	Annually distributes approximately 26 Bcf of natural gas to approximately 68,000 residential, commercial, and industrial customers through regulated utilities operating in Kentucky, Maine, Montana, North Carolina, Ohio, and Pennsylvania.  Approximately 93%, 89%, and 91% of the Company’s revenue was derived from its regulated natural gas operations for the years ended December 31, 2014, 2013, and 2012, respectively.
	⋅	Marketing & Production	Annually markets approximately 1.3 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 55% gross working interest (average 46% net revenue interest) in 160 natural gas producing wells and gas gathering assets located in Glacier and Toole Counties in Montana.
	⋅	Corporate & Other	Encompasses costs associated with business development and acquisitions, dispositions of subsidiary entities and 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.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
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 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, loss contingencies, 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.
	For build-to-suit leases, the Company evaluates its level of risk during the asset’s construction or development period. If the Company determines that it bears substantially all of the risk during this period, it establishes an asset and liability for the total project costs with the liability reduced by any project costs paid directly by the Company. Once the build-to-suit asset is complete, the Company assesses whether the arrangement qualifies for sales recognition under the sale-leaseback accounting guidance. If the lease meets the criteria to qualify as a sales-lease back transaction, then the asset and liability are removed from the Company’s consolidated balance sheet. If it does not meet the criteria to qualify as a sale-leaseback transaction, then the asset and liability remain on the Company's consolidated balance sheet and the transaction is treated as a financing.
	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, 2014, 2013 and 2012.
	The Company recognizes interest and penalties related to unrecognized tax benefits in operating expense. As of December 31, 2014 and 2013, there were no unrecognized tax benefits nor interest or penalties accrued related to unrecognized tax benefits. For the years ended December 31, 2014, 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 2010 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
	Accounts receivable are generated from sales and delivery of natural gas 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.
	At December 31, 2013, included in the accounts receivable, trade line item on the accompanying Consolidated Balance Sheet was $1,059,224, net of allowance for doubtful accounts of $1,421,000, due from a large industrial customer in bankruptcy proceedings. The Company believed that it had an administrative claim for the unreserved portion and that it was likely to collect the amount. In June 2014, the bankruptcy court denied the Company’s administrative claim on the customer. The Company’s claim is now considered that of an unsecured creditor and as such the Company believes that it is unlikely that it will collect any of the previously unreserved amounts. As a result, the Company has written-off the remaining balance of the receivable. This receivable was related to the Company’s Marketing & Production operating segment. The impact of the amount written-off is reflected in the Provision for doubtful accounts line of the Company’s Consolidated Statement of Comprehensive Income. Total write-offs of receivables for the years ended December 31, 2014, 2013, and 2012 were $2,717,844, $161,674, and $213,855, respectively.
	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.
	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. 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 $557,500 and $254,667 at December 31, 2014 and 2013, respectively. Amortization expense for customer relationships for the years ended December 31, 2014, 2013, and 2012 was $302,833, $186,167 and $22,833. The following table shows the Company’s estimated amortization related to its intangible assets over the next five years.
	Estimated intangible asset amortization expense for the years ended December 31,
	2015	$	302,833
	2016		302,833
	2017		302,833
	2018		302,833
	2019		302,833
	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
	For equity investments in which the Company does not control the investee, but can exert significant influence over the financial and operating policies of the investees, the Company uses the equity method of accounting. Under this accounting treatment, the Company’s share of the investee’s underlying net income or loss is recorded as non-operating income on the Company’s Consolidated Statement of Comprehensive Income with a corresponding increase or decrease in the investment account. Distributions received from the investment reduce the Company’s investment balance.
	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, 2014 and 2013, 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 in the accompanying Consolidated Balance Sheets. The Company amortizes this amount added to property, plant, and equipment. The accretion of the asset retirement liability is allocated to operating expense using a systematic and rational method.
Derivatives and Hedging Activities
ASC 815 - Derivatives and Hedging requires companies to recognize all of its derivative instruments as either assets or liabilities in the statement of financial position at fair value. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and further, on the type of hedging relationship. For those derivative instruments that are designated and qualify as hedging instruments, a company must designate the hedging instrument, based upon the exposure being hedged, as a fair value hedge, cash flow hedge, or a hedge of a net investment in a foreign operation. For derivative instruments not designated as hedging instruments, the gain or loss is recognized in the statement of financial performance during the current period.
The Company is exposed to certain risks relating to its ongoing business operations. The primary risk managed by using derivative instruments is commodity price risk related to natural gas. Forward contracts and commodity price swaps with fixed pricing are entered into by the Company to protect profit margins on future obligations to deliver gas at fixed prices or to protect its regulated utility customers from possible adverse price fluctuations in the market. These forward contracts usually qualify as a “normal purchase” or “normal sale” and are exempt from derivative accounting treatment. The Company’s commodity price swaps do not meet any of the exemption criteria under ASC 815 and are accounted for as derivatives. At December 31, 2014, none of the Company’s derivatives were accounted for as hedging instruments.
Recent Accounting Pronouncements
In May 2014, the FASB issued ASU 2014-09 Revenue from Contracts with Customers, which supersedes nearly all existing revenue recognition guidance under U.S. GAAP. The core principle of ASU 2014-09 is to recognize revenues when promised goods or services are transferred to customers in an amount that reflects the consideration to which an entity expects to be entitled for those goods or services. ASU 2014-09 defines a five step process to achieve this core principle and, in doing so, more judgment and estimates may be required within the revenue recognition process than are required under existing U.S. GAAP. This pronouncement is effective for annual reporting periods beginning after December 15, 2016 and is to be applied using one of two retrospective application methods, with early application not permitted. The Company is currently evaluating the impact of the pending adoption of ASU 2014-09 on the consolidated financial statements.
In April 2014, the FASB issued ASU 2014-08 Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity, which amends the prior guidance of the reclassification of components of an entity to discontinued operations under U.S. GAAP. Under the amended guidance, a disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. The amendment also removes requirements relating to the cessation of operations, cash flows and significant continuing involvement with the discontinued component. This pronouncement is effective for annual and interim periods beginning after December 15, 2014 with early adoption permitted. This update is to be applied prospectively on components classified as held for sale after the adoption date. The Company has chosen to early adopt ASU 2014-08 effective September 30, 2014.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Acquisitions	Note 3 – Acquisitions
	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, father of the Company’s chief executive officer and the Company’s former 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 allowed 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. 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.
	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 GNR 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 GNR’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 GNR’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. The Company’s estimate of the total liability at December 31, 2014 was $747,000. See Note 8 – Fair Value Measurements for details regarding this valuation. The Company calculated first and second year earn-out payments of $671,638 and $0, respectively, as its best estimate for financial reporting purposes. This amount is included in the Contingent consideration, current portion line of the Company’s Consolidated Balance Sheets. The Company does not believe a first year earn-out payment is due to JDOG Marketing as a result of payments made by the Ohio utilities to JDOG Marketing during 2013 that were disallowed by the PUCO. Mr. Osborne believes that JDOG Marketing is entitled to the first year earn-out. Mr. Osborne and JDOG Marketing have filed a suit against the Company for the earn-out payment. See Note 24 – Commitments and Contingencies for more information.
	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. This amount was approximately $21,600. 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 fair value of these contracts was $2.8 million. 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, $2.1 million was allocated to goodwill. The Company expects none of the goodwill to be deductible for tax purposes.
	The results of GNR are included in the Company’s Marketing and Production Operations reporting segment. GNR contributed $4.3 million and $1.9 million to the Company’s revenues for the years ended December 31, 2014 and 2013, respectively, and a loss of $99,000 and income of $765,000 to the Company’s net income, respectively.
	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 and an operating lease agreement. Both of the note receivable and the lease agreement were effectively settled with the completion of the transaction. See Note 21 – Related Party Transactions for more information regarding the Company’s transactions with JDOG Marketing prior to the acquisition.
	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, father of the Company’s chief executive officer and the Company’s former 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 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 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 acquisition provided the Company with 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.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Note 4 – Discontinued Operations
	The following table reconciles the carrying amounts of the major classes of assets and liabilities to the Company’s discontinued operations as presented on its Consolidated Balance Sheet.
		December 31,
		2014		2013
	Current Assets:
	Cash and cash equivalents	$	257,358	$	406,184
	Accounts receivable, net		1,002,918		971,308
	Unbilled gas		735,122		557,498
	Inventory		181,197		748,482
	Prepayments and other		71,101		99,219
	Regulatory assets, current		250,031		88,318
	Total current assets		2,497,727		2,871,009
	Non-Current Assets:
	Property, plant & equipment, net		8,966,965		8,960,986
	Regulatory assets, non-current		155,826		155,826
	Other assets		33,416		44,382
	Total non-current assets		9,156,207		9,161,194
	Total discontinued assets	$	11,653,934	$	12,032,203
	Current Liabilities:
	Checks in excess of amounts on deposit	$	-	$	1,192
	Accounts payable		29,657		62,131
	Accrued liabilities		334,664		429,961
	Other current liabilities		139,318		52,200
	Total current liabilities		503,639		545,484
	Non-Current Liabilities:
	Customer advances for construction		40,793		29,405
	Total discontinued liabilities	$	544,432	$	574,889
	The following table reconciles the carrying amounts of the major line items constituting the pretax profit of discontinued operations to the after-tax profit or loss of discontinued operations that are presented on the Consolidated Statement of Comprehensive Income.
		Year Ended December 31,
		2014		2013		2012
	Revenues	$	10,927,150	$	13,130,554	$	12,422,318
	Cost of sales		-6,696,602		-7,855,827		-7,279,787
	Distribution, general & administrative		-1,559,021		-2,643,821		-2,666,911
	Maintenance		-175,509		-239,321		-263,559
	Depreciation & amortization		-541,777		-925,389		-989,535
	Taxes other than income		-326,214		-395,145		-363,802
	Other income (expense)		23,597		5,098		89,048
	Interest expense		-1,603		-25,268		-23,615
	Pretax income from discontinued operations		1,650,021		1,050,881		924,157
	Loss on sale of discountinued operations		-		-7,915		-
	Total pretax income from discontinued operations		1,650,021		1,042,966		924,157
	Income tax expense		-617,410		-223,828		-400,328
	Income from discontinued operations	$	1,032,611	$	819,138	$	523,829
	Energy West Wyoming and the Glacier & Shoshone Pipelines
	On October 10, 2014, the Company executed a stock purchase agreement for the sale of all of the stock of its wholly-owned subsidiary, Energy West Wyoming, Inc. (“EWW”), to Cheyenne Light, Fuel and Power Company (“Cheyenne”). EWW has historically been included in the Company’s Natural Gas Operations segment. In conjunction with this sale, the Company’s Energy West Development, Inc. subsidiary, entered into an asset purchase agreement for the sale of the of the transmission pipeline system known as the Shoshone Pipeline and the gathering pipeline system known as the Glacier Pipeline and certain other assets directly used in the operation of the pipelines (together the “Pipeline Assets”) to Black Hills Exploration and Production, Inc. (“Black Hills”), an affiliate of Cheyenne. The Pipeline Assets have historically comprised the entirety of the Company’s Pipeline segment. As a result of EWW and the Pipeline Asset’s classification as discontinued operations, their results have been included in Corporate & Other segment for all periods presented. The Company will receive approximately $15.8 million for the sale of EWW and approximately $1.2 million for the sale of the Pipeline Assets. These amounts are subject to adjustments based upon the working capital on the closing of the transaction and any amendments to the disclosure schedules to the agreement that result in losses to EWW or the Pipeline Assets. The agreements contain customary representations, warranties, covenants and indemnification provisions. The consummation of the transactions depend upon the satisfaction or waiver of a number of customary closing conditions, the receipt of regulatory approvals and the consent of certain of the Company’s lenders. In addition, Cheyenne and Black Hills have the right to terminate the agreements in the event that the amendments to the disclosure schedules to the purchase agreements are reasonably likely to result in losses to EWW and the Pipeline Assets, collectively, in excess of $750,000. The Company expects to close the transactions sometime in the second or third quarter of 2015.
	Upon completion of the transactions, the Company’s subsidiary, EWR, will continue to conduct some business with both EWW and Black Hills relating to the Pipeline Assets. EWW will continue to purchase natural gas from EWR under an established gas purchase agreement through the first quarter of 2017. Concurrently, EWR will continue to use EWW’s transmission system under a standing transportation agreement through the first quarter of 2017. Finally, EWR will continue to use the Pipeline Assets’ transmission systems under a standing transportation agreement through October 2017. These transactions are a continuation of transactions that were conducted prior to the sales EWW and the Pipeline Assets and have been eliminated through the consolidation process.
	Independence
	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. The Company recorded a loss on sale of $7,915 in the fourth quarter of 2013. 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 segment. As a result of its classification as discontinued operations, its results have been included in Corporate & Other segment for all periods presented. The Company has no material continuing cash flows or other contractual obligations associated with this sales transaction.

Assets_and_Liabilities_Held_fo

Assets and Liabilities Held for Sale	12 Months Ended
	Dec. 31, 2014
Assets [Abstract]
Assets And Liabilities Held For Sale	Note 5 – Assets and Liabilities Held for Sale
	At December 31, 2014, the Company was involved in final negotiations for the sale of its Pennsylvania utilities, Clarion and Walker, to Utility Pipeline, LTD. Clarion and Walker have historically been reported as a component of the Company’s Natural Gas Operations segment and have, collectively, contributed $212,774, $46,092, and $56,388 to the Company’s pre-tax income from continuing operations for the years ended December 31, 2014, 2013, and 2012, respectively. The Company does not believe that the sale of Clarion and Walker constitutes a strategic shift that will have a major effect on its operations or financial results and as such, neither of the subsidiaries have classified as discontinued operations in the Company’s financial statements, but instead have been classified as assets and liabilities held for sale at December 31, 2014. See Note 25 – Subsequent Events for more information regarding this transaction.
	The following table summarizes the major classes of asset and liabilities classified as held for sale at December 31, 2014.
		December 31,
		2014
	Current Assets:
	Accounts receivable, net		49,069
	Unbilled gas		22,151
	Inventory		3,622
	Prepayments and other		5,401
	Regulatory assets, current		203,241
	Total current assets		283,484
	Non-Current Assets:
	Property, plant & equipment, net		407,247
	Goodwill		111,705
	Total non-current assets		518,952
	Total assets held for sale	$	802,436
	Current Liabilities:
	Accounts payable		36,184
	Accrued liabilities		21,632
	Other current liabilities		3,600
	Total liabilities held for sale	$	61,416

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill Disclosure	Note 6 - 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 purchasing 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 an Opinion and Order related to the 2012 NEO and Orwell 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 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 GNR 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 led to the 2013 goodwill impairment charge included in the Company’s Marketing & Production segment. 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 ended December 31, 2014 and 2013:
				Marketing &
		Natural Gas		Production		Total
	Balance as of December 31, 2012	$	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
	Classified as asset held for sale		-111,705		-		-111,705
	Balance as of December 31, 2014	$	14,779,672	$	1,376,000	$	16,155,672
	The following table shows the Company’s gross goodwill balance and accumulated impairment loss as of the balance sheet dates.
		December 31,
		2014		2013
	Goodwill, gross
	Natural Gas	$	14,779,672	$	14,891,377
	Marketing & Production		2,101,744		2,101,744
	Total goodwill, gross		16,881,416		16,993,121
	Accumulated impairment loss
	Natural Gas		-		-
	Marketing & Production		-725,744		-725,744
	Total accumulated impairment loss		-725,744		-725,744
	Goodwill, net	$	16,155,672	$	16,267,377

Investment_in_Unconsolidated_A

Investment in Unconsolidated Affiliate	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Note 7 - Investment in Unconsolidated Affiliate
	The Company’s EWR subsidiary 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 as it could provide a supply of natural gas in close proximity to our natural gas operations in Montana. Our obligations to make additional investments in Kykuit are limited under our agreement with the other Kykuit investors. At December 31, 2014, we are obligated to invest no more than an additional $0.1 million over the life of the venture. Other investors in Kykuit include Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer; John D. Oil and Gas Company, a publicly held gas exploration company, which is also the managing member of Kykuit; Thomas J. Smith, a former director of the Company and its former chief financial officer and a director of John D. Oil and Gas Company; and Gregory J. Osborne, chief executive officer and a director of the Company and the former president and director of John D. Oil and Gas Company. Due to significant doubts regarding the recoverability of Kykuit’s leaseholds on unproven oil and gas properties coupled with the bankruptcy of the managing member, the Company believes its investment in Kykuit to be completely impaired. As a result, an impairment expense was recorded reducing the investments value to $0 at December 31, 2014. This expense is included in the Loss from unconsolidated affiliate line of the Consolidated Statement of Comprehensive Income.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 8 – 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, 2014 and 2013.
		December 31, 2014
		Level 1		Level 2			Level 3			TOTAL
	LIABILITIES:
	Contingent consideration	$	-	$	-		$	747,000		$	747,000
	Commodity swap contracts	$	-	$	3,023,271		$	-		$	3,023,271
		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
	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. 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 fair values of marketable securities are estimated based on closing share prices on the open market at the measurement date for those investments. Cost basis is determined by specific identification of securities sold.
	The commodity swap contracts, categorized in level 2 of the fair value hierarchy, are valued by comparing the futures price at the measurement date of the natural gas commodity specified in the contract to the fixed price to be paid by the Company. See Note 10 – Derivative Financial Instruments for more information regarding the commodity swap contracts.
	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 Liability
		2014		2013
	Balance January 1st	$	685,000	$	-
	Transfers into level 3		-		-
	Transfers out of level 3		-		-
	Total (gains) losses for period:
	Included in net income		62,000		-1,565,000
	Included in other comprehensive income		-		-
	Purchases		-		-
	Sales		-		-
	Settlements		-		-
	Issuances		-		2,250,000
	Balance December 31st	$	747,000	$	685,000
	The change in fair value included as a part of net income in the table above is reflected in the Contingent consideration loss (gain) line of the Company’s Consolidated Statement of Comprehensive Income and is the result of an unrealized holding loss (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		Valuation		Unobservable Input			Range
				Techniques
	31-Dec-14
	Contingent Consideration	$	747,000	Monte Carlo analysis		Forecasted annual EBITDA				$0.5 - $0.7 million
						Weighted avg cost of capital				14.0% - 14.0%
						U.S. Treasury yields				0.3% -1.1%
				Discounted cash flow		U.S. Treasury yields				0.3% -1.1%
						Credit spread				2.3% - 3.8%
	31-Dec-13
	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.

Marketable_Securities

Marketable Securities	12 Months Ended
	Dec. 31, 2014
Investments, Debt and Equity Securities [Abstract]
Marketable Securities	Note 9 – Marketable Securities
	The following is a summary of available-for-sale securities at December 31, 2013.
		December 31, 2013
		Investment		Unrealized		Unrealized		Estimated
		at cost		gains		losses		fair value
	Common stock	$	238,504	$	167,630	$	-	$	406,134
	During the year ended December 31, 2014, the Company sold all of its available-for-sale securities. The Company received $0.5 million in proceeds which resulted in a gain on sale of approximately $0.2 million. All unrealized gains and losses on these securities have been included in Other comprehensive  income on the Company’s Consolidated Statement of Comprehensive Income net of tax. An unrealized gain of approximately $0.1 million, net of tax, was reclassified from Other comprehensive income to a component of Net income during the period as a result of the sale. This amount represented the complete cumulative net unrealized gain on these securities. During the years ended December 31, 2013 and 2012, the Company did not sell any of its marketable securities and there were no gross realized gains or losses.

Derivative_Financial_Instrumen

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities Disclosure	Note 10 – Derivative Financial Instruments
	The Company has entered into commodity swap contracts in order to reduce the commodity price risk related to natural gas prices. These commodity swap contracts set a fixed price that the Company will ultimately pay for quantities of natural gas specified in the contracts. The Company has not designated any of these commodity swaps contracts as hedging instruments.
	The following table summarizes the commodity swap contracts entered into by the Company as of December 31, 2014. The Company will pay the fixed price listed for the volumes denoted in the table below. In exchange it will receive from a counterparty a variable payment based on the market price for the natural gas product listed for these volumes. These payments are settled monthly.
	Product		Type			Contract Period			Volume		Price per MMBtu
	CIG - Rockies - IFERC Natural Gas			Swap			1/1/15 - 3/31/15			500 MMBtu/Day	$	3.98
	CIG - Rockies - IFERC Natural Gas			Swap			1/1/15 - 3/31/15			500 MMBtu/Day	$	4.075
	AECO Canada - CGPR 7A Natural Gas			Swap			1/1/15 - 3/31/15			501 MMBtu/Day	$	3.56
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			1/1/15 - 3/31/15			3600 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			4/1/15 - 4/30/15			2500 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			5/1/15 - 5/31/15			1390 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			6/1/15 - 6/30/15			950 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			7/1/15 - 7/31/15			890 MMBtu/Day	$	13
	The table below summarizes the amount of unrealized loss recognized as a component of Net income from the commodity swap contracts.
			Year Ended December 31,
			2014			2013			2012
	Unrealized loss on commodity swap contracts not designated as hedging instruments		$	3,023,271		$	-		$	-
	Deferred unrealized loss on commodity swap contracts (1)			-2,872,386			-			-
	Unrealized loss included in Other income, net		$	150,885		$	-		$	-
		-1	Unrealized losses on commodity swap agreements incurred by the Company’s regulated subsidiaries have been deferred as a regulatory asset on the Company’s Consolidated Balance Sheet. See Note 11 - Regulatory Assets and Liabilities.
	The table below shows the line item in the Company’s Consolidated Balance Sheets where the fair value of the commodity swap contracts is included.
	Fair Value of Derivative Instruments
			Liabilities
					December 31,
			Balance Sheet Location		2014			2013
	Derivatives not designated as hedging instruments
	Commodity swap contracts		Derivative instruments		$	3,023,271		$	-

Regulatory_Assets_and_Liabilit

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets	Note 11 – Regulatory Assets and Liabilities
	The following table summarizes the components of the Company’s regulatory asset and liability balances at December 31, 2014 and 2013.
			December 31,
			2014						2013
			Current			Long-term			Current		Long-term
	REGULATORY ASSETS
	Recoverable cost of gas purchases		$	692,117		$	-		$	1,209,982	$	-
	Deferred costs			489,996			1,715,006			-		-
	Deferred loss on commodity swaps			2,872,385			-			-		-
	Income taxes			-			296,819			-		296,819
	Property taxes			-			-			-		25,000
	Rate case costs			43,324			43,579			-		130,228
	Total regulatory assets		$	4,097,822		$	2,055,404		$	1,209,982	$	452,047
	REGULATORY LIABILITIES
	Over-recovered gas pruchases		$	925,175		$	-		$	793,184	$	-
	Income taxes			-			83,161			-		83,161
	Asset retirement costs			-			1,006,689			-		881,301
	Total regulatory liabilities		$	925,175		$	1,089,850		$	793,184	$	964,462
	Recoverable Cost of Gas Purchases/Over-recovered 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 (recoverable cost of gas purchases) or credited through future rate changes (over-recovered gas purchases). These amounts are generally recovered or credited through rates within one year. The gas cost recovery mechanisms 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.
	Deferred Costs
	On June 27, 2014, the Company’s Frontier Natural Gas subsidiary entered into a stipulation with the Public Staff of the North Carolina Utilities Commission (Docket No G-40, Sub 124), in which the subsidiary agreed, among other items, to reclassify $2.5 million from its recoverable cost of gas purchases asset account to a deferred gas cost asset account. This amount represents a portion of deferred expenses related to the subsidiary’s January and February 2014 gas purchases on which it will not earn return. The stipulation calls for amortization of this amount as operating expense over a five year period beginning July 1, 2014. Under the stipulation, the Public Staff agreed to not request a change in Frontier Natural Gas’s base margin rates, exclusive of cost of gas, for the same five-year period.
	Deferred Loss on Commodity Swaps
	The Company’s regulated subsidiaries defer recognition of unrealized losses and gains on its commodity swap derivative instruments as regulatory assets and liabilities, respectively. Deferred losses and gains are recognized as a component of Cost of sales – natural gas purchased on the Company’s Consolidated Statement of Comprehensive Income during the period in which they are settled and recovered through rates. The regulatory asset on the Company’s Consolidated Balance Sheet at December 31, 2014 will be recovered by the end of July 2015.
	Income Taxes
	The regulatory asset related to income taxes earns a return equal to that of the Company’s rate base and will be recovered through rates. The regulatory liability related to income taxes will be credited to our customers.
	Asset Retirement Costs
	As a result of regulatory action by the PUCO, Orwell and Brainard accrue an estimated liability for removing certain classes of utility plant long-lived assets at the end of their useful lives. The liability is equal to a set percent of the asset’s historic cost according to the following table:
		Percent of Asset Cost
		Orwell				Brainard
	Mains			15	%			20	%
	Meter/regulator stations			10	%
	Service lines			75	%
	These liabilities are accrued over the useful lives of the assets with the corresponding expense included as a portion of depreciation expense. Upon retirement of any assets included in these asset classes, any costs incurred to retire the asset will be recorded against this regulatory liability. Any costs in excess of the liability will be expensed as incurred and any residual liability in excess of incurred costs to retire the asset will act to reduce Orwell and Brainard’s future rates. As of December 31, 2014, none of the assets included in these asset classes have been retired.
	Other Regulatory Assets
	The rate case costs do not earn a return and will be amortized over a period of 2 to 3 years. The regulatory asset for property tax was recovered in rates over a ten-year period starting January 1, 2004.

Accrued_Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2014
Payables and Accruals [Abstract]
Accounts Payable and Accrued Liabilities Disclosure	Note 12 – Accrued Liabilities
	The following table summarizes the components of the Company’s accrued liabilities balances at December 31, 2014 and 2013.
		December 31,
		2014		2013
	Taxes other than income	$	2,082,690	$	3,043,583
	Vacation		93,845		83,189
	Employee benefits		123,171		161,440
	Interest		200,502		169,581
	Deferred payments received from levelized billing		2,360,455		2,293,801
	Accrued liabilities	$	4,860,663	$	5,751,594

Restricted_Cash

Restricted Cash	12 Months Ended
	Dec. 31, 2014
Cash and Cash Equivalents [Abstract]
Restricted Cash	Note 13 – Restricted Cash
	At December 31, 2014 and 2013, the Company had a restricted cash balance of $1.9 million and $1.1 million, respectively. Of these amounts, $0.9 million and $1.1 million at December 31, 2014 and 2013, respectively, are related to the Company’s Sun Life debt covenants. See the Sun Life Debt Covenant section of Note 17 – Credit Facilities and Long-Term Debt for more information regarding these restricted funds. The remaining $0.9 million at December 31, 2014 is related to a deposit paid in the first quarter of 2014 to Bangor Gas, a subsidiary of the Company, by Verso Bucksport Power LLC (“Verso”) as a required condition related to Verso acquiring the rights of H.Q. Energy Services (U.S.) Inc. under a gas transportation service agreement with Bangor Gas. Bangor Gas is restricted from using these funds unless and until a default under this agreement has occurred. This deposit will be refunded to Verso at the termination of the gas transportation service agreement.

Earnings_per_Share

Earnings per Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share	Note 14 – Earnings per Share
		Year Ended December 31,
		2014		2013		2012
	Numerator:
	Income from continuing operations	$	2,729,166	$	5,852,141	$	3,195,488
	Income from discontinued operations		1,032,611		819,138		523,829
	Net income	$	3,761,777	$	6,671,279	$	3,719,317
	Denominator:
	Basic weighted average common shares outstanding		10,478,312		9,339,002		8,163,814
	Dilutive effect of stock options		-		720		5,865
	Dilutive effect of restricted stock awards		505		-		-
	Diluted weighted average common shares outstanding		10,478,817		9,339,722		8,169,679
	Basic & diluted earnings per share of common stock:
	Continuing operations	$	0.26	$	0.63	$	0.39
	Discontinued operations		0.1		0.08		0.07
	Net income	$	0.36	$	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, 2014, 2013 and 2012.

Property_Plant_Equipment

Property Plant & Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure	Note 15 – Property Plant & Equipment
	Components of property, plant, and equipment were as follows:
		December 31,
		2014		2013
	Gas transmission & distribution facilities	$	163,138,652	$	138,812,125
	Land		3,773,998		3,773,998
	Buildings & leasehold improvements		11,212,860		11,241,104
	Transportation equipment		3,735,809		3,449,615
	Computer equipment		3,876,106		3,844,776
	Other equipment		11,150,519		10,065,908
	Producing natural gas properties		3,900,455		3,900,455
	Construction work in progress		8,646,219		10,762,535
	Property, plant & equipment		209,434,618		185,850,516
	Accumulated depreciation, depletion & amortization		-58,049,321		-52,301,885
			151,385,297		133,548,631
	Assets held for sale		-407,247		-
	Discontinued operations		-8,966,965		-8,960,986
	Property, plant & equipment, net	$	142,011,085	$	124,587,645
	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, 2014 and 2013, management of the Company, considering reserve estimates provided by an independent reservoir engineer, estimated the net gas reserves at 2.1 Bcf (unaudited) and 2.3 Bcf (unaudited), respectively, and with net present values of $2.7 million and $2.1 million, respectively, after applying a 10% discount (unaudited). The net book value of the gas properties totals $0.9 million and $1.0 million at December 31, 2014 and 2013, respectively.
	The wells are depleted based upon production at approximately 10% and 10% per year as of December 31, 2014 and 2013, respectively. For the years ended December 31, 2014, 2013  and 2012, EWR’s portion of the daily gas production was 395 Mcf, 422 Mcf and 461 Mcf per day, or 20.0%, 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, 2014, 2013 and 2012, EWD’s portion of the daily gas production was 107 Mcf, 129 Mcf and 132 Mcf per day, or 5.5%, 5.8% and 4.4% of EWR’s volume requirements, respectively.
	For the years ended December 31, 2014, 2013 and 2012, EWR and EWD’s combined portion of the estimated daily gas production from the reserves was 502 Mcf, 550 Mcf and 593 Mcf, or 26.0%, 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.
	Build-to-suit Lease
	Included as a component of Construction work in progress is a $6.5 million asset that represents the Company’s new build-to-suit lease enterprise resource planning (“ERP”) system. The Company has determined that during the application development stage it possesses substantially all of the project’s risk and as such should be considered the owner of the asset during this period. In addition, the Company has recorded a $5.6 million liability included in the Build-to-suit liability line item on its Condensed Consolidated Balance Sheet dated December 31, 2014 related to this project. Upon completion of the ERP project, the Company will assess whether the lease qualifies for sales recognition under sale-leaseback accounting guidance.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure	Note 16 – Asset Retirement Obligations
	The Company 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.
	The Company’s recognized asset retirement obligations represent the estimate costs to retire certain natural gas producing wells. The following schedule is a reconciliation of the Company’s recognized asset retirement obligations for the years ended December 31, 2014 and 2013.
		2014		2013
	Balance, January 1st	$	1,145,052	$	1,087,140
	Accretion expense		51,466		57,912
	Balance, December 31st	$	1,196,518	$	1,145,052
	The Company has no assets legally restricted for purposes of settling its asset retirement obligations. As of December 31, 2014 and 2013, the Company had capitalized ARO costs included in property, plant and equipment of $48,954 and $86,415, respectively.

Credit_Facilities_and_LongTerm

Credit Facilities and Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Credit Facilities and Long-Term Debt	Note 17 – Credit Facilities and Long-Term Debt
	Line of Credit
	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. On November 26, 2014, the Company entered into an amendment temporarily increasing the borrowing capacity by $10.0 million to a maximum of $40.0 million. In an order approving this temporary increase in borrowing capacity, the MPSC stated that any amounts borrowed under this increase in excess of $5.0 million would first require the approval of the MPSC. Amounts borrowed under this temporary increase have a maturity date of July 1, 2015. 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 $28.8 million and $24.5 million at December 31, 2014 and 2013, respectively. For the year ended December 31, 2014, the weighted average borrowing outstanding on the revolving line of credit was $23.4 million. For the years ended December 31, 2014, 2013 and 2012, the weighted average interest rate on the revolving credit facility was 2.45%, 2.42% and 3.33%, respectively.
	Notes Payable
	The following table details the Company’s outstanding long-term debt balances at December 31, 2014 and 2013.
		December 31,
		2014		2013
	LIBOR plus 1.75 to 2.25%, Bank of America amortizing term loan, due April 1, 2017	$	8,875,000	$	9,375,000
	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
	4.15% Sun Life senior secured guaranteed note, due June 1, 2017		2,989,552		2,989,552
	Vehicle and equipment financing loans		64,509		2,190
	Total notes payable		40,263,061		43,700,742
	Less: current portion		542,201		3,502,190
	Notes payable, less current portion	$	39,720,860	$	40,198,552
	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, 2014, the Company had not exercised the interest rate swap provision for the fixed interest rate. For the years ended December 31, 2014, 2013 and 2012, the weighted average interest rate on the term loan was 2.15%, 2.19% and 2.14%, respectively, resulting in $200,727, $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, 2014, 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, 2014, 2013 and 2012, interest expense related to the fixed rate note was $824,969 per year.
	The Sun Life floating rate note is an obligation of Great Plains and is guaranteed by the Company. This note was repaid in May 2014. For the years ended December 31, 2014, 2013 and 2012, the weighted average interest rate on the floating rate note was 4.10%, 4.13% and 4.31% respectively resulting in $40,900, $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, 2014, 2013 and 2012, interest expense from the senior secured guaranteed note was $123,007, $123,007 and $23,576, respectively.
	The following table shows the aggregate future maturities of the Company’s notes payable.
	Years Ending
	2015	$	542,201
	2016		522,308
	2017		39,198,552
	2018		-
	2019		-
	Thereafter		-
	Total	$	40,263,061
	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 $0.9 million and $1.1 million at December 31, 2014 and 2013, 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.
	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, 2014
Equity [Abstract]
Stockholdersb Equity	Note 18 – Stockholders’ Equity
	Share Repurchase Plan
	The Company’s common stock trades on the NYSE MKT 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. As of December 31, 2014, there has been no share repurchase activity.
	Stock Compensation
	During the years ended December 31, 2014, 2013 and 2012, the Company recorded $316,985, $2,962 and $9,406, respectively, of stock-based compensation expense. As of December 31, 2014, there was $49,544 of total unrecognized compensation cost related to stock-based compensation that will be recognized through July 21, 2017.
	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. 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.
	A summary of the status of the outstanding stock options is as follows:
				Weighted		Aggregate
		Number of		Average		Intrinsic
		Shares		Exercise Price		Value
	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	$	-
	Granted		-	$	-
	Exercised		-5,000	$	8.44
	Forfeited		-	$	-
	Expired		-	$	-
	Outstanding December 31, 2014		-	$	-	$	-
	Exerciseable December 31, 2014		-	$	-	$	-
	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 and directors. The number of shares authorized for issuance under the plan is 500,000.
	On March 26, 2014, in order to further align the directors’ interests with those of the Company’s shareholders, the board granted an award of the Company’s common stock to each current director of Gas Natural. The total number of shares awarded was 30,833 with a grant date fair value of $0.3 million. The award was not conditional on any future performance or event and as such, the award was fully expensed on the grant date. These shares were issued on April 3, 2014.
	On July 21, 2014, in conjunction with his employment agreement, the Company granted 5,000 shares of restricted stock to Gregory J. Osborne, chief executive officer and a director of the Company. These shares had a grant date fair value of $58,200 and will vest ratably through July 21, 2017. During the vesting period, each restricted share has the same rights to dividend distributions and voting as any other common share of the Company.
		Restricked Stock
		Awards
	Outstanding, December 31, 2013	-
	Granted	5,000
	Vested	-
	Forfeited	-
	Outstanding, December 31, 2014	5,000
	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. The number of shares authorized for issuance under the plan is 250,000. As of December 31, 2014, no shares had been issued under the plan.
	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 17 – Credit Facilities and Long-Term Debt, the MPUC, MPSC, NCUC and WPSC have each placed ring fencing provisions over the subsidiary companies in their jurisdictions. 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 on the net assets of the Company’s subsidiaries are the Sun Life debt covenant restriction on distributions to the holding company from its obligors and the MPSC restriction, related to the November 25, 2014 BOA line of credit amendment, which restricts distributions to the holding company from Energy West and its Montana, Maine, or North Carolina subsidiaries.
	The total restricted net assets of consolidated subsidiaries related to the Company’s debt covenants and ring fencing restrictions is $92.3 million, which accounts for 95.7% of Gas Natural Inc.’s net assets of $96.5 million at December 31, 2014.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Employee Benefit Plans	Note 19 – 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, 2014, 2013 and 2012 was $492,047, $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 $57,245, $57,590 and $52,719 for the years ended December 31, 2014, 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, 2014, 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, 2014 and 2013, the value of plan assets was $132,717 and $155,750, 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
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	Note 20 – Income Taxes
	Significant components of the deferred tax assets and liabilities are as follows:
		December 31,
		2014				2013
		Current		Long-term		Current		Long-term
	Deferred tax assets:
	Allowance for doubtful accounts	$	141,701	$	-	$	724,534	$	-
	Contributions in aid of construction		-		2,480,637		-		1,652,760
	Other nondeductible accruals		46,102		-		47,484		-
	Recoverable purchase gas costs		217,349		-		60,903		-
	Net operating loss carryforwards		-		13,255,842		-		7,733,763
	Property tax		157,683		-		154,146		-
	Other		451,213		-		754,235		-
	Total deferrred tax assets		1,014,048		15,736,479		1,741,302		9,386,523
	Deferred tax liabilities:
	Recoverable purchase gas costs		378,853		-		454,795		-
	Property, plant and equipment		-		17,375,812		-		11,402,464
	Unrealized gain on securities available for sale		-		549,046		61,475		-
	Amortization of intangibles		-		738,608		-		539,498
	Other		-		1,114,692		-		800,698
	Total deferrred tax liabilities		378,853		19,778,158		516,270		12,742,660
	Net deferred tax asset (liability) before valuation allowance		635,195		-4,041,679		1,225,032		-3,356,137
	Less: valuation allowance		-		-6,496,715		-		-5,699,029
	Total deferred tax asset (liability)		635,195		-10,538,394		1,225,032		-9,055,166
	Discontinued operations		-		-		-		-
	Net deferred tax asset (liability), continuing operations	$	635,195	$	-10,538,394	$	1,225,032	$	-9,055,166
	Income tax expense from continuing operations consists of the following:
		Year Ended December 31,
		2014		2013		2012
	Current income tax expense (benefit):
	Federal	$	49,270	$	-344,342	$	-150,224
	State		10,961		120,753		245,483
	Total current income tax expense (benefit)		60,231		-223,589		95,259
	Deferred income tax expense:
	Federal		1,987,409		3,692,413		2,030,525
	State		138,414		-200,217		252,403
	Total deferred income tax expense		2,125,823		3,492,196		2,282,928
	Total income taxes before credits		2,186,054		3,268,607		2,378,187
	Investment tax credit, net		-21,062		-21,062		-21,062
	Total income tax expense		2,164,992		3,247,545		2,357,125
	Income tax expense from discontinued operations		-617,410		-223,834		-400,326
	Income tax expense from continuing operations	$	1,547,582	$	3,023,711	$	1,956,799
	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,
		2014		2013		2012
	Tax expense at statutory rate of 34%	$	2,015,101	$	3,372,404	$	2,065,991
	State income tax, net of federal tax expense		307,099		348,151		228,051
	Amortization of deferred investment tax credits		-21,062		-21,062		-21,062
	Change in valuation allowance		-397,619		-237,557		-262,343
	Permanent differences		24,580		134,583		140,211
	State rate change		149,015		-346,149		-
	Other		87,878		-2,825		206,277
	Total income tax expense		2,164,992		3,247,545		2,357,125
	Income tax expense from discontinued operations		-617,410		-223,834		-400,326
	Income tax expense from continuing operations	$	1,547,582	$	3,023,711	$	1,956,799
	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 $22.5 million in federal net operating loss carryovers as of December 31, 2014. 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, 2014. The Company has recorded a state deferred tax asset valuation allowance of $4.7 million against the state net operating loss carryover. In addition, the Company has approximately $20.0 million of carryover tax basis as of December 31, 2014. 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, 2014, 2013 and 2012, no adjustments were recognized for uncertain tax benefits.
	The tax years after 2010 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
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	Note 21 – Related Party Transactions
	The Company is party to certain agreements and transactions with Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, and companies owned or controlled by Richard M. Osborne.
	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, father of the Company’s chief executive officer and the Company’s former 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, father of the Company’s chief executive officer and the Company’s former 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.
	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. In September of 2014, OsAir was evicted from the office space for failure to make payment. At December 31, 2014, $29,150 of past due rent was still owed the Company.
	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, father of the Company’s chief executive officer and the Company’s former 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, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, at December 31, 2014 and 2013.
		Accounts Receivable				Accounts Payable
		December 31,		December 31,		December 31,		December 31,
		2014		2013		2014		2013
	Cobra Pipeline	$	178,596	$	131,208	$	67,982	$	76,909
	Orwell Trumbell Pipeline		-		-		102,231		122,693
	Great Plains Exploration		959		7,033		9		73,983
	Big Oats Oil Field Supply		4,752		4,945		-		179,447
	John D. Oil and Gas Company		6,854		91		-		82,188
	OsAir		35,329		-		97		16,703
	Other		8,120		2,948		-		8,010
	Total related party balances		234,610		146,225		170,319		559,933
	Less amounts included in discontinued operations		-		-		-		-
	Total related party balances included in continuing operations	$	234,610	$	146,225	$	170,319	$	559,933
	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for the year ended December 31, 2014:
		Year Ended December 31, 2014
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas Sales		Rental Income
		Purchases		Construction		Consulting and				and Other Sales
				Purchases		Other Purchases
	Cobra Pipeline	$	1,119,192	$	-	$	18,000	$	104,623	$	13,400
	Orwell Trumbell Pipeline		788,026		-		-		1,956		37,124
	Great Plains Exploration		611,187		-		-		13,073		5,200
	Big Oats Oil Field Supply		-		254,752		93,741		5,181		850
	John D. Oil and Gas Company		737,522		-		-		575		42,209
	OsAir		176,116		-		6,317		3,788		52,045
	Lake Shore Gas Storage		162,360		-		-		-		-
	Other		76,282		-		22,808		22,240		1,676
	Total	$	3,670,685	$	254,752	$	140,866	$	151,436	$	152,504
	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for the year ended December 31, 2013:
		Year Ended December 31, 2013
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas Sales		Rental Income
		Purchases		Construction		Consulting and				and Other Sales
				Purchases		Other Purchases
	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, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for the year ended December 31, 2012:
		Year Ended December 31, 2012
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas Sales		Rental Income
		Purchases		Construction		Consulting and				and Other Sales
				Purchases		Other Purchases
	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 $111,133 and $0 due to companies controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for natural gas used and transportation charges through December 31, 2014 and 2013, 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, father of the Company’s chief executive officer and the Company’s former 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.
In addition, the Company had related party natural gas imbalances of $98,081 and $151,780 at December 31, 2014 and December 31, 2013, respectively, which were included in the Company’s natural gas inventory balance. These amounts represent quantities of natural gas due to the Company from natural gas transportation companies controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer.

Unaudited_Quarterly_Results_of

Unaudited Quarterly Results of Operations	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Results of Operations	Note 22 – Unaudited Quarterly Results of Operations
		2014 Quarter Ended
		December 31,		September 30,  (1)		June 30,		March 31,
	Revenue	$	36,958,232	$	13,614,971	$	20,499,919	$	61,496,719
	Gross margin		12,036,544		7,014,641		8,392,127		17,409,150
	Income (loss) from continuing operations	$	1,200,689	$	-1,514,569	$	-1,493,499	$	4,536,545
	Discontinued operations		450,959		34,825		64,881		481,946
	Net income (loss)	$	1,651,648	$	-1,479,744	$	-1,428,618	$	5,018,491
	Basic and diluted earnings per share
	Continuing operations	$	0.11	$	-0.14	$	-0.14	$	0.43
	Discontinued operations		0.05		-		-		0.05
	Net income (loss) per share	$	0.16	$	-0.14	$	-0.14	$	0.48
		2013 Quarter Ended
		December 31, (2)		September 30,  (3)		June 30,  (4)		March 31,
	Revenue	$	36,286,131	$	13,617,328	$	18,707,462	$	40,789,432
	Gross margin		13,476,706		7,234,509		7,351,808		15,307,311
	Income (loss) from continuing operations	$	2,797,734	$	-850,046	$	-429,753	$	4,334,206
	Discontinued operations		417,076		-154,292		102,837		453,517
	Net income (loss)	$	3,214,810	$	-1,004,338	$	-326,916	$	4,787,723
	Basic and diluted earnings per share
	Continuing operations	$	0.27	$	-0.08	$	-0.05	$	0.52
	Discontinued operations		0.04		-0.02		0.01		0.05
	Net income (loss) per share	$	0.31	$	-0.1	$	-0.04	$	0.57
	(1) Company classified its Energy West Wyoming subsidiary and Glacier and Shoshone Pipeline Assets as discontinued operations. All prior periods have been restated to match this presentation.
	(2) Company recorded a goodwill impairment expense of $0.7 million and an unrealized gain on its contingent consideration liability of $1.6 million.
	(3) Company classified its Independence subsidiary as discontinued operations. All prior periods have been restated to match this presentation.
	(4) Company recorded a contingent liability of $0.9 million, related to the PUCO’s GCR audit of its Ohio utilities, reducing gross margin.

Segments_of_Operation

Segments of Operation	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segments of Operations	Note 23 – Segments of Operation
	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 non-regulated marketing and production businesses, and its corporate level operations. See Note 4 – Discontinued Operations for more information regarding the Company’s previously reported Pipeline and Propane segments. The Company has regulated natural gas utility businesses in the states of Kentucky, Maine, Montana, North Carolina, Ohio, and Pennsylvania that form the Company’s Natural Gas segment. The Company has non-regulated natural gas marketing and production businesses in Montana and Ohio that together form the Company’s Marketing & Production segment. The Company’s Lone Wolf subsidiary, its holding company, and the Company’s discontinued operations together form its Corporate & Other segment. 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 & Production, and Corporate & Other operating segments.
	Year Ended December 31, 2014	Natural Gas		Marketing &		Corporate &		Consolidated
				Production		Other
	OPERATING REVENUES	$	123,378,718	$	17,605,367	$	-	$	140,984,085
	Intersegment eliminations		-326,164		-8,088,080		-		-8,414,244
	Total operating revenue		123,052,554		9,517,287		-		132,569,841
	COST OF SALES		79,422,717		16,708,906		-		96,131,623
	Intersegment eliminations		-326,164		-8,088,080		-		-8,414,244
	Total cost of sales		79,096,553		8,620,826		-		87,717,379
	GROSS MARGIN		43,956,001		896,461		-		44,852,462
	OPERATING EXPENSES
	Distribution, general and administrative		20,975,963		1,833,476		3,175,197		25,984,636
	Maintenance		1,224,998		493		-		1,225,491
	Depreciation and amortization		6,070,669		514,654		19,246		6,604,569
	Accretion		6,856		44,610		-		51,466
	Taxes other than income		3,898,337		23,367		6,314		3,928,018
	Unrealized holding loss		-		62,000		-		62,000
	Intersegment eliminations		-102,898		-		-		-102,898
	Total operating expenses		32,073,925		2,478,600		3,200,757		37,753,282
	OPERATING INCOME (LOSS)		11,882,076		-1,582,139		-3,200,757		7,099,180
	Other income (expense)		889,873		-502,367		16,158		403,664
	Interest expense		-2,619,294		-121,041		-485,761		-3,226,096
	Income (loss) before taxes		10,152,655		-2,205,547		-3,670,360		4,276,748
	Income tax benefit (expense)		-3,661,125		771,844		1,341,699		-1,547,582
	INCOME (LOSS) FROM CONTINUING OPERATIONS		6,491,530		-1,433,703		-2,328,661		2,729,166
	Discontinued operations, net of income tax		-		-		1,032,611		1,032,611
	NET INCOME (LOSS)	$	6,491,530	$	-1,433,703	$	-1,296,050	$	3,761,777
	Capital expenditures	$	21,530,449	$	60,415	$	21,816	$	21,612,680
	Year Ended December 31, 2013	Natural Gas		Marketing &		Corporate &		Consolidated
				Production		Other
	OPERATING REVENUES	$	97,259,443	$	20,260,001	$	-	$	117,519,444
	Intersegment eliminations		-26,331		-8,092,760		-		-8,119,091
	Total operating revenue		97,233,112		12,167,241		-		109,400,353
	COST OF SALES		56,003,485		18,145,625		-		74,149,110
	Intersegment eliminations		-26,331		-8,092,760		-		-8,119,091
	Total cost of sales		55,977,154		10,052,865		-		66,030,019
	GROSS MARGIN		41,255,958		2,114,376		-		43,370,334
	OPERATING EXPENSES
	Distribution, general and administrative		19,560,991		801,305		1,770,564		22,132,860
	Maintenance		1,139,496		2,765		-		1,142,261
	Depreciation and amortization		5,081,293		456,790		12,670		5,550,753
	Accretion		7,068		50,844		-		57,912
	Unrealized holding gain		-		-1,565,000		-		-1,565,000
	Goodwill impairment		-		725,744		-		725,744
	Taxes other than income		3,619,304		28,113		24,513		3,671,930
	Intersegment eliminations		-13,744		-		-84,090		-97,834
	Total operating expenses		29,394,408		500,561		1,723,657		31,618,626
	OPERATING INCOME (LOSS)		11,861,550		1,613,815		-1,723,657		11,751,708
	Other income (expense)		767,235		151,168		-618,104		300,299
	Interest expense		-2,566,310		-142,031		-467,814		-3,176,155
	Income (loss) before taxes		10,062,475		1,622,952		-2,809,575		8,875,852
	Income tax benefit (expense)		-3,242,814		-586,326		805,429		-3,023,711
	INCOME (LOSS) FROM CONTINUING OPERATIONS		6,819,661		1,036,626		-2,004,146		5,852,141
	Discontinued operations, net of income tax		-		-		819,138		819,138
	NET INCOME (LOSS)	$	6,819,661	$	1,036,626	$	-1,185,008	$	6,671,279
	Capital expenditures	$	23,241,913	$	217,201	$	57,809	$	23,516,923
				Marketing &		Corporate &
	Year Ended December 31, 2012	Natural Gas		Production		Other		Consolidated
	OPERATING REVENUES	$	73,925,318	$	13,417,723	$	-	$	87,343,041
	Intersegment eliminations		-24,837		-5,924,362		-		-5,949,199
	Total operating revenue		73,900,481		7,493,361		-		81,393,842
	COST OF SALES		38,577,444		11,877,518		-		50,454,962
Intersegment eliminations		-24,837		-5,924,362		-		-5,949,199
Total cost of sales		38,552,607		5,953,156		-		44,505,763
GROSS MARGIN	$	35,347,874	$	1,540,205	$	-	$	36,888,079
OPERATING EXPENSES
Distribution, general and administrative		17,904,439		449,665		1,109,677		19,463,781
Maintenance		994,058		1,014		-		995,072
Depreciation and amortization		4,034,452		268,202		34,542		4,337,196
Accretion		113,106		48,192		-		161,298
Taxes other than income		3,110,909		38,052		39,110		3,188,071
Total operating expenses		26,156,964		805,125		1,183,329		28,145,418
OPERATING INCOME (LOSS)	$	9,190,910	$	735,080	$	-1,183,329	$	8,742,661
Other income (expense)		346,048		-6,051		-1,230,651		-890,654
Interest expense		-2,198,888		-133,440		-367,391		-2,699,719
Income (loss) before taxes		7,338,070		595,589		-2,781,371		5,152,288
Income tax benefit (expense)		-2,869,083		4,542		907,742		-1,956,799
INCOME (LOSS) FROM CONTINUING OPERATIONS	$	4,468,987	$	600,131	$	-1,873,629	$	3,195,489
Discontinued operations, net of income tax		-		-		523,829		523,829
NET INCOME (LOSS)	$	4,468,987	$	600,131	$	-1,349,800	$	3,719,318
Capital expenditures	$	17,686,583	$	1,393,040	$	856,359	$	19,935,982
			Marketing &
	Natural Gas		Produrction		Corporate & Other
	Operations		Operations		Operations		Consolidated
31-Dec-14
Investment in unconsolidated affiliate	$	-	$	-	$	-	$	-
Total assets	$	214,030,368	$	9,192,830	$	100,781,302	$	324,004,500
Intersegment eliminations		-68,714,744		-2,714,405		-38,571,439		-110,000,588
Total assets	$	145,315,624	$	6,478,425	$	62,209,863	$	214,003,912
31-Dec-13
Investment in unconsolidated affiliate	$	-	$	351,724	$	-	$	351,724
Total assets	$	184,085,665	$	11,633,544	$	94,981,858	$	290,701,067
Intersegment eliminations		-53,772,095		-3,678,311		-29,518,864		-86,969,270
Total assets	$	130,313,570	$	7,955,233	$	65,462,994	$	203,731,797

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 24 – Commitments and Contingencies
	Lease Commitments
	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, 2014, 2013 and 2012, totaled $184,008, $222,093 and $429,743, 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 lease payments of $300,000 per year through 2022. Additionally, the agreement calls for a $120,000 facility service fee to be paid by the Company each year, 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 2014, 2013 or 2012. During the year end December 31, 2014, the Company paid $120,000 for services related to this lease. There were 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, 2014 and 2013:
		December 31,
		2014		2013
	Gas transmission & distribution facilities	$	6,320,000	$	6,320,000
	Capital lease assets, gross		6,320,000		6,320,000
	Accumulated depreciation		-902,857		-501,587
	Capital lease assets, net	$	5,417,143	$	5,818,413
	Depreciation expense recorded in connection with assets under capital leases was $401,270, $401,270 and $100,317 for the years ended December 31, 2014, 2013 and 2012, respectively.
	The following schedule presents the future minimum lease payments under the Company’s lease agreements as of December 31, 2014.
	Future Minimum Lease Payments
		Operating Leases		Build-to-suit Lease (1)		Capital Leases
	2015	$	277,634	$	2,405,890	$	300,000
	2016		242,917		2,226,081		300,000
	2017		233,913		2,092,063		300,000
	2018		222,719		205,958		300,000
	2019		210,579		-		300,000
	Thereafter		994,701		-		900,000
	Total minimum lease payments	$	2,182,463	$	6,929,992		2,400,000
	Less: Interest portion						537,062
	Liability					$	1,862,938
	(1) Relates to the Company’s ERP system build-to-suit lease. See Note 15 – Property Plant & Equipment.
	Long-term Contracts
	The following table summarizes the Company’s future minimum obligations under its long-term contracts at December 31, 2014.
	Future Minimum Long-term Contract Obligations
		Northwestern				Maritimes and		Gas Purchase
		Energy		Trans-Canada		Northeast Pipeline		Contracts
	2015	$	1,434,680	$	829,775	$	357,042	$	2,939,547
	2016		519,356		368,768		357,042		817,325
	2017		519,356		368,768		357,042		-
	2018		476,076		338,036		357,042		-
	2019		-		-		357,042		-
	Thereafter		-		-		-		-
	Total	$	2,949,468	$	1,905,347	$	1,785,210	$	3,756,872
	One of the Company’s subsidiaries 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.
	The Company’s subsidiary, Bangor Gas, entered into an agreement with Maritimes and Northeast Pipeline for the transportation and storage of natural gas.
	One of the Company’s subsidiaries has entered into long-term gas purchase agreements committing it to purchase gas through March of 2016 at a fixed spread above AECO pricing. Future commitments under these contracts have been estimated using AECO forward pricing for the periods covered by the agreements.
	None of the preceding long-term contracts have been recognized on the Company’s Consolidated Balance Sheets.
	Loss Contingency
	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 a contingent liability in its financial statements for the period ended June 30, 2013. Based on the PUCO staff’s calculations and management’s assessment, the Company accrued an additional $0.9 million to establish a total liability to its customers of $1.2 million as its best estimate to resolve this matter.
	On November 13, 2013, the PUCO issued an Opinion and Order related to the outstanding NEO and Orwell GCR cases; case numbers 12-209-GA-GCR and 12-212-GA-GCR. In it, the PUCO ordered adjustments to NEO and Orwell’s GCRs to disallow agent fees paid by the two companies to JDOG Marketing for natural gas procurement, disallow processing and treatment fees paid by NEO to Cobra for NEO’s natural gas supply being delivered through Cobra’s pipeline, and disallow certain excess costs associated with local production gas purchased by NEO and Orwell from JDOG Marketing. The total adjustment for the disallowance for these costs was approximately $1.0 million. Neo and Orwell ceased the inclusion of these disallowed costs in its GCR rates and their payment in the second half of 2013. Both JDOG Marketing and Cobra were companies controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer during the periods covered by these audits.
	Immediately following the release of the Opinion and Order, the Company examined NEO and Orwell’s GCRs for these disallowed cost in periods subsequent to the companies’ audit periods. As a result, the Company accrued a $0.5 million contingent liability in the fourth quarter of 2013 as its best estimate of these disallowed costs. The expense associated with this amount was partially offset by the $0.2 million over accrual of the expected audit period adjustments required by the PUCO.
	In addition to the GCR adjustments called for in the November 2013 Opinion and Order, the PUCO ordered an investigative audit to be conducted of NEO, Orwell and all affiliated and related companies. These audits examined the companies’ corporate separation and management structures, internal regulatory and financial controls, compensation systems, gas purchasing transactions and practices related to GCR calculations, and financial and accounting statements filed with regulatory agencies. The audit was completed and filed with the PUCO and can be found under case number 14-0205-GA-COI. The PUCO has yet to act based on the audit report. Additionally, the Ohio Consumers’ Counsel has intervened and has requested additional documentation associated with the investigative audit. At this time, the Company cannot reasonably estimate the financial impact, if any, of any potential actions taken by the PUCO as a result of this report. Any actions taken by the PUCO as a result of this report could have a material adverse effect on the Company.
	In 2014, the PUCO staff conducted an audit of NEO and Orwell’s GCR for the periods March 1, 2012 through June 30, 2014 and July 1, 2012 through June 30, 2014; case numbers 14-209-GA-GCR and 14-212-GA-GCR. These audits include the post audit periods discussed above. In addition to the disallowed costs previously identified in the November 2013 Opinion and Order, the 2014 PUCO staff report identified additional disallowed costs and errors in the GCR calculation. The Company does not agree with all of the disallowances as calculated in the PUCO staff report and intends to contest that some of these costs should be allowed as recoverable. The Company calculates that the total liability to NEO and Orwell due to its customers to be in the range of $0.2 million to $1.0 million. As a result, the Company adjusted its contingent liability to settle this mater to $0.2 million. This adjustment is included on the accompanying Consolidated Statement of Comprehensive Income for 2014 as a component of Cost of Sales – Natural gas purchased. New information may cause the Company to materially change this estimate in future periods.
	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.
	Richard M. Osborne Suits
	On June 13, 2014, Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, filed a lawsuit against the Company and the Company’s corporate secretary captioned, “Richard M. Osborne and Richard M. Osborne Trust, Under Restated and Amended Trust Agreement of February 24, 2012 v. Gas Natural, Inc. et al.,” Case No. 14CV001210 which was filed in the Court of Common Pleas in Lake County, Ohio. In this lawsuit, Mr. Osborne seeks an order requiring the Company to provide him with “the minutes and any corporate resolutions for the past five years.” The Company has provided Mr. Osborne with all the board minutes he requested that have been approved by the board. On October 29, 2014, Mr. Osborne filed an amended complaint in this matter demanding minutes of the committees of the board of directors and additional board minutes which he claims he is entitled to receive. Mr. Osborne has also filed requests for discovery in this lawsuit. On November 17, 2014, the defendants moved to dismiss Mr. Osborne’s amended complaint for failure to state a claim upon which relief can be granted, and for summary judgment. On February 11, 2015, the Court granted defendants’ motion, dismissing the case except for one allegation in one paragraph of Mr. Osborne’s amended complaint: that the Company failed to produce minutes of any board meeting that occurred between June 1, 2014 and June 13, 2014. The Court held in abeyance its ruling on this issue, to give Mr. Osborne 30 days to conduct discovery limited to determining whether any board meetings occurred during that two-week period. On February 13, 2015, Mr. Osborne voluntarily dismissed his Complaint, without prejudice.
	On June 26, 2014, Mr. Osborne filed a lawsuit against Gas Natural and the Company’s board of directors captioned “Richard M. Osborne, Richard M. Osborne Trust, Under Restated and Amended Trust Agreement of February 24, 2012 and John D. Oil and Gas Marketing Company, LLC v. Gas Natural, Inc. et al.,” Case No. 14CV001290, filed in the Court of Common Pleas in Lake County, Ohio. In this lawsuit, among other things, Mr. Osborne (1) demanded payment of an earnout associated with Gas Natural’s purchase of assets from John D. Marketing, (2) alleged that the board of directors breached its fiduciary duties, primarily by removing Mr. Osborne as chairman of the board and chief executive officer, (3) sought injunctive relief to restrain the Company’s board members from “taking any actions on behalf of Gas Natural until they are in compliance with the law and the documents governing corporate governance,” and (4) asked the Court to enjoin the 2014 annual meeting that was scheduled to take place on July 30, 2014, and to delay it until such time that the board of directors would be “in compliance with the law and corporate governance.”
	Mr. Osborne dismissed the above lawsuit on July 15, 2014, without prejudice, as the parties started to engage in settlement negotiations in an attempt to resolve the dispute. After settlement negotiations broke down, Mr. Osborne refiled the lawsuit on July 28, 2014, against Gas Natural and the Company’s board members. In the re-filed lawsuit, among other things, Mr. Osborne (1) demands payment of an earnout amount associated with Gas Natural’s purchase of assets from John D. Marketing, (2) alleges that the board of directors breached its fiduciary duties by removing Mr. Osborne as chairman and chief executive officer, (3) seeks to enforce a July 15, 2014 term sheet, where the parties memorialized certain discussions they had in connection with their efforts to resolve the dispute arising out of the lawsuit, which included a severance payment of $1.0 million, and (4) seeks to invalidate the results of the July 30, 2014 shareholder meeting and asks the court to order Gas Natural to hold a new meeting at a later date. Mr. Osborne is also seeking compensatory and punitive damages. The parties are currently conducting discovery in this lawsuit. Gas Natural believes that Mr. Osborne’s claims in this lawsuit are wholly without merit and will vigorously defend this case on all grounds.
	As disclosed above, on June 26, 2014, Mr. Osborne filed a lawsuit against the Company in the Court of Common Pleas in Lake County, Ohio. In the lawsuit, Mr. Osborne sought injunctive relief delaying the 2014 annual meeting scheduled to take place on July 30, 2014. While that suit was pending, on July 9, 2014, Mr. Osborne mailed the first of several letters to the Company’s shareholders, criticizing the Company’s board and seeking the shareholders’ support in replacing them. On July 15, 2014, Mr. Osborne dismissed without prejudice his Lake County lawsuit, but he refiled it on July 28, 2014. He did not again seek to enjoin the annual shareholder meeting, which occurred as scheduled two days later. Instead, he requests in his complaint that the Lake County court void the election of directors at the July 30, 2014 meeting and order the Company to conduct another shareholder meeting for the purpose of electing directors no later than February 2015, which the Court has not done. Mr. Osborne’s refiled lawsuit remains pending. Mr. Osborne wrote two additional letters, dated August 12, 2014, and September 9, 2014, which he mailed to the Company’s shareholders in mid-September. In the letters Mr. Osborne continued to criticize the Company’s board and management.
	Mr. Osborne did not file his letters with the Securities and Exchange Commission and the Company believes that his letters violated Section 14(a) of the Securities Exchange Act and related regulations that require shareholder solicitations to be filed with the SEC. On October 2, 2014, Gas Natural filed a suit against Mr. Osborne captioned “Gas Natural Inc. v. Richard M. Osborne” in the United States District Court Northern District of Ohio (Case No. 1:14-cv-2181). In this case the Company sought to enjoin Mr. Osborne from sending additional letters to the Company’s shareholders without complying with applicable Federal securities laws. The court held a hearing on October 8, 2014, and the judge granted the injunction, requiring Mr. Osborne to file with the SEC any letters he writes to shareholders so long as his action in Lake County seeking to invalidate the July 30, 2014 meeting is pending. Mr. Osborne has appealed the ruling. The Company believes his appeal is wholly without merit and will vigorously contest it.
	Shareholders Suit
	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 the Company’s 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). 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.
	The consolidated action contains claims against various current or former directors or officers of Gas Natural alleging, among other things, violations of federal securities laws, breaches of fiduciary duty, waste of corporate assets and unjust enrichment 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 former chairman and chief executive officer, and Thomas J. Smith, a director of the Company and its former chief financial officer. The suit seeks 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 and other relief.
	Gas Natural and the other defendants filed a motion to dismiss the consolidated action in its entirety on May 8, 2014. The motion to dismiss was based on, among other things, the failure of the plaintiffs to make demand on Gas Natural’s board of directors to address the alleged wrongdoing prior to filing their lawsuits and the failure to state viable claims against various individual defendants. Richard Osborne, individually, is now represented by counsel independent of all other defendants in the case and submitted a filing in support of the motion to dismiss on his own behalf.
	On September 24, 2014, the magistrate judge assigned to the case issued a report and recommendation in response to the motion to dismiss. The magistrate judge recommended that the plaintiffs’ claims against the individual defendants with respect to the “unjust enrichment” allegation in the complaint be dismissed. The magistrate judge recommended that all other portions of the motion to dismiss be denied. The report and recommendation, the objections filed by the defendants, and the responses from the plaintiffs will all be reviewed by the trial judge assigned to the case who will then either adopt the report and recommendation in full, reject it in full, or adopt in part and modify in part. The parties engaged in a settlement mediation on February 25, 2015. The parties failed to reach a settlement, but discussions are ongoing.
	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 action. This insurance carries a $250,000 deductible, which the Company has reached. Although the Company believes these insurance proceeds are available, the Company may incur costs and expenses related to the lawsuits that are not covered by insurance which may be substantial. Any unfavorable outcome of the pending lawsuits could adversely impact the Company’s business and results of operations.
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 he was terminated in violation of a 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 Gas Natural’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 court had asked the parties to file comprehensive statements of fact and scheduled a hearing on the motion to dismiss on July 1, 2014. On July 1, 2014, the court conducted a hearing, made extensive findings on the record, and issued an Order finding in favor of the Company and dismissing all of Mr. Harrington’s claims. On July 21, 2014, Mr. Harrington appealed the dismissal to the Montana Supreme Court where the matter is presently pending awaiting full briefing by the parties. The Company continues to believe Mr. Harrington’s claims under Montana law are without merit, and will continue to vigorously defend this case on all grounds.
Special Committee of the Board Investigation
On March 26, 2014, the board of directors formed a special committee comprised of three independent directors to investigate the allegations contained in a letter received from one of our shareholders. The letter demands that the board take legal action to remedy alleged breaches of fiduciary duties by the board and certain of our executive officers in connection with the Order and Opinion issued by the PUCO on November 13, 2013. The special committee has the power to retain any advisors, including legal counsel and accounting, financial and regulatory advisors, that the committee determines to be appropriate to carry out its responsibilities in connection with its investigation. The special committee has retained legal counsel and financial and regulatory advisors and is in the process of investigating and evaluating the allegations in order to determine the position Gas Natural will take with respect to the letter. Although the Company believes that insurance proceeds are available for a portion of the cost of the investigation, the Company will incur costs and expenses related to the investigation that are not covered by insurance, which may be substantial.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events	Note 25 – Subsequent Events
	On January 14, 2015, the Company entered into an asset purchase agreement with Utility Pipeline, LTD to sell nearly all of the assets and liabilities of its Clarion and Walker subsidiaries. The Company will receive $0.9 million under the transaction. The agreement contains customary representations, warranties, covenants and indemnification provisions. The consummation of the transaction is dependent upon the satisfaction or waiver of a number of customary closing conditions, the receipt of regulatory approvals and the consent of certain of the Company’s lenders. The Company expects this transaction to be finalized in the second quarter of 2015.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
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 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, loss contingencies, 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.
	For build-to-suit leases, the Company evaluates its level of risk during the asset’s construction or development period. If the Company determines that it bears substantially all of the risk during this period, it establishes an asset and liability for the total project costs with the liability reduced by any project costs paid directly by the Company. Once the build-to-suit asset is complete, the Company assesses whether the arrangement qualifies for sales recognition under the sale-leaseback accounting guidance. If the lease meets the criteria to qualify as a sales-lease back transaction, then the asset and liability are removed from the Company’s consolidated balance sheet. If it does not meet the criteria to qualify as a sale-leaseback transaction, then the asset and liability remain on the Company's consolidated balance sheet and the transaction is treated as a financing.
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, 2014, 2013 and 2012.
	The Company recognizes interest and penalties related to unrecognized tax benefits in operating expense. As of December 31, 2014 and 2013, there were no unrecognized tax benefits nor interest or penalties accrued related to unrecognized tax benefits. For the years ended December 31, 2014, 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 2010 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
	Accounts receivable are generated from sales and delivery of natural gas 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.
	At December 31, 2013, included in the accounts receivable, trade line item on the accompanying Consolidated Balance Sheet was $1,059,224, net of allowance for doubtful accounts of $1,421,000, due from a large industrial customer in bankruptcy proceedings. The Company believed that it had an administrative claim for the unreserved portion and that it was likely to collect the amount. In June 2014, the bankruptcy court denied the Company’s administrative claim on the customer. The Company’s claim is now considered that of an unsecured creditor and as such the Company believes that it is unlikely that it will collect any of the previously unreserved amounts. As a result, the Company has written-off the remaining balance of the receivable. This receivable was related to the Company’s Marketing & Production operating segment. The impact of the amount written-off is reflected in the Provision for doubtful accounts line of the Company’s Consolidated Statement of Comprehensive Income. Total write-offs of receivables for the years ended December 31, 2014, 2013, and 2012 were $2,717,844, $161,674, and $213,855, respectively.
	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.
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. 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 $557,500 and $254,667 at December 31, 2014 and 2013, respectively. Amortization expense for customer relationships for the years ended December 31, 2014, 2013, and 2012 was $302,833, $186,167 and $22,833. The following table shows the Company’s estimated amortization related to its intangible assets over the next five years.
	Estimated intangible asset amortization expense for the years ended December 31,
	2015	$	302,833
	2016		302,833
	2017		302,833
	2018		302,833
	2019		302,833
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
	For equity investments in which the Company does not control the investee, but can exert significant influence over the financial and operating policies of the investees, the Company uses the equity method of accounting. Under this accounting treatment, the Company’s share of the investee’s underlying net income or loss is recorded as non-operating income on the Company’s Consolidated Statement of Comprehensive Income with a corresponding increase or decrease in the investment account. Distributions received from the investment reduce the Company’s investment balance.
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, 2014 and 2013, 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 in the accompanying Consolidated Balance Sheets. The Company amortizes this amount added to property, plant, and equipment. 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
	ASC 815 - Derivatives and Hedging requires companies to recognize all of its derivative instruments as either assets or liabilities in the statement of financial position at fair value. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and further, on the type of hedging relationship. For those derivative instruments that are designated and qualify as hedging instruments, a company must designate the hedging instrument, based upon the exposure being hedged, as a fair value hedge, cash flow hedge, or a hedge of a net investment in a foreign operation. For derivative instruments not designated as hedging instruments, the gain or loss is recognized in the statement of financial performance during the current period.
	The Company is exposed to certain risks relating to its ongoing business operations. The primary risk managed by using derivative instruments is commodity price risk related to natural gas. Forward contracts and commodity price swaps with fixed pricing are entered into by the Company to protect profit margins on future obligations to deliver gas at fixed prices or to protect its regulated utility customers from possible adverse price fluctuations in the market. These forward contracts usually qualify as a “normal purchase” or “normal sale” and are exempt from derivative accounting treatment. The Company’s commodity price swaps do not meet any of the exemption criteria under ASC 815 and are accounted for as derivatives. At December 31, 2014, none of the Company’s derivatives were accounted for as hedging instruments.
Recent Accounting Pronouncements	Recent Accounting Pronouncements
	In May 2014, the FASB issued ASU 2014-09 Revenue from Contracts with Customers, which supersedes nearly all existing revenue recognition guidance under U.S. GAAP. The core principle of ASU 2014-09 is to recognize revenues when promised goods or services are transferred to customers in an amount that reflects the consideration to which an entity expects to be entitled for those goods or services. ASU 2014-09 defines a five step process to achieve this core principle and, in doing so, more judgment and estimates may be required within the revenue recognition process than are required under existing U.S. GAAP. This pronouncement is effective for annual reporting periods beginning after December 15, 2016 and is to be applied using one of two retrospective application methods, with early application not permitted. The Company is currently evaluating the impact of the pending adoption of ASU 2014-09 on the consolidated financial statements.
	In April 2014, the FASB issued ASU 2014-08 Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity, which amends the prior guidance of the reclassification of components of an entity to discontinued operations under U.S. GAAP. Under the amended guidance, a disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. The amendment also removes requirements relating to the cessation of operations, cash flows and significant continuing involvement with the discontinued component. This pronouncement is effective for annual and interim periods beginning after December 15, 2014 with early adoption permitted. This update is to be applied prospectively on components classified as held for sale after the adoption date. The Company has chosen to early adopt ASU 2014-08 effective September 30, 2014.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Schedule of Finite-Lived Intangible Assets	The following table shows the Company’s estimated amortization related to its intangible assets over the next five years.
	Estimated intangible asset amortization expense for the years ended December 31,
	2015	$	302,833
	2016		302,833
	2017		302,833
	2018		302,833
	2019		302,833

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Revenue and Income from Discontinued Operations Associated with Independence	The following table reconciles the carrying amounts of the major classes of assets and liabilities to the Company’s discontinued operations as presented on its Consolidated Balance Sheet.
		December 31,
		2014		2013
	Current Assets:
	Cash and cash equivalents	$	257,358	$	406,184
	Accounts receivable, net		1,002,918		971,308
	Unbilled gas		735,122		557,498
	Inventory		181,197		748,482
	Prepayments and other		71,101		99,219
	Regulatory assets, current		250,031		88,318
	Total current assets		2,497,727		2,871,009
	Non-Current Assets:
	Property, plant & equipment, net		8,966,965		8,960,986
	Regulatory assets, non-current		155,826		155,826
	Other assets		33,416		44,382
	Total non-current assets		9,156,207		9,161,194
	Total discontinued assets	$	11,653,934	$	12,032,203
	Current Liabilities:
	Checks in excess of amounts on deposit	$	-	$	1,192
	Accounts payable		29,657		62,131
	Accrued liabilities		334,664		429,961
	Other current liabilities		139,318		52,200
	Total current liabilities		503,639		545,484
	Non-Current Liabilities:
	Customer advances for construction		40,793		29,405
	Total discontinued liabilities	$	544,432	$	574,889
	The following table reconciles the carrying amounts of the major line items constituting the pretax profit of discontinued operations to the after-tax profit or loss of discontinued operations that are presented on the Consolidated Statement of Comprehensive Income.
		Year Ended December 31,
		2014		2013		2012
	Revenues	$	10,927,150	$	13,130,554	$	12,422,318
	Cost of sales		-6,696,602		-7,855,827		-7,279,787
	Distribution, general & administrative		-1,559,021		-2,643,821		-2,666,911
	Maintenance		-175,509		-239,321		-263,559
	Depreciation & amortization		-541,777		-925,389		-989,535
	Taxes other than income		-326,214		-395,145		-363,802
	Other income (expense)		23,597		5,098		89,048
	Interest expense		-1,603		-25,268		-23,615
	Pretax income from discontinued operations		1,650,021		1,050,881		924,157
	Loss on sale of discountinued operations		-		-7,915		-
	Total pretax income from discontinued operations		1,650,021		1,042,966		924,157
	Income tax expense		-617,410		-223,828		-400,328
	Income from discontinued operations	$	1,032,611	$	819,138	$	523,829

Assets_and_Liabilities_Held_fo1

Assets and Liabilities Held for Sale (Tables)	12 Months Ended
	Dec. 31, 2014
Assets [Abstract]
Assets And Liabilities Available Or Held For Sale	The following table summarizes the major classes of asset and liabilities classified as held for sale at December 31, 2014.
		December 31,
		2014
	Current Assets:
	Accounts receivable, net		49,069
	Unbilled gas		22,151
	Inventory		3,622
	Prepayments and other		5,401
	Regulatory assets, current		203,241
	Total current assets		283,484
	Non-Current Assets:
	Property, plant & equipment, net		407,247
	Goodwill		111,705
	Total non-current assets		518,952
	Total assets held for sale	$	802,436
	Current Liabilities:
	Accounts payable		36,184
	Accrued liabilities		21,632
	Other current liabilities		3,600
	Total liabilities held for sale	$	61,416

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	The schedule below describes the changes in carrying amount of goodwill for the years ended December 31, 2014 and 2013:
				Marketing &
		Natural Gas		Production		Total
	Balance as of December 31, 2012	$	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
	Classified as asset held for sale		-111,705		-		-111,705
	Balance as of December 31, 2014	$	14,779,672	$	1,376,000	$	16,155,672
Schedule of Intangible Assets and Goodwill	The following table shows the Company’s gross goodwill balance and accumulated impairment loss as of the balance sheet dates.
		December 31,
		2014		2013
	Goodwill, gross
	Natural Gas	$	14,779,672	$	14,891,377
	Marketing & Production		2,101,744		2,101,744
	Total goodwill, gross		16,881,416		16,993,121
	Accumulated impairment loss
	Natural Gas		-		-
	Marketing & Production		-725,744		-725,744
	Total accumulated impairment loss		-725,744		-725,744
	Goodwill, net	$	16,155,672	$	16,267,377

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014 and 2013.
		December 31, 2014
		Level 1		Level 2			Level 3			TOTAL
	LIABILITIES:
	Contingent consideration	$	-	$	-		$	747,000		$	747,000
	Commodity swap contracts	$	-	$	3,023,271		$	-		$	3,023,271
		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
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 Liability
		2014		2013
	Balance January 1st	$	685,000	$	-
	Transfers into level 3		-		-
	Transfers out of level 3		-		-
	Total (gains) losses for period:
	Included in net income		62,000		-1,565,000
	Included in other comprehensive income		-		-
	Purchases		-		-
	Sales		-		-
	Settlements		-		-
	Issuances		-		2,250,000
	Balance December 31st	$	747,000	$	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		Valuation		Unobservable Input			Range
				Techniques
	31-Dec-14
	Contingent Consideration	$	747,000	Monte Carlo analysis		Forecasted annual EBITDA				$0.5 - $0.7 million
						Weighted avg cost of capital				14.0% - 14.0%
						U.S. Treasury yields				0.3% -1.1%
				Discounted cash flow		U.S. Treasury yields				0.3% -1.1%
						Credit spread				2.3% - 3.8%
	31-Dec-13
	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%

Marketable_Securities_Tables

Marketable Securities (Tables)	12 Months Ended
	Dec. 31, 2014
Investments, Debt and Equity Securities [Abstract]
Summary of Available-For-Sale Securities Owned by Company	The following is a summary of available-for-sale securities at December 31, 2013.
		December 31, 2013
		Investment		Unrealized		Unrealized		Estimated
		at cost		gains		losses		fair value
	Common stock	$	238,504	$	167,630	$	-	$	406,134

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	The following table summarizes the commodity swap contracts entered into by the Company as of December 31, 2014. The Company will pay the fixed price listed for the volumes denoted in the table below. In exchange it will receive from a counterparty a variable payment based on the market price for the natural gas product listed for these volumes. These payments are settled monthly.
	Product		Type			Contract Period			Volume		Price per MMBtu
	CIG - Rockies - IFERC Natural Gas			Swap			1/1/15 - 3/31/15			500 MMBtu/Day	$	3.98
	CIG - Rockies - IFERC Natural Gas			Swap			1/1/15 - 3/31/15			500 MMBtu/Day	$	4.075
	AECO Canada - CGPR 7A Natural Gas			Swap			1/1/15 - 3/31/15			501 MMBtu/Day	$	3.56
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			1/1/15 - 3/31/15			3600 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			4/1/15 - 4/30/15			2500 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			5/1/15 - 5/31/15			1390 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			6/1/15 - 6/30/15			950 MMBtu/Day	$	13
	IFERC Gas Market Report at Algonquin Citygate Natural Gas			Swap			7/1/15 - 7/31/15			890 MMBtu/Day	$	13
Derivative Instruments, Gain (Loss)	The table below summarizes the amount of unrealized loss recognized as a component of Net income from the commodity swap contracts.
			Year Ended December 31,
			2014			2013			2012
	Unrealized loss on commodity swap contracts not designated as hedging instruments		$	3,023,271		$	-		$	-
	Deferred unrealized loss on commodity swap contracts (1)			-2,872,386			-			-
	Unrealized loss included in Other income, net		$	150,885		$	-		$	-
		-1	Unrealized losses on commodity swap agreements incurred by the Company’s regulated subsidiaries have been deferred as a regulatory asset on the Company’s Consolidated Balance Sheet. See Note 11 - Regulatory Assets and Liabilities.
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The table below shows the line item in the Company’s Consolidated Balance Sheets where the fair value of the commodity swap contracts is included.
	Fair Value of Derivative Instruments
			Liabilities
					December 31,
			Balance Sheet Location		2014			2013
	Derivatives not designated as hedging instruments
	Commodity swap contracts		Derivative instruments		$	3,023,271		$	-

Regulatory_Assets_and_Liabilit1

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets And Liabilities	The following table summarizes the components of the Company’s regulatory asset and liability balances at December 31, 2014 and 2013.
			December 31,
			2014						2013
			Current			Long-term			Current		Long-term
	REGULATORY ASSETS
	Recoverable cost of gas purchases		$	692,117		$	-		$	1,209,982	$	-
	Deferred costs			489,996			1,715,006			-		-
	Deferred loss on commodity swaps			2,872,385			-			-		-
	Income taxes			-			296,819			-		296,819
	Property taxes			-			-			-		25,000
	Rate case costs			43,324			43,579			-		130,228
	Total regulatory assets		$	4,097,822		$	2,055,404		$	1,209,982	$	452,047
	REGULATORY LIABILITIES
	Over-recovered gas pruchases		$	925,175		$	-		$	793,184	$	-
	Income taxes			-			83,161			-		83,161
	Asset retirement costs			-			1,006,689			-		881,301
	Total regulatory liabilities		$	925,175		$	1,089,850		$	793,184	$	964,462
Liability is Equal to Percent of Asset Cost	The liability is equal to a set percent of the asset’s historic cost according to the following table:
		Percent of Asset Cost
		Orwell				Brainard
	Mains			15	%			20	%
	Meter/regulator stations			10	%
	Service lines			75	%

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Payables and Accruals [Abstract]
Schedule of Accrued Liabilities	The following table summarizes the components of the Company’s accrued liabilities balances at December 31, 2014 and 2013.
		December 31,
		2014		2013
	Taxes other than income	$	2,082,690	$	3,043,583
	Vacation		93,845		83,189
	Employee benefits		123,171		161,440
	Interest		200,502		169,581
	Deferred payments received from levelized billing		2,360,455		2,293,801
	Accrued liabilities	$	4,860,663	$	5,751,594

Earnings_per_Share_Tables

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted		Year Ended December 31,
		2014		2013		2012
	Numerator:
	Income from continuing operations	$	2,729,166	$	5,852,141	$	3,195,488
	Income from discontinued operations		1,032,611		819,138		523,829
	Net income	$	3,761,777	$	6,671,279	$	3,719,317
	Denominator:
	Basic weighted average common shares outstanding		10,478,312		9,339,002		8,163,814
	Dilutive effect of stock options		-		720		5,865
	Dilutive effect of restricted stock awards		505		-		-
	Diluted weighted average common shares outstanding		10,478,817		9,339,722		8,169,679
	Basic & diluted earnings per share of common stock:
	Continuing operations	$	0.26	$	0.63	$	0.39
	Discontinued operations		0.1		0.08		0.07
	Net income	$	0.36	$	0.71	$	0.46

Property_Plant_Equipment_Table

Property Plant & Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Components of property, plant, and equipment were as follows:
		December 31,
		2014		2013
	Gas transmission & distribution facilities	$	163,138,652	$	138,812,125
	Land		3,773,998		3,773,998
	Buildings & leasehold improvements		11,212,860		11,241,104
	Transportation equipment		3,735,809		3,449,615
	Computer equipment		3,876,106		3,844,776
	Other equipment		11,150,519		10,065,908
	Producing natural gas properties		3,900,455		3,900,455
	Construction work in progress		8,646,219		10,762,535
	Property, plant & equipment		209,434,618		185,850,516
	Accumulated depreciation, depletion & amortization		-58,049,321		-52,301,885
			151,385,297		133,548,631
	Assets held for sale		-407,247		-
	Discontinued operations		-8,966,965		-8,960,986
	Property, plant & equipment, net	$	142,011,085	$	124,587,645

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The Company’s recognized asset retirement obligations represent the estimate costs to retire certain natural gas producing wells. The following schedule is a reconciliation of the Company’s recognized asset retirement obligations for the years ended December 31, 2014 and 2013.
		2014		2013
	Balance, January 1st	$	1,145,052	$	1,087,140
	Accretion expense		51,466		57,912
	Balance, December 31st	$	1,196,518	$	1,145,052

Credit_Facilities_and_LongTerm1

Credit Facilities and Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014 and 2013.
		December 31,
		2014		2013
	LIBOR plus 1.75 to 2.25%, Bank of America amortizing term loan, due April 1, 2017	$	8,875,000	$	9,375,000
	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
	4.15% Sun Life senior secured guaranteed note, due June 1, 2017		2,989,552		2,989,552
	Vehicle and equipment financing loans		64,509		2,190
	Total notes payable		40,263,061		43,700,742
	Less: current portion		542,201		3,502,190
	Notes payable, less current portion	$	39,720,860	$	40,198,552
Schedule of Aggregate Future Maturities of Notes Payable	The following table shows the aggregate future maturities of the Company’s notes payable.
	Years Ending
	2015	$	542,201
	2016		522,308
	2017		39,198,552
	2018		-
	2019		-
	Thereafter		-
	Total	$	40,263,061

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of Status of Outstanding Stock Options	A summary of the status of the outstanding stock options is as follows:
				Weighted		Aggregate
		Number of		Average		Intrinsic
		Shares		Exercise Price		Value
	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	$	-
	Granted		-	$	-
	Exercised		-5,000	$	8.44
	Forfeited		-	$	-
	Expired		-	$	-
	Outstanding December 31, 2014		-	$	-	$	-
	Exerciseable December 31, 2014		-	$	-	$	-
Schedule of Share-based Compensation, Restricted Stock Units Award Activity	During the vesting period, each restricted share has the same rights to dividend distributions and voting as any other common share of the Company.
		Restricked Stock
		Awards
	Outstanding, December 31, 2013	-
	Granted	5,000
	Vested	-
	Forfeited	-
	Outstanding, December 31, 2014	5,000

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
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,
		2014				2013
		Current		Long-term		Current		Long-term
	Deferred tax assets:
	Allowance for doubtful accounts	$	141,701	$	-	$	724,534	$	-
	Contributions in aid of construction		-		2,480,637		-		1,652,760
	Other nondeductible accruals		46,102		-		47,484		-
	Recoverable purchase gas costs		217,349		-		60,903		-
	Net operating loss carryforwards		-		13,255,842		-		7,733,763
	Property tax		157,683		-		154,146		-
	Other		451,213		-		754,235		-
	Total deferrred tax assets		1,014,048		15,736,479		1,741,302		9,386,523
	Deferred tax liabilities:
	Recoverable purchase gas costs		378,853		-		454,795		-
	Property, plant and equipment		-		17,375,812		-		11,402,464
	Unrealized gain on securities available for sale		-		549,046		61,475		-
	Amortization of intangibles		-		738,608		-		539,498
	Other		-		1,114,692		-		800,698
	Total deferrred tax liabilities		378,853		19,778,158		516,270		12,742,660
	Net deferred tax asset (liability) before valuation allowance		635,195		-4,041,679		1,225,032		-3,356,137
	Less: valuation allowance		-		-6,496,715		-		-5,699,029
	Total deferred tax asset (liability)		635,195		-10,538,394		1,225,032		-9,055,166
	Discontinued operations		-		-		-		-
	Net deferred tax asset (liability), continuing operations	$	635,195	$	-10,538,394	$	1,225,032	$	-9,055,166
Summary of Income Tax Expense from Continuing Operations	Income tax expense from continuing operations consists of the following:
		Year Ended December 31,
		2014		2013		2012
	Current income tax expense (benefit):
	Federal	$	49,270	$	-344,342	$	-150,224
	State		10,961		120,753		245,483
	Total current income tax expense (benefit)		60,231		-223,589		95,259
	Deferred income tax expense:
	Federal		1,987,409		3,692,413		2,030,525
	State		138,414		-200,217		252,403
	Total deferred income tax expense		2,125,823		3,492,196		2,282,928
	Total income taxes before credits		2,186,054		3,268,607		2,378,187
	Investment tax credit, net		-21,062		-21,062		-21,062
	Total income tax expense		2,164,992		3,247,545		2,357,125
	Income tax expense from discontinued operations		-617,410		-223,834		-400,326
	Income tax expense from continuing operations	$	1,547,582	$	3,023,711	$	1,956,799
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,
		2014		2013		2012
	Tax expense at statutory rate of 34%	$	2,015,101	$	3,372,404	$	2,065,991
	State income tax, net of federal tax expense		307,099		348,151		228,051
	Amortization of deferred investment tax credits		-21,062		-21,062		-21,062
	Change in valuation allowance		-397,619		-237,557		-262,343
	Permanent differences		24,580		134,583		140,211
	State rate change		149,015		-346,149		-
	Other		87,878		-2,825		206,277
	Total income tax expense		2,164,992		3,247,545		2,357,125
	Income tax expense from discontinued operations		-617,410		-223,834		-400,326
	Income tax expense from continuing operations	$	1,547,582	$	3,023,711	$	1,956,799

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
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, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, at December 31, 2014 and 2013.
		Accounts Receivable				Accounts Payable
		December 31,		December 31,		December 31,		December 31,
		2014		2013		2014		2013
	Cobra Pipeline	$	178,596	$	131,208	$	67,982	$	76,909
	Orwell Trumbell Pipeline		-		-		102,231		122,693
	Great Plains Exploration		959		7,033		9		73,983
	Big Oats Oil Field Supply		4,752		4,945		-		179,447
	John D. Oil and Gas Company		6,854		91		-		82,188
	OsAir		35,329		-		97		16,703
	Other		8,120		2,948		-		8,010
	Total related party balances		234,610		146,225		170,319		559,933
	Less amounts included in discontinued operations		-		-		-		-
	Total related party balances included in continuing operations	$	234,610	$	146,225	$	170,319	$	559,933
Summary of Related Parties Transactions	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for the year ended December 31, 2014:
		Year Ended December 31, 2014
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas Sales		Rental Income
		Purchases		Construction		Consulting and				and Other Sales
				Purchases		Other Purchases
	Cobra Pipeline	$	1,119,192	$	-	$	18,000	$	104,623	$	13,400
	Orwell Trumbell Pipeline		788,026		-		-		1,956		37,124
	Great Plains Exploration		611,187		-		-		13,073		5,200
	Big Oats Oil Field Supply		-		254,752		93,741		5,181		850
	John D. Oil and Gas Company		737,522		-		-		575		42,209
	OsAir		176,116		-		6,317		3,788		52,045
	Lake Shore Gas Storage		162,360		-		-		-		-
	Other		76,282		-		22,808		22,240		1,676
	Total	$	3,670,685	$	254,752	$	140,866	$	151,436	$	152,504
	The table below details transactions with related parties, including companies owned or controlled by Richard M. Osborne, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for the year ended December 31, 2013:
		Year Ended December 31, 2013
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas Sales		Rental Income
		Purchases		Construction		Consulting and				and Other Sales
				Purchases		Other Purchases
	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, father of the Company’s chief executive officer and the Company’s former chairman and chief executive officer, for the year ended December 31, 2012:
		Year Ended December 31, 2012
		Natural Gas		Pipeline		Rent, Supplies,		Natural Gas Sales		Rental Income
		Purchases		Construction		Consulting and				and Other Sales
				Purchases		Other Purchases
	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

Unaudited_Quarterly_Results_of1

Unaudited Quarterly Results of Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Results of Operations		2014 Quarter Ended
		December 31,		September 30,  (1)		June 30,		March 31,
	Revenue	$	36,958,232	$	13,614,971	$	20,499,919	$	61,496,719
	Gross margin		12,036,544		7,014,641		8,392,127		17,409,150
	Income (loss) from continuing operations	$	1,200,689	$	-1,514,569	$	-1,493,499	$	4,536,545
	Discontinued operations		450,959		34,825		64,881		481,946
	Net income (loss)	$	1,651,648	$	-1,479,744	$	-1,428,618	$	5,018,491
	Basic and diluted earnings per share
	Continuing operations	$	0.11	$	-0.14	$	-0.14	$	0.43
	Discontinued operations		0.05		-		-		0.05
	Net income (loss) per share	$	0.16	$	-0.14	$	-0.14	$	0.48
		2013 Quarter Ended
		December 31, (2)		September 30,  (3)		June 30,  (4)		March 31,
	Revenue	$	36,286,131	$	13,617,328	$	18,707,462	$	40,789,432
	Gross margin		13,476,706		7,234,509		7,351,808		15,307,311
	Income (loss) from continuing operations	$	2,797,734	$	-850,046	$	-429,753	$	4,334,206
	Discontinued operations		417,076		-154,292		102,837		453,517
	Net income (loss)	$	3,214,810	$	-1,004,338	$	-326,916	$	4,787,723
	Basic and diluted earnings per share
	Continuing operations	$	0.27	$	-0.08	$	-0.05	$	0.52
	Discontinued operations		0.04		-0.02		0.01		0.05
	Net income (loss) per share	$	0.31	$	-0.1	$	-0.04	$	0.57
	(1) Company classified its Energy West Wyoming subsidiary and Glacier and Shoshone Pipeline Assets as discontinued operations. All prior periods have been restated to match this presentation.
	(2) Company recorded a goodwill impairment expense of $0.7 million and an unrealized gain on its contingent consideration liability of $1.6 million.
	(3) Company classified its Independence subsidiary as discontinued operations. All prior periods have been restated to match this presentation.
	(4) Company recorded a contingent liability of $0.9 million, related to the PUCO’s GCR audit of its Ohio utilities, reducing gross margin.

Segments_of_Operation_Tables

Segments of Operation (Tables)	12 Months Ended
	Dec. 31, 2014
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 & Production, and Corporate & Other operating segments.
	Year Ended December 31, 2014	Natural Gas		Marketing &		Corporate &		Consolidated
				Production		Other
	OPERATING REVENUES	$	123,378,718	$	17,605,367	$	-	$	140,984,085
	Intersegment eliminations		-326,164		-8,088,080		-		-8,414,244
	Total operating revenue		123,052,554		9,517,287		-		132,569,841
	COST OF SALES		79,422,717		16,708,906		-		96,131,623
	Intersegment eliminations		-326,164		-8,088,080		-		-8,414,244
	Total cost of sales		79,096,553		8,620,826		-		87,717,379
	GROSS MARGIN		43,956,001		896,461		-		44,852,462
	OPERATING EXPENSES
	Distribution, general and administrative		20,975,963		1,833,476		3,175,197		25,984,636
	Maintenance		1,224,998		493		-		1,225,491
	Depreciation and amortization		6,070,669		514,654		19,246		6,604,569
	Accretion		6,856		44,610		-		51,466
	Taxes other than income		3,898,337		23,367		6,314		3,928,018
	Unrealized holding loss		-		62,000		-		62,000
	Intersegment eliminations		-102,898		-		-		-102,898
	Total operating expenses		32,073,925		2,478,600		3,200,757		37,753,282
	OPERATING INCOME (LOSS)		11,882,076		-1,582,139		-3,200,757		7,099,180
	Other income (expense)		889,873		-502,367		16,158		403,664
	Interest expense		-2,619,294		-121,041		-485,761		-3,226,096
	Income (loss) before taxes		10,152,655		-2,205,547		-3,670,360		4,276,748
	Income tax benefit (expense)		-3,661,125		771,844		1,341,699		-1,547,582
	INCOME (LOSS) FROM CONTINUING OPERATIONS		6,491,530		-1,433,703		-2,328,661		2,729,166
	Discontinued operations, net of income tax		-		-		1,032,611		1,032,611
	NET INCOME (LOSS)	$	6,491,530	$	-1,433,703	$	-1,296,050	$	3,761,777
	Capital expenditures	$	21,530,449	$	60,415	$	21,816	$	21,612,680
	Year Ended December 31, 2013	Natural Gas		Marketing &		Corporate &		Consolidated
				Production		Other
	OPERATING REVENUES	$	97,259,443	$	20,260,001	$	-	$	117,519,444
	Intersegment eliminations		-26,331		-8,092,760		-		-8,119,091
	Total operating revenue		97,233,112		12,167,241		-		109,400,353
	COST OF SALES		56,003,485		18,145,625		-		74,149,110
	Intersegment eliminations		-26,331		-8,092,760		-		-8,119,091
	Total cost of sales		55,977,154		10,052,865		-		66,030,019
	GROSS MARGIN		41,255,958		2,114,376		-		43,370,334
	OPERATING EXPENSES
	Distribution, general and administrative		19,560,991		801,305		1,770,564		22,132,860
	Maintenance		1,139,496		2,765		-		1,142,261
	Depreciation and amortization		5,081,293		456,790		12,670		5,550,753
	Accretion		7,068		50,844		-		57,912
	Unrealized holding gain		-		-1,565,000		-		-1,565,000
	Goodwill impairment		-		725,744		-		725,744
	Taxes other than income		3,619,304		28,113		24,513		3,671,930
	Intersegment eliminations		-13,744		-		-84,090		-97,834
	Total operating expenses		29,394,408		500,561		1,723,657		31,618,626
	OPERATING INCOME (LOSS)		11,861,550		1,613,815		-1,723,657		11,751,708
	Other income (expense)		767,235		151,168		-618,104		300,299
	Interest expense		-2,566,310		-142,031		-467,814		-3,176,155
	Income (loss) before taxes		10,062,475		1,622,952		-2,809,575		8,875,852
	Income tax benefit (expense)		-3,242,814		-586,326		805,429		-3,023,711
	INCOME (LOSS) FROM CONTINUING OPERATIONS		6,819,661		1,036,626		-2,004,146		5,852,141
	Discontinued operations, net of income tax		-		-		819,138		819,138
	NET INCOME (LOSS)	$	6,819,661	$	1,036,626	$	-1,185,008	$	6,671,279
	Capital expenditures	$	23,241,913	$	217,201	$	57,809	$	23,516,923
				Marketing &		Corporate &
	Year Ended December 31, 2012	Natural Gas		Production		Other		Consolidated
	OPERATING REVENUES	$	73,925,318	$	13,417,723	$	-	$	87,343,041
	Intersegment eliminations		-24,837		-5,924,362		-		-5,949,199
	Total operating revenue		73,900,481		7,493,361		-		81,393,842
	COST OF SALES		38,577,444		11,877,518		-		50,454,962
	Intersegment eliminations		-24,837		-5,924,362		-		-5,949,199
	Total cost of sales		38,552,607		5,953,156		-		44,505,763
GROSS MARGIN	$	35,347,874	$	1,540,205	$	-	$	36,888,079
OPERATING EXPENSES
Distribution, general and administrative		17,904,439		449,665		1,109,677		19,463,781
Maintenance		994,058		1,014		-		995,072
Depreciation and amortization		4,034,452		268,202		34,542		4,337,196
Accretion		113,106		48,192		-		161,298
Taxes other than income		3,110,909		38,052		39,110		3,188,071
Total operating expenses		26,156,964		805,125		1,183,329		28,145,418
OPERATING INCOME (LOSS)	$	9,190,910	$	735,080	$	-1,183,329	$	8,742,661
Other income (expense)		346,048		-6,051		-1,230,651		-890,654
Interest expense		-2,198,888		-133,440		-367,391		-2,699,719
Income (loss) before taxes		7,338,070		595,589		-2,781,371		5,152,288
Income tax benefit (expense)		-2,869,083		4,542		907,742		-1,956,799
INCOME (LOSS) FROM CONTINUING OPERATIONS	$	4,468,987	$	600,131	$	-1,873,629	$	3,195,489
Discontinued operations, net of income tax		-		-		523,829		523,829
NET INCOME (LOSS)	$	4,468,987	$	600,131	$	-1,349,800	$	3,719,318
Capital expenditures	$	17,686,583	$	1,393,040	$	856,359	$	19,935,982
Schedule of Company's Assets by Operating Segment				Marketing &
		Natural Gas		Produrction		Corporate & Other
		Operations		Operations		Operations		Consolidated
	31-Dec-14
	Investment in unconsolidated affiliate	$	-	$	-	$	-	$	-
	Total assets	$	214,030,368	$	9,192,830	$	100,781,302	$	324,004,500
	Intersegment eliminations		-68,714,744		-2,714,405		-38,571,439		-110,000,588
	Total assets	$	145,315,624	$	6,478,425	$	62,209,863	$	214,003,912
	31-Dec-13
	Investment in unconsolidated affiliate	$	-	$	351,724	$	-	$	351,724
	Total assets	$	184,085,665	$	11,633,544	$	94,981,858	$	290,701,067
	Intersegment eliminations		-53,772,095		-3,678,311		-29,518,864		-86,969,270
	Total assets	$	130,313,570	$	7,955,233	$	65,462,994	$	203,731,797

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
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, 2014 and 2013:
		December 31,
		2014		2013
	Gas transmission & distribution facilities	$	6,320,000	$	6,320,000
	Capital lease assets, gross		6,320,000		6,320,000
	Accumulated depreciation		-902,857		-501,587
	Capital lease assets, net	$	5,417,143	$	5,818,413
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, 2014.
	Future Minimum Lease Payments
		Operating Leases		Build-to-suit Lease (1)		Capital Leases
	2015	$	277,634	$	2,405,890	$	300,000
	2016		242,917		2,226,081		300,000
	2017		233,913		2,092,063		300,000
	2018		222,719		205,958		300,000
	2019		210,579		-		300,000
	Thereafter		994,701		-		900,000
	Total minimum lease payments	$	2,182,463	$	6,929,992		2,400,000
	Less: Interest portion						537,062
	Liability					$	1,862,938
	(1) Relates to the Company’s ERP system build-to-suit lease. See Note 15 – Property Plant & Equipment.
Summary of Future Minimum Long-term Contract Obligations	The following table summarizes the Company’s future minimum obligations under its long-term contracts at December 31, 2014.
	Future Minimum Long-term Contract Obligations
		Northwestern				Maritimes and		Gas Purchase
		Energy		Trans-Canada		Northeast Pipeline		Contracts
	2015	$	1,434,680	$	829,775	$	357,042	$	2,939,547
	2016		519,356		368,768		357,042		817,325
	2017		519,356		368,768		357,042		-
	2018		476,076		338,036		357,042		-
	2019		-		-		357,042		-
	Thereafter		-		-		-		-
	Total	$	2,949,468	$	1,905,347	$	1,785,210	$	3,756,872

Summary_of_Business_Additional

Summary of Business - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	bbl
Summary of Business and Accounting Policies [Line Items]
Number of reporting segments	3
Natural Gas Operations [Member]
Summary of Business and Accounting Policies [Line Items]
Annual distribution of natural gas	26,000,000,000
Natural gas customers	68,000
Percentage Of Revenue On Natural Gas Operations	93.00%	89.00%	91.00%
Marketing & Production Operations [Member]
Summary of Business and Accounting Policies [Line Items]
Annually market of natural gas	1,300,000,000
EWR Subsidiary [Member]
Summary of Business and Accounting Policies [Line Items]
Number of natural gas producing wells and gas gathering assets	160
Gross Percentage Of Working Interest	55.00%
Average Net Revenue Interest, Percentage	46.00%

Significant_Accounting_Policie3

Significant Accounting Policies - Intangible Asset Amortization (Detail) (USD $)	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
2015	$302,833
2016	302,833
2017	302,833
2018	302,833
2019	$302,833

Significant_Accounting_Policie4

Significant Accounting Policies - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary of Business and Accounting Policies [Line Items]
Accounts Receivable		$1,059,224
Allowance for Doubtful Accounts		1,421,000
Receivable, Write-offs	2,717,844	161,674	213,855
Minimum [Member]
Summary of Business and Accounting Policies [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Maximum [Member]
Summary of Business and Accounting Policies [Line Items]
Property, Plant and Equipment, Useful Life	40 years
Customer Relationships [Member]
Summary of Business and Accounting Policies [Line Items]
Accumulated amortization	557,500	254,667
Amortization expense	$302,833	$186,167	$22,833

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

Mar. 05, 2013

Sep. 25, 2012

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 01, 2013

Dec. 31, 2011

Apr. 30, 2012

Jun. 04, 2012

Apr. 01, 2012

Business Acquisition [Line Items]

Fair value of earn-out provision

$747,000

$685,000

$747,000

$685,000

Customer contracts amortized estimated useful lives

10 years

Amount contributed to the company's net income

1,651,648

-1,479,744

[1]

-1,428,618

5,018,491

3,214,810

[2]

-1,004,338

[3]

-326,916

[4]

4,787,723

3,761,777

6,671,279

3,719,317

Contingent consideration, current portion

671,638

671,638

671,638

671,638

Purchase of Matchworks Building in Mentor, Ohio

1,900,000

Shares issued to purchase Loring Pipeline

2,250,004

Additional shares of common stock

210,951

Duration Of Lease Payments

10 years

Station Street 8500 [Member] | Building [Member]

Business Acquisition [Line Items]

Property, plant and equipment amounts

1,607,915

Station Street 8500 [Member] | Land [Member]

Business Acquisition [Line Items]

Property, plant and equipment amounts

244,859

Earn Out Payment [Member]

Business Acquisition [Line Items]

Contingent consideration, current portion

671,638

0

671,638

0

John D. Oil and Gas Marketing [Member]

Business Acquisition [Line Items]

Acquisition cost

600,000

Number of shares issued for payment

256,926

Purchase consideration paid

2,641,199

Fair value of earn-out provision

2,250,000

2,250,000

Business combination estimated current liability for earn out payment

669,396

669,396

Amount allocated to goodwill

2,100,000

2,100,000

Trading days used to calculate earn out payments

20 days

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment

21,600

21,600

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill

2,800,000

2,800,000

Gas Natural Resources , LIc [Member]

Business Acquisition [Line Items]

Contingent earn out payment period

5 years

Targeted EBITDA amount for contingent earn out payments

810,432

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

575,000

Amount contributed to the Company's revenues

4,300,000

1,900,000

Amount contributed to the company's net income

99,000

765,000

Loring Pipeline Lease and Related Property [Member]

Business Acquisition [Line Items]

Public Foreclosure Auction Amount

4,500,000

Lease payments per year

300,000

Shares issued to purchase Loring Pipeline

2,250,000

Annual service fee

120,000

Annual Service Fee Charge

0.0125

Discount rate of present value of the lease payments

90.00%

Present value of the minimum lease payment

2,208,026

2,208,026

Total fair value of all the assets

605,352

Leased Pipeline and Leased Pipeline Easements [Member]

Business Acquisition [Line Items]

Total fair value of all the assets

6,320,000

Public Gas Company, Inc [Member]

Business Acquisition [Line Items]

Amount allocated to Goodwill

142,971

Percentage of stock purchased

100.00%

Increase (Decrease) in Deferred Income Taxes

283,425

Public Gas Company, Inc [Member] | Kentucky [Member]

Business Acquisition [Line Items]

Product delivered to number of customers

1,600

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

1,600,000

Costs related to the transaction

$51,187

[1]

Company classified its Energy West Wyoming subsidiary and Glacier and Shoshone Pipeline Assets as discontinued operations. All prior periods have been restated to match this presentation.

[2]

Company recorded a goodwill impairment expense of $0.7 million and an unrealized gain on its contingent consideration liability of $1.6 million.

[3]

Company classified its Independence subsidiary as discontinued operations. All prior periods have been restated to match this presentation.

[4]

Company recorded a contingent liability of $0.9 million, related to the PUCObs GCR audit of its Ohio utilities, reducing gross margin.

Discontinued_Operations_Schedu

Discontinued Operations - Schedule of Major Classes of Assets and Liabilities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current Assets:
Total current assets	$11,653,934	$12,032,203
Current Liabilities:
Total current liabilities	544,432	574,889
Discontinued Operations [Member]
Current Assets:
Cash and cash equivalents	257,358	406,184
Accounts receivable, net	1,002,918	971,308
Unbilled gas	735,122	557,498
Inventory	181,197	748,482
Prepayments and other	71,101	99,219
Regulatory assets, current	250,031	88,318
Total current assets	2,497,727	2,871,009
Non-Current Assets:
Property, plant & equipment, net	8,966,965	8,960,986
Regulatory assets, non-current	155,826	155,826
Other assets	33,416	44,382
Total non-current assets	9,156,207	9,161,194
Total discontinued assets	11,653,934	12,032,203
Current Liabilities:
Checks in excess of amounts on deposit	0	1,192
Accounts payable	29,657	62,131
Accrued liabilities	334,664	429,961
Other current liabilities	139,318	52,200
Total current liabilities	503,639	545,484
Non-Current Liabilities:
Customer advances for construction	40,793	29,405
Total discontinued liabilities	$544,432	$574,889

Discontinued_Operations_Consol

Discontinued Operations - Consolidated Statement of Comprehensive Income (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$10,927,150	$13,130,554	$12,422,318
Cost of sales	-6,696,602	-7,855,827	-7,279,787
Distribution, general & administrative	-1,559,021	-2,643,821	-2,666,911
Maintenance	-175,509	-239,321	-263,559
Depreciation & amortization	-541,777	-925,389	-989,535
Taxes other than income	-326,214	-395,145	-363,802
Other income (expense)	23,597	5,098	89,048
Interest expense	-1,603	-25,268	-23,615
Pretax income from discontinued operations	1,650,021	1,050,881	924,157
Loss on sale of discountinued operations	0	-7,915	0
Total pretax income from discontinued operations	1,650,021	1,042,966	924,157
Income tax expense	-617,410	-223,828	-400,328
Income from discontinued operations	$1,032,611	$819,138	$523,829

Discontinued_Operations_Additi

Discontinued Operations - Additional Information (Detail) (USD $)	0 Months Ended		3 Months Ended
	Oct. 10, 2014	Nov. 06, 2013	Dec. 31, 2013
Schedule Of Discontinued Operations [Line Items]
Loss Limit Causes Termination Under Agreement	$750,000
Energy West Wyoming, Inc [Member]
Schedule Of Discontinued Operations [Line Items]
Proceeds from Divestiture of Businesses	15,800,000
Shoshone Pipelines [Member]
Schedule Of Discontinued Operations [Line Items]
Proceeds from Divestiture of Businesses	1,200,000
Blue Ridge Energies LLC [Member]
Schedule Of Discontinued Operations [Line Items]
Proceeds from Divestiture of Businesses		2,300,000
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal			$7,915

Assets_and_Liabilities_Held_fo2

Assets and Liabilities Held for Sale - Major Classes of Asset and Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current Assets:
Total current assets	$11,653,934	$12,032,203
Liabilities Held For Sale [Member]
Current Liabilities:
Accounts payable	36,184
Accrued liabilities	21,632
Other current liabilities	3,600
Total liabilities held for sale	61,416
Assets Held-for-sale [Member]
Current Assets:
Accounts receivable, net	49,069
Unbilled gas	22,151
Inventory	3,622
Prepayments and other	5,401
Regulatory assets, current	203,241
Total current assets	283,484
Non-Current Assets:
Property, plant & equipment, net	407,247	0
Goodwill	111,705
Total non-current assets	518,952
Total assets held for sale	$802,436

Assets_and_Liabilities_Held_fo3

Assets and Liabilities Held for Sale - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Assets And Liabilities Held For Sale [Line Items]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	$4,276,748	$8,875,852	$5,152,287
Clarion and Walker subsidiaries [Member]
Assets And Liabilities Held For Sale [Line Items]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	$212,774	$46,092	$56,388

Goodwill_changes_in_carrying_a

Goodwill - changes in carrying amount of goodwill (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Line Items]
Beginning balance	$16,267,377	$14,891,377
Acquisition of JDOG Marketing		2,101,744
GNR impairment loss	0	-725,744
Classified as asset held for sale	-111,705
Ending balance	16,155,672	16,267,377
Marketing And Production Operations [Member]
Goodwill [Line Items]
Beginning balance	1,376,000	0
Acquisition of JDOG Marketing		2,101,744
GNR impairment loss		-725,744
Classified as asset held for sale	0
Ending balance	1,376,000	1,376,000
Natural Gas Operations [Member]
Goodwill [Line Items]
Beginning balance	14,891,377	14,891,377
Acquisition of JDOG Marketing		0
GNR impairment loss		0
Classified as asset held for sale	-111,705
Ending balance	$14,779,672	$14,891,377

Goodwill_gross_goodwill_balanc

Goodwill - gross goodwill balance and accumulated impairment loss (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Goodwill, gross
Total goodwill, gross	$16,881,416	$16,993,121
Accumulated impairment loss
Total accumulated impairment loss	-725,744	-725,744
Goodwill, net	16,155,672	16,267,377	14,891,377
Natural Gas Operations [Member]
Goodwill, gross
Total goodwill, gross	14,779,672	14,891,377
Accumulated impairment loss
Total accumulated impairment loss	0	0
Goodwill, net	14,779,672	14,891,377	14,891,377
Marketing And Production Operations [Member]
Goodwill, gross
Total goodwill, gross	2,101,744	2,101,744
Accumulated impairment loss
Total accumulated impairment loss	-725,744	-725,744
Goodwill, net	$1,376,000	$1,376,000	$0

Goodwill_Additional_Informatio

Goodwill - Additional Information (Detail) (USD $)	3 Months Ended
	Jun. 30, 2013
John D. Oil And Gas Marketing [Member]
Goodwill, Acquired During Period	$2,100,000

Investment_in_Unconsolidated_A1

Investment in Unconsolidated Affiliate - Additional Information (Detail) (Kykuit [Member], USD $)	Dec. 31, 2014
Kykuit [Member]
Schedule of Equity Method Investments [Line Items]
Maximum Limit Of Additional Investment	$100,000
Equity Method Investment, Ownership Percentage	24.50%
Equity Method Investment, Aggregate Cost	2,200,000
Investments	$0

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Value Hierarchy of Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
ASSETS:
Available-for-sale securities		$406,134
LIABILITIES:
Contingent consideration	747,000	685,000
Commodity swap contracts	3,023,271
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
ASSETS:
Available-for-sale securities		406,134
LIABILITIES:
Contingent consideration	0	0
Commodity swap contracts	0
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
ASSETS:
Available-for-sale securities		0
LIABILITIES:
Contingent consideration	0	0
Commodity swap contracts	3,023,271
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
ASSETS:
Available-for-sale securities		0
LIABILITIES:
Contingent consideration	747,000	685,000
Commodity swap contracts	$0

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, 2014	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Total (gains) losses for period: Included in net income	($62,000)	$1,565,000	$0
Contingent Consideration [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Opening balance	685,000	0
Transfers into level 3	0	0
Transfers out of level 3	0	0
Total (gains) losses for period: Included in net income	62,000	-1,565,000
Total gains or losses for period Included in other comprehensive income	0	0
Purchases	0	0
Sales	0	0
Settlements	0	0
Issuances	0	2,250,000
Closing balance	$747,000	$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, 2014	Dec. 31, 2013
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value	$747,000	$685,000
Monte Carlo Analysis [Member] | Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Forecasted annual EBITDA	500,000	400,000
Weighted average cost of capital	14.00%	15.00%
U.S. Treasury yields	0.30%	0.10%
Monte Carlo Analysis [Member] | Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Forecasted annual EBITDA	$700,000	$600,000
Weighted average cost of capital	14.00%	15.00%
U.S. Treasury yields	1.10%	1.30%
Discounted Cash Flow [Member] | Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
U.S. Treasury yields	0.30%	0.10%
Credit spread	2.30%	1.30%
Discounted Cash Flow [Member] | Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
U.S. Treasury yields	1.10%	1.30%
Credit spread	3.80%	3.30%

Marketable_Securities_Addition

Marketable Securities - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Available-for-sale Securities, Fair Value to Amortized Cost Basis [Abstract]
Available-for-sale securities	$421,875	$0	$0
Unrealized gains or losses reclassified from other comprehensive income	119,720	0	0
Marketable Securities, Realized Gain (Loss)	183,371	0	0
Gross realized gains or losses		0	0
Common Stock [Member]
Available-for-sale Securities, Fair Value to Amortized Cost Basis [Abstract]
Available-for-sale securities	500,000
Unrealized gains or losses reclassified from other comprehensive income	100,000
Marketable Securities, Realized Gain (Loss)	$200,000

Marketable_Securities_Summary_

Marketable Securities - Summary of Available-For-Sale Securities Owned by Company (Detail) (USD $)	Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]
Estimated fair value	$406,134
Common Stock [Member]
Schedule of Available-for-sale Securities [Line Items]
Investment at cost	238,504
Unrealized gains	167,630
Unrealized losses	0
Estimated fair value	$406,134

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Derivative Instruments, Gain (Loss) (Details) (Swap [Member])	12 Months Ended
	Dec. 31, 2014
	MMBTuPerDay
Product [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Jan-15
Derivative, Maturity Date	31-Mar-15
Underlying, Derivative Volume	500
Derivative, Swap Type, Fixed Price	3.98
Product One [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Jan-15
Derivative, Maturity Date	31-Mar-15
Underlying, Derivative Volume	500
Derivative, Swap Type, Fixed Price	4.075
Product Two [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Jan-15
Derivative, Maturity Date	31-Mar-15
Underlying, Derivative Volume	501
Derivative, Swap Type, Fixed Price	3.56
Product Three [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Jan-15
Derivative, Maturity Date	31-Mar-15
Underlying, Derivative Volume	3,600
Derivative, Swap Type, Fixed Price	13
Product Four [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Apr-15
Derivative, Maturity Date	30-Apr-15
Underlying, Derivative Volume	2,500
Derivative, Swap Type, Fixed Price	13
Product Five [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-May-15
Derivative, Maturity Date	31-May-15
Underlying, Derivative Volume	1,390
Derivative, Swap Type, Fixed Price	13
Product Six [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Jun-15
Derivative, Maturity Date	30-Jun-15
Underlying, Derivative Volume	950
Derivative, Swap Type, Fixed Price	13
Product Seven [Member]
Derivative [Line Items]
Derivative, Type of Instrument	Swap
Derivative, Inception Date	1-Jul-15
Derivative, Maturity Date	31-Jul-15
Underlying, Derivative Volume	890
Derivative, Swap Type, Fixed Price	13

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Schedule of Derivative Instruments) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Unrealized loss on commodity swap contracts not designated as hedging instruments	$3,023,271		$0		$0
Deferred unrealized loss on commodity swap contracts	-2,872,386	[1]	0	[1]	0	[1]
Unrealized loss included in Other income, net	$150,885		$0		$0
[1]	Unrealized losses on commodity swap agreements incurred by the Companybs regulated subsidiaries have been deferred as a regulatory asset on the Companybs Consolidated Balance Sheet. See Note 11 - Regulatory Assets and Liabilities.

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Schedule of Derivative Instruments in Statement of Financial Position, Fair Value) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments Not Designated as Hedging Instruments, Type	Commodity swap contracts
Derivative Liability, Current	$3,023,271	$0

Regulatory_Assets_and_Liabilit2

Regulatory Assets and Liabilities - Schedule Of Regulatory Assets And Liabilities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
REGULATORY ASSETS
Regulatory Assets, Current	$4,097,822	$1,209,982
Regulatory Assets, Noncurrent	2,055,404	452,047
REGULATORY LIABILITIES
Regulatory Liability, Current	925,175	793,184
Regulatory Liability, Noncurrent	1,089,850	964,462
Recoverable Cost of Gas Purchases [Member]
REGULATORY ASSETS
Regulatory Assets, Current	692,117	1,209,982
Regulatory Assets, Noncurrent	0	0
Deferred Cost [Member]
REGULATORY ASSETS
Regulatory Assets, Current	489,996	0
Regulatory Assets, Noncurrent	1,715,006	0
Deferred Loss on Commodity Swaps [Member]
REGULATORY ASSETS
Regulatory Assets, Current	2,872,385	0
Regulatory Assets, Noncurrent	0	0
Income Taxes [Member]
REGULATORY ASSETS
Regulatory Assets, Current	0	0
Regulatory Assets, Noncurrent	296,819	296,819
REGULATORY LIABILITIES
Regulatory Liability, Current	0	0
Regulatory Liability, Noncurrent	83,161	83,161
Property Taxes [Member]
REGULATORY ASSETS
Regulatory Assets, Current	0	0
Regulatory Assets, Noncurrent	0	25,000
Rate Case Costs [Member]
REGULATORY ASSETS
Regulatory Assets, Current	43,324	0
Regulatory Assets, Noncurrent	43,579	130,228
Over Recovered Gas Pruchases [Member]
REGULATORY LIABILITIES
Regulatory Liability, Current	925,175	793,184
Regulatory Liability, Noncurrent	0	0
Asset Retirement Obligation Costs [Member]
REGULATORY LIABILITIES
Regulatory Liability, Current	0	0
Regulatory Liability, Noncurrent	$1,006,689	$881,301

Regulatory_Assets_and_Liabilit3

Regulatory Assets and Liabilities - Liability is Equal to Percent of Asset Cost (Detail)	12 Months Ended
	Dec. 31, 2014
Orwell [Member] | Mains [Member]
Asset Retirement Obligations [Line Items]
Regulatory Actions Estimated Useful Life Percentage Of Asset Cost Estimated Liability	15.00%
Orwell [Member] | Meter And Regulator Stations [Member]
Asset Retirement Obligations [Line Items]
Regulatory Actions Estimated Useful Life Percentage Of Asset Cost Estimated Liability	10.00%
Orwell [Member] | Service Lines [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%

Regulatory_Assets_and_Liabilit4

Regulatory Assets and Liabilities - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Jun. 27, 2014
Regulatory Assets and Liabilities [Line Items]
Amount Reclassified To Deferred Gas Cost		$2.50
Regulatory Noncurrent Asset, Amortization Period	amortized over a period of 2 to 3 years
Property Taxes [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period	over a ten-year period starting January 1, 2004

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Accrued Liabilities, Current [Abstract]
Taxes other than income	$2,082,690	$3,043,583
Vacation	93,845	83,189
Employee benefits	123,171	161,440
Interest	200,502	169,581
Deferred payments received from levelized billing	2,360,455	2,293,801
Accrued liabilities	$4,860,663	$5,751,594

Restricted_Cash_Additional_Inf

Restricted Cash - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Restricted Cash and Cash Equivalents Items [Line Items]
Additional restricted cash balance	$1.90	$1.10
Sun Life Assurance Company Of Canada [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Additional restricted cash balance	0.9	1.1
Subsidiaries [Member] | Verso Bucksport Power Llc [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Additional restricted cash balance	$0.90

Earnings_per_Share_Summary_of_

Earnings per Share Summary of Earnings Per Share (Detail) (USD $)	3 Months Ended												12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014		Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Numerator:
Income from continuing operations	$1,200,689	($1,514,569)	[1]	($1,493,499)	$4,536,545	$2,797,734	[2]	($850,046)	[3]	($429,753)	[4]	$4,334,206	$2,729,166	$5,852,141	$3,195,488
Income from discontinued operations	450,959	34,825	[1]	64,881	481,946	417,076	[2]	-154,292	[3]	102,837	[4]	453,517	1,032,611	819,138	523,829
Net income	$1,651,648	($1,479,744)	[1]	($1,428,618)	$5,018,491	$3,214,810	[2]	($1,004,338)	[3]	($326,916)	[4]	$4,787,723	$3,761,777	$6,671,279	$3,719,317
Denominator:
Basic weighted average common shares outstanding													10,478,312	9,339,002	8,163,814
Dilutive effect of stock options													0	720	5,865
Dilutive effect of stock based compensation (in shares)													505	0	0
Diluted weighted average common shares outstanding													10,478,817	9,339,722	8,169,679
Basic & diluted earnings per share of common stock:
Continuing operations	$0.11	($0.14)	[1]	($0.14)	$0.43	$0.27	[2]	($0.08)	[3]	($0.05)	[4]	$0.52	$0.26	$0.63	$0.39
Discontinued operations	$0.05	$0	[1]	$0	$0.05	$0.04	[2]	($0.02)	[3]	$0.01	[4]	$0.05	$0.10	$0.08	$0.07
Net income	$0.16	($0.14)	[1]	($0.14)	$0.48	$0.31	[2]	($0.10)	[3]	($0.04)	[4]	$0.57	$0.36	$0.71	$0.46
[1]	Company classified its Energy West Wyoming subsidiary and Glacier and Shoshone Pipeline Assets as discontinued operations. All prior periods have been restated to match this presentation.
[2]	Company recorded a goodwill impairment expense of $0.7 million and an unrealized gain on its contingent consideration liability of $1.6 million.
[3]	Company classified its Independence subsidiary as discontinued operations. All prior periods have been restated to match this presentation.
[4]	Company recorded a contingent liability of $0.9 million, related to the PUCObs GCR audit of its Ohio utilities, reducing gross margin.

Earnings_per_Share_Additional_

Earnings per Share - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	0	0

Property_Plant_Equipment_Detai

Property Plant & Equipment (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Property, plant & equipment	$209,434,618	$185,850,516
Accumulated depreciation, depletion & amortization	-58,049,321	-52,301,885
Property Plant And Equipment Net Including Discontinued Operations	151,385,297	133,548,631
Property, plant & equipment, net	142,011,085	124,587,645
Discontinued Operations [Member]
Property, plant & equipment	-8,966,965	-8,960,986
Assets Held-for-sale [Member]
Property, plant & equipment	-407,247	0
Gas, Transmission and Distribution Equipment [Member]
Property, plant & equipment	163,138,652	138,812,125
Land [Member]
Property, plant & equipment	3,773,998	3,773,998
Buildings And Leasehold Improvements [Member]
Property, plant & equipment	11,212,860	11,241,104
Transportation Equipment [Member]
Property, plant & equipment	3,735,809	3,449,615
Computer Equipment [Member]
Property, plant & equipment	3,876,106	3,844,776
Property, Plant and Equipment, Other Types [Member]
Property, plant & equipment	11,150,519	10,065,908
Oil and Gas Properties [Member]
Property, plant & equipment	3,900,455	3,900,455
Construction in Progress [Member]
Property, plant & equipment	$8,646,219	$10,762,535

Property_Plant_Equipment_Addit

Property Plant & Equipment Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Natural Gas Production Per Day	502	550	593
Percentage Of Gas Production As Aggregate Volume Requirements	26.00%	25.00%	19.90%
Property, Plant and Equipment, Net	$142,011,085	$124,587,645
Build-to-suit Lease [Member]
Construction in Progress, Gross	6,500,000
Ewr Subsidiary [Member]
Natural Gas Production Per Day	395	422	461
Percentage Of Gas Production As Aggregate Volume Requirements	20.00%	19.00%	15.50%
Ewd Subsidiary [Member]
Number Of Natural Gas Production Properties Owned	50
Natural Gas Production Per Day	107	129	132
Percentage Of Gas Production As Aggregate Volume Requirements	5.50%	5.80%	4.40%
Percentage Of Ownership Interest In Gathering System	75.00%
Natural Gas [Member]
Net Present Value Of Natural Gas Reserves	2,700,000	2,100,000
Percentage Of Depletion On Wells Per Year	10.00%	10.00%
Proved Developed and Undeveloped Reserves, Net	2.1	2.3
Fair Value Inputs, Discount Rate	10.00%
Property, Plant and Equipment, Net	$900,000	$1,000,000

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Balance	$1,145,052	$1,087,140
Accretion expense	51,466	57,912	161,298
Balance	$1,196,518	$1,145,052	$1,087,140

Asset_Retirement_Obligations_A

Asset Retirement Obligations - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation Assets Net	$48,954	$86,415

Credit_Facilities_and_LongTerm2

Credit Facilities and Long-Term Debt - Lines of Credit - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Nov. 26, 2014
Bank of America [Member]
Line of Credit Facility [Line Items]
Interest on amount outstanding	LIBOR plus 175 to 225 basis points
Debt Instruments Weighted Average Interest Rate	2.15%	2.19%	2.14%
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Maximum borrowing credit facility	30
Line of credit maturity date	1-Apr-17
Line of Credit Facility, Covenant Terms	the MPSC stated that any amounts borrowed under this increase in excess of $5.0 million would first require the approval of the MPSC
Revolving Credit Facility [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Maximum borrowing credit facility				10
Revolving Credit Facility [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Maximum borrowing credit facility				40
Revolving Credit Facility [Member] | Bank of America [Member]
Line of Credit Facility [Line Items]
Outstanding borrowings	28.8	24.5
Debt Instruments Weighted Average Interest Rate	2.45%	2.42%	3.33%
Borrowings Outstanding On Revolving Line Of Credit	23.4

Credit_Facilities_and_LongTerm3

Credit Facilities and Long-Term Debt - Summary of Outstanding Long-Term Debt Balances (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Summary of outstanding long-term debt balances
Total notes payable	$40,263,061	$43,700,742
Less: current portion	542,201	3,502,190
Notes payable, less current portion	39,720,860	40,198,552
Vehicle & Equipment Financing Loans [Member]
Summary of outstanding long-term debt balances
Total notes payable	64,509	2,190
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	8,875,000	9,375,000
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	0	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

Credit_Facilities_and_LongTerm4

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

Credit_Facilities_and_LongTerm5

Credit Facilities and Long-Term Debt - Schedule of Aggregate Future Maturities of Notes Payable (Detail) (USD $)	Dec. 31, 2014
2015	$542,201
2016	522,308
2017	39,198,552
2018	0
2019	0
Thereafter	0
Total	$40,263,061

Credit_Facilities_and_LongTerm6

Credit Facilities and Long-Term Debt - Notes Payable - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Term loan amortized per quarter	$125,000
Bank Of America [Member]
Debt Instrument [Line Items]
Weighted average interest rate on term loan	2.15%	2.19%	2.14%
Interest Expense, Debt	200,727	215,593	56,226
Allstate Or Cuna [Member] | Senior Unsecured Note [Member]
Debt Instrument [Line Items]
Interest Expense, Debt	800,800	800,800	800,800
Sun Life Assurance Company Of Canada [Member]
Debt Instrument [Line Items]
Interest Expense, Debt	824,969	824,969	824,969
Sun Life Assurance Company Of Canada [Member] | Senior Secured Guaranteed Floating Rate [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	4.10%	4.13%	4.31%
Interest Expense, Debt	40,900	123,850	129,200
Sun Life Assurance Company Of Canada [Member] | Senior Secured Guaranteed Note [Member]
Debt Instrument [Line Items]
Interest Expense, Debt	$123,007	$123,007	$23,576

Credit_Facilities_and_LongTerm7

Credit Facilities and Long-Term Debt - Debt Covenants - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2011
Sun Life Assurance Company of Canada [Member]
Summary of outstanding long-term debt balances
Interest coverage ratio	at least 2.0 to 1.0
Maximum other borrowing obligation			$500,000
Debt to capitalization rate	60.00%
Debt service reserve account	900,000	1,100,000
Maximum percentage of dividend distribution redemptions of net income	70.00%
Maximum limit for sale or transfer of assets	1.00%
Percentage of maximum limit of making acquisition	10.00%
Bank of America [Member]
Summary of outstanding long-term debt balances
Minimum Debt To Capital Ratio	0.55
Maximum debt to capital ratio	1
Maximum capital lease borrowing obligation	1,000,000
Period consider for distribution and redemption restriction	60 years
Percent of net income consider for distribution and redemption restriction	80.00%
Maximum percent of assets disposal restriction in fiscal year	5.00%
Maximum capitalized leases and purchase money obligations	$500,000
Allstate/CUNA [Member]
Summary of outstanding long-term debt balances
Aggregate consolidated net income	100.00%
Debt to capitalization rate	65.00%
Debt Instrument Interest Coverage Ratio	150.00%

Stockholders_Equity_Summary_of

Stockholders' Equity - Summary of Status of Outstanding Stock Options (Detail) (Stock Option [Member], USD $)	Stock Option [Member]
	USD ($)
Aggregate Intrinsic Value Outstanding, Beginning Balance at Dec. 31, 2012	$31,550
Number of Shares Outstanding, Beginning Balance at Dec. 31, 2012	35,000
Weighted Average Exercise Price Outstanding, Beginning Balance at Dec. 31, 2012	$8.66
Granted, Number of Shares	0
Exercised, Number of Shares	-20,000
Expired, Number of Shares	-10,000
Granted, Weighted Average Exercise Price	$0
Exercised, Weighted Average Exercise Price	$7.98
Expired, Weighted Average Exercise Price	$10.15
Aggregate Intrinsic Value Outstanding, Ending Balance at Dec. 31, 2013	0
Number of Shares Outstanding, Ending Balance at Dec. 31, 2013	5,000
Weighted Average Exercise Price Outstanding, Ending Balance at Dec. 31, 2013	$8.44
Granted, Number of Shares	0
Exercised, Number of Shares	-5,000
Forfeited, Number of Shares	0
Expired, Number of Shares	0
Exercisable, Number of Shares Outstanding	0
Granted, Weighted Average Exercise Price	$0
Exercised, Weighted Average Exercise Price	$8.44
Forfeited, Weighted Average Exercise Price	$0
Expired, Weighted Average Exercise Price	$0
Exercisable, Weighted Average Exercise Price	$0
Exercisable, Aggregate Intrinsic Value	0
Aggregate Intrinsic Value Outstanding, Ending Balance at Dec. 31, 2014	$0
Number of Shares Outstanding, Ending Balance at Dec. 31, 2014	0
Weighted Average Exercise Price Outstanding, Ending Balance at Dec. 31, 2014	$0

Stockholders_Equity_Schedule_o

Stockholders' Equity - Schedule of Restricted Stock Awards (Detail) (Restricted Stock [Member])	12 Months Ended
	Dec. 31, 2014
Restricted Stock [Member]
Outstanding, December 31, 2013	0
Granted	5,000
Vested	0
Forfeited	0
Outstanding, December 31, 2014	5,000

Stockholders_Equity_Additional

Stockholders' Equity - Additional Information (Detail) (USD $)	12 Months Ended			1 Months Ended	0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 26, 2014	Jul. 21, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures
Stock Repurchase Program, Number of Shares Authorized to be Repurchased	448,500
Share-based Compensation	316,985	2,962	60,009
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Stock Options	49,544
Subsidiaries [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Amount of Restricted Net Assets for Consolidated and Unconsolidated Subsidiaries	92,300,000
Parent Company [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Amount of Restricted Net Assets for Consolidated and Unconsolidated Subsidiaries	96,500,000
Restricted Investments, Percent of Net Assets	95.70%
2002 Stock Option Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of common shares issued subject to adjustment			300,000
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 shares granted during period				30,833
Number of shares granted fair value				300,000
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
2012 Non-Employee Director Stock Award Plan [Member] | Chief Executive Officer [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures					$58,200
Stock Issued During Period, Shares, Restricted Stock Award, Net of Forfeitures					5,000

Employee_Benefit_Plans_Additio

Employee Benefit Plans - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Annual contribution of employees salaries	3.00%
Discretionary contributions made by an employer to a defined contribution plan	3.00%
Expense related to plan	$492,047	$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	57,245	57,590	52,719
Contribution to ESOP by company	0	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	$132,717	$155,750

Income_Taxes_Summary_of_Signif

Income Taxes - Summary of Significant Components of Deferred Tax Assets and Liabilities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Deferred tax assets:
Allowance for doubtful accounts (Current)	$141,701	$724,534
Contributions in aid of construction (Current)	0	0
Other nondeductible accruals (Current)	46,102	47,484
Recoverable purchase gas costs (Current)	217,349	60,903
Net operating loss carryforwards (Current)	0	0
Property tax (Current)	157,683	154,146
Other (Current)	451,213	754,235
Total deferrred tax assets (Current)	1,014,048	1,741,302
Allowance for doubtful accounts (non current)	0	0
Contributions in aid of construction (non current)	2,480,637	1,652,760
Other nondeductible accruals (non current)	0	0
Recoverable purchase gas costs (non current)	0	0
Net operating loss carryforwards (non current)	13,255,842	7,733,763
Property tax (non current)	0	0
Other (non current)	0	0
Total deferred tax assets (non current)	15,736,479	9,386,523
Deferred tax liabilities:
Recoverable purchase gas costs (Current)	378,853	454,795
Property, plant and equipment (Current)	0	0
Unrealized gain on securities available for sale (Current)	0	61,475
Amortization of intangibles (Current)	0	0
Other (Current)	0	0
Total deferrred tax liabilities	378,853	516,270
Net deferred tax asset (liability) before valuation allowance (Current)	635,195	1,225,032
Less: valuation allowance (Current)	0	0
Total deferred tax asset (liability)	635,195	1,225,032
Discontinued operations	0	0
Net deferred tax asset (liability), continuing operations	635,195	1,225,032
Recoverable purchase gas costs (non current)	0	0
Property, plant and equipment (non current)	17,375,812	11,402,464
Unrealized gain on securities available for sale (non current)	549,046	0
Amortization of intangibles (non current)	738,608	539,498
Other (non current)	1,114,692	800,698
Total deferred tax liabilities (non current)	19,778,158	12,742,660
Net deferred tax asset (liability) before valuation allowance (non current)	-4,041,679	-3,356,137
Less: valuation allowance (non current)	-6,496,715	-5,699,029
Total deferred tax asset (liability)	-10,538,394	-9,055,166
Discontinued operations	0	0
Net deferred tax asset (liability), continuing operations	($10,538,394)	($9,055,166)

Income_Taxes_Summary_of_Income

Income Taxes - Summary of Income Tax Expense from Continuing Operations (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current income tax expense (benefit):
Federal	$49,270	($344,342)	($150,224)
State	10,961	120,753	245,483
Total current income tax expense (benefit)	60,231	-223,589	95,259
Deferred income tax expense:
Federal	1,987,409	3,692,413	2,030,525
State	138,414	-200,217	252,403
Total deferred income tax expense	2,125,823	3,492,196	2,282,928
Total income taxes before credits	2,186,054	3,268,607	2,378,187
Investment tax credit, net	-21,062	-21,062	-21,062
Total income tax expense	2,164,992	3,247,545	2,357,125
Income tax expense from discontinued operations	-617,410	-223,834	-400,326
Income tax expense from continuing operations	$1,547,582	$3,023,711	$1,956,799

Income_Taxes_Federal_Statutory

Income Taxes - Federal Statutory Rate to Pre-Tax Income from Continuing Operations (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Tax expense at statutory rate of 34%	$2,015,101	$3,372,404	$2,065,991
State income tax, net of Federal tax expense	307,099	348,151	228,051
Amortization of deferred investment tax credits	-21,062	-21,062	-21,062
Change in valuation allowance	-397,619	-237,557	-262,343
Permanent differences	24,580	134,583	140,211
State rate change	149,015	-346,149	0
Other	87,878	-2,825	206,277
Total income tax expense	2,164,992	3,247,545	2,357,125
Income tax expense from discontinued operations	-617,410	-223,834	-400,326
Income tax expense from continuing operations	$1,547,582	$3,023,711	$1,956,799

Income_Taxes_Federal_Statutory1

Income Taxes - Federal Statutory Rate to Pre-Tax Income from Continuing Operations (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statutory income tax rate	34.00%	34.00%	34.00%

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
State rate change	$149,015	($346,149)	$0
Change in valuation allowance	-397,619	-237,557	-262,343
Carryover tax basis amount	20,000,000
Net Operating Loss Carry Forwards Expiration Dates	net operating losses begin to expire in 2024
Deferred Tax Assets, Valuation Allowance	96,000
Domestic Tax Authority [Member]
Net operating loss carryover	22,500,000
State and Local Jurisdiction [Member]
Net operating loss carryover	66,800,000
State deferred tax asset valuation allowance, against the state net operating loss carryover	4,700,000
State deferred tax asset valuation allowance on the carryover tax basis of the subsidiaries	1,700,000
Frontier Utilities [Member]
Deferred Tax Assets, Operating Loss Carryforwards	98,000,000
Valuation allowance percentage	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
North Carolina And Kentucky [Member]
State rate change	336,007
NORTH CAROLINA [Member] | Frontier Utilities [Member]
Increase in deferred tax asset allowance	$1,970,586

Related_Party_Transactions_Amo

Related Party Transactions - Amounts Due from and Due to Related Parties (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Accounts Receivable, Total	$234,610	$146,225
Accounts Payable, Total	170,319	559,933
Amounts included in discontinued operations [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	0	0
Accounts Payable, Total	0	0
Amounts included in continuing operations [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	234,610	146,225
Accounts Payable, Total	170,319	559,933
Cobra Pipeline [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	178,596	131,208
Accounts Payable, Total	67,982	76,909
Orwell Trumbell Pipeline [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	0	0
Accounts Payable, Total	102,231	122,693
Great Plains Exploration [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	959	7,033
Accounts Payable, Total	9	73,983
Big Oats Oil Field Supply [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	4,752	4,945
Accounts Payable, Total	0	179,447
John D. Oil and Gas Company [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	6,854	91
Accounts Payable, Total	0	82,188
OsAir [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	35,329	0
Accounts Payable, Total	97	16,703
Other [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	8,120	2,948
Accounts Payable, Total	0	8,010
Total related party balances [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Total	234,610	146,225
Accounts Payable, Total	$170,319	$559,933

Related_Party_Transactions_Sum

Related Party Transactions - Summary of Related Parties Transactions (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Natural gas purchased	$79,096,553	$55,977,154	$38,552,607
Pipeline Construction Purchases	254,752	3,252,161	1,247,313
Rent, Supplies, Consulting and Other Purchases	140,866	798,271	662,923
Natural Gas Sales	151,436	203,362	67,549
Rental Income and Other Sales	152,504	234,499	64,664
John D. Oil and Gas Marketing [Member]
Related Party Transaction [Line Items]
Natural gas purchased		951,120	2,405,158
Pipeline Construction Purchases		0	9,870
Rent, Supplies, Consulting and Other Purchases		16,599	58,043
Natural Gas Sales		5,470	0
Rental Income and Other Sales		0	13,128
Cobra Pipeline [Member]
Related Party Transaction [Line Items]
Natural gas purchased	1,119,192	842,620	389,233
Pipeline Construction Purchases	0	263,574	5,390
Rent, Supplies, Consulting and Other Purchases	18,000	20,000	5,104
Natural Gas Sales	104,623	157,834	0
Rental Income and Other Sales	13,400	381	23,210
Orwell Trumbell Pipeline [Member]
Related Party Transaction [Line Items]
Natural gas purchased	788,026	795,190	526,785
Pipeline Construction Purchases	0	0	132
Rent, Supplies, Consulting and Other Purchases	0	0	19,547
Natural Gas Sales	1,956	1,260	26,519
Rental Income and Other Sales	37,124	33,911	4,785
Great Plains Exploration [Member]
Related Party Transaction [Line Items]
Natural gas purchased	611,187	856,696	506,503
Pipeline Construction Purchases	0	854	0
Rent, Supplies, Consulting and Other Purchases	0	1,341	0
Natural Gas Sales	13,073	9,310	7,068
Rental Income and Other Sales	5,200	47,640	10,643
Big Oats Oil Field Supply [Member]
Related Party Transaction [Line Items]
Natural gas purchased	0	0	0
Pipeline Construction Purchases	254,752	2,967,705	1,231,921
Rent, Supplies, Consulting and Other Purchases	93,741	624,147	256,607
Natural Gas Sales	5,181	3,996	2,131
Rental Income and Other Sales	850	5,125	7,068
John D. Oil and Gas Company [Member]
Related Party Transaction [Line Items]
Natural gas purchased	737,522	911,507	502,897
Pipeline Construction Purchases	0	5,975	0
Rent, Supplies, Consulting and Other Purchases	0	0	0
Natural Gas Sales	575	572	575
Rental Income and Other Sales	42,209	29,356	0
Sleepy Hollow Oil & Gas [Member]
Related Party Transaction [Line Items]
Natural gas purchased			0
Pipeline Construction Purchases			0
Rent, Supplies, Consulting and Other Purchases			0
Natural Gas Sales			0
Rental Income and Other Sales			5,113
OsAir [Member]
Related Party Transaction [Line Items]
Natural gas purchased	176,116	241,693	248,588
Pipeline Construction Purchases	0	13,200	0
Rent, Supplies, Consulting and Other Purchases	6,317	91,850	196,451
Natural Gas Sales	3,788	4,866	2,479
Rental Income and Other Sales	52,045	72,787	306
Lake Shore Gas [Member]
Related Party Transaction [Line Items]
Natural gas purchased	162,360
Pipeline Construction Purchases	0
Rent, Supplies, Consulting and Other Purchases	0
Natural Gas Sales	0
Rental Income and Other Sales	0
Other [Member]
Related Party Transaction [Line Items]
Natural gas purchased	76,282	86,987	135,927
Pipeline Construction Purchases	0	853	0
Rent, Supplies, Consulting and Other Purchases	22,808	44,334	127,171
Natural Gas Sales	22,240	20,054	28,777
Rental Income and Other Sales	$1,676	$45,299	$411

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	0 Months Ended	12 Months Ended			0 Months Ended	1 Months Ended
	Mar. 05, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Oct. 07, 2013	Dec. 18, 2013
					sqft	sqft
Related Party Transaction [Line Items]
Purchase of Matchworks Building in Mentor, Ohio	$1,900,000
Energy Related Inventory, Natural Gas in Storage		98,081	151,780
Other Nonoperating Expense		0	309,432	274,213
Affiliated Entity [Member]
Related Party Transaction [Line Items]
Accrued liability, related parties		111,133	0
John D. Oil And Gas Marketing [Member]
Related Party Transaction [Line Items]
Lease expense			5,500	13,200
Lease Expiration Date		31-Dec-16
OsAir [Member]
Related Party Transaction [Line Items]
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. In September of 2014, OsAir was evicted from the office space for failure to make payment. At December 31, 2014, $29,150 of past due rent was still owed the Company.
Monthly lease rental payments					5,500
Office space in square feet					6,472
Lessee arrangements term of contract					3 years
Deferred Rent Receivables, Net		29,150
Cobra Pipeline [Member]
Related Party Transaction [Line Items]
Description of lessee arrangement		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.
Monthly lease rental payments						2,000
Office And Ware House Superficies Square Feet						2,400
8500 Station Street [Member]
Related Party Transaction [Line Items]
Purchase of Matchworks Building in Mentor, Ohio	$1,900,000

Unaudited_Quarterly_Results_of2

Unaudited Quarterly Results of Operations - Schedule of Quarterly Results of Operations (Detail) (USD $)	3 Months Ended												12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014		Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenue	$36,958,232	$13,614,971	[1]	$20,499,919	$61,496,719	$36,286,131	[2]	$13,617,328	[3]	$18,707,462	[4]	$40,789,432	$132,569,841	$109,400,353	$81,393,842
Gross margin	12,036,544	7,014,641	[1]	8,392,127	17,409,150	13,476,706	[2]	7,234,509	[3]	7,351,808	[4]	15,307,311	44,852,462	43,370,334	36,888,079
Income (loss) from continuing operations	1,200,689	-1,514,569	[1]	-1,493,499	4,536,545	2,797,734	[2]	-850,046	[3]	-429,753	[4]	4,334,206	2,729,166	5,852,141	3,195,488
Discontinued operations	450,959	34,825	[1]	64,881	481,946	417,076	[2]	-154,292	[3]	102,837	[4]	453,517	1,032,611	819,138	523,829
Net income	$1,651,648	($1,479,744)	[1]	($1,428,618)	$5,018,491	$3,214,810	[2]	($1,004,338)	[3]	($326,916)	[4]	$4,787,723	$3,761,777	$6,671,279	$3,719,317
Basic and diluted earnings per share
Continuing operations (in dollars per share)	$0.11	($0.14)	[1]	($0.14)	$0.43	$0.27	[2]	($0.08)	[3]	($0.05)	[4]	$0.52	$0.26	$0.63	$0.39
Discontinued operations (in dollars per share)	$0.05	$0	[1]	$0	$0.05	$0.04	[2]	($0.02)	[3]	$0.01	[4]	$0.05	$0.10	$0.08	$0.07
Net income (loss) per share (in dollars per share)	$0.16	($0.14)	[1]	($0.14)	$0.48	$0.31	[2]	($0.10)	[3]	($0.04)	[4]	$0.57	$0.36	$0.71	$0.46
[1]	Company classified its Energy West Wyoming subsidiary and Glacier and Shoshone Pipeline Assets as discontinued operations. All prior periods have been restated to match this presentation.
[2]	Company recorded a goodwill impairment expense of $0.7 million and an unrealized gain on its contingent consideration liability of $1.6 million.
[3]	Company classified its Independence subsidiary as discontinued operations. All prior periods have been restated to match this presentation.
[4]	Company recorded a contingent liability of $0.9 million, related to the PUCObs GCR audit of its Ohio utilities, reducing gross margin.

Unaudited_Quarterly_Results_of3

Unaudited Quarterly Results of Operations - Additional Information (Detail) (USD $)	3 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2013
Goodwill, Impairment Loss	$700,000	$0	$725,744	$0
Contingent Consideration Liability	685,000	747,000	685,000
Business Combination, Contingent Consideration Arrangements, Change in Amount of Contingent Consideration, Liability	1,600,000
PUCO [Member]
Contingent Consideration Liability					$900,000

Segments_of_Operation_Summary_

Segments of Operation - Summary of Financial Information for Operating Segments (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Total operating revenue	$132,569,841	$109,400,353	$81,393,842
Total cost of sales	87,717,379	66,030,019	44,505,763
GROSS MARGIN	44,852,462	43,370,334	36,888,079
OPERATING EXPENSES
Distribution, general and administrative	25,984,636	22,132,860	19,463,781
Maintenance	1,225,491	1,142,261	995,072
Depreciation and amortization	6,604,569	5,550,753	4,337,196
Accretion	51,466	57,912	161,298
Taxes other than income	3,928,018	3,671,930	3,188,071
Unrealized holding loss	62,000	-1,565,000
Goodwill impairment	0	725,744	0
Total operating expenses	37,753,282	31,618,626	28,145,418
OPERATING INCOME (LOSS)	7,099,180	11,751,708	8,742,661
Other income (expense)	403,664	300,299	-890,654
Interest expense	-3,226,096	-3,176,155	-2,699,720
Income (loss) before taxes	4,276,748	8,875,852	5,152,287
Income tax benefit (expense)	-1,547,582	-3,023,711	-1,956,799
INCOME (LOSS) FROM CONTINUING OPERATIONS	2,729,166	5,852,141	3,195,488
Discontinued operations, net of income tax	1,032,611	819,138	523,829
NET INCOME (LOSS)	3,761,777	6,671,279	3,719,317
Capital expenditures	21,612,680	23,516,923	19,935,982
Operating Segments [Member]
Segment Reporting Information [Line Items]
Total operating revenue	140,984,085	117,519,444	87,343,041
Total cost of sales	96,131,623	74,149,110	50,454,962
Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Total operating revenue	-8,414,244	-8,119,091	-5,949,199
Total cost of sales	-8,414,244	-8,119,091	-5,949,199
OPERATING EXPENSES
Total operating expenses	-102,898	-97,834
Natural Gas Operations [Member]
Segment Reporting Information [Line Items]
Total operating revenue	123,052,554	97,233,112	73,900,481
Total cost of sales	79,096,553	55,977,154	38,552,607
GROSS MARGIN	43,956,001	41,255,958	35,347,874
OPERATING EXPENSES
Distribution, general and administrative	20,975,963	19,560,991	17,904,439
Maintenance	1,224,998	1,139,496	994,058
Depreciation and amortization	6,070,669	5,081,293	4,034,452
Accretion	6,856	7,068	113,106
Taxes other than income	3,898,337	3,619,304	3,110,909
Unrealized holding loss	0	0
Goodwill impairment		0
Total operating expenses	32,073,925	29,394,408	26,156,964
OPERATING INCOME (LOSS)	11,882,076	11,861,550	9,190,910
Other income (expense)	889,873	767,235	346,048
Interest expense	-2,619,294	-2,566,310	-2,198,888
Income (loss) before taxes	10,152,655	10,062,475	7,338,070
Income tax benefit (expense)	-3,661,125	-3,242,814	-2,869,083
INCOME (LOSS) FROM CONTINUING OPERATIONS	6,491,530	6,819,661	4,468,987
Discontinued operations, net of income tax	0	0	0
NET INCOME (LOSS)	6,491,530	6,819,661	4,468,987
Capital expenditures	21,530,449	23,241,913	17,686,583
Natural Gas Operations [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total operating revenue	123,378,718	97,259,443	73,925,318
Total cost of sales	79,422,717	56,003,485	38,577,444
Natural Gas Operations [Member] | Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Total operating revenue	-326,164	-26,331	-24,837
Total cost of sales	-326,164	-26,331	-24,837
OPERATING EXPENSES
Total operating expenses	-102,898	-13,744
Marketing and Production [Member]
Segment Reporting Information [Line Items]
Total operating revenue	9,517,287	12,167,241	7,493,361
Total cost of sales	8,620,826	10,052,865	5,953,156
GROSS MARGIN	896,461	2,114,376	1,540,205
OPERATING EXPENSES
Distribution, general and administrative	1,833,476	801,305	449,665
Maintenance	493	2,765	1,014
Depreciation and amortization	514,654	456,790	268,202
Accretion	44,610	50,844	48,192
Taxes other than income	23,367	28,113	38,052
Unrealized holding loss	62,000	-1,565,000
Goodwill impairment		725,744
Total operating expenses	2,478,600	500,561	805,125
OPERATING INCOME (LOSS)	-1,582,139	1,613,815	735,080
Other income (expense)	-502,367	151,168	-6,051
Interest expense	-121,041	-142,031	-133,440
Income (loss) before taxes	-2,205,547	1,622,952	595,589
Income tax benefit (expense)	771,844	-586,326	4,542
INCOME (LOSS) FROM CONTINUING OPERATIONS	-1,433,703	1,036,626	600,131
Discontinued operations, net of income tax	0	0	0
NET INCOME (LOSS)	-1,433,703	1,036,626	600,131
Capital expenditures	60,415	217,201	1,393,040
Marketing and Production [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total operating revenue	17,605,367	20,260,001	13,417,723
Total cost of sales	16,708,906	18,145,625	11,877,518
Marketing and Production [Member] | Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Total operating revenue	-8,088,080	-8,092,760	-5,924,362
Total cost of sales	-8,088,080	-8,092,760	-5,924,362
OPERATING EXPENSES
Total operating expenses	0	0
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Total operating revenue	0	0	0
Total cost of sales	0	0	0
GROSS MARGIN	0	0	0
OPERATING EXPENSES
Distribution, general and administrative	3,175,197	1,770,564	1,109,677
Maintenance	0	0	0
Depreciation and amortization	19,246	12,670	34,542
Accretion	0	0	0
Taxes other than income	6,314	24,513	39,110
Unrealized holding loss	0	0
Goodwill impairment		0
Total operating expenses	3,200,757	1,723,657	1,183,329
OPERATING INCOME (LOSS)	-3,200,757	-1,723,657	-1,183,329
Other income (expense)	16,158	-618,104	-1,230,651
Interest expense	-485,761	-467,814	-367,391
Income (loss) before taxes	-3,670,360	-2,809,575	-2,781,371
Income tax benefit (expense)	1,341,699	805,429	907,742
INCOME (LOSS) FROM CONTINUING OPERATIONS	-2,328,661	-2,004,146	-1,873,629
Discontinued operations, net of income tax	1,032,611	819,138	523,829
NET INCOME (LOSS)	-1,296,050	-1,185,008	-1,349,800
Capital expenditures	21,816	57,809	856,359
Corporate and Other [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total operating revenue	0	0	0
Total cost of sales	0	0	0
Corporate and Other [Member] | Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Total operating revenue	0	0	0
Total cost of sales	0	0	0
OPERATING EXPENSES
Total operating expenses	$0	($84,090)

Segments_of_Operation_Schedule

Segments of Operation - Schedule of Company's Asset by Operating Segment (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting, Asset Reconciling Item [Line Items]
Investment in unconsolidated affiliate	$0	$351,724
Total assets	214,003,912	203,731,797
Operating Segments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	324,004,500	290,701,067
Intersegment Elimination [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	-110,000,588	-86,969,270
Natural Gas Operations [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Investment in unconsolidated affiliate	0	0
Total assets	145,315,624	130,313,570
Natural Gas Operations [Member] | Operating Segments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	214,030,368	184,085,665
Natural Gas Operations [Member] | Intersegment Elimination [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	-68,714,744	-53,772,095
Marketing and Production [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Investment in unconsolidated affiliate	0	351,724
Total assets	6,478,425	7,955,233
Marketing and Production [Member] | Operating Segments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	9,192,830	11,633,544
Marketing and Production [Member] | Intersegment Elimination [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	-2,714,405	-3,678,311
Corporate and Other [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Investment in unconsolidated affiliate	0	0
Total assets	62,209,863	65,462,994
Corporate and Other [Member] | Operating Segments [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	100,781,302	94,981,858
Corporate and Other [Member] | Intersegment Elimination [Member]
Segment Reporting, Asset Reconciling Item [Line Items]
Total assets	($38,571,439)	($29,518,864)

Commitments_and_Contingencies_1

Commitments and Contingencies - Summary of Cost Basis and Accumulated Depreciation of Assets Recorded under Capital Leases (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Capital Leased Assets [Line Items]
Capital lease assets, gross	$6,320,000	$6,320,000
Accumulated depreciation	-902,857	-501,587
Capital lease assets, net	5,417,143	5,818,413
Gas, Transmission and Distribution Equipment [Member]
Capital Leased Assets [Line Items]
Capital lease assets, gross	$6,320,000	$6,320,000

Commitments_and_Contingencies_2

Commitments and Contingencies - Schedule of Future Minimum Lease Payments (Detail) (USD $)	Dec. 31, 2014
Future Minimum Lease Payments [Line Items]
2015	$277,634
2016	242,917
2017	233,913
2018	222,719
2019	210,579
Thereafter	994,701
Total minimum lease payments	2,182,463
2015	300,000
2016	300,000
2017	300,000
2018	300,000
2019	300,000
Thereafter	900,000
Total minimum lease payments	2,400,000
Less: Interest portion	537,062
Liability	1,862,938
Build-to-suit [Member]
Future Minimum Lease Payments [Line Items]
2015	2,405,890	[1]
2016	2,226,081	[1]
2017	2,092,063	[1]
2018	205,958	[1]
2019	0	[1]
Thereafter	0	[1]
Total minimum lease payments	$6,929,992	[1]
[1]	Relates to the Companybs ERP system build-to-lease. See Note 15 B Property Plant & Equipment.

Commitments_and_Contingencies_3

Commitments and Contingencies - Summary of Future Minimum Long-term Contract Obligations (Detail) (USD $)	Dec. 31, 2014
Northwestern Energy [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2015	$1,434,680
2016	519,356
2017	519,356
2018	476,076
2019	0
Thereafter	0
Total	2,949,468
Trans Canada [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2015	829,775
2016	368,768
2017	368,768
2018	338,036
2019	0
Thereafter	0
Total	1,905,347
Maritimes And Northeast Pipeline [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2015	357,042
2016	357,042
2017	357,042
2018	357,042
2019	357,042
Thereafter	0
Total	1,785,210
Gas Purchase Contracts [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
2015	2,939,547
2016	817,325
2017	0
2018	0
2019	0
Thereafter	0
Total	$3,756,872

Commitments_and_Contingencies_4

Commitments and Contingencies - Additional Information (Detail) (USD $)	0 Months Ended	12 Months Ended
	Nov. 13, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jul. 15, 2014	Jun. 30, 2013
Loss Contingencies [Line Items]
Severance payment					$1,000,000
Valuation adjustments	1,000,000
Increase in initial estimated liability			500,000
Lease expense resulting from operating leases		184,008	222,093	429,743
Future lease payment, per year		300,000
Facility service fee to be paid each year		120,000
Throughput charge		0.0125
Capital Leases, Income Statement, Amortization Expense		401,270	401,270	100,317
Additional Loss Contingency						900,000
Loss Contingency Accrual						1,200,000
Loss Contingency, Damages Paid, Value			200,000
Cost of Natural Gas Purchases		79,096,553	55,977,154	38,552,607
Customer [Member]
Loss Contingencies [Line Items]
Cost of Natural Gas Purchases		200,000
Minimum [Member]
Loss Contingencies [Line Items]
Loss Contingency, Range of Possible Loss, Minimum		200,000
Maximum [Member]
Loss Contingencies [Line Items]
Loss Contingency, Range of Possible Loss, Minimum		1,000,000
Shareholders Suit [Member]
Loss Contingencies [Line Items]
Insurance premium paid before any losses covered		$250,000

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (Subsequent Event [Member], Clarion and Walker subsidiaries [Member], USD $)	Jan. 14, 2015
In Millions, unless otherwise specified
Subsequent Event [Member] | Clarion and Walker subsidiaries [Member]
Subsequent Event [Line Items]
Disposal Group, Including Discontinued Operation, Consideration	$0.90