American Eagle Energy Inactive 10-K31 Mar 152014 FY Annual reportFinancial data

Company Profile

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
Document And Entity Information (USD $)	Dec. 31, 2014	Jun. 30, 2014	Mar. 25, 2014
Document Information [Line Items]
Entity Registrant Name	AMERICAN EAGLE ENERGY Corp
Entity Central Index Key	1282613
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding			30,448,714
Trading Symbol	AMZG
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		$182,316,228

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash	$25,888	$31,850
Trade receivables	9,466	17,920
Income tax receivable	25	0
Prepaid expenses	128	68
Derivative asset	0	211
Total current assets	35,507	50,049
Equipment and leasehold improvements, net of accumulated depreciation and amortization of $490 and $322, respectively	210	174
Oil and gas properties, full-cost method - subject to amortization, net of accumulated depletion of $35,332 and $12,849, respectively	226,918	155,145
Oil and gas properties, full-cost method - not subject to amortization	0	2,487
Marketable securities	756	1,050
Other assets	7,543	7,503
Total assets	270,934	216,408
Current liabilities:
Accounts payable and accrued liabilities	49,065	41,841
Derivative liability	0	276
Bonds payable, net of discount of $1,532 and $0, respectively	173,467	0
Current portion of notes payable	0	3,000
Total current liabilities	222,532	45,117
Asset retirement obligation	1,428	1,060
Noncurrent portion of notes payable	0	105,000
Noncurrent derivative liability	0	750
Deferred taxes	0	5,386
Total liabilities	223,960	157,313
Commitments and contingencies (Note 13)
Stockholders' equity:
Common stock, $.001 par value, 48,611 shares authorized, 30,449 and 17,712 shares outstanding	30	18
Additional paid-in capital	147,275	67,198
Accumulated other comprehensive income (loss)	0	-6
Accumulated deficit	-100,331	-8,115
Total stockholders' equity	46,974	59,095
Total liabilities and stockholders' equity	$270,934	$216,408

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets [Parenthetical] (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Equipment and leasehold improvements, accumulated depreciation and amortization	$490	$322
Oil and gas properties - subject to amortization, accumulated depletion	35,332	12,849
Discount on bonds payable	$1,532	$0
Common stock, par value (in dollars per share)	$0.00	$0.00
Common stock, shares authorized (in shares)	48,611	48,611
Common stock, shares outstanding (in shares)	30,449	17,712

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Oil and gas sales	$60,549	$43,139	$10,714
Operating expenses:
Oil and gas production costs	22,069	11,609	3,200
General and administrative	7,832	7,361	4,504
Depletion, depreciation and amortization	24,604	10,073	2,860
Impairment of oil and gas properties, subject to amortization	81,908	1,732	10,631
Total operating expenses	136,413	30,775	21,195
Total operating income (loss)	-75,864	12,364	-10,481
Other income (expense):
Interest and dividend income	57	81	72
Interest expense	-15,900	-5,356	-1
Loss on early extinguishment of debt	-11,894	-3,714	0
Loss on sale of oil & gas properties	-12	0	0
Change in fair value of marketable securities	-491	0	0
Gains on settlement of derivatives	6,608	803	0
Change in fair value of derivatives	0	-815	-122
Total other income (expense)	-21,632	-9,001	-51
Income (loss) before taxes	-97,496	3,363	-10,532
Income tax expense (benefit)	-5,280	1,769	-1,240
Net income (loss)	($92,216)	$1,594	($9,292)
Net income (loss) per common share:
Basic (in dollars per share)	($3.35)	$0.11	($0.81)
Diluted (in dollars per share)	($3.35)	$0.11	($0.81)
Weighted average number of shares outstanding:
Basic (in shares)	27,513	13,962	11,448
Diluted (in shares)	27,513	14,599	11,448

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Loss) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net income (loss)	($92,216)	$1,594	($9,292)
Other comprehensive income (loss), net of tax:
Unrealized losses on securities	-491	-1	-110
Foreign current translation adjustments	497	28	-103
Comprehensive income (loss)	($92,210)	$1,621	($9,505)

Consolidated_Statements_of_Sto

Consolidated Statements of Stockholders' Equity (USD $)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	AccumulatedDeficit[Member]
In Thousands, except Share data	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	AccumulatedDeficit[Member]
Balance at Dec. 31, 2011	$25,758	$12	$25,983	$180	($417)
Balance (In shares) at Dec. 31, 2011		11,398,000
Stock based compensation	822	0	822	0	0
Shares issued in private placements	110	0	110	0	0
Shares issued in private placements (in shares)		25,000
Shares issued upon exercise of options	35	0	35	0	0
Shares issued upon exercise of options (in shares)		38,000
Shares issued in debt financing	180	0	180	0	0
Shares issued in debt financing (in shares)		56,000
Unrealized loss on securities, net of tax	-110	0	0	-110	0
Foreign exchange translation adjustments	-103	0	0	-103	0
Net income (loss)	-9,292	0	0	0	-9,292
Balance at Dec. 31, 2012	17,400	12	27,130	-33	-9,709
Balance (in shares) at Dec. 31, 2012		11,517,000
Stock based compensation	1,203	0	1,203	0	0
Shares issued in private placements	13,877	2	13,875	0	0
Shares issued in private placements (in shares)		2,250,000
Shares issued in public offerings	24,994	4	24,990	0	0
Shares issued in public offerings (in shares)		3,941,000
Shares issued upon exercise of options	0	0	0	0	0
Shares issued upon exercise of options (in shares)		4,000
Shares issued in debt financing	0
Unrealized loss on securities, net of tax	-1	0	0	-1	0
Foreign exchange translation adjustments	28	0	0	28	0
Net income (loss)	1,594	0	0	0	1,594
Balance at Dec. 31, 2013	59,095	18	67,198	-6	-8,115
Balance (in shares) at Dec. 31, 2013		17,712,000
Stock based compensation	1,791	0	1,791	0	0
Round up shares issued in reverse-split	0	0	0	0	0
Round up shares issued in reverse-split (in shares)		75,000
Shares issued in public offerings	78,298	12	78,286	0	0
Shares issued in public offerings (in shares)		12,650,000
Shares issued upon exercise of options	0	0	0	0	0
Shares issued upon exercise of options (in shares)		12,000
Shares issued in debt financing	0
Unrealized loss on securities, net of tax	-491	0	0	-491	0
Foreign exchange translation adjustments	497	0	0	497	0
Net income (loss)	-92,216	0	0	0	-92,216
Balance at Dec. 31, 2014	$46,974	$30	$147,275	$0	($100,331)
Balance (in shares) at Dec. 31, 2014		30,449,000

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows provided by operating activities:
Net income (loss)	($92,216)	$1,594	($9,292)
Non-cash transactions:
Stock-based compensation	1,791	1,203	822
Depletion, depreciation and amortization	24,604	10,073	2,860
Impairment of oil and gas properties	81,908	1,732	10,631
Accretion of discount on asset retirement obligations	83	49	5
Amortization of deferred financing costs	1,556	602	0
Amortization of debt discount	113	0
Provision for deferred income tax expense (benefit)	-5,386	1,794	-938
Loss on early extinguishment of debt	11,894	3,714	0
Loss on sale of oil and gas properties	-12	0	0
Change in fair value of marketable securities	491	0	0
Change in fair value of derivatives	-815	692	122
Foreign currency transaction gains (losses)	11	-11	-53
Changes in operating assets and liabilities:
Prepaid expenses	-60	64	-87
Trade receivables	-5,857	4,468	-799
Income taxes receivable	-25	190	-190
Receivables from related parties	0	0	315
Deposits	0	0	-3
Accounts payable and accrued liabilities	8,534	4,247	1,955
Income taxes payable	0	0	-1,460
Net cash provided by operating activities	26,614	30,411	3,888
Cash flows used for investing activities:
Proceeds from conveyance of working interests	0	0	3,790
Additions to oil and gas properties	-164,265	-136,267	-18,915
Proceeds from sale of oil and gas properties	1,824	0	228
Additions to equipment and leasehold improvements	-204	-68	-252
Purchases of marketable securities	-222	0	-51
Purchases of certificates of deposit	0	0	-50
Increase (decrease) in amounts due to Carry Agreement Partner	0	-4,957	2,723
Net cash used for investing activities	-162,867	-141,292	-12,527
Cash flows provided by financing activities:
Proceeds from issuance of stock	78,298	38,871	110
Proceeds from exercise of stock options	0	0	35
Proceeds from issuance of notes	0	105,935	16,000
Repayment of notes	-113,465	-21,131	-600
Proceeds from issuance of bonds	173,353	0	0
Payment of other deferred financing costs	-8,025	0	0
Net cash provided by financing activities	130,161	123,675	15,545
Effect of exchange rate changes on cash	130	-2	0
Net change in cash	-5,962	12,792	6,906
Cash - beginning of period	31,850	19,058	12,152
Cash - end of period	25,888	31,850	19,058
Cash paid (received) during the period for:
Interest	7,598	3,746	1
Taxes	0	-178	1,255
Supplemental Disclosure of Non-Cash Investing and Financing Activities
Stock issued in connection with debt financing	0	0	180
Property additions included in accounts payable	24,798	19,425	25,671
Property additions through the establishment of asset retirement obligations	516	516	407
Direct financing of prepayment and other penalties	$5,465	$0	$0

Description_of_Business

Description of Business	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations [Text Block]	1	Description of Business

	American Eagle Energy Corporation (the “Company”) was incorporated in the state of Nevada in March 2003 under the name Golden Hope Resources. In July 2005, the Company changed its name to Eternal Energy Corp. In December 2011, the Company changed its name to American Eagle Energy Corporation, in connection with its acquisition of, and merger with, American Eagle Energy Inc.

	The Company engages in the acquisition, exploration and development of oil and gas properties, and is primarily focused on extracting proved oil reserves from those properties. As of September 30, 2014, the Company had entered into participation agreements related to oil and gas exploration and development projects in the Spyglass Area, located in Divide County, North Dakota, and Sheridan County, Montana. In addition, the Company owns working interests in mineral leases located in Richland, Roosevelt and Toole Counties in Montana.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Significant Accounting Policies [Text Block]		2	Summary of Significant Accounting Policies

	Basis of Presentation

	The accompanying consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, AMZG, Inc., EERG Energy ULC (“EERG” - Canadian) and AEE Canada Inc. (“AEE Canada” - Canadian). All material intercompany accounts, transactions and profits have been eliminated.

	As discussed in Note 4, the Company sold 100% of its net revenue and working interests in its Canadian oil and gas properties in July 2014. The Company legally dissolved its Canadian subsidiaries (EERG and AEE Canada) in October 2014, at which time, all remaining assets held by the Canadian entities were transferred back to the parent company. The accompanying Consolidated Statements of Operations and Comprehensive Income (Loss) and Consolidated Statements of Cash Flows for the year ended December 31, 2014 include the operating results and activities of EERG and AEE Canada through the date of dissolution.

	Certain reclassifications have been made to prior year balances to conform to the current year’s presentation. These reclassifications had no effect on net income (loss) for the years ended December 31, 2013 and 2012.

	Revenue Recognition

	Revenue from the sale of produced oil and gas is recognized when the terms of the sale have been finalized and the oil or gas has been delivered to the purchaser. The Company accrues estimated oil and gas sales for production periods that have not yet been settled in cash.

	Concentration of Credit Risk

	At any point throughout the year, the Company may have amounts on deposit that exceed the United States Federal Deposit Insurance Company insurance limit of $250,000 per bank.

	Foreign Currency Adjustments

	The functional currency of EERG and AEE Canada is the Canadian Dollar. EERG’s and AEE Canada’s asset and liability account balances are translated into US Dollars at the exchange rate in effect as of the balance sheet dates. Gains and losses realized upon the settlement of foreign currency transactions are included in the Company’s results of operations. Foreign currency translation adjustments are presented as other comprehensive income.

	Components of Other Comprehensive Income

	Comprehensive income consists of net income and other gains and losses affecting stockholders’ equity that, under generally accepted accounting principles, are excluded from net income. For the Company, such items consist of unrealized gains (losses) on marketable securities and foreign currency translation adjustments.

	Cash and Cash Equivalents

	Cash equivalents consist of time deposits and liquid debt investments with original maturities of three months or less at the time of purchase.

	Receivables

	Receivables are stated at the amount the Company expects to collect. In certain instances, the Company has the legal right to offset undistributed revenues from its operated wells against uncollected receivables from its working interest partners. The Company considers the following factors when evaluating the collectability of specific receivable balances: credit-worthiness of the debtor, past transaction history with the debtor, current economic industry trends, and changes in debtor payment terms. If the financial condition of the Company’s debtors were to deteriorate, adversely affecting their ability to make payments, additional allowances would be required.

	The Company maintains an allowance for doubtful accounts for estimated losses resulting from the inability of its customers to make required payments. Changes to the allowance for doubtful accounts made as a result of management’s determination regarding the ultimate collectability of such accounts are recognized as a charge to the Company’s earnings. Specific receivable balances that remain outstanding after the Company has used reasonable collection efforts are written off through a charge to the valuation allowance and a credit to the receivable.

	At December 31, 2014 and 2013, the Company has determined that all receivable balances are fully collectible and, accordingly, no allowance for doubtful accounts has been recorded.

	Equipment and Leasehold Improvements

	Equipment and leasehold improvements are recorded at cost. Expenditures for major additions and improvements are capitalized and depreciated or amortized over the estimated useful lives of the related assets using the straight-line method for financial reporting purposes. The estimated useful lives for significant property and equipment categories are as follows:

	Furniture and equipment		3 years
	Leasehold improvements		lesser of useful life or lease term

	When equipment and improvements are retired or otherwise disposed of, the cost and the related accumulated depreciation are removed from the Company’s accounts and any resulting gain or loss is included in the results of operations for the respective period.

	Expenditures for minor replacements, maintenance and repairs are charged to expense as incurred.

	Oil and Gas Properties and Prospects

	The Company follows the full-cost method of accounting for its investments in oil and gas properties. Under the full-cost method, all costs associated with the acquisition, exploration or development of properties, are capitalized into appropriate cost centers within the full-cost pool. Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities. Cost centers are established on a country-by-country basis.

	Capitalized costs for each of the Company’s cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory uneconomic holes are included in the amortization base immediately upon determination that the well is uneconomic.

	Proceeds received from the disposal of oil and gas properties are credited against accumulated costs, except when the sale represents a significant disposal of reserves, in which case a gain or loss is recognized.

	During the year ended December 31, 2014, the Company determined that it was unlikely that it would pursue the development of its oil and gas properties that are not subject to amortization in the foreseeable future. As a result, the Company reclassified all of the capitalized costs associated with these properties into the full cost pool.

	As of the end of each reporting period, the capitalized costs of each cost center are subject to a ceiling test, in which the costs may not exceed the cost center ceiling. The cost center ceiling is equal to (i) the present value of estimated future net revenues, computed by applying the unweighted arithmetic average of prices posted on the first day of each of the preceding twelve months (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; plus (ii) the cost of properties not being amortized; plus (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; less (iv) income tax effects related to differences between the book and tax basis of the properties. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs. The Company recognized impairment losses totaling approximately $81.9 million associated with its US cost center for the year ended December 31, 2014, and losses totaling approximately $1.7 million and approximately $10.6 million associated with its Canadian cost center for the years ended December 31, 2013 and 2012, respectively.

	Deferred Loan Costs

	The Company capitalizes costs that are directly related to securing bank loans and other types of long-term financing and amortizes such costs over the life of the corresponding debt using the effective interest method.

Derivatives

Historically, the Company has entered into a number of oil price swap agreements, which represent derivative financial instruments. The Company reports its derivatives at their fair market value as of the end of each reporting period. Changes in the fair value of derivatives are included in the Company’s results of operations in the period in which they occur. The Company has no open derivative positions as of December 31, 2014.

Asset Retirement Obligations

The Company records estimated asset retirement obligations related to the future plugging and abandoning of its existing wells in the period in which the wells are completed. The initial recording of an asset retirement obligation results in an increase in the carrying amount of the related long-lived asset and the creation of a liability. The portion of the asset retirement obligation expected to be realized during the next 12-month period is classified as a current liability, while the portion of the asset retirement obligation expected to be realized during subsequent periods is discounted and recorded at its net present value. The discount factors used to determine the net present value of the Company’s asset retirement obligation range from 4.2% to 11.0%, which represented the Company’s estimated incremental borrowing rate as of the dates that the corresponding wells were put on production.

Changes in the noncurrent portion of the asset retirement obligation due to the passage of time are accreted using the interest method. The amount of change is recognized as an increase in the liability and an accretion expense in the statement of operations. Changes in either the current or noncurrent portion of the Company’s asset retirement obligation resulting from revisions to the timing or the amount of the original estimate of undiscounted cash flows are recognized as an increase or a decrease to the carrying amount of the liability and the related long-lived asset.

Stock-Based Compensation

The Company measures compensation cost for all stock-based awards at fair value on the date of grant and recognizes compensation expense in its statements of operations over the service period that the awards are expected to vest. The Company has elected to recognize compensation cost for all options with graded vesting on a straight-line basis over the vesting period of the entire option. The Company recognized stock-based compensation expense of approximately $1.8 million, $1.2 million and $822,000 for the years ended December 31, 2014, 2013 and 2012, respectively.

Fair Value of Financial Instruments

Fair value is the price that would be received from the sale of an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 or 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.

Basic and Diluted Earnings Per Share

Basic earnings per common share is computed by dividing net earnings available to common stockholders by the weighted average number of common shares outstanding during the period. For periods in which the Company recognizes net income, diluted earnings per common share is computed in the same way as basic earnings per common share except that the denominator is increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued that were dilutive. For periods in which the Company recognizes losses, the calculation of diluted earnings per share is the same as the calculation of basic earnings per share. See Note 16 for the calculation of basic and diluted weighted average common shares outstanding for the years ended December 31, 2014, 2013 and 2012.

Income Taxes

The Company follows the liability method of accounting for income taxes. Under this method, deferred income tax assets and liabilities are recognized for the future tax benefits and consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax balances. Deferred income tax assets and liabilities are measured using enacted or substantially enacted tax rates expected to apply to the taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred income tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the date of enactment or substantive enactment. Net operating loss carry forwards and other deferred tax assets are reviewed annually for recoverability and, if necessary, are recorded net of a valuation allowance. See Note 15 for a summary of the Company’s income tax expense (benefit) for the years ended December 31, 2014, 2013 and 2012.

Liquidity

The Company finances its oil and gas exploration and development activities and corporate operations through a combination of internally generated funds, external debt financing and sales of its common stock. As of December 31, 2014, the Company had working capital deficit of approximately $13.6 million. See Note 19 for further discussion regarding the liquidity of the Company.

Use of Estimates and Assumptions

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent obligations in the financial statements and accompanying notes. The Company’s most significant assumptions are the estimates used in the determination of the deferred income tax asset valuation allowance and the valuation of oil and gas reserves to which the Company owns rights. The estimation process requires assumptions to be made about future events and conditions, and as such, is inherently subjective and uncertain. Actual results could differ materially from these estimates.

New Accounting Pronouncements

In April 2014, the Financial Accounting Standards Board (“FASB”) issued Update 2014-08 - Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The objective of the amendments in this update is to change the criteria for reporting discontinued operations and enhance convergence of the FASB's and the International Accounting Standards Board's reporting requirements for discontinued operations. The amendments in this update change the requirements for reporting discontinued operations in Subtopic 205-20. A discontinued operation may include a component of an entity or a group of components of an entity, or a business or nonprofit activity. 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 amendments in this update require an entity to present, for each comparative period, the assets and liabilities of a disposal group that includes a discontinued operation separately in the asset and liability sections, respectively, of the statement of financial position. The amendments in this update also require additional disclosures about discontinued operations. Public business entities must apply the amendments in this update prospectively to both of the following: (1) All disposals (or classifications as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years; (2) All businesses or nonprofit activities that, on acquisition, are classified as held for sale that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. The Company does not believe the adoption of this update will have a material impact on the Company’s consolidated financial statements.

In May 2014, the FASB issued Update 2014-09 - Revenue from Contracts with Customers (Topic 606). The objective of the amendments in this update is to improve financial reporting by creating common revenue recognition guidance for accounting principles generally accepted in the United States and International Financial Reporting Standards. The guidance in this update supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. An entity should disclose sufficient information, both qualitative and quantitative, to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The amendments in this update are effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application is not permitted. The Company does not believe the adoption of this update will have a material impact on the Company’s consolidated financial statements.

In June 2014, the FASB issued ASC Update No. 2014-12 - Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (“ASC No. 2014-12”). The objective of the amendments in this update is to resolve the diverse accounting treatment of share-based payment awards. The amendments in this update apply to all reporting entities that grant their employees share-based payments in which the terms of the award provide that a performance target that affects vesting could be achieved after the requisite service period. The amendments require that a performance target that affects vesting and that could be achieved after the requisite service period be treated as a performance condition. As such, the performance target should not be reflected in estimating the grant-date fair value of the award. Compensation cost should be recognized in either (i) the period in which it becomes probable that the performance target will be achieved and should represent the compensation cost attributable to the period(s) for which the requisite service has already been rendered or (ii) if the performance target becomes probable of being achieved before the end of the requisite service period, the remaining unrecognized compensation cost should be recognized prospectively over the remaining requisite service period. The total amount of compensation cost recognized during and after the requisite service period will reflect the number of awards that are expected to vest and will be adjusted to reflect those awards that ultimately vest. The requisite service period ends when the employee can cease rendering service and still be eligible to vest in the award if the performance target is achieved. The amendments in this update are effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Earlier adoption is permitted. Entities may apply the amendments in this update either (a) prospectively to all awards granted or modified after the effective date or (b) retrospectively to all awards with performance targets that are outstanding as of the beginning of the earliest annual period presented in the financial statements and to all new or modified awards thereafter. The Company does not believe the adoption of this update will have a material impact on the Company’s consolidated financial statements.

Marketable_Securities_and_Fair

Marketable Securities and Fair Value Measurements	12 Months Ended
Marketable Securities and Fair Value Measurements	Dec. 31, 2014
Investments, Debt and Equity Securities [Abstract]
Investments In Debt and Marketable Equity Securities and Certain Trading Assets Disclosure [Text Block]		3	Marketable Securities and Fair Value Measurements

	Available-for-sale marketable securities at December 31, 2014 and 2013 consist of the following (in thousands):
						Gains in			Losses in
						Accumulated			Accumulated
			Estimated			Other			Other
			Fair			Comprehensive			Comprehensive
			Value			Income			Income
	31-Dec-14
	Noncurrent assets:
	Marketable securities		$	756		$	-		$	-

	31-Dec-13
	Noncurrent assets:
	Marketable securities		$	1,050		$	100		$	-75

	The fair value of substantially all securities is determined by quoted market prices. There were no sales of marketable securities for the years ended December 31, 2014 or 2013.

	The fair value of the Company’s financial instruments, measured on a recurring basis at December 31, 2014 and 2013, were as follows (in thousands):

			Level 1			Level 2			Level 3			Total
	December 31, 2014
	Marketable securities	$		756	$		-	$		-	$		756

	31-Dec-13
	Marketable securities			1,050			-			-			1,050
	Current derivative asset			-			211			-			211
	Current derivative liability			-			-276			-			-276
	Noncurrent derivative liability			-			-750			-			-750

Purchases_and_Sales_of_Royalty

Purchases and Sales of Royalty and Property Interests	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets Disclosure [Text Block]		4	Purchases and Sales of Royalty and Property Interests

	In January 2013, the Company purchased additional net revenue and working interests in several key, non-operated spacing units within the Spyglass Area from SM Energy Company. The purchase price totaled approximately $3.9 million in cash, which was paid at closing.

	In October 2013, the Company purchased additional net revenue and working interests in proved producing and proved undeveloped properties located within the Spyglass Area from a certain working interest partner. The transaction closed on October 2, 2013 with an effective date of June 1, 2013. The gross purchase price for the acquired interests totaled $47.0 million. The net purchase prices, after taking into consideration revenues and operating expenses associated with the acquired interests from the period June 1, 2013 through the closing date, totaled approximately $41.4 million. To finance the acquisition, the Company sold shares of its common stock, through two public offerings (See Note 14), and borrowed an additional $40 million under its then-existing Credit Facility (the “MSCG Credit Facility”) with Morgan Stanley Capital Group, Inc. (“MSCG”) (See Note 8). The agreement contained the option to purchase additional net revenue and working interests in the same producing and proved undeveloped properties at a later date.

	In March 2014, the Company exercised its option to purchase the additional net revenue and working interests in proved producing and proved undeveloped properties located within the Spyglass Area from the same working interest partner. The transaction closed on March 26, 2014 with an effective date of June 1, 2013. The gross purchase price for the acquired interests totaled approximately $47.1 million. The acquisition of the additional net revenue and working interests was funded with proceeds received from a March 2014 public offering, as discussed in Note 14.

	Supplemental Pro Forma Information (Unaudited)

	The Company’s consolidated statements of income for the years ended December 31, 2014 and 2013 include revenues and oil and gas operating expenses related to the net revenue and working interests acquired for the periods subsequent to the effective date of each transaction.

	Had the purchase of these additional net revenue and working interests occurred on January 1, 2012, the Company’s consolidated financial statements for the years ended December 31, 2014, 2013 and 2012 would have been as follows (in thousands):

			2014		2013
	Pro forma revenues		$	63,723	$	67,360
	Pro forma net income (loss)		$	-91,728	$	5,708
	Pro forma income (loss) per share – basic		$	-3.02	$	0.21
	Pro forma income (loss) per share – diluted		$	-3.02	$	0.21

	Also in March 2014, the Company acquired certain undeveloped acreage from the same working interest partner at a price of approximately $7.5 million.

	In July 2014, the Company sold 100% of its net revenue and working interests in its Canadian oil and gas properties (the “Hardy Property) to its then working interest partner. Prior to the sale, the Hardy Property represented 100% of the Canadian cost center for the Company’s full-cost pool. Cash proceeds received from the sale approximated $1.8 million, which resulted in a loss on the sale of approximately $12,000.

Carry_Agreements

Carry Agreements	12 Months Ended
	Dec. 31, 2014
Carry Agreement [Abstract]
Carry Agreement Disclosure [Text Block]	5	Carry Agreements

	On April 16, 2012, the Company entered into a Carry Agreement with a third-party working interest partner (the “Carry Agreement Partner”), pursuant to which (i) the Carry Agreement Partner agreed to fund 100% of the Company’s working interest share of the drilling and completion costs of up to six new oil and gas wells within our Spyglass Area, up to 120% of the original AFE amount, and (ii) the Company agreed to convey, for a limited duration, a portion of its revenue interest in the pre-payout revenues of each carried well and a portion of its working interest in the pre-payout operating costs of each carried well, to the Carry Agreement Partner. In the event that the gross drilling and completion cost of a carried well exceeds 120% of the AFE amount, the Company and the Carry Agreement Partner would share in the excess costs based on the working interests stipulated in the Carry Agreement.

	Pursuant to the terms of the Carry Agreement, the portion of the Company’s net revenue interest in each well to be conveyed to the Carry Agreement Partner followed a graduated scale, whereby 50% of the Company’s net revenue and working interests are assigned to the Carry Agreement Partner during the first year of the well’s production or until the carried costs, plus the 12% return, have been achieved, whichever occurs first. In the event that the Carry Agreement Partner had not recouped all of the carried costs plus the 12% return by the end of the first year of production, the assignment of the Company’s net revenue and working interests in the well would increase from 50% to 75% for the second year of production or until the carried costs, plus the 12% return, had been achieved, whichever occurs first. In the event that the Carry Agreement Partner had not recouped all of the carried costs, plus the 12% return, by the end of the second year of production, the assignment of the Company’s net revenue and working interests in the well would increase to 100% until the carried costs, plus the 12% return, had been achieved. Once payout has occurred (112% of the costs on a well-by-well basis), the respective working interests in the revenues from each carried well would revert to the original working interests in each such well.

	Effective July 15, 2012, the Company amended the Carry Agreement with the third-party to include an additional four oil and gas wells.

	As discussed in Note 4, the Company acquired net revenue and working interests associated with certain properties, in March 2014, including 100% of the net revenue and working interests that had been conveyed to the Carry Agreement Partner, which effectively terminated the Carry Agreement.

	In August 2013, the Company entered into a second carry agreement (the “Second Carry Agreement”) with the Carry Agreement Partner, pursuant to which (i) that Carry Agreement Partner agreed to fund 100% of the Company’s working interest share of the drilling and completion costs of up to five new oil and gas wells to be located within the Spyglass Area, up to 120% of the original AFE amount, and (ii) the Company agreed to convey, for a limited duration, 50% of its revenue interest in the pre-payout revenues of each carried well and 50% of its working interest in the pre-payout operating costs of each carried well, to the Carry Agreement Partner. In the event that the gross drilling and completion cost of a carried well exceeds 120% of the AFE amount, the Company and the Carry Agreement Partner will share in the excess costs based on the working interests stipulated in the Carry Agreement.

	Pursuant to the terms of the Second Carry Agreement, 50% of the Company’s net revenue interest in each well will be conveyed to the Carry Agreement Partner for a period of two years or until such a time when the working interest partner has recouped 112% of the carried drilling and completion costs of the well, whichever occurs sooner. In the event that the Carry Agreement Partner has not recouped 112% of the carried drilling and completion costs by the end of the second year of production, the Company has agreed to make cash payments to the Carry Agreement Partner in the amount of the shortfall. Once the Carry Agreement Partner has recouped 112% of the carried drilling and completion costs of a well, the conveyed working interest and net revenue interest will revert to the Company.

	As of December 31, 2014, all five of the wells to be drilled pursuant to the Second Carry Agreement have been completed. To date, the Company has received approximately $17.7 million of funding under the Second Carry Agreement. This amount is net of cumulative revenues and oil and gas operating costs associated with the carried wells, which were conveyed to the Carry Agreement Partner pursuant to the terms of the Second Carry Agreement. As noted above, the Carry Agreement Partner is entitled to receive a 12% return on the amount of capitalized drilling and completion costs that it has funded on the Company’s behalf.

	As of December 31, 2014, the cost of drilling and completing one of the five wells exceeded the 120% of AFE cost threshold. Accordingly, the Company has recorded its portion of excess drilling and completion costs associated with this well, totaling approximately $1.0 million as of December 31, 2014. None of the five wells covered by the Second Carry Agreement has achieved payout as of December 31, 2014.

FarmOut_Agreement

Farm-Out Agreement	12 Months Ended
	Dec. 31, 2014
Farm-Out Agreement [Abstract]
Farm-Out Agreement Disclosure [Text Block]		6	Farm-Out Agreement

	In August 2013, the Company entered into a Farm-Out Agreement (the “Farm-Out Agreement”) with the same Carry Agreement Partner, pursuant to which (i) that Carry Agreement Partner agreed to fund 100% of the Company’s working interest share of the drilling and completion costs of up to six new oil and gas wells to be located within the original Spyglass and West Spyglass sections of the Spyglass Property and (ii) the Company will convey, for a period of time, 100% of its net revenue interest in the pre-payout revenues of each farm-out well and 100% of its working interest in the pre-payout operating costs of each farm-out well, to the Carry Agreement Partner, until such a time when the Carry Agreement Partner has recouped 112% of the drilling and completion costs associated with each well. Once the Carry Agreement Partner has recouped 112% of the drilling and completion costs of a well, the Carry Agreement Partner will convey 30% of the Company’s original working and net revenue interests in each farm-out well back to the Company.

	As of December 31, 2014, all six of the wells drilled pursuant to the Farm-Out Agreement have been completed. None of the six wells covered by the Farm-Out Agreement has achieved payout as of December 31, 2014.

Swap_Facility

Swap Facility	12 Months Ended
	Dec. 31, 2014
Credit Facility [Abstract]
Swap Facility [Text Block]	7	Swap Facility

	On December 28, 2012, the Company entered into a prepaid Swap Facility with Macquarie Bank Limited (“MBL”), pursuant to which MBL agreed to advance up to $18 million, of which $16 million was received at closing. The remaining $2 million was received in January 2013.

	Funds received under the Swap Facility were accounted for as debt and were scheduled to be repaid through a series of monthly payments from the sale of approximately 212,000 barrels of oil over the five-year period from January 2013 to December 2017, with a final balloon payment of $2 million, due in February 2018.

	On August 19, 2013, the Company repaid in full the outstanding balance under the Swap Facility using proceeds received from its Credit Facility with MSCG (see Note 8). The total payoff amount was approximately $18 million, which included 100% of the then outstanding principal balance, the settlement of all outstanding swap agreements, and certain prepayment penalties. The Company recognized a loss during 2013 on the early extinguishment of debt of approximately $3.7 million, which included prepayment penalties, the termination of related price swap agreements and the write-off of deferred financing costs associated with the Swap Facility.

	The annual interest rate associated with the Swap Facility approximated 7.4%. The Company recognized interest expense related to the Swap Facility totaling approximately $903,000 and $183,000 for the years ended December 31, 2013 and 2012, respectively.

	The Company incurred investment banking fees and closing costs totaling approximately $780,000 in connection with the negotiation and closing of the MBL Swap Facility. The Company capitalized these items as deferred financing costs, and began amortizing the deferred financing costs over the life of the Swap Facility. The Company recognized approximately $151,000 and $0 of amortization expense related to the deferred financing costs for the years ended December 31, 2013 and 2012, respectively. The amortization of deferred loan costs is included as an additional component of interest expense for the respective periods.

Credit_Facility

Credit Facility (Credit Facility [Member])	12 Months Ended
	Dec. 31, 2014
Credit Facility [Member]
Debt Disclosure [Text Block]	8	Credit Facility

	In August 2013, the Company entered into the $200 million MSCG Credit Facility, which was comprised of a $68 million initial term loan (the “Initial Term Loan”), a $40 million term loan to be used to fund certain working interest purchases (the “Spyglass Tranche A Loan”) and an uncommitted term loan of up to $92 million (the “Tranche B Loan”). The MSCG Credit Facility was collateralized by, among other things, the Company’s oil and gas properties and future oil and gas sales derived from such properties.

	Net proceeds from borrowings under the Initial Term Loan totaling approximately $67.3 million were used: (i) to repay amounts outstanding under the Swap Facility, thus fully extinguishing the Swap Facility, (ii) to reduce the Company’s payables, (iii) to develop its Spyglass Area in North Dakota to increase production of hydrocarbons, (iv) to acquire new oil and gas properties within the Spyglass Area and (v) to fund general corporate purposes that are usual and customary in the oil and gas exploration and production business.

	Proceeds from borrowings under the Spyglass Tranche A Loan totaling approximately $40 million were used to purchase additional net revenue and working interests in the Spyglass Area (See Note 4).

	In July 2014, the Company borrowed approximately $2.2 million in connection with the amendment of certain financial covenants contained in the original MSCG Credit Facility agreement.

	In August 2014, the Company repaid all amounts then-outstanding under the MSCG Credit Agreement with funds received from the issuance of certain bonds (see Note 9) and, in doing so, recognized a loss on the early extinguishment of debt totaling approximately $11.9 million. The loss on the early extinguishment of debt included, the covenant amendment fee of approximately $2.2 million, a prepayment penalty of approximately $3.3 million and the write-off of unamortized deferred financing costs of approximately $6.4 million.

	The MSCG Credit Facility contained customary affirmative and negative covenants for borrowings of this type, including limitations on the Company with respect to transactions with affiliates, hedging agreements, dividends and distributions, operations in respect of the property that secures its collective obligations under the MSCG Credit Facility, liens and encumbrances in respect of the property that secures the Company’s collective obligations under the MSCG Credit Facility, subsidiaries and divestitures, indebtedness, investments, and changes in business. The MSCG Credit Agreement also contained a number of financial covenants, including the maintaining of an adjusted minimum working capital ratio of 1.0.

	The MSCG Credit Facility had a five-year term and carried a variable interest rate ranging from approximately 5.5% to 10.5%. The variable interest rate was based primarily on the ratio of the Company’s proved developed reserves to its debt for a given period. Interest expense related to the Initial Term Loan and Spyglass Tranche A Loan totaled approximately $7.6 million and $3.8 million for the years ended December 31, 2014 and 2013, respectively.

	The Company incurred investment banking fees and closing costs totaling approximately $7.8 million in connection with the negotiation and closing of the Initial Term Loan and Spyglass Tranche A Loan. The Company capitalized these items as deferred financing costs, and began amortizing these costs over the life of the MSCG Credit Facility using the effective interest method. The amortization of deferred financing costs is included as a component of the Company’s interest expense for the period. The Company amortized approximately $1.0 million and $451,000 of deferred financing costs related to the MSCG Credit Facility during the years ended December 31, 2014 and 2013, respectively.

Bonds_Payable

Bonds Payable (Bonds [Member])	12 Months Ended
	Dec. 31, 2014
Bonds [Member]
Debt Disclosure [Text Block]		9	Bonds Payable

	In August 2014, the Company issued a series of 11% secured bonds (the “Bonds”) through a Rule 144A / Regulation S private offering. The Bonds mature on September 1, 2019 and have an aggregate gross value of $175 million. The Bonds were issued at a discount (99.059%), resulting in a discount of approximately $1.6 million. Net proceeds received from the issuance of the Bonds approximated $167.3 million, net of the bond discount, investment banking fees and closing costs. A portion of the net proceeds received from the issuance of the Bonds was used to repay in full the then-outstanding balance of the MSCG Credit Facility (see Note 8). The Company is amortizing the bond discount over the life of the bonds using the effective interest method. Amortization of the Bond discount totaled approximately $114,000 for the year ended December 31, 2014.

	The Bonds bear interest at a rate of 11.0% annually. Interest on the Bonds is payable in arrears each March 1^st and September 1^st. Interest expense related to the Bonds totaled approximately $6.6 million for the year ended December 31, 2014.

	The Company incurred investment banking fees and closing costs totaling approximately $7.2 million in connection with the issuance of the Bonds. The Company has capitalized these items as deferred financing costs, and is amortizing these costs over the life of the Bonds using the effective interest method. The amortization of deferred financing costs is included as a component of the Company’s interest expense for the period. The Company amortized deferred financing costs related to the Bonds of approximately $500,000 for the year ended December 31, 2014.

	The Bond Indenture contains customary affirmative and negative covenants for financial instruments of this nature, including limitations on the Company with respect to dividends, distributions and additional future borrowings. The Company is in compliance with all covenants required by the Bond Indenture as of December 31, 2014. The Bonds are secured by a second priority lien on virtually all of the Company’s assets.

	The Bonds traded on the open market at a significant discount during the fourth quarter of 2014. On December 29, 2014, the date of the last recorded public trade of the bonds during 2014, Bonds with an aggregate par value of $1.0 million were traded at a discounted price of $0.4325 on the dollar, which suggests that the aggregate fair market value of the Bonds outstanding as of December 31, 2014 was approximately $75.7 million. The actual trade price represents a Hierarchy Level 1 input for the purpose of estimating fair market value.

	As discussed in Note 18. the Company elected to defer the payment of interest due on the bonds on March 2, 2015. The terms of the Bond Indenture provide for a 30-day grace period, during which the interest payment can be paid without triggering an event of default. The 30-day grace period expires on March 31, 2015. As of the date of these financial statements, the Company has not yet determined whether the interest payment will be made. Accordingly, pursuant to generally accepted accounting principles, the Company has classified the Bonds as a current liability as of December 31, 2014. Absent any event of default, the subsequent payment of the interest due on the Bonds within the prescribed grace period, would allow the Company to classify the Bonds as a non-current liability in any revised or future financial statements.

Senior_Secured_Revolving_Credi

Senior Secured Revolving Credit Facility (Revolving Credit Facility [Member])	12 Months Ended
	Dec. 31, 2014
Revolving Credit Facility [Member]
Debt Disclosure [Text Block]	10	Senior Secured Revolving Credit Facility

	Also in August 2014, the Company entered into a Senior Secured Credit Facility (the “Senior Credit Facility”) with SunTrust Robinson Humphrey, Inc. (“SunTrust), which provided for the initial availability of up to $35 million of borrowing capacity. Borrowing capacity is periodically evaluated and adjusted based on, among other things, the discounted value of the Company’s oil and gas reserves (see Note 20). Given falling oil prices throughout the fourth quarter of 2014, SunTrust elected to perform a borrowing capacity redetermination as of December 31, 2014, at which time the borrowing capacity was temporarily reduced to zero. In the event that market conditions improve and/or the Company achieves certain milestones or maintains certain financial ratios, the borrowing capacity of the Senior Credit Facility may be increased to a maximum $60 million at some point in the future. At no time has the Company borrowed funds under the Senior Credit Facility to date.

	When outstanding, amounts drawn under the Senior Credit Facility are subject to variable annual interest rates ranging from LIBOR plus 1.75% to LIBOR plus 3.75%, depending on the nature of the borrowing and the balance outstanding under the Senior Credit Facility at the time the funds are drawn. The terms of the Senior Credit Facility also call for the payment of unused commitment fees relative to amounts that are available, but not drawn, under the Senior Credit Facility. Unused commitment fees associated with the unused portion of the borrowing capacity are included as a component of the Company’s interest expense for the period. The Company recognized approximately $46,000 of unused commitment fees related to the Senior Credit Facility for the year ended December 31, 2014. The Company will not incur additional unused commitment fees during any future period for which the borrowing capacity is zero.

	The Company incurred investment banking fees and closing costs totaling approximately $779,000 in connection with the establishment of the Senior Credit Facility. The Company has capitalized these items as deferred financing costs, and is amortizing these costs over the life of the Senior Credit Facility using a method that approximates the effective interest method. The amortization of deferred financing costs is included as a component of the Company’s interest expense for the period. The Company amortized approximately $52,000 of deferred financing costs related to the Bonds during the year ended December 31, 2014.

	The Senior Credit Facility contains customary affirmative and negative covenants for borrowings of this type, including limitations on the Company with respect to transactions with affiliates, hedging agreements, dividends and distributions, operations in respect of the property that secures its collective obligations under the Senior Credit Facility, indebtedness, investments, and changes in business. The Senior Credit Facility also contains a number of financial covenants, including the maintaining of a current ratio of no less than 1.0 and a ratio of total debt to EBITDAX of no more than 4.0. The Company was not in compliance with these covenants for the period ended December 31, 2014, but has obtained a waiver from SunTrust for the period in question. Pursuant to the terms of the Intercreditor Agreement between the Company, SunTrust and the Bond holders, non-compliance with the covenants does not trigger any cross-default provisions associated with the Bonds.

Price_Swap_Derivatives

Price Swap Derivatives	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities Disclosure [Text Block]		11	Price Swap Derivatives

	As a condition of closing for the Swap Facility (see Note 7), the Company entered into various commodity derivative contracts to mitigate the effects of potential downward pricing on the Company’s oil and gas revenues. The contracts included floating vs. fixed price swaps for the Company’s produced oil. The Company did not designate the price swap agreements as hedges. Accordingly, management elected not to apply hedge accounting to these derivatives but, instead, recognized the changes in the fair value of the price swap agreements in its statement of operations in the period for which such unrealized changes occurred. These price swaps were closed in August 2013, concurrent with the full repayment of the Swap Facility. The Company recognized realized gains associated with the price swap agreements totaling approximately $116,000 for the year ended December 31, 2013.

	As a condition of the MSCG Credit Facility (see Note 8), the Company was required to enter into commodity price swap agreements covering up to 85% of its projected five-year future production on its proved, developed, producing properties. The Company did not designate the price swap agreements as hedges. Accordingly, management elected not to apply hedge accounting to these derivatives but, instead, recognized the changes in the fair value of the price swap agreements in its statement of operations in the period in which such unrealized changes in fair value occur. The Company recognized estimated unrealized losses on the price swaps associated with the MSCG Credit Facility of approximately $815,000 and $0 for the years ended December 31, 2013 and 2012, respectively. The price swap agreements were fully settled in August 2014 in conjunction with the full-repayment of the then-outstanding balance of the MSCG Credit Facility (see Note 8). The Company recognized realized losses on the settlement of the price swaps associated with the MSCG Credit Facility totaling approximately $7.5 million for the years ended December 31, 2014.

	In September 2014, the Company entered into new commodity price swap agreements. The new price swap agreements were settled in December 2014. The Company recognized realized gains on the new price swaps of approximately $14.1 million for the year ended December 31, 2014. The Company has no open derivative positions as of December 31, 2014.

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure [Text Block]	12	Asset Retirement Obligations

	During the years ended December 31, 2014 and 2013, the Company recorded initial, estimated asset retirement obligations totaling approximately $516,000 and $569,000, respectively, in connection with wells that were drilled and completed during the period. The asset retirement obligations represent the discounted future plugging and abandonment costs for operated and non-operated wells located within its Spyglass and Hardy Properties. As of December 31, 2014 and 2013, the consolidated discounted value of the Company’s asset retirement obligations was approximately $1.4 million and $1.1 million, respectively. The projected plugging dates for wells in which the Company owns a working interest ranges from December 31, 2015 to December 31, 2032.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure [Text Block]		13	Commitments and Contingencies

	Drilling Obligations

	The Company has the option to participate in the drilling of future non-operated, development wells related to its working interest in the Spyglass Property, should any such wells be proposed by the other working interest owners. As of December 31, 2014, the Company has elected to participate in nine future wells located within the Spyglass Property, with the Company's non-operated working interest in the Spyglass wells ranging from 0.2% to 23.0%. The Company's estimated portion of the aggregate drilling and completion costs of these wells is approximately $3.8 million. In January 2015, the Company sold its net revenue and working interests in six of the nine non-operated wells to SM Energy (Note 18), which reduced its drilling obligation by approximately $1.8 million. Of the remaining $2.0 million of drilling obligation, approximately $1.1 million has been incurred as of December 31, 2014. Additional wells could be proposed in the future, at which time the Company may or may not elect to participate in such additional wells.

	Employment Contracts

	The Company has entered into employment agreements with its President, its Chief Operating Officer, its Chief Financial Officer and three other members of management, which stipulate, among other things, severance payments in the event that employment is terminated without cause or as a result of a change in control, as defined by the employment agreements. As of December 31, 2014, the amount of severance payments that the Company would be obligated to make under the terms of the employment agreements would total approximately $2.2 million.

	Lease Obligation

	The Company currently leases office space pursuant to the terms of a three-year lease agreement. Future minimum lease payments related to the Company’s office lease as of December 31, 2014 are as follows (in thousands):

			Amount
	2015		$	184
	2016			96
	Total		$	280

	Rent expense for the years ended December 31, 2014, 2013 and 2012 totaled approximately $259,000, $146,000 and $110,000, respectively.

Equity_Transactions

Equity Transactions	12 Months Ended
Equity Transactions	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]		14	Equity Transactions

	Reverse Split
	In March 2014, the Company completed a 1-for-4 reverse split of its common stock. Pursuant to accounting guidelines, all historical share and per-share data contained in these financial statements have been restated to reflect the reverse split for all periods presented.

	Private Placements
	In January 2013, the Company sold 1,000,000 shares of its common stock in a private placement at a price of $4.00 per share. Proceeds from the sale totaled $4.0 million.

	In August 2013, the Company sold 1,250,000 shares of its common stock in a private offering at a price of $8.00 per share. Proceeds from the sale totaled $9.9 million, net investment banking fees.

	Public Offerings
	In October 2013, the Company sold 3,941,449 shares of its common stock at a price of $6.80 per share in two public offerings. The sale of stock was completed pursuant to the Company’s August 2, 2013 shelf registration. Proceeds from the sale, net of expenses and broker fees, totaled approximately $25.0 million.

	In March 2014, the Company sold 12,650,000 shares of its common stock in a public offering at a price of $6.60 per share. The sale of the stock was completed pursuant to the Company’s December 2013 shelf registration. Proceeds from the sale, net of expenses, broker fees and commissions, totaled approximately $78.3 million.

	Stock Options

	During the years ended December 31, 2014, and 2013, the Company granted to members of its Board of Directors, employees and certain key third-party consultants 87,500 and 648,125 stock options with a weighted average fair market value per option granted of $1.63 and $4.41, respectively. The aggregate fair market value of the options granted during the years ended December 31, 2014 and 2013 was approximately $142,000 and $2.9 million, respectively. Each of the stock options granted have a five-year life and vest 50% on the one-year anniversary of the grant date, with the remaining 50% vesting on the second-year anniversary of the grant date.

	The assumptions used in the Black-Scholes Option Pricing Model for the stock options granted were as follows:

				2014		2013
	Risk-free interest rate			0.43% to 0.56%		0.22% to 0.35%
	Expected volatility of common stock			59% to 76%		62% to 84%
	Dividend yield			$0.00		$0.00
	Expected life of options			5 years		5 years

	A summary of stock option activity for the years ended December 31, 2014 and December 31, 2013 is presented below:
									Weighted
						Weighted			Average
						Average			Remaining
						Exercise			Contract
			Options			Price ($)			Term

	Outstanding at December 31, 2012			1,283,650		$	3.12		3.6 years
	Options granted			648,125			8.48
	Options exercised			-5,000			3.12
	Options expired			-			-
	Options forfeited			-			-

	Outstanding at December 31, 2013			1,926,775		$	4.92		3.4 years
	Options granted			87,500			3.19
	Options exercised			-23,125			2.92
	Options expired			-			-
	Options forfeited			-			-

	Outstanding at December 31, 2014			1,991,150		$	4.81		2.5 years

	Exercisable at December 31, 2014			1,584,588		$	4.18		2.1 years

	The following is a schedule of outstanding stock options as of December 31, 2014 by exercise price:

			Options		Options			Exercise
	Grant Date		Outstanding		Exercisable			Price
	12-Dec-14			50,000		-		$	0.73
	30-Oct-09			166,652		166,652			0.9
	1-Oct-12			10,000		10,000			2.76
	1-Aug-12			30,000		30,000			2.88
	1-Sep-12			12,500		12,500			2.92
	14-Dec-12			216,875		216,875			2.96
	30-Dec-10			433,248		433,248			2.97
	1-Nov-12			55,000		55,000			3.12
	21-Feb-12			50,000		50,000			3.68
	14-Dec-11			291,250		291,250			4.72
1-Feb-13			31,250		15,625			5.84
23-Jun-14			25,000		-			6.18
1-Oct-13			50,000		25,000			6.72
15-Jun-13			37,500		18,750			6.84
5-May-14			12,500		-			7.05
28-Oct-13			12,500		6,250			8.6
13-Dec-13			441,875		220,938			8.68
23-Sep-13			7,500		3,750			9.16
1-Oct-13			7,500		3,750			9.28
14-Nov-13			50,000		25,000			9.56
Totals			1,991,150		1,584,588

The options outstanding as of December 31, 2014 and December 31, 2013 have an intrinsic value of $0 and $4.12 per share and an aggregate intrinsic value of approximately $0 and $7.9 million, respectively.

Shares Reserved for Future Issuance

As of December 31, 2014 and December 31, 2013, the Company had reserved 1,991,150 and 1,926,275 shares, respectively, for future issuance upon exercise of outstanding options.

The Company recognized stock-based compensation expense associated with its outstanding stock options of approximately $1.8 million, $1.2 million and $822,000 for the years ended December 31, 2014, 2013 and 2012, respectively.

Income_Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]		15	Income Taxes

	The Company recognized income tax benefit of approximately $5.3 million and $1.2 million for the years ended December 31, 2014 and 2012, respectively, and income tax expense of approximately $1.8 million for the year ended December 31, 2013. Income tax expense (benefit) for the years ended December 31, 2014, 2013 and 2012 consisted of the following (in thousands):

			2014			2013			2012
	Current income tax expense (benefit):
	Domestic		$	16		$	-17		$	-302
	Foreign			-			-77			-32
	Total current income tax expense (benefit)			16			-94			-334

	Deferred income tax expense (benefit):
	Domestic		$	-40,424		$	1,863		$	349
	Foreign			2,891			-636			-3,421
	Change in valuation allowance			32,237			636			2,166
	Total deferred income tax expense (benefit)			-5,296			1,863			-906

	Total income tax expense (benefit)		$	-5,280		$	1,769		$	-1,240

	Significant components of the Company’s deferred income tax assets and liabilities at December 31, 2014 and 2013 are as follows (in thousands):

			2014			2013
	Deferred tax assets:
	Foreign tax credits		$	52		$	52
	Unrealized hedging loss			488			301
	Asset retirement obligations			534			308
	Net operating losses – domestic			18,900			5,688
	Net operating losses – foreign			-			864
	Domestic fixed assets			14,848			-
	Foreign fixed assets			-			1,937
	Stock options			1,881			1,214
	Marketable securities			-			48
	Other			17			160
	Total deferred tax assets			36,720			10,572
	Valuation allowance			-35,038			-2,858
	Net deferred income tax assets		$	1,682		$	7,714

			2014			2013
	Deferred tax liabilities:
	Investment in foreign subsidiary		$	-			321
	Domestic fixed assets			-			12,779
	Asset retirement obligations			491			-
	Other			1,191			-
	Deferred tax liabilities		$	1,682		$	13,100

	Net deferred tax liabilities		$	-		$	5,386

	A reconciliation between the amount of income tax expense for the years ended December 31, 2014, 2013 and 2012, determined by applying the appropriate applicable statutory income tax rates, is as follows (in thousands):

			2014				2013				2012
	US Statutory tax expense (benefit)		$	-33,149			$	1,144			$	-3,581
	State income taxes, net of federal expense (benefit)			-2,508				96				-242
	Foreign taxes paid			6				12				-
	Permanent differences			8				11				8
	Change in valuation allowance			32,228				641				2,166
	True-up of prior year amounts			657				244				-537
	Foreign operations			-2,437				-236				909
	Rate change			-92				-143				39
	Other			7				-				-2
	Net income tax expense (benefit)		$	-5,280			$	1,769			$	-1,240

	Effective tax rate			5.4	%			52.6	%			11.8	%

	As discussed in Note 4, the Company divested all of its foreign operations through the sale of its interests in the oil and gas properties held by its Canadian subsidiaries in July 2014 and subsequent dissolution of the two subsidiaries on October 31, 2014. For tax purposes, the Company recognized losses that include certain bad debt and worthless security deductions because it did not receive repayment for its investments in the Canadian subsidiaries.

Based upon the Company’s history of operating losses, the Company’s management has determined that it is more likely than not that the U.S. federal and state deferred tax assets as of December 31, 2014 will not be realized. Consequently, the Company has established a valuation allowance for its net U.S. federal and state deferred tax assets during the year ended December 31, 2014.

As of December 31, 2014, the Company has U.S. federal and aggregate state net operating loss carryforwards of approximately $49.9 million and $36.0 million, which expire at various dates through 2034. IRC Section 382 of the Internal Revenue Code of 1986, as amended, provides an annual limitation on the utilization of net operating losses should the Company undergo an ownership change, as defined in IRC Section 382. The utilization of the estimated net operating losses may be limited due to changes in ownership. The possible limitations have not been determined as of December 31, 2014 since there would be no financial statement impact based on a full valuation allowance against the estimated net operating losses.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
Earnings Per Share	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share [Text Block]		16	Earnings Per Share

	The following is a reconciliation of the number of shares used in the calculation of basic and diluted earnings per share for the years ended December 31, 2014, 2013 and 2012 (in thousands, except per share data):

			2014		2013		2012
	Net income (loss)		$	-92,216	$	1,594	$	-9,292

	Weighted average number of common shares outstanding			27,513		13,962		11,448
	Incremental shares from the assumed exercise of dilutive stock options			-		637		-
	Diluted common shares outstanding			27,513		14,599		11,448

	Earnings (loss) per share – basic		$	-3.35	$	0.11	$	-0.81
	Earnings (loss) per share – diluted		$	-3.35	$	0.11	$	-0.81

	Because the Company recognized a net loss for the years ended December 31, 2014 and 2012, the calculation of diluted loss per share is the same as the calculation of basic loss per share, as the effect of including any incremental shares from the assumed exercise of dilutive stock options would be anti-dilutive. The number of anti-dilutive shares that have been excluded from the calculation of diluted loss per share for the years ended December 31, 2014 and 2012 is approximately 322,000 and 469,000 shares, respectively.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions Disclosure [Text Block]		17	Related Party Transactions

	The Company routinely obtains legal services from a firm for whom one of its directors serves as a principal. Fees paid this firm approximated $56,000, $37,000 and $24,000 for the years ended December 31, 2014, 2013 and 2012, respectively.

	The Company receives monthly geological consulting services from Synergy Energy Resources LLC (“Synergy”). One of the Company’s current directors and one current officer own material ownership interests in Synergy. The Company incurred $84,000, $168,000 and $168,000 of consulting expenses from Synergy during each of the years ended December 31, 2014, 2013 and 2012, respectively. The Company terminated its agreement with Synergy effective June 30, 2014.

	The Company’s Chairman and Chief Operating Officer each owns overriding royalty interests in certain of the Company’s operated wells. The overriding royalty interests were obtained prior the Company’s acquisition of AEE, Inc. in December 2011. Royalties paid to the Company’s Chairman totaled approximately $472,000, $608,000 and $67,000 for the years ended December 31, 2014, 2013 and 2012, respectively. Royalties paid to the Company’s Chief Operating Officer totaled approximately $382,000, $540,000 and $52,000 for the years ended December 31, 2014, 2013 and 2012, respectively.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events [Text Block]		18	Subsequent Events

	In January 2015, the Company sold its net revenue and working interests in certain non-operated wells to SM Energy. Cash proceeds received from the sale totaled approximately $9.5 million.

	The Company elected to defer the payment of approximately $9.8 million of interest due on its Bonds on March 2, 2015. The terms of the Bond Indenture provide for a 30-day cure period, during which the interest payment can be made without the late payment constituting an event of default. The Company intends to utilize the 30-day grace period to evaluate strategies for improving its liquidity.

Going_Concern

Going Concern	12 Months Ended
	Dec. 31, 2014
Going Concern [Abstract]
Going Concern [Text Block]		19	Going Concern

	As of December 31, 2014, the Company has a working capital deficit of approximately $13.6 million. The sharp decline in oil prices that occurred during the latter part of 2014 materially reduced the revenues that were generated from the sale of the Company’s oil and gas production volumes during that period which, in turn, negatively affected the Company’s year-end working capital balance. The potential for future oil prices to remain at their current price levels for an extended period of time raises substantial doubt regarding the Company’s ability to continue as a going concern. For purposes of this discussion, the term “substantial doubt” refers to concerns that a company may not be able to meet its obligations when they come due.

	Should the prevailing oil prices as of December 31, 2014 remain in effect for an extended period of time, it is likely that the Company would need to pursue some form of asset sale, debt restructuring or capital raising effort in order to fund its operations and to service its existing debt during the next twelve months. The Company’s management is actively developing plans to improve its working capital position and/or to reduce its future debt service costs, through the aforementioned means, in order to remain a going concern for the foreseeable future. If the Company is unable to restructure its Bonds, obtain additional debt or equity financing or achieve adequate proceeds from the sale of assets, the Company may file a voluntary petition for reorganization relief under Chapter 11 of the Bankruptcy Code in order to provide additional time to identify an appropriate solution to its financial situation and to implement a plan of reorganization aimed at improving its capital structure.

Supplemental_Oil_and_Gas_Infor

Supplemental Oil and Gas Information (Unaudited)	12 Months Ended
Supplemental Oil and Gas Information (Unaudited)	Dec. 31, 2014
Supplemental Oil And Gas Information [Abstract]
Oil and Gas Properties [Text Block]		20	Supplemental Oil and Gas Information (Unaudited)

	During the years ended December 31, 2014, 2013 and 2012, the Company incurred the following costs associated with the acquisition, exploration and development of oil and gas properties (in thousands):

			2014			2013			2012
	Acquisition costs		$	57,946		$	62,860		$	16,671
	Exploration costs			53,651			32,053			-
	Development costs			60,711			28,543			27,914
	Total costs		$	172,308		$	123,456		$	44,585

	The net capitalized cost of the Company’s oil and gas properties, subject to amortization, as of December 31, 2014 and 2013 is summarized below (in thousands):

			2014			2013
	Acquisition costs		$	147,477		$	88,910
	Exploration costs			-			-
	Development costs			196,774			93,696
	Impairments and sales			-82,001			-14,612
	Gross capitalized costs			262,250			167,994
	Accumulated depletion			-35,332			-12,849
	Net capitalized costs		$	226,918		$	155,145

	The Company has owned mineral interests in both operated and non-operated producing wells, as well as in undeveloped acreage, for which proved oil and gas reserves have been assigned in both the United States and Canada. The Company sold its interests in its Canadian oil and gas properties in July 2014 (See Note 4). Pursuant to full-cost accounting rules, the Company maintained separate cost centers for it’s US and Canadian oil and gas properties and related costs. The proved reserves associated with the Company’s US cost center represents 100% and 99.5% of the Company’s total proved reserves, both on a volume and discounted, future cash flow (PV10) basis as of December 31, 2014 and 2013, respectively. Furthermore, revenues generated from the Company’s US oil and gas properties accounted for 99.4%, 97.1% and 82.0% of the Company’s total revenue for the years ended December 31, 2014, 2013 and 2012, respectively. Because the result of operations and proved reserves associated with the Company’s Canadian oil and gas operations is not material to the Company’s overall results of operations and reserves, the Company has elected to present the following supplemental oil and gas information on a consolidated basis, rather than by cost center.

	The tables presented below set forth the Company’s net interests in quantities of proved developed and undeveloped reserves of crude oil, condensate and natural gas and changes in such quantities from the prior period. Crude oil reserves estimates include condensate.

			Oil				Gas				Total
			(Barrels)				(Mcf)				(BOE)
	For the year ended December 31, 2014:
	Proved reserves, beginning of year			12,109				8,652				13,550
	Revisions			(3,726	)			(2,377	)			(4,122	)
	Extensions and discoveries			1,064				640				1,171
	Purchases of reserves in place			1,051				948				1,209
	Sale of reserves in place			(148	)			(1	)			(148	)
	Production			(763	)			(42	)			(770	)
	Proved reserves, end of year			9,587				7,820				10,890

	Proved developed reserves			5,495				4,820				6,298
	Proved undeveloped reserves			4,092				3,000				4,592
	Total proved reserves			9,587				7,820				10,890

	As a result of participating in 32 gross new wells, the Company converted approximately 1,713,000 barrels of oil and approximately 1,187,000 mcf of gas from proved undeveloped reserves to proved developed reserves during the year ended December 31, 2014. The Company incurred approximately $56.5 million of capitalized expenditures to drill these wells.

	The decrease in the Company’s proved undeveloped reserves from December 31, 2013 to December 31, 2014 is primarily due to uncertainty regarding whether or not the Company will have sufficient capital to support its current development plan. The Company has historically utilized carry agreements (see Note 5) and farm-out agreements (see Note 6) to accelerate the drilling of its operated wells. The amount of proved undeveloped reserves that the Company is claiming as of December 31, 2014 have been determined based on the assumption that the Company will continue to utilize such arrangements in the future in order to continue its planned drilling activities. The Company’s has reduced its net revenue and working interests in the future wells that comprise its proved undeveloped reserves by 50% in consideration of the anticipated terms of such arrangements.

			Oil				Gas				Total
			(Barrels)				(Mcf)				(BOE)
	For the year ended December 31, 2013:
	Proved reserves, beginning of year			5,398				2,139				5,754
	Revisions			(1,614	)			308				(1,563	)
	Extensions and discoveries			7,412				5,334				8,301
	Purchases of reserves in place			1,411				899				1,561
	Production			(498	)			(28	)			(503	)
	Proved reserves, end of year			12,109				8,652				13,550

	Proved developed reserves			4,207				3,047				4,714
	Proved undeveloped reserves			7,902				5,605				8,836
	Total proved reserves			12,109				8,652				13,550


	As a result of participating in 19 new wells, the Company converted 956,515 barrels of oil and 340,926 mcf of gas from proved undeveloped reserves to proved developed reserves during the year ended December 31, 2013. The Company incurred approximately $19.8 million of capitalized expenditures to drill these wells.

			Oil				Gas				Total
			(Barrels)				(Mcf)				(BOE)
	For the year ended December 31, 2012:
Proved reserves, beginning of year			1,511				417				1,581
Revisions			(687	)			(191	)			(719	)
Extensions and discoveries			4,429				1,774				4,725
Purchases of reserves in place			479				248				520
Sales of reserves in place			(200	)			(107	)			(218	)
Production			(134	)			(2	)			(135	)
Proved reserves, end of year			5,398				2,139				5,754

Proved developed reserves			2,388				1,074				2,566
Proved undeveloped reserves			3,010				1,065				3,188
Total proved reserves			5,398				2,139				5,754

As a result of participating in 15 new wells, the Company converted 351,883 barrels of oil and 195,092 mcf of gas from proved undeveloped reserves to proved developed reserves during the year ended December 31, 2012. The Company incurred approximately $2.9 million of capitalized expenditures to drill these wells.

Standardized Measure, Including Year-to-Year Changes Therein, of Discounted Future Net Cash Flows

For purposes of the following disclosures, estimates were made of quantities of proved reserves and the periods during which they are expected to be produced. Estimated future cash flows were computed by applying a 12-month average of oil prices, except in those instances where future oil or natural gas sales are covered by physical contract terms providing for higher or lower prices, to the Company’s share of estimated annual future production from proved oil and gas reserves, net of royalties. Future development and production costs were computed by applying year-end costs to be incurred in producing and further developing the proved reserves. Future income tax expenses were computed by applying, generally, year-end statutory tax rates (adjusted for permanent differences, tax credits, allowances and foreign income repatriation considerations) to the estimated net future pre-tax cash flows. The discount was computed by application of a 10 % discount factor. The calculations assumed the continuation of existing economic, operating and contractual conditions at December 31, 2014, 2013 and 2012, respectively.

Standardized Measure of Discounted Future Net Cash Flows (in thousands):

		2014			2013			2012
Future cash flows		$	829,316		$	1,141,907		$	448,623
Future costs:
Production costs			-273,430			-307,093			-99,411
Development costs			-109,102			-177,750			-50,693
Income taxes			-47,464			-184,362			-104,827
Future net cash flows			399,320			472,702			193,692
Ten percent discount factor			-195,573			-250,648			-116,784
Standardized measure of discounted future net cash flows		$	203,747		$	222,054		$	76,908

The following table summarizes the changes in the Company’s standardized measure of discounted future net cash flows for the years ended December 31, 2014, 2013 and 2012 (in thousands):

		2014			2013			2012
Extensions and discoveries		$	35,491		$	167,600		$	84,276
Net changes in sales prices and production costs			-54,609			1,001			-2,939
Oil and gas sales, net of production costs			-38,480			-31,530			-7,514
Change in estimated future development costs			95,259			-5,659			12,376
Revision of quantity estimates			-136,988			-34,499			-22,267
Purchases of mineral interests			42,855			35,496			12,777
Sales of mineral interests			-5,368			-			-
Previously estimated development costs incurred in the current period			-58,895			14,256			2,897
Changes in production rates, timing & other			14,366			21,692			1,947
Changes in income taxes			57,037			-35,914			-33,864
Accretion of discount			31,025			12,703			3,994
Net increase			-18,307			145,146			51,683
Standardized measure of discounted future cash flows – beginning of the year			222,054			76,908			25,225
Standardized measure of discounted future cash flows – end of the year		$	203,747		$	222,054		$	76,908

Assumed prices used to calculate future cash flows

		2014			2013			2012
Oil price per barrel		$	82.36		$	90.63		$	81.78
Gas price per mcf		$	5.08		$	5.15		$	3.38

Quarterly_Financial_Informatio

Quarterly Financial Information (Unaudited)	12 Months Ended
Quarterly Financial Information (Unaudited)	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information [Text Block]		21	Quarterly Financial Information (Unaudited)

	The Company’s quarterly financial information for the years ended December 31, 2014, 2013 and 2012 is as follows (in thousands, except for per-share data):

			For the Year Ended December 31, 2014
			First		Second		Third		Fourth
			Quarter		Quarter		Quarter		Quarter
	Oil and gas revenues		$	12,545	$	16,463	$	17,091	$	14,450
	Operating expenses			9,306		12,570		13,885		100,652
	Other income (expense)			-4,905		-9,896		-14,513		7,682
	Net income (loss)			-1,028		-3,900		-8,738		-78,550
	Basic earnings (loss) per share			-0.06		-0.13		-0.29		-2.58
	Diluted earnings (loss) per share			-0.06		-0.13		-0.29		-2.58
	Cash provided by operating activities			7,384		1,850		11,353		6,027
	Cash used for investing activities			-67,441		-29,731		-36,661		-29,034
	Cash provided by (used for) financing activities			78,299		-		51,909		-47


			For the Year Ended December 31, 2013
			First		Second		Third		Fourth
			Quarter		Quarter		Quarter		Quarter
	Oil and gas revenues		$	7,629	$	10,370	$	11,639	$	13,501
	Operating expenses			5,756		6,330		7,391		11,298
	Other income (expense)			-425		-210		-5,830		-2,536
	Net income (loss)			355		2,637		-936		-462
	Basic earnings (loss) per share			0.03		0.21		-0.07		-0.03
	Diluted earnings (loss) per share			0.03		0.2		-0.07		-0.03
	Cash provided by operating activities			10,484		3,377		11,390		5,160
	Cash used for investing activities			-16,378		-2,903		-66,123		-55,888
	Cash provided by (used for) financing activities			5,029		-1,640		56,706		63,580

			For the Year Ended December 31, 2012
			First		Second		Third		Fourth
			Quarter		Quarter		Quarter		Quarter
	Oil and gas revenues		$	1,226	$	1,691	$	2,875	$	4,922
	Operating expenses			1,882		1,832		2,388		15,093
	Other income (expense)			21		12		19		-103
	Net income (loss)			-358		-147		892		-9,679
	Basic earnings (loss) per share			-0.01		0		0.02		-0.21
	Diluted earnings (loss) per share			-0.01		0		0.02		-0.21
	Cash provided by (used for) operating activities			3,443		5,040		5,855		-10,450
	Cash provided by (used for) investing activities			-8,657		-2,038		3,486		-5,318
	Cash provided by financing activities			145		-		-		15,400

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation

	The accompanying consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, AMZG, Inc., EERG Energy ULC (“EERG” - Canadian) and AEE Canada Inc. (“AEE Canada” - Canadian). All material intercompany accounts, transactions and profits have been eliminated.

	As discussed in Note 4, the Company sold 100% of its net revenue and working interests in its Canadian oil and gas properties in July 2014. The Company legally dissolved its Canadian subsidiaries (EERG and AEE Canada) in October 2014, at which time, all remaining assets held by the Canadian entities were transferred back to the parent company. The accompanying Consolidated Statements of Operations and Comprehensive Income (Loss) and Consolidated Statements of Cash Flows for the year ended December 31, 2014 include the operating results and activities of EERG and AEE Canada through the date of dissolution.

	Certain reclassifications have been made to prior year balances to conform to the current year’s presentation. These reclassifications had no effect on net income (loss) for the years ended December 31, 2013 and 2012.

Revenue Recognition, Policy [Policy Text Block]	Revenue Recognition

	Revenue from the sale of produced oil and gas is recognized when the terms of the sale have been finalized and the oil or gas has been delivered to the purchaser. The Company accrues estimated oil and gas sales for production periods that have not yet been settled in cash.

Concentration Risk, Credit Risk, Policy [Policy Text Block]	Concentration of Credit Risk

	At any point throughout the year, the Company may have amounts on deposit that exceed the United States Federal Deposit Insurance Company insurance limit of $250,000 per bank.

Foreign Currency Transactions and Translations Policy [Policy Text Block]	Foreign Currency Adjustments

	The functional currency of EERG and AEE Canada is the Canadian Dollar. EERG’s and AEE Canada’s asset and liability account balances are translated into US Dollars at the exchange rate in effect as of the balance sheet dates. Gains and losses realized upon the settlement of foreign currency transactions are included in the Company’s results of operations. Foreign currency translation adjustments are presented as other comprehensive income.

Comprehensive Income, Policy [Policy Text Block]	Components of Other Comprehensive Income

	Comprehensive income consists of net income and other gains and losses affecting stockholders’ equity that, under generally accepted accounting principles, are excluded from net income. For the Company, such items consist of unrealized gains (losses) on marketable securities and foreign currency translation adjustments.

Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents

	Cash equivalents consist of time deposits and liquid debt investments with original maturities of three months or less at the time of purchase.

Receivables, Policy [Policy Text Block]	Receivables

	Receivables are stated at the amount the Company expects to collect. In certain instances, the Company has the legal right to offset undistributed revenues from its operated wells against uncollected receivables from its working interest partners. The Company considers the following factors when evaluating the collectability of specific receivable balances: credit-worthiness of the debtor, past transaction history with the debtor, current economic industry trends, and changes in debtor payment terms. If the financial condition of the Company’s debtors were to deteriorate, adversely affecting their ability to make payments, additional allowances would be required.

	The Company maintains an allowance for doubtful accounts for estimated losses resulting from the inability of its customers to make required payments. Changes to the allowance for doubtful accounts made as a result of management’s determination regarding the ultimate collectability of such accounts are recognized as a charge to the Company’s earnings. Specific receivable balances that remain outstanding after the Company has used reasonable collection efforts are written off through a charge to the valuation allowance and a credit to the receivable.

	At December 31, 2014 and 2013, the Company has determined that all receivable balances are fully collectible and, accordingly, no allowance for doubtful accounts has been recorded.

Equipment And Leasehold Improvements [Policy Text Block]	Equipment and Leasehold Improvements

	Equipment and leasehold improvements are recorded at cost. Expenditures for major additions and improvements are capitalized and depreciated or amortized over the estimated useful lives of the related assets using the straight-line method for financial reporting purposes. The estimated useful lives for significant property and equipment categories are as follows:

	Furniture and equipment	3 years
	Leasehold improvements	lesser of useful life or lease term

	When equipment and improvements are retired or otherwise disposed of, the cost and the related accumulated depreciation are removed from the Company’s accounts and any resulting gain or loss is included in the results of operations for the respective period.

	Expenditures for minor replacements, maintenance and repairs are charged to expense as incurred.

Oil and Gas Properties Policy [Policy Text Block]	Oil and Gas Properties and Prospects

	The Company follows the full-cost method of accounting for its investments in oil and gas properties. Under the full-cost method, all costs associated with the acquisition, exploration or development of properties, are capitalized into appropriate cost centers within the full-cost pool. Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities. Cost centers are established on a country-by-country basis.

	Capitalized costs for each of the Company’s cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unproved properties are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory uneconomic holes are included in the amortization base immediately upon determination that the well is uneconomic.

	Proceeds received from the disposal of oil and gas properties are credited against accumulated costs, except when the sale represents a significant disposal of reserves, in which case a gain or loss is recognized.

	During the year ended December 31, 2014, the Company determined that it was unlikely that it would pursue the development of its oil and gas properties that are not subject to amortization in the foreseeable future. As a result, the Company reclassified all of the capitalized costs associated with these properties into the full cost pool.

	As of the end of each reporting period, the capitalized costs of each cost center are subject to a ceiling test, in which the costs may not exceed the cost center ceiling. The cost center ceiling is equal to (i) the present value of estimated future net revenues, computed by applying the unweighted arithmetic average of prices posted on the first day of each of the preceding twelve months (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; plus (ii) the cost of properties not being amortized; plus (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; less (iv) income tax effects related to differences between the book and tax basis of the properties. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs. The Company recognized impairment losses totaling approximately $81.9 million associated with its US cost center for the year ended December 31, 2014, and losses totaling approximately $1.7 million and approximately $10.6 million associated with its Canadian cost center for the years ended December 31, 2013 and 2012, respectively.

Deferred Charges, Policy [Policy Text Block]	Deferred Loan Costs

	The Company capitalizes costs that are directly related to securing bank loans and other types of long-term financing and amortizes such costs over the life of the corresponding debt using the effective interest method.

Derivatives, Policy [Policy Text Block]	Derivatives

	Historically, the Company has entered into a number of oil price swap agreements, which represent derivative financial instruments. The Company reports its derivatives at their fair market value as of the end of each reporting period. Changes in the fair value of derivatives are included in the Company’s results of operations in the period in which they occur. The Company has no open derivative positions as of December 31, 2014.

Asset Retirement Obligations, Policy [Policy Text Block]	Asset Retirement Obligations

	The Company records estimated asset retirement obligations related to the future plugging and abandoning of its existing wells in the period in which the wells are completed. The initial recording of an asset retirement obligation results in an increase in the carrying amount of the related long-lived asset and the creation of a liability. The portion of the asset retirement obligation expected to be realized during the next 12-month period is classified as a current liability, while the portion of the asset retirement obligation expected to be realized during subsequent periods is discounted and recorded at its net present value. The discount factors used to determine the net present value of the Company’s asset retirement obligation range from 4.2% to 11.0%, which represented the Company’s estimated incremental borrowing rate as of the dates that the corresponding wells were put on production.

	Changes in the noncurrent portion of the asset retirement obligation due to the passage of time are accreted using the interest method. The amount of change is recognized as an increase in the liability and an accretion expense in the statement of operations. Changes in either the current or noncurrent portion of the Company’s asset retirement obligation resulting from revisions to the timing or the amount of the original estimate of undiscounted cash flows are recognized as an increase or a decrease to the carrying amount of the liability and the related long-lived asset.

Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]	Stock-Based Compensation

	The Company measures compensation cost for all stock-based awards at fair value on the date of grant and recognizes compensation expense in its statements of operations over the service period that the awards are expected to vest. The Company has elected to recognize compensation cost for all options with graded vesting on a straight-line basis over the vesting period of the entire option. The Company recognized stock-based compensation expense of approximately $1.8 million, $1.2 million and $822,000 for the years ended December 31, 2014, 2013 and 2012, respectively.

Fair Value of Financial Instruments, Policy [Policy Text Block]	Fair Value of Financial Instruments

	Fair value is the price that would be received from the sale of an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 or 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.

Earnings Per Share, Policy [Policy Text Block]	Basic and Diluted Earnings Per Share

	Basic earnings per common share is computed by dividing net earnings available to common stockholders by the weighted average number of common shares outstanding during the period. For periods in which the Company recognizes net income, diluted earnings per common share is computed in the same way as basic earnings per common share except that the denominator is increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued that were dilutive. For periods in which the Company recognizes losses, the calculation of diluted earnings per share is the same as the calculation of basic earnings per share. See Note 16 for the calculation of basic and diluted weighted average common shares outstanding for the years ended December 31, 2014, 2013 and 2012.

Income Tax, Policy [Policy Text Block]	Income Taxes

	The Company follows the liability method of accounting for income taxes. Under this method, deferred income tax assets and liabilities are recognized for the future tax benefits and consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax balances. Deferred income tax assets and liabilities are measured using enacted or substantially enacted tax rates expected to apply to the taxable income in the years in which those differences are expected to be recovered or settled. The effect on deferred income tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the date of enactment or substantive enactment. Net operating loss carry forwards and other deferred tax assets are reviewed annually for recoverability and, if necessary, are recorded net of a valuation allowance. See Note 15 for a summary of the Company’s income tax expense (benefit) for the years ended December 31, 2014, 2013 and 2012.

Liquidity Disclosure [Policy Text Block]	Liquidity

	The Company finances its oil and gas exploration and development activities and corporate operations through a combination of internally generated funds, external debt financing and sales of its common stock. As of December 31, 2014, the Company had working capital deficit of approximately $13.6 million. See Note 19 for further discussion regarding the liquidity of the Company.

Use of Estimates, Policy [Policy Text Block]	Use of Estimates and Assumptions

	The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent obligations in the financial statements and accompanying notes. The Company’s most significant assumptions are the estimates used in the determination of the deferred income tax asset valuation allowance and the valuation of oil and gas reserves to which the Company owns rights. The estimation process requires assumptions to be made about future events and conditions, and as such, is inherently subjective and uncertain. Actual results could differ materially from these estimates.

New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements

	In April 2014, the Financial Accounting Standards Board (“FASB”) issued Update 2014-08 - Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The objective of the amendments in this update is to change the criteria for reporting discontinued operations and enhance convergence of the FASB's and the International Accounting Standards Board's reporting requirements for discontinued operations. The amendments in this update change the requirements for reporting discontinued operations in Subtopic 205-20. A discontinued operation may include a component of an entity or a group of components of an entity, or a business or nonprofit activity. 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 amendments in this update require an entity to present, for each comparative period, the assets and liabilities of a disposal group that includes a discontinued operation separately in the asset and liability sections, respectively, of the statement of financial position. The amendments in this update also require additional disclosures about discontinued operations. Public business entities must apply the amendments in this update prospectively to both of the following: (1) All disposals (or classifications as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years; (2) All businesses or nonprofit activities that, on acquisition, are classified as held for sale that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. The Company does not believe the adoption of this update will have a material impact on the Company’s consolidated financial statements.

	In May 2014, the FASB issued Update 2014-09 - Revenue from Contracts with Customers (Topic 606). The objective of the amendments in this update is to improve financial reporting by creating common revenue recognition guidance for accounting principles generally accepted in the United States and International Financial Reporting Standards. The guidance in this update supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. An entity should disclose sufficient information, both qualitative and quantitative, to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The amendments in this update are effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application is not permitted. The Company does not believe the adoption of this update will have a material impact on the Company’s consolidated financial statements.

	In June 2014, the FASB issued ASC Update No. 2014-12 - Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (“ASC No. 2014-12”). The objective of the amendments in this update is to resolve the diverse accounting treatment of share-based payment awards. The amendments in this update apply to all reporting entities that grant their employees share-based payments in which the terms of the award provide that a performance target that affects vesting could be achieved after the requisite service period. The amendments require that a performance target that affects vesting and that could be achieved after the requisite service period be treated as a performance condition. As such, the performance target should not be reflected in estimating the grant-date fair value of the award. Compensation cost should be recognized in either (i) the period in which it becomes probable that the performance target will be achieved and should represent the compensation cost attributable to the period(s) for which the requisite service has already been rendered or (ii) if the performance target becomes probable of being achieved before the end of the requisite service period, the remaining unrecognized compensation cost should be recognized prospectively over the remaining requisite service period. The total amount of compensation cost recognized during and after the requisite service period will reflect the number of awards that are expected to vest and will be adjusted to reflect those awards that ultimately vest. The requisite service period ends when the employee can cease rendering service and still be eligible to vest in the award if the performance target is achieved. The amendments in this update are effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Earlier adoption is permitted. Entities may apply the amendments in this update either (a) prospectively to all awards granted or modified after the effective date or (b) retrospectively to all awards with performance targets that are outstanding as of the beginning of the earliest annual period presented in the financial statements and to all new or modified awards thereafter. The Company does not believe the adoption of this update will have a material impact on the Company’s consolidated financial statements.

Marketable_Securities_and_Fair1

Marketable Securities and Fair Value Measurements (Tables)	12 Months Ended
Marketable Securities and Fair Value Measurements (Tables)	Dec. 31, 2014
Investments, Debt and Equity Securities [Abstract]
Available-for-sale Securities [Table Text Block]	Available-for-sale marketable securities at December 31, 2014 and 2013 consist of the following (in thousands):
						Gains in			Losses in
						Accumulated			Accumulated
			Estimated			Other			Other
			Fair			Comprehensive			Comprehensive
			Value			Income			Income
	31-Dec-14
	Noncurrent assets:
	Marketable securities		$	756		$	-		$	-

	31-Dec-13
	Noncurrent assets:
	Marketable securities		$	1,050		$	100		$	-75

Fair Value, Assets Measured on Recurring Basis [Table Text Block]	The fair value of the Company’s financial instruments, measured on a recurring basis at December 31, 2014 and 2013, were as follows (in thousands):

			Level 1			Level 2			Level 3			Total
	December 31, 2014
	Marketable securities	$		756	$		-	$		-	$		756

	31-Dec-13
	Marketable securities			1,050			-			-			1,050
	Current derivative asset			-			211			-			211
	Current derivative liability			-			-276			-			-276
	Noncurrent derivative liability			-			-750			-			-750

Purchases_and_Sales_of_Royalty1

Purchases and Sales of Royalty and Property Interests (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Business Acquisition, Pro Forma Information [Table Text Block]	Had the purchase of these additional net revenue and working interests occurred on January 1, 2012, the Company’s consolidated financial statements for the years ended December 31, 2014, 2013 and 2012 would have been as follows (in thousands):

		2014		2013
	Pro forma revenues	$	63,723	$	67,360
	Pro forma net income (loss)	$	-91,728	$	5,708
	Pro forma income (loss) per share – basic	$	-3.02	$	0.21
	Pro forma income (loss) per share – diluted	$	-3.02	$	0.21

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
Commitments and Contingencies (Tables)	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	Future minimum lease payments related to the Company’s office lease as of December 31, 2014 are as follows (in thousands):

		Amount
	2015	$	184
	2016		96
	Total	$	280

Equity_Transactions_Tables

Equity Transactions (Tables)	12 Months Ended
Equity Transactions (Tables)	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	The assumptions used in the Black-Scholes Option Pricing Model for the stock options granted were as follows:

			2014		2013
	Risk-free interest rate		0.43% to 0.56%		0.22% to 0.35%
	Expected volatility of common stock		59% to 76%		62% to 84%
	Dividend yield		$0.00		$0.00
	Expected life of options		5 years		5 years

Schedule of Share-based Compensation, Activity [Table Text Block]	A summary of stock option activity for the years ended December 31, 2014 and December 31, 2013 is presented below:
								Weighted
					Weighted			Average
					Average			Remaining
					Exercise			Contract
		Options			Price ($)			Term

	Outstanding at December 31, 2012		1,283,650		$	3.12		3.6 years
	Options granted		648,125			8.48
	Options exercised		-5,000			3.12
	Options expired		-			-
	Options forfeited		-			-

	Outstanding at December 31, 2013		1,926,775		$	4.92		3.4 years
	Options granted		87,500			3.19
	Options exercised		-23,125			2.92
	Options expired		-			-
	Options forfeited		-			-

	Outstanding at December 31, 2014		1,991,150		$	4.81		2.5 years

	Exercisable at December 31, 2014		1,584,588		$	4.18		2.1 years

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	The following is a schedule of outstanding stock options as of December 31, 2014 by exercise price:

		Options		Options			Exercise
	Grant Date	Outstanding		Exercisable			Price
	12-Dec-14		50,000		-		$	0.73
	30-Oct-09		166,652		166,652			0.9
	1-Oct-12		10,000		10,000			2.76
	1-Aug-12		30,000		30,000			2.88
	1-Sep-12		12,500		12,500			2.92
	14-Dec-12		216,875		216,875			2.96
	30-Dec-10		433,248		433,248			2.97
	1-Nov-12		55,000		55,000			3.12
	21-Feb-12		50,000		50,000			3.68
	14-Dec-11		291,250		291,250			4.72
	1-Feb-13		31,250		15,625			5.84
	23-Jun-14		25,000		-			6.18
	1-Oct-13		50,000		25,000			6.72
	15-Jun-13		37,500		18,750			6.84
	5-May-14		12,500		-			7.05
	28-Oct-13		12,500		6,250			8.6
	13-Dec-13		441,875		220,938			8.68
	23-Sep-13		7,500		3,750			9.16
	1-Oct-13		7,500		3,750			9.28
	14-Nov-13		50,000		25,000			9.56
	Totals		1,991,150		1,584,588

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	The Company recognized income tax benefit of approximately $5.3 million and $1.2 million for the years ended December 31, 2014 and 2012, respectively, and income tax expense of approximately $1.8 million for the year ended December 31, 2013. Income tax expense (benefit) for the years ended December 31, 2014, 2013 and 2012 consisted of the following (in thousands):

		2014			2013			2012
	Current income tax expense (benefit):
	Domestic	$	16		$	-17		$	-302
	Foreign		-			-77			-32
	Total current income tax expense (benefit)		16			-94			-334

	Deferred income tax expense (benefit):
	Domestic	$	-40,424		$	1,863		$	349
	Foreign		2,891			-636			-3,421
	Change in valuation allowance		32,237			636			2,166
	Total deferred income tax expense (benefit)		-5,296			1,863			-906

	Total income tax expense (benefit)	$	-5,280		$	1,769		$	-1,240

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	Significant components of the Company’s deferred income tax assets and liabilities at December 31, 2014 and 2013 are as follows (in thousands):

		2014			2013
	Deferred tax assets:
	Foreign tax credits	$	52		$	52
	Unrealized hedging loss		488			301
	Asset retirement obligations		534			308
	Net operating losses – domestic		18,900			5,688
	Net operating losses – foreign		-			864
	Domestic fixed assets		14,848			-
	Foreign fixed assets		-			1,937
	Stock options		1,881			1,214
	Marketable securities		-			48
	Other		17			160
	Total deferred tax assets		36,720			10,572
	Valuation allowance		-35,038			-2,858
	Net deferred income tax assets	$	1,682		$	7,714

		2014			2013
	Deferred tax liabilities:
	Investment in foreign subsidiary	$	-			321
	Domestic fixed assets		-			12,779
	Asset retirement obligations		491			-
	Other		1,191			-
	Deferred tax liabilities	$	1,682		$	13,100

	Net deferred tax liabilities	$	-		$	5,386

Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation [Table Text Block]	A reconciliation between the amount of income tax expense for the years ended December 31, 2014, 2013 and 2012, determined by applying the appropriate applicable statutory income tax rates, is as follows (in thousands):

		2014				2013				2012
	US Statutory tax expense (benefit)	$	-33,149			$	1,144			$	-3,581
	State income taxes, net of federal expense (benefit)		-2,508				96				-242
	Foreign taxes paid		6				12				-
	Permanent differences		8				11				8
	Change in valuation allowance		32,228				641				2,166
	True-up of prior year amounts		657				244				-537
	Foreign operations		-2,437				-236				909
	Rate change		-92				-143				39
	Other		7				-				-2
	Net income tax expense (benefit)	$	-5,280			$	1,769			$	-1,240

	Effective tax rate		5.4	%			52.6	%			11.8	%

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
Earnings Per Share (Tables)	Dec. 31, 2014
Earnings Per Share [Abstract]
Schedule of Earnings Per Share Reconciliation [Table Text Block]	The following is a reconciliation of the number of shares used in the calculation of basic and diluted earnings per share for the years ended December 31, 2014, 2013 and 2012 (in thousands, except per share data):

		2014		2013		2012
	Net income (loss)	$	-92,216	$	1,594	$	-9,292

	Weighted average number of common shares outstanding		27,513		13,962		11,448
	Incremental shares from the assumed exercise of dilutive stock options		-		637		-
	Diluted common shares outstanding		27,513		14,599		11,448

	Earnings (loss) per share – basic	$	-3.35	$	0.11	$	-0.81
	Earnings (loss) per share – diluted	$	-3.35	$	0.11	$	-0.81

Supplemental_Oil_and_Gas_Infor1

Supplemental Oil and Gas Information (Unaudited) (Tables)	12 Months Ended
Supplemental Oil and Gas Information (Unaudited) (Tables)	Dec. 31, 2014
Supplemental Oil And Gas Information [Abstract]
Cost Incurred In Oil And Gas Property Acquisition Exploration And Development Activities Disclosure One [Table Text Block]	During the years ended December 31, 2014, 2013 and 2012, the Company incurred the following costs associated with the acquisition, exploration and development of oil and gas properties (in thousands):

		2014			2013			2012
	Acquisition costs	$	57,946		$	62,860		$	16,671
	Exploration costs		53,651			32,053			-
	Development costs		60,711			28,543			27,914
	Total costs	$	172,308		$	123,456		$	44,585

Schedule of Amortization Expense Per Unit of Production [Table Text Block]	The net capitalized cost of the Company’s oil and gas properties, subject to amortization, as of December 31, 2014 and 2013 is summarized below (in thousands):

		2014			2013
	Acquisition costs	$	147,477		$	88,910
	Exploration costs		-			-
	Development costs		196,774			93,696
	Impairments and sales		-82,001			-14,612
	Gross capitalized costs		262,250			167,994
	Accumulated depletion		-35,332			-12,849
	Net capitalized costs	$	226,918		$	155,145

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]		Oil				Gas				Total
		(Barrels)				(Mcf)				(BOE)
	For the year ended December 31, 2014:
	Proved reserves, beginning of year		12,109				8,652				13,550
	Revisions		(3,726	)			(2,377	)			(4,122	)
	Extensions and discoveries		1,064				640				1,171
	Purchases of reserves in place		1,051				948				1,209
	Sale of reserves in place		(148	)			(1	)			(148	)
	Production		(763	)			(42	)			(770	)
	Proved reserves, end of year		9,587				7,820				10,890

	Proved developed reserves		5,495				4,820				6,298
	Proved undeveloped reserves		4,092				3,000				4,592
	Total proved reserves		9,587				7,820				10,890


		Oil				Gas				Total
		(Barrels)				(Mcf)				(BOE)
	For the year ended December 31, 2013:
	Proved reserves, beginning of year		5,398				2,139				5,754
	Revisions		(1,614	)			308				(1,563	)
	Extensions and discoveries		7,412				5,334				8,301
	Purchases of reserves in place		1,411				899				1,561
	Production		(498	)			(28	)			(503	)
	Proved reserves, end of year		12,109				8,652				13,550

	Proved developed reserves		4,207				3,047				4,714
	Proved undeveloped reserves		7,902				5,605				8,836
	Total proved reserves		12,109				8,652				13,550


		Oil				Gas				Total
		(Barrels)				(Mcf)				(BOE)
	For the year ended December 31, 2012:
	Proved reserves, beginning of year		1,511				417				1,581
	Revisions		(687	)			(191	)			(719	)
	Extensions and discoveries		4,429				1,774				4,725
	Purchases of reserves in place		479				248				520
	Sales of reserves in place		(200	)			(107	)			(218	)
	Production		(134	)			(2	)			(135	)
	Proved reserves, end of year		5,398				2,139				5,754

	Proved developed reserves		2,388				1,074				2,566
	Proved undeveloped reserves		3,010				1,065				3,188
	Total proved reserves		5,398				2,139				5,754

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	Standardized Measure of Discounted Future Net Cash Flows (in thousands):

		2014			2013			2012
	Future cash flows	$	829,316		$	1,141,907		$	448,623
	Future costs:
	Production costs		-273,430			-307,093			-99,411
	Development costs		-109,102			-177,750			-50,693
	Income taxes		-47,464			-184,362			-104,827
	Future net cash flows		399,320			472,702			193,692
	Ten percent discount factor		-195,573			-250,648			-116,784
	Standardized measure of discounted future net cash flows	$	203,747		$	222,054		$	76,908

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	The following table summarizes the changes in the Company’s standardized measure of discounted future net cash flows for the years ended December 31, 2014, 2013 and 2012 (in thousands):

		2014			2013			2012
	Extensions and discoveries	$	35,491		$	167,600		$	84,276
	Net changes in sales prices and production costs		-54,609			1,001			-2,939
	Oil and gas sales, net of production costs		-38,480			-31,530			-7,514
	Change in estimated future development costs		95,259			-5,659			12,376
	Revision of quantity estimates		-136,988			-34,499			-22,267
	Purchases of mineral interests		42,855			35,496			12,777
	Sales of mineral interests		-5,368			-			-
	Previously estimated development costs incurred in the current period		-58,895			14,256			2,897
	Changes in production rates, timing & other		14,366			21,692			1,947
	Changes in income taxes		57,037			-35,914			-33,864
	Accretion of discount		31,025			12,703			3,994
	Net increase		-18,307			145,146			51,683
	Standardized measure of discounted future cash flows – beginning of the year		222,054			76,908			25,225
	Standardized measure of discounted future cash flows – end of the year	$	203,747		$	222,054		$	76,908

Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure [Table Text Block]	Assumed prices used to calculate future cash flows

		2014			2013			2012
	Oil price per barrel	$	82.36		$	90.63		$	81.78
	Gas price per mcf	$	5.08		$	5.15		$	3.38

Quarterly_Financial_Informatio1

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
Quarterly Financial Information (Unaudited) (Tables)	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information [Table Text Block]	The Company’s quarterly financial information for the years ended December 31, 2014, 2013 and 2012 is as follows (in thousands, except for per-share data):

		For the Year Ended December 31, 2014
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Oil and gas revenues	$	12,545	$	16,463	$	17,091	$	14,450
	Operating expenses		9,306		12,570		13,885		100,652
	Other income (expense)		-4,905		-9,896		-14,513		7,682
	Net income (loss)		-1,028		-3,900		-8,738		-78,550
	Basic earnings (loss) per share		-0.06		-0.13		-0.29		-2.58
	Diluted earnings (loss) per share		-0.06		-0.13		-0.29		-2.58
	Cash provided by operating activities		7,384		1,850		11,353		6,027
	Cash used for investing activities		-67,441		-29,731		-36,661		-29,034
	Cash provided by (used for) financing activities		78,299		-		51,909		-47


		For the Year Ended December 31, 2013
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Oil and gas revenues	$	7,629	$	10,370	$	11,639	$	13,501
	Operating expenses		5,756		6,330		7,391		11,298
	Other income (expense)		-425		-210		-5,830		-2,536
	Net income (loss)		355		2,637		-936		-462
	Basic earnings (loss) per share		0.03		0.21		-0.07		-0.03
	Diluted earnings (loss) per share		0.03		0.2		-0.07		-0.03
	Cash provided by operating activities		10,484		3,377		11,390		5,160
	Cash used for investing activities		-16,378		-2,903		-66,123		-55,888
	Cash provided by (used for) financing activities		5,029		-1,640		56,706		63,580

		For the Year Ended December 31, 2012
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Oil and gas revenues	$	1,226	$	1,691	$	2,875	$	4,922
	Operating expenses		1,882		1,832		2,388		15,093
	Other income (expense)		21		12		19		-103
	Net income (loss)		-358		-147		892		-9,679
	Basic earnings (loss) per share		-0.01		0		0.02		-0.21
	Diluted earnings (loss) per share		-0.01		0		0.02		-0.21
	Cash provided by (used for) operating activities		3,443		5,040		5,855		-10,450
	Cash provided by (used for) investing activities		-8,657		-2,038		3,486		-5,318
	Cash provided by financing activities		145		-		-		15,400

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Significant Accounting Policies [Line Items]
Concentration Risk Credit Risk Insurance Limit	$250,000
Share-based Compensation, Total	1,791,000	1,203,000	822,000
Working Capital Deficit	13,600,000
US Cost Center [Member]
Significant Accounting Policies [Line Items]
Results of Operations, Impairment of Oil and Gas Properties	81,900,000
Canadian Cost Center [Member]
Significant Accounting Policies [Line Items]
Results of Operations, Impairment of Oil and Gas Properties		$1,700,000	$10,600,000
Maximum [Member]
Significant Accounting Policies [Line Items]
Asset Retirement Obligations Rate	11.00%
Minimum [Member]
Significant Accounting Policies [Line Items]
Asset Retirement Obligations Rate	4.20%
Furniture And Equipment [Member]
Significant Accounting Policies [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Leasehold Improvements [Member]
Significant Accounting Policies [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	lesser of useful life or lease term

Marketable_Securities_and_Fair2

Marketable Securities and Fair Value Measurements (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Noncurrent assets:
Estimated Fair Value	$756	$1,050
Marketable Securites [Member]
Noncurrent assets:
Estimated Fair Value	756	1,050
Gains in Accumulated Other Comprehensive Income	0	100
Losses in Accumulated Other Comprehensive Income	$0	($75)

Marketable_Securities_and_Fair3

Marketable Securities and Fair Value Measurements (Details 1) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	$756	$1,050
Current derivative asset	0	211
Current derivative liability		-276
Noncurrent derivative liability	0	-750
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	756	1,050
Current derivative asset		0
Current derivative liability		0
Noncurrent derivative liability		0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	0	0
Current derivative asset		211
Current derivative liability		-276
Noncurrent derivative liability		-750
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	0	0
Current derivative asset		0
Current derivative liability		0
Noncurrent derivative liability		$0

Purchases_and_Sales_of_Royalty2

Purchases and Sales of Royalty and Property Interests (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Pro forma revenues	$63,723	$67,360
Pro forma net income (loss)	($91,728)	$5,708
Pro forma income (loss) per share - basic (in dollars per share)	($3.02)	$0.21
Pro forma income (loss) per share - diluted (in dollars per share)	($3.02)	$0.21

Purchases_and_Sales_of_Royalty3

Purchases and Sales of Royalty and Property Interests (Details Textual) (USD $)	1 Months Ended		4 Months Ended	10 Months Ended	1 Months Ended
	Jul. 31, 2014	Jan. 31, 2013	Oct. 02, 2013	Mar. 26, 2014	Mar. 31, 2014	Oct. 31, 2013
Business Acquisition [Line Items]
Debt Instrument, Face Amount	$2,200,000
Hardy Property [Member]
Business Acquisition [Line Items]
Sale of Property Interests Percentage of Ownership Interest Sold	100.00%
Proceeds from Sale of Equity Method Investments	1,800,000
Gain (Loss) on Sale of Equity Investments	12,000
Spyglass Property [Member]
Business Acquisition [Line Items]
Payments to Acquire Additional Interest in Subsidiaries		3,900,000	47,000,000	47,100,000
Business Combination, Consideration Transferred			41,400,000
Debt Instrument, Face Amount						40,000,000
Undeveloped Acreage Property [Member]
Business Acquisition [Line Items]
Payments to Acquire Additional Interest in Subsidiaries					$7,500,000

Carry_Agreements_Details_Textu

Carry Agreements (Details Textual) (USD $)	3 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2014	Apr. 16, 2012	Dec. 31, 2012	Dec. 31, 2013	Jul. 15, 2012	Aug. 31, 2013
Carry Agreement [Line Items]
Percentage of Net Revenue Conveyed to Partner	100.00%
Excess Drilling And Completion Costs		$1
Capitalized Drilling and Completion Costs Percentage Return to Carry Agreement Partner		12.00%
First Carry Agreement [Member]
Carry Agreement [Line Items]
Working Interest Partner, Date Of Agreement				16-Apr-12
Working Interest Partner Funding Percentage On Company Working Interest Share Of Drilling and Completion Costs				100.00%
Number Of Oil And Gas Wells			6			4
Drilling Cost Limit Percentage				120.00%
Working Partner Interest Revenue Description			Carry Agreement with a third-party working interest partner (the Carry Agreement Partner), pursuant to which (i) the Carry Agreement Partner agreed to fund 100% of the Companys working interest share of the drilling and completion costs of up to six new oil and gas wells within our Spyglass Area	Pursuant to the terms of the Carry Agreement, the portion of the Companys net revenue interest in each well to be conveyed to the Carry Agreement Partner followed a graduated scale, whereby 50% of the Companys net revenue and working interests are assigned to the Carry Agreement Partner during the first year of the wells production or until the carried costs, plus the 12% return, have been achieved, whichever occurs first
Working Partner Interest Revenue Description Year One				In the event that the Carry Agreement Partner had not recouped all of the carried costs plus the 12% return by the end of the first year of production, the assignment of the Companys net revenue and working interests in the well would increase from 50% to 75%
Working Partner Interest Revenue Description Year Two				for the second year of production or until the carried costs, plus the 12% return, had been achieved, whichever occurs first. In the event that the Carry Agreement Partner had not recouped all of the carried costs, plus the 12% return, by the end of the second year of production, the assignment of the Company’s net revenue and working interests in the well would increase to 100% until the carried costs, plus the 12% return, had been achieved. Once payout has occurred (112% of the costs on a well-by-well basis)
Increase Percentage Of Working Interest Considered As Revenue To Partner				112.00%
Second Carry Agreement [Member]
Carry Agreement [Line Items]
Working Interest Partner Funding Percentage On Company Working Interest Share Of Drilling and Completion Costs					100.00%
Number Of Oil And Gas Wells							5
Drilling Cost Limit Percentage		120.00%			120.00%
Working Partner Interest Revenue Description					the Company agreed to convey, for a limited duration, 50% of its revenue interest in the pre-payout revenues of each carried well and 50% of its working interest in the pre-payout operating costs of each carried well, to the Carry Agreement Partner
Working Partner Interest Revenue Description Year One					In the event that the gross drilling and completion cost of a carried well exceeds 120% of the AFE amount, the Company and the Carry Agreement Partner will share in the excess costs based on the working interests stipulated in the Carry Agreement
Working Partner Interest Revenue Description Year Two					Pursuant to the terms of the Second Carry Agreement, 50% of the Company’s net revenue interest in each well will be conveyed to the Carry Agreement Partner for a period of two years or until such a time when the working interest partner has recouped 112% of the carried drilling and completion costs of the well, whichever occurs sooner. In the event that the Carry Agreement Partner has not recouped 112% of the carried drilling and completion costs by the end of the second year of production, the Company has agreed to make cash payments to the Carry Agreement Partner in the amount of the shortfall
Increase Percentage Of Working Interest Considered As Revenue To Partner					112.00%
Fund Received Under Carry Agreement		$17.70

FarmOut_Agreement_Details_Text

Farm-Out Agreement (Details Textual) (Farm - Out Agreement [Member])	1 Months Ended	12 Months Ended
	Aug. 31, 2013	Dec. 31, 2013
Farm - Out Agreement [Member]
Farm-Out Agreements Disclosure [Line Items]
Working Interest Partner Funding Percentage On Company Working Interest Share Of Drilling and Completion Costs	100.00%
Increase Percentage Of Working Interest Considered As Revenue To Partner	30.00%
Working Partner Interest Revenue Description		August 2013, the Company entered into a Farm-Out Agreement (the “Farm-Out Agreement”) with the Carry Agreement Partner, pursuant to which (i) that Carry Agreement Partner agreed to fund 100% of the Company’s working interest share of the drilling and completion costs of up to six new oil and gas wells to be located within the original Spyglass and West Spyglass sections of the Spyglass Property
Working Partner Interest Revenue Description One		(ii) the Company agreed to convey, for a period of time, 100% of its net revenue interest in the pre-payout revenues of each farm-out well and 100% of its working interest in the pre-payout operating costs of each farm-out well, to the Carry Agreement Partner, until such a time when the Carry Agreement Partner has recouped 112% of the drilling and completion costs associated with each well.
Working Partner Interest Revenue Description Two		Once the Carry Agreement Partner has recouped 112% of the drilling and completion costs of a well, the Carry Agreement Partner will convey 30% of the Companys original working and net revenue interests in each farm-out well back to the Company.

Swap_Facility_Details_Textual

Swap Facility (Details Textual) (USD $)	1 Months Ended				12 Months Ended
	Aug. 31, 2014	Aug. 19, 2013	Jan. 31, 2013	Dec. 28, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	Aug. 31, 2014	Aug. 19, 2013	Jan. 31, 2013	Dec. 28, 2012	bbl	Dec. 31, 2013	Dec. 31, 2012
Swap Facility Disclosure [Line Items]
Derivative, Cost of Hedge				$18,000,000
Derivative, Cash Received on Hedge			2,000,000	16,000,000
Sale Barrels Of Oil Equivalents Future Sales					212,000
Sale Barrels Of Oil Equivalents Future Sales Description					five-year period from January 2013 to December 2017, with a final balloon payment of $2 million, due in February 2018
Extinguishment of Debt, Amount		18,000,000
Gains (Losses) on Extinguishment of Debt, Total	11,900,000	3,700,000			-11,894,000	-3,714,000	0
Outstanding balance under Swap Facility Percentage of outstanding principal balance repaid		100.00%
Debt Instrument, Interest Rate, Stated Percentage					7.40%
Interest Expense, Debt, Total						903,000	183,000
Deferred Finance Costs, Gross					780,000
Amortization of Financing Costs						$151,000	$0

Credit_Facility_Details_Textua

Credit Facility (Details Textual) (USD $)	1 Months Ended		12 Months Ended			1 Months Ended
Credit Facility (Details Textual) (USD $)	Aug. 31, 2014	Aug. 19, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2013	Jul. 31, 2014
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount							$2,200,000
Debt Instrument, Term			5 years
Interest Expense, Debt, Total				903,000	183,000
Investment Banking, Advisory, Brokerage, and Underwriting Fees and Commissions, Total			7,800,000
Amortization of Financing Costs				151,000	0
Debt Instrument, Fee Amount	2,200,000
Gains (Losses) on Extinguishment of Debt	11,900,000	3,700,000	-11,894,000	-3,714,000	0
Prepayment Fees on Advances, Net	3,300,000
Write off of Deferred Debt Issuance Cost	6,400,000
Debt Instrument, Covenant Description			The MSCG Credit Agreement also contained a number of financial covenants, including the maintaining of an adjusted minimum working capital ratio of 1.0
Minimum [Member]
Line of Credit Facility [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate			5.50%
Maximum [Member]
Line of Credit Facility [Line Items]
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate			10.50%
MSCG Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount						200,000,000
Amortization of Financing Costs			1,000,000	451,000
Proceeds from Loan Originations						67,300,000
Initial Term Loan [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount						68,000,000
Interest Expense, Debt, Total			7,600,000
Spyglass Tranche A Loan [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount						40,000,000
Interest Expense, Debt, Total				3,800,000
Tranche B Loan [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount						$92,000,000

Bonds_Payable_Details_Textual

Bonds Payable (Details Textual) (USD $)	12 Months Ended			1 Months Ended
Bonds Payable (Details Textual) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2014	Jul. 31, 2014
Debt Instrument, Interest Rate, Stated Percentage	7.40%
Amortization of Debt Discount (Premium)	$113,000	$0
Amortization of Financing Costs		151,000	0
Interest Expense, Total	15,900,000	5,356,000	1,000
Debt Instrument, Face Amount					2,200,000
Bonds [Member]
Debt Instrument, Interest Rate, Stated Percentage	11.00%			11.00%
Debt Instrument, Maturity Date				1-Sep-19
Long-term Debt, Gross				175,000,000
Debt Instrument Discount Percentage				99.06%
Debt Instrument, Unamortized Discount (Premium), Net				1,600,000
Proceeds from Issuance of Debt				167,300,000
Amortization of Debt Discount (Premium)	114,000
Debt Issuance Cost	7,200,000
Amortization of Financing Costs	500,000
Interest Expense, Total	6,600,000
Public Utility, Bonds [Member]
Debt Instrument, Face Amount	1,000,000
Public Trade Bonds Discounted Price	0.4325
Bonds Fair Value Disclosure	$75,700,000

Senior_Secured_Revolving_Credi1

Senior Secured Revolving Credit Facility (Details Textual) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2014
Line of Credit Facility [Line Items]
Amortization of Financing Costs		$151,000	$0
Debt Instrument, Covenant Description	The MSCG Credit Agreement also contained a number of financial covenants, including the maintaining of an adjusted minimum working capital ratio of 1.0
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity				35,000,000
Line of Credit Facility, Increase (Decrease), Net				60,000,000
Line of Credit Facility, Commitment Fee Amount	46,000
Debt Issuance Cost	779,000
Amortization of Financing Costs	52,000
Debt Instrument, Covenant Description	The Senior Credit Facility also contains a number of financial covenants, including the maintaining of a current ratio of no less than 1.0 and a ratio of total debt to EBITDAX of no more than 4.0. The Company was not in compliance with these covenants for the period ended December 31, 2014, but has obtained a waiver from SunTrust for the period in question.
Revolving Credit Facility [Member] \| Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.75%
Revolving Credit Facility [Member] \| Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%

Price_Swap_Derivatives_Details

Price Swap Derivatives (Details Textual) (USD $)	12 Months Ended
Price Swap Derivatives (Details Textual) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative [Line Items]
Marketable Securities, Unrealized Gain (Loss), Total	($491,000)	$0	$0
Revolving Credit Facility [Member]
Derivative [Line Items]
Gain (Loss) on Sale of Derivatives	7,500,000	815,000	0
Percentage of future production covered under commodity price swap agreement	85.00%
Swap [Member]
Derivative [Line Items]
Gain (Loss) on Sale of Derivatives		116,000
Marketable Securities, Unrealized Gain (Loss), Total	$14,100,000

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details Textual) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Assets Retirement Obligation [Line Items]
Asset retirement obligation	$1,428	$1,060
Asset Retirement Obligations, Description	The projected plugging dates for wells in which the Company owns a working interest ranges from December 31, 2015 to December 31, 2032.
Asset Retirement Obligation, Liabilities Incurred	516	516	407
Spyglass And Hardy Properties [Member]
Assets Retirement Obligation [Line Items]
Asset Retirement Obligation, Liabilities Incurred	$516	$569

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified	Dec. 31, 2014
2015	$184
2016	96
Total	$280

Commitments_and_Contingencies_2

Commitments and Contingencies (Details Textual) (USD $)	12 Months Ended			1 Months Ended
Commitments and Contingencies (Details Textual) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 31, 2015
Severance Costs	$2,200,000
Operating Leases, Rent Expense	259,000	146,000	110,000
Drilling And Completion Costs	3,800,000
Drilling obligation	2,000,000
Drilling obligation incurred	1,100,000
Subsequent Event [Member]
Increase Decrease in drilling obligation				$1,800,000
Maximum [Member]
Percentage Of Productive Assets Spyglass Property Interest Range	23.00%
Minimum [Member]
Percentage Of Productive Assets Spyglass Property Interest Range	0.20%

Equity_Transactions_Details

Equity Transactions (Details) (USD $)	12 Months Ended
Equity Transactions (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend yield	$0	$0
Expected life of options	5 years	5 years
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate	0.43%	0.22%
Expected volatility of common stock	59.00%	62.00%
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate	0.56%	0.35%
Expected volatility of common stock	76.00%	84.00%

Equity_Transactions_Details_1

Equity Transactions (Details 1) (USD $)	12 Months Ended
Equity Transactions (Details 1) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding - Options	1,926,775	1,283,650
Options granted	87,500	648,125
Options exercised	-23,125	-5,000
Options expired	0	0
Options forfeited	0	0
Outstanding - Options	1,991,150	1,926,775	1,283,650
Exercisable - Options	1,584,588
Outstanding - Weighted Average Exercise Price	$4.92	$3.12
Options granted - Weighted Average Exercise Price	$3.19	$8.48
Options exercised - Weighted Average Exercise Price	$2.92	$3.12
Options expired - Weighted Average Exercise Price	$0	$0
Options forfeited - Weighted Average Exercise Price	$0	$0
Outstanding - Weighted Average Exercise Price	$4.81	$4.92	$3.12
Exercisable - Weighted Average Exercise Price	$4.18
Outstanding - Weighted Average Remaining Contractual Term	2 years 6 months	3 years 4 months 24 days	3 years 7 months 6 days
Exercisable - Weighted Average Remaining Contractual Term	2 years 1 month 6 days

Equity_Transactions_Details_2

Equity Transactions (Details 2) (USD $)	12 Months Ended
Equity Transactions (Details 2) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding	1,991,150	1,926,775	1,283,650
Options Exercisable	1,584,588
Exercise Price	$4.81	$4.92	$3.12
0.73 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	12-Dec-14
Options Outstanding	50,000
Options Exercisable	0
Exercise Price	$0.73
0.90 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	30-Oct-09
Options Outstanding	166,652
Options Exercisable	166,652
Exercise Price	$0.90
2.76 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Oct-12
Options Outstanding	10,000
Options Exercisable	10,000
Exercise Price	$2.76
2.88 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Aug-12
Options Outstanding	30,000
Options Exercisable	30,000
Exercise Price	$2.88
2.92 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Sep-12
Options Outstanding	12,500
Options Exercisable	12,500
Exercise Price	$2.92
2.96 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	14-Dec-12
Options Outstanding	216,875
Options Exercisable	216,875
Exercise Price	$2.96
2.97 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	30-Dec-10
Options Outstanding	433,248
Options Exercisable	433,248
Exercise Price	$2.97
3.12 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Nov-12
Options Outstanding	55,000
Options Exercisable	55,000
Exercise Price	$3.12
3.68 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	21-Feb-12
Options Outstanding	50,000
Options Exercisable	50,000
Exercise Price	$3.68
4.72 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	14-Dec-11
Options Outstanding	291,250
Options Exercisable	291,250
Exercise Price	$4.72
5.84 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Feb-13
Options Outstanding	31,250
Options Exercisable	15,625
Exercise Price	$5.84
6.18 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	23-Jun-14
Options Outstanding	25,000
Options Exercisable	0
Exercise Price	$6.18
6.72 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Oct-13
Options Outstanding	50,000
Options Exercisable	25,000
Exercise Price	$6.72
6.84 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	15-Jun-13
Options Outstanding	37,500
Options Exercisable	18,750
Exercise Price	$6.84
7.05 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	5-May-14
Options Outstanding	12,500
Options Exercisable	0
Exercise Price	$7.05
8.60 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	28-Oct-13
Options Outstanding	12,500
Options Exercisable	6,250
Exercise Price	$8.60
8.68 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	13-Dec-13
Options Outstanding	441,875
Options Exercisable	220,938
Exercise Price	$8.68
9.16 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	23-Sep-13
Options Outstanding	7,500
Options Exercisable	3,750
Exercise Price	$9.16
9.28 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	1-Oct-13
Options Outstanding	7,500
Options Exercisable	3,750
Exercise Price	$9.28
9.56 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant Date	14-Nov-13
Options Outstanding	50,000
Options Exercisable	25,000
Exercise Price	$9.56

Equity_Transactions_Details_Te

Equity Transactions (Details Textual) (USD $)	1 Months Ended	12 Months Ended			1 Months Ended
Equity Transactions (Details Textual) (USD $)	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Aug. 31, 2013	Jan. 31, 2013	Oct. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stockholders Equity, Reverse Stock Split	1-for-4 reverse split
Proceeds from issuance of stock		$78,298,000	$38,871,000	$110,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value		0	7,900,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Grant Date Intrinsic Value		$0	$4.12
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number		1,991,150	1,926,775	1,283,650
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		5 years
Share-based Compensation, Total		1,791,000	1,203,000	822,000
Fair value of options granted		142,000	2,900,000
Employee Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross		87,500	648,125
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value		$1.63	$4.41
Private Placement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Proceeds from issuance of stock					9,900,000	4,000,000
Public Offering [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Proceeds from issuance of stock	78,300,000						$25,000,000
Common Stock [Member] \| Private Placement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, New Issues					1,250,000	1,000,000
Sale of Stock, Price Per Share (in dollars per share)					$8	$4
Common Stock [Member] \| Public Offering [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, New Issues	12,650,000						3,941,449
Sale of Stock, Price Per Share (in dollars per share)	6.6						$6.80
One Year Anniversary [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		50.00%	50.00%
Two Year Anniversary [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		50.00%	50.00%

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current income tax expense (benefit):
Domestic	$16	($17)	($302)
Foreign	0	-77	-32
Total current income tax expense (benefit)	16	-94	-334
Deferred income tax expense (benefit):
Domestic	-40,424	1,863	349
Foreign	2,891	-636	-3,421
Change in valuation allowance	32,237	636	2,166
Total deferred income tax expense (benefit)	-5,296	1,863	-906
Total income tax expense (benefit)	($5,280)	$1,769	($1,240)

Income_Taxes_Details_1

Income Taxes (Details 1) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Deferred tax assets:
Foreign tax credits	$52	$52
Unrealized hedging loss	488	301
Asset retirement obligations	534	308
Net operating losses - domestic	18,900	5,688
Net operating losses - foreign	0	864
Domestic fixed assets	14,848	0
Foreign fixed assets	0	1,937
Stock options	1,881	1,214
Marketable securities	0	48
Other	17	160
Total deferred tax assets	36,720	10,572
Valuation allowance	-35,038	-2,858
Net deferred income tax assets	1,682	7,714
Deferred tax liabilities:
Investment in foreign subsidiary	0	321
Domestic fixed assets	0	12,779
Asset retirement obligations	491	0
Other	1,191	0
Deferred tax liabilities	1,682	13,100
Net deferred tax liabilities	$0	$5,386

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
US Statutory tax expense (benefit)	($33,149)	$1,144	($3,581)
State income taxes, net of federal expense (benefit)	-2,508	96	-242
Foreign taxes paid	6	12	0
Permanent differences	8	11	8
Change in valuation allowance	32,228	641	2,166
True-up of prior year amounts	657	244	-537
Foreign operations	-2,437	-236	909
Rate change	-92	-143	39
Other	7	0	-2
Net income tax expense (benefit)	($5,280)	$1,769	($1,240)
Effective tax rate	5.40%	52.60%	11.80%

Income_Taxes_Details_Textual

Income Taxes (Details Textual) (USD $)	12 Months Ended
Income Taxes (Details Textual) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Expense (Benefit)	($5,280,000)	$1,769,000	($1,240,000)
Domestic Tax Authority [Member]
Operating Loss Carryforwards	49,900,000
State and Local Jurisdiction [Member]
Operating Loss Carryforwards	$36,000,000

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended												12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	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, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Line Items]
Net income (loss)	($78,550)	($8,738)	($3,900)	($1,028)	($462)	($936)	$2,637	$355	($9,679)	$892	($147)	($358)	($92,216)	$1,594	($9,292)
Weighted average number of common shares outstanding (in shares)													27,513	13,962	11,448
Incremental shares from the assumed exercise of dilutive stock options (in shares)													0	637	0
Diluted common shares outstanding (in shares)													27,513	14,599	11,448
Earnings (loss) per share - basic (in dollars per share)	($2.58)	($0.29)	($0.13)	($0.06)	($0.03)	($0.07)	$0.21	$0.03	($0.21)	$0.02	$0	($0.01)	($3.35)	$0.11	($0.81)
Earnings (loss) per share - diluted (in dollars per share)	($2.58)	($0.29)	($0.13)	($0.06)	($0.03)	($0.07)	$0.20	$0.03	($0.21)	$0.02	$0	($0.01)	($3.35)	$0.11	($0.81)

Earnings_Per_Share_Details_Tex

Earnings Per Share (Details Textual)	12 Months Ended
Earnings Per Share (Details Textual)	Dec. 31, 2014	Dec. 31, 2012
Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	322,000	469,000

Related_Party_Transactions_Det

Related Party Transactions (Details Textual) (USD $)	12 Months Ended
Related Party Transactions (Details Textual) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	$56,000	$37,000	$24,000
Synergy [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	84,000	168,000	168,000
Board of Directors Chairman [Member]
Related Party Transaction [Line Items]
Payments for Royalties	472,000	608,000	67,000
Chief Operating Officer [Member]
Related Party Transaction [Line Items]
Payments for Royalties	$382,000	$540,000	$52,000

Subsequent_Events_Details_Text

Subsequent Events (Details Textual) (Subsequent Event [Member], USD $)	1 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Jan. 31, 2015	Mar. 02, 2015
Subsequent Event [Line Items]
Proceeds from Sale of Equity Method Investments	$9.50
Bonds [Member]
Subsequent Event [Line Items]
Debt Instrument, Periodic Payment, Interest		$9.80

Going_Concern_Details_Textual

Going Concern (Details Textual) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified	Dec. 31, 2014
Going Concern [Line Items]
Working Capital Deficit	$13.60

Supplemental_Oil_and_Gas_Infor2

Supplemental Oil and Gas Information (Unaudited) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Oil and Gas Information [Line Items]
Acquisition costs	$57,946	$62,860	$16,671
Exploration costs	53,651	32,053	0
Development costs	60,711	28,543	27,914
Total costs	$172,308	$123,456	$44,585

Supplemental_Oil_and_Gas_Infor3

Supplemental Oil and Gas Information (Unaudited) (Details 1) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Supplemental Oil and Gas Information [Line Items]
Acquisition costs	$147,477	$88,910
Exploration costs	0	0
Development costs	196,774	93,696
Impairments and sales	-82,001	-14,612
Gross capitalized costs	262,250	167,994
Accumulated depletion	-35,332	-12,849
Net capitalized costs	$226,918	$155,145

Supplemental_Oil_and_Gas_Infor4

Supplemental Oil and Gas Information (Unaudited) (Details 2)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	MBbls	MBbls	MMcf
	MMcf	MMcf	MBoe
	MBoe	MBoe	MBbls
Oil Reserves
Proved reserves, beginning of year	12,109	5,398	1,511
Revisions	-3,726	-1,614	-687
Extensions and discoveries	1,064	7,412	4,429
Purchases of reserves in place	1,051	1,411	479
Sale of reserves in place	-148		-200
Production	-763	-498	-134
Proved reserves, end of year	9,587	12,109	5,398
Proved developed reserves	5,495	4,207	2,388
Proved undeveloped reserves	4,092	7,902	3,010
Total proved reserves	9,587	12,109	5,398
Natural Gas Reserves
Proved reserves, beginning of year	8,652	2,139	417
Revisions	-2,377	308	-191
Extensions and discoveries	640	5,334	1,774
Purchases of reserves in place	948	899	248
Sale of reserves in place	-1		-107
Production	-42	-28	-2
Proved reserves, end of year	7,820	8,652	2,139
Proved developed reserves	4,820	3,047	1,074
Proved undeveloped reserves	3,000	5,605	1,065
Total proved reserves	7,820	8,652	2,139
Total Proved Oil And Gas Reserves
Proved reserves, beginning of year	13,550	5,754	1,581
Revisions	-4,122	-1,563	-719
Extensions and discoveries	1,171	8,301	4,725
Purchases of reserves in place	1,209	1,561	520
Sale of reserves in place	-148		-218
Production	-770	-503	-135
Proved reserves, end of year	10,890	13,550	5,754
Proved developed reserves	6,298	4,714	2,566
Proved undeveloped reserves	4,592	8,836	3,188
Total proved reserves	10,890	13,550	5,754

Supplemental_Oil_and_Gas_Infor5

Supplemental Oil and Gas Information (Unaudited) (Details 3) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Oil and Gas Information [Line Items]
Future cash flows	$829,316	$1,141,907	$448,623
Future costs:
Production costs	-273,430	-307,093	-99,411
Development costs	-109,102	-177,750	-50,693
Income taxes	-47,464	-184,362	-104,827
Future net cash flows	399,320	472,702	193,692
Ten percent discount factor	-195,573	-250,648	-116,784
Standardized measure of discounted future net cash flows	$203,747	$222,054	$76,908	$25,225

Supplemental_Oil_and_Gas_Infor6

Supplemental Oil and Gas Information (Unaudited) (Details 4) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Oil and Gas Information [Line Items]
Extensions and discoveries	$35,491	$167,600	$84,276
Net changes in sales prices and production costs	-54,609	1,001	-2,939
Oil and gas sales, net of production costs	-38,480	-31,530	-7,514
Change in estimated future development costs	95,259	-5,659	12,376
Revision of quantity estimates	-136,988	-34,499	-22,267
Purchases of mineral interests	42,855	35,496	12,777
Sales of mineral interests	-5,368	0	0
Previously estimated development costs incurred in the current period	-58,895	14,256	2,897
Changes in production rates, timing & other	14,366	21,692	1,947
Changes in income taxes	57,037	-35,914	-33,864
Accretion of Discount	31,025	12,703	3,994
Net increase	-18,307	145,146	51,683
Standardized measure of discounted future cash flows - beginning of the year	222,054	76,908	25,225
Standardized measure of discounted future cash flows - end of the year	$203,747	$222,054	$76,908

Supplemental_Oil_and_Gas_Infor7

Supplemental Oil and Gas Information (Unaudited) (Details 5)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Oil [Member]
Supplemental Oil and Gas Information [Line Items]
Consolidated Oil and Gas Production Costs Per Unit of Production	82.36	90.63	81.78
Natural Gas [Member]
Supplemental Oil and Gas Information [Line Items]
Consolidated Oil and Gas Production Costs Per Unit of Production	5.08	5.15	3.38

Supplemental_Oil_and_Gas_Infor8

Supplemental Oil and Gas Information (Unaudited) (Details Textual) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Standardized Measure Of Discounted Future Net Cash Flows Percentage	10.00%
New Wells In Process Of Drilling	32	19	15
Capitalized Expenditure Oil And Gas Drill	$56.50	$19.80	$2.90
Percentage Cost Of Total Proved Reserves	100.00%	99.50%
Percentage Of Oil And Gas Properties Of Total Revenue	99.40%	97.10%	82.00%
Oil [Member]
Conversion Of Proved Undeveloped Reserves Gas	1,713,000	956,515	351,883
Natural Gas [Member]
Conversion Of Proved Undeveloped Reserves Gas	1,187,000	340,926	195,092

Quarterly_Financial_Informatio2

Quarterly Financial Information (Unaudited) (Details) (USD $)	3 Months Ended												12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	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, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Oil and gas revenues	$14,450	$17,091	$16,463	$12,545	$13,501	$11,639	$10,370	$7,629	$4,922	$2,875	$1,691	$1,226	$60,549	$43,139	$10,714
Operating expenses	100,652	13,885	12,570	9,306	11,298	7,391	6,330	5,756	15,093	2,388	1,832	1,882	136,413	30,775	21,195
Other income (expense)	7,682	-14,513	-9,896	-4,905	-2,536	-5,830	-210	-425	-103	19	12	21	-21,632	-9,001	-51
Net income (loss)	-78,550	-8,738	-3,900	-1,028	-462	-936	2,637	355	-9,679	892	-147	-358	-92,216	1,594	-9,292
Basic earnings (loss) per share	($2.58)	($0.29)	($0.13)	($0.06)	($0.03)	($0.07)	$0.21	$0.03	($0.21)	$0.02	$0	($0.01)	($3.35)	$0.11	($0.81)
Diluted earnings (loss) per share	($2.58)	($0.29)	($0.13)	($0.06)	($0.03)	($0.07)	$0.20	$0.03	($0.21)	$0.02	$0	($0.01)	($3.35)	$0.11	($0.81)
Cash provided by operating activities	6,027	11,353	1,850	7,384	5,160	11,390	3,377	10,484	-10,450	5,855	5,040	3,443	26,614	30,411	3,888
Cash used for investing activities	-29,034	-36,661	-29,731	-67,441	-55,888	-66,123	-2,903	-16,378	-5,318	3,486	-2,038	-8,657	-162,867	-141,292	-12,527
Cash provided by (used for) financing activities	($47)	$51,909	$0	$78,299	$63,580	$56,706	($1,640)	$5,029	$15,400	$0	$0	$145	$130,161	$123,675	$15,545