FX Energy (FXEN) 10-K 13 Mar 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Mar. 12, 2014	Jun. 30, 2013
Document Information [Line Items]	'	'	'
Entity Registrant Name	'FX ENERGY INC	'	'
Entity Central Index Key	'0000907649	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Accelerated Filer	'	'
Trading Symbol	'FXEN	'	'
Entity Common Stock, Shares Outstanding	'	53,912,277	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Period Focus	'FY	'	'
Document Fiscal Year Focus	'2013	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$162,334,000

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$11,153	$33,990
Receivables:	'	'
Accrued oil and gas sales	3,464	3,447
Joint interest and other receivables	5,029	7,733
Value-added tax receivable	1,847	1,136
Inventory	100	199
Other current assets	234	614
Total current assets	21,827	47,119
Property and equipment, at cost:	'	'
Proved	85,244	63,821
Unproved	2,404	2,337
Other property and equipment	11,857	10,717
Gross property and equipment	99,505	76,875
Less accumulated depreciation, depletion and amortization	-23,369	-19,786
Net property and equipment	76,136	57,089
Other assets:	'	'
Certificates of deposit	406	382
Loan fees	2,323	1,364
Total other assets	2,729	1,746
Total assets	100,692	105,954
Current liabilities:	'	'
Accounts payable	9,694	8,532
Accrued liabilities	833	1,192
Current portion of long-term debt	0	7,000
Total current liabilities	10,527	16,724
Long-term liabilities:	'	'
Notes payable	45,000	33,000
Asset retirement obligation	1,620	1,431
Total long-term liabilities	46,620	34,431
Total liabilities	57,147	51,155
Commitments and Contingencies (Note 6)	'	'
Stockholders' equity:	'	'
Preferred stock, $0.001 par value, 5,000,000 shares authorized as of December 31, 2013 and 2012; no shares outstanding	0	0
Common stock, $0.001 par value, 100,000,000 shares authorized as of December 31, 2013 and 2012; 53,733,398 and 53,246,620 shares issued and outstanding as of December 31, 2013 and 2012, respectively	54	53
Additional paid-in capital	226,060	222,513
Cumulative translation adjustment	15,025	18,027
Accumulated deficit	-197,594	-185,794
Total stockholders' equity	43,545	54,799
Total liabilities and stockholders' equity	$100,692	$105,954

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets [Parenthetical] (USD $)	Dec. 31, 2013	Dec. 31, 2012
Preferred stock, par value (in dollars per share)	$0.00	$0.00
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares outstanding	0	0
Common stock, par value (in dollars per share)	$0.00	$0.00
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	53,733,398	53,246,620
Common stock, shares outstanding	53,733,398	53,246,620

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues:	'	'	'
Oil and gas sales	$33,311	$34,461	$29,807
Oilfield services	1,218	2,137	5,631
Total revenues	34,529	36,598	35,438
Operating costs and expenses:	'	'	'
Lease operating expenses	3,680	3,631	3,834
Exploration costs	20,792	23,795	16,618
Impairment of oil and gas properties	6,129	2,562	72
Loss on sale of assets	0	49	0
Asset retirement obligation gain	0	0	-52
Oilfield services costs	1,179	1,610	4,458
Depreciation, depletion and amortization (DD&A)	4,573	4,239	3,397
Accretion expense	90	63	68
Stock compensation	2,853	2,325	1,744
General and administrative costs (G&A)	8,836	8,369	8,396
Total operating costs and expenses	48,132	46,643	38,535
Operating loss	-13,603	-10,045	-3,097
Other income (expense):	'	'	'
Interest expense	-3,269	-2,485	-2,167
Interest and other income	105	356	188
Foreign exchange gain (loss)	4,967	16,292	-23,448
Total other income (expense)	1,803	14,163	-25,427
Net income (loss)	($11,800)	$4,118	($28,524)
Basic and diluted net income (loss) per common share (in dollars per share)	($0.22)	$0.08	($0.57)
Basic and diluted weighted average number of shares outstanding (in shares)	52,752	52,274	50,262

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Loss) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income (loss)	($11,800)	$4,118	($28,524)
Other comprehensive income (loss)	'	'	'
Foreign currency translation adjustment	-3,002	-10,937	14,951
Comprehensive loss	($14,802)	($6,819)	($13,573)

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Net income (loss)	($11,800)	$4,118	($28,524)
Adjustments to reconcile net loss to net cash used in operating activities:	'	'	'
Depreciation, depletion, and amortization	4,573	4,239	3,397
Impairment of oil and gas properties	6,129	6,979	72
Accretion expense	90	63	68
Loss on property dispositions	0	49	44
Stock compensation	2,853	2,325	1,744
Foreign exchange (gains) losses	-4,986	-16,289	23,397
Common stock issued for services (G&A)	694	666	777
Asset retirement obligation revisions	-6	408	-52
Loan fee amortization	1,182	504	554
Increase (decrease) from changes in working capital items:	'	'	'
Receivables	2,097	-2,905	-5,241
Inventory	98	-2	-3
Other current assets	370	-50	-253
Other assets	-25	25	0
Accounts payable and accrued liabilities	1,089	-1,320	3,950
Asset retirement obligations settled	-50	-43	-50
Net cash provided by (used in) operating activities	2,308	-1,233	-120
Cash flows from investing activities:	'	'	'
Additions to oil and gas properties	-26,792	-15,836	-17,300
Additions to other property and equipment	-1,153	-735	-1,221
Proceeds from sale of assets	0	221	35
Net cash used in investing activities	-27,945	-16,350	-18,486
Cash flows from financing activities:	'	'	'
Proceeds from issuance of common stock, net of offering costs	0	0	45,041
Proceeds from notes payable, net of deferred loan fees	42,964	0	40,000
Payments of notes payable	-40,000	0	-35,000
Proceeds from exercise of stock options and warrants	0	0	801
Net cash provided by (used in) financing activities	2,964	0	50,842
Effect of exchange rate changes on cash	-164	714	-1,117
Net increase (decrease) in cash	-22,837	-16,869	31,119
Cash and cash equivalents at beginning of year	33,990	50,859	19,740
Cash and cash equivalents at end of year	$11,153	$33,990	$50,859

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (USD $)	Total	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Accumulated Deficit [Member]
In Thousands
Balance at Dec. 31, 2010	$23,837	$0	$45	$171,167	$14,013	($161,388)
Balance (in shares) at Dec. 31, 2010	'	'	45,285	'	'	'
Issuance of common stock	45,041	0	7	45,034	0	0
Issuance of common stock (in shares)	'	'	6,900	'	'	'
Common stock issued for services and other	777	0	1	776	0	0
Common stock issued for services and other (in shares)	'	'	440	'	'	'
Exercise of stock options and warrants	801	0	0	801	0	0
Exercise of stock options and warrants (in shares)	'	'	162	'	'	'
Stock compensation	1,744	0	0	1,744	0	0
Other comprehensive income (loss)	14,951	0	0	0	14,951	0
Net income (loss) for year	-28,524	0	0	0	0	-28,524
Balance at Dec. 31, 2011	58,627	0	53	219,522	28,964	-189,912
Balance (in shares) at Dec. 31, 2011	'	'	52,787	'	'	'
Common stock issued for services and other	666	0	0	666	0	0
Common stock issued for services and other (in shares)	'	'	460	'	'	'
Stock compensation	2,325	0	0	2,325	0	0
Other comprehensive income (loss)	-10,937	0	0	0	-10,937	0
Net income (loss) for year	4,118	0	0	0	0	4,118
Balance at Dec. 31, 2012	54,799	0	53	222,513	18,027	-185,794
Balance (in shares) at Dec. 31, 2012	'	'	53,247	'	'	'
Common stock issued for services and other	695	0	1	694	0	0
Common stock issued for services and other (in shares)	'	'	486	'	'	'
Stock compensation	2,853	0	0	2,853	0	0
Other comprehensive income (loss)	-3,002	0	0	0	-3,002	0
Net income (loss) for year	-11,800	0	0	0	0	-11,800
Balance at Dec. 31, 2013	$43,545	$0	$54	$226,060	$15,025	($197,594)
Balance (in shares) at Dec. 31, 2013	'	'	53,733	'	'	'

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Basis Of Presentation [Abstract]	'
Significant Accounting Policies [Text Block]	'
	Note 1: Summary of Significant Accounting Policies
	Organization
	FX Energy, Inc., a Nevada corporation, together with its subsidiaries (collectively referred to hereinafter as “us,” “we,” “our,” or “the Company”), is an independent oil and gas exploration and production company with principal production, reserves, and exploration in Poland and oil production, oilfield service, and exploration activities in the United States. In Poland, we have projects involving the exploration and exploitation of oil and gas prospects in partnership with Polskie Górnictwo Naftowe i Gazownictwo (“PGNiG”), the Polish national oil and gas company, other industry partners, and for our own account. In the United States, we explore for and produce oil from fields in Montana and Nevada, and we have an oilfield services company in northern Montana that performs contract drilling and well-servicing operations.
	Principles of Consolidation
	The consolidated financial statements include the accounts of FX Energy, Inc., and its wholly owned subsidiaries and its undivided interests in Poland. All significant intercompany accounts and transactions have been eliminated in consolidation. At December 31, 2013, we owned 100% of the voting common stock or other equity securities of our subsidiaries.
	Cash and Cash Equivalents
	We consider all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. We determine the appropriate classification of our investments in cash and cash equivalents at the time of purchase and reevaluate such designation at each balance sheet date.
	Fair Value of Financial Instruments and Nonfinancial Assets and Liabilities
	The carrying amounts of our financial instruments, including cash and cash equivalents, accounts receivable, accounts payable, and accrued liabilities, approximate fair value because of their generally short maturities. The accounting standards for fair value measurements provide for fair value measurements of all nonfinancial assets and nonfinancial liabilities not recognized or disclosed at fair value in the financial statements on a recurring basis.
	Concentration of Credit Risk
	The majority of our receivables are within the oil and gas industry, primarily from the purchasers of our oil and gas and fees generated from oilfield services and our industry partners. Substantially all of our Polish receivables are with PGNiG or one of its affiliates, and substantially all of our domestic receivables are with Cenex, a regional refiner and marketer. The receivables are not collateralized. To date, we have experienced minimal bad debts and have no allowance for doubtful accounts at December 31, 2013 and 2012. The majority of our cash and cash equivalents are held by four financial institutions in Utah, Montana, and Poland.
	Inventory
	Inventory consists primarily of tubular goods and production-related equipment and is valued at the lower of average cost or market.
	Oil and Gas Properties
	We follow the successful-efforts method of accounting for our oil and gas operations. Under this method of accounting, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether an individual well has found proved reserves. If it is determined that an exploratory well has not found proved reserves, if the determination that proved reserves have been found cannot be made within one year, or if we are not making sufficient progress assessing the reserves and the economic and operating viability of the project, the costs of the well are expensed. The costs of development wells are capitalized whether productive or nonproductive. Geological and geophysical costs on exploratory prospects and the costs of carrying and retaining unproved properties are expensed as incurred. An impairment charge is provided to the extent that capitalized costs of unproved properties, on a field-by-field basis, are not considered to be realizable. Depreciation, depletion, and amortization (“DD&A”) of capitalized costs of proved oil and gas properties is provided on a field-by-field basis using the units-of-production method. The computation of DD&A takes into consideration the anticipated proceeds from equipment salvage. An impairment loss is recorded if the net capitalized costs of proved oil and gas properties exceed the aggregate undiscounted future net revenues determined on a field-by-field basis. The impairment loss recognized equals the excess of net capitalized costs over the related discounted future net cash flows determined on field-by-field basis. Gains and losses are recognized on sales of entire interests in proved and unproved properties. Sales of partial interests are generally treated as a recovery of costs and any resulting gain or loss is recorded as other income.
	Total dry hole costs (in thousands) of $6,678 in 2013 were principally related to the Mieczewo-1K and Plawce-2 wells in Poland.  Dry hole costs of $12,711 in 2012 were principally related to the Kutno-2 well drilled in Poland and one Alberta Bakken well drilled in Montana.  Dry hole costs of $1,328 in 2011 were principally related to the Machnatka-1 well drilled in Poland.
	During 2013, we recorded impairments of oil and gas properties of $6.1 million. We relinquished certain concessions in Poland, impairing the remaining capitalized costs of $1.0 million. In addition, we impaired approximately $4.5 million of prior-year costs associated with our Plawce-2 well following its unsuccessful fracture stimulation, along with approximately $200,000 of prior-year costs associated with our Mieczewo-1K well. Finally, our Zaniemysl-3 well ceased production during 2013, causing us to charge its remaining net book value of $367,000 to impairment expense.
	During 2012, we recorded impairments of oil and gas properties of $2.6 million. We relinquished certain concessions in Poland, impairing the remaining capitalized costs of $787,000. In Montana, we determined that our Alberta Bakken-related wells and leases were not prospective for hydrocarbon potential. We impaired the remaining capitalized costs of $1.8 million. The $7.0 million of impairment of oil and gas properties on the statements of cash flows includes both the $2.6 million of impairment recognized, as well as $4.4 million of exploration costs capitalized in 2011 related to the Kutno-1 dry hole, which were recognized in the third quarter of 2012. During 2011, we relinquished certain concessions in Poland and  impaired the remaining capitalized costs of $72,000.
	The following table reflects the net changes in capitalized exploratory well costs, which are capitalized pending the determination of proved reserves:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Beginning balance at January 1	$	11,160		$	9,965	$	3,614
	Additions to capitalized exploratory well costs
	pending the determination of proved reserves		13,022			6,984		9,965
	Reclassifications to wells, facilities, and equipment
	based on the determination of proved reserves		—			—		-3,614
	Capitalized exploratory well costs charged to expense		-4,941			-5,789		—
	Ending balance at December 31	$	19,241		$	11,160	$	9,965
	The 2013 additions include costs associated with our Tuchola-3K, Tuchola-4K, and Gorka-Duchowna-1 wells in Poland. The costs associated with the Plawce-2 well were charged to expense following an unsuccessful fracture stimulation in 2013. The following table shows the capitalized costs, by well, at December 31, 2013, along with the year for which the costs of each well were incurred:
							Total at
		Drilling Costs					December 31,
		2013			2012		2013
		(in thousands)
	Well:
	Tuchola-4K	$	290		$	—	$	290
	Tuchola-3K		7,513			1,467		8,980
	Gorka-Duchowna-1		4,747			—		4,747
	Frankowo-1		472			4,752		5,224
	Total cost	$	13,022		$	6,219	$	19,241
	The 2012 additions include costs associated with our Mieczewo-1K, Tuchola-3K, Plawce-2, and Frankowo-1 wells in Poland. The Mieczewo-1K and Tuchola-3K wells were drilling at year-end 2012. The Plawce-2 well was drilled in 2011 and was fracture stimulated during the first half of 2013. The Frankowo-1 well is currently being evaluated for future potential. The exploratory wells costs charged to expense during 2012 included costs at our Kutno-2 well in Poland along with costs associated with all Alberta Bakken test wells drilled in Montana. The 2011 activity included costs associated with the Plawce-1 and Kutno-2 wells in Poland and our first three Alberta Bakken tests in Montana. All five wells were either in progress or being evaluated or tested at the end of 2011.
	Other Property and Equipment
	Other property and equipment, including oilfield-servicing equipment, is stated at cost. Depreciation of other property and equipment is calculated using the straight-line method over the estimated useful lives (ranging from three to 40 years) of the respective assets. The costs of normal maintenance and repairs are charged to expense as incurred. Material expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of other property and equipment sold, or otherwise disposed of, and the related accumulated depreciation are removed from the accounts, and any gain or loss is reflected in current operations.
	The historical cost of other property and equipment, presented on a gross basis with accumulated depreciation, is summarized as follows:
							Estimated
		December 31,					Useful Life
		2013			2012		(in years)
		(in thousands)
	Other property and equipment:
	Drilling rigs	$	9,797		$	8,872	6
	Other vehicles		414			412	5
	Building		293			139	40
	Office equipment and furniture		1,353			1,294	3 to 6
	Total cost		11,857			10,717
	Accumulated depreciation		-9,125			-8,147
	Net other property and equipment	$	2,732		$	2,570
	Supplemental Disclosure of Cash Flows Information
	Noncash investing and financing transactions not reflected in the consolidated statements of cash flows include the following:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Noncash investing transactions:
	Additions to properties included in current liabilities	$	2,999		$	3,374	$	3,409
Cash paid for interest:
Cash paid during the year for interest		2,111			1,983		1,596
Cash paid for interest in 2013, 2012, and 2011 (in thousands) includes $270, $454, and $858, respectively, in commitment and other fees on our expanded credit facility.
Revenue Recognition
Revenues associated with oil and gas sales are recorded when title passes, which is upon delivery to the pipeline or other purchaser, and are net of royalties and value-added taxes. Oilfield service revenues are recognized when the related service is performed.
Stock-Based Compensation
We maintain several stock-based incentive plans.  Under these plans, we may issue options or restricted stock awards.  Options are granted at an option price equal to the market value of the stock at the date of grant, have a term of ten years, and vest in three equal annual installments.  Restricted stock awards have similar terms and vesting requirements.   Accounting standards require stock-based compensation costs to be measured at the grant date, based on the estimated fair value of the award, and recognized as expense over the employee’s requisite service period.
Income Taxes
Deferred income taxes are provided for the differences between the tax bases of assets or liabilities and their reported amounts in the consolidated financial statements. Such differences may result in taxable or deductible amounts in future years when the asset or liability is recovered or settled, respectively.
We did not have any unrecognized tax benefits at December 31, 2013. We are subject to audit in the United States by the Internal Revenue Service and various states for the prior three years and in Poland by Polish tax authorities for the prior five years. We do not believe there will be any material changes in our unrecognized tax positions over the next 12 months. Our policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax expense. No tax-related interest expense or penalties were recognized during the year ended December 31, 2013.
New Accounting Standards
In December 2011, the Financial Accounting Standards Board (“FASB”) issued new standards that require an entity to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position.   The new standards were effective for annual periods beginning on or after January 1, 2013.   We evaluated the provisions of the new standards and determined that they did not have a significant effect on financial position, cash flow, or current or future earnings or operations.
We have reviewed all other recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our consolidated results of operations, financial position, and cash flows. Based on that review, we believe that none of these pronouncements will have a significant effect on financial position, cash flow, or current or future earnings or operations.
Foreign Operations
The functional currency of our Polish subsidiary is the Polish zloty. The functional currency for the Polish subsidiary affects the amounts reported for Polish assets, liabilities, revenues, and expenses from those that would be reported if we used the U.S. dollar as the functional currency. The differences depend on changes in period-average and period-end exchange rates. Translation adjustments result from the process of translating the Polish subsidiary’s financial statements into the U.S. dollar reporting currency. Translation adjustments are not included in determining net income but are reported separately and accumulated in other comprehensive income. The accounting basis of the assets and liabilities of FX Energy Poland, our wholly owned subsidiary, is adjusted to reflect the difference between the exchange rate when the asset or liability was first recorded and the exchange rate on the date of the change. We record a cumulative translation adjustment (“CTA”) on our balance sheet to reflect those basis differences. At December 31, 2013 and 2012, the CTA balance was $15.0 million and $18.0 million, respectively. Because of the fluctuation in exchange rates between reporting periods and changes in certain account balances, the CTA will change from period to period.
During 2013, we recorded foreign currency transaction gains of approximately $5.0 million attributable to decreases in the amount of Polish zlotys necessary for FX Energy Poland to satisfy outstanding intercompany dollar-denominated loans and unpaid interest to FX Energy, Inc., as well as dollar-denominated notes payable held by FX Energy Poland. There was a corresponding debit to other comprehensive income for the gains attributable to the dollar-denominated loans, notes payable, and unpaid interest, which was then offset by translation adjustments of approximately $2.0 million related to our other balance sheet accounts as discussed above.
During 2013, we converted approximately $45 million of loans between FX Energy Poland and FX Energy, Inc., to equity. The conversion was necessary in order to make future interest payments from FX Energy Poland to FX Energy, Inc., tax deductible in Poland. The total amount of outstanding intercompany loans and accrued interest at December 31, 2013, was approximately $56 million and $63 million, respectively.
During 2012, we recorded foreign currency transaction gains of approximately $16.3 million attributable to decreases in the amount of Polish zlotys necessary for FX Energy Poland to satisfy outstanding intercompany dollar-denominated loans and unpaid interest to FX Energy, Inc., as well as dollar-denominated notes payable held by FX Energy Poland. There was a corresponding debit to other comprehensive income for the gains attributable to the dollar-denominated loans, notes payable, and unpaid interest, which was then offset by translation adjustments of approximately $5.4 million related to our other balance sheet accounts as discussed above. The total amount of outstanding intercompany loans and accrued interest at December 31, 2012, was approximately $106 million and $53 million, respectively.
During 2011, we recorded foreign currency transaction losses of approximately $23.5 million. We recorded a loss of approximately $23.4 million attributable to increases in the amount of Polish zlotys necessary for FX Energy Poland to satisfy outstanding intercompany dollar-denominated loans and unpaid interest to FX Energy, Inc., as well as dollar-denominated notes payable held by FX Energy Poland. There was a corresponding credit to other comprehensive income for the losses attributable to the dollar-denominated loans, notes payable, and unpaid interest, which was then offset by translation adjustments of approximately $8.6 million related to our other balance sheet accounts as discussed above. The total amount of outstanding intercompany loans and accrued interest at December 31, 2011, was approximately $111 million and $43 million, respectively.
The following table provides a summary of changes in CTA:
	Year Ended December 31,
	2013			2012
	(in thousands)
Beginning balance	$	18,027		$	28,964
Decrease related to losses (gains)
on dollar-denominated loans and notes payable		-4,986			-16,289
Increase related to translation adjustments		1,984			5,352
Ending balance	$	15,025		$	18,027
Future transaction gains or losses may be significant given the amount of dollar-denominated intercompany loans and notes payable and the volatility of exchange rates. Future translation adjustments will also vary in concert with changes in exchange rates. These gains, losses, and adjustments are noncash items for U.S. reporting purposes and have no impact on our actual zloty-based revenues and expenditures in Poland.
We enter into various operating agreements in Poland denominated in the Polish zloty, which is subject to exchange-rate fluctuations. We do not use derivative financial instruments for trading or speculative purposes.
Use of Estimates
The preparation of the consolidated financial statements in conformity with Generally Accepted Accounting Principles, or   “GAAP,” requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenue and expense during the reporting period. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our financial statements. The most significant estimates regarding these financial statements relate to the provision for income taxes, including uncertain tax positions, stock-based compensation, future development and abandonment costs, estimates to certain oil and gas revenues and expenses, and estimates of proved oil and natural gas reserve quantities used to calculate depletion, depreciation, and impairment of proved oil and natural gas properties and equipment.
Net Income (Loss) per Share
Basic earnings per share is computed by dividing the net loss applicable to common shares by the weighted average number of common shares outstanding. Diluted earnings per share is computed by dividing the net income (loss) by the sum of the weighted average number of common shares and the effect of dilutive unexercised stock options, warrants, unvested restricted stock, and convertible preferred stock or debt.
Outstanding options, warrants, and unvested restricted stock as of December 31, 2013, 2012, and 2011, were as follows:
	Options, Warrants, and
	Unvested Restricted Stock		Price Range
Balance sheet date:
31-Dec-13	2,551,928			$0.00-$5.06
31-Dec-12	1,930,398			0.00-5.06
31-Dec-11	1,356,041			0.00-10.65
The above options, warrants, and unvested restricted stock were not included in the computation of diluted earnings per share for the years presented because the effect would have been antidilutive.

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligation Disclosure [Text Block]	'
	Note 2: Asset Retirement Obligation
	We account for future site restoration costs by recording a liability for the fair value of asset retirement obligations when incurred, which is typically at the time the assets are placed in service. Amounts recorded for the related assets are increased by the amount of these obligations. Over time, the liabilities are accreted for the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets. We use an expected cash flow approach to estimate our asset retirement obligations. We recorded accretion expense of $90,000, $63,000, and $68,000 in 2013, 2012, and 2011, respectively.
	Following is a reconciliation of the yearly changes in the asset retirement obligation:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Asset retirement obligations:
	Beginning balance	$	1,431	$	1,184
	Current year additions		164		—
	Current year revisions		-64		408
	Liabilities settled		-25		-43
	Changes in classification from long-term to short-term		—		-267
	Foreign exchange adjustments		24		86
	Accretion expense		90		63
	Ending balance	$	1,620	$	1,431
	When the present value of a future asset retirement obligation changes due to the increase or decrease of the estimated plugging costs of that asset, we adjust the related asset retirement cost. During 2013, the economic lives of our United States oil wells were decreased due to higher than previously estimated production declines. This change resulted in an increase in the net present value of the retirement obligations. During 2012, the economic lives of our United States oil wells were decreased, as lower oil prices resulted in less economic barrels. This change, along with an increase in the estimated amount of future plugging costs, resulted in an increase in the net present value of the retirement obligations, which in turn resulted in losses associated with those obligations, as the related asset retirement costs had been previously written off.

Other_Assets

Other Assets	12 Months Ended
	Dec. 31, 2013
Other Assets, Noncurrent [Abstract]	'
Other Assets Disclosure [Text Block]	'
	Note 3: Other Assets
	As of December 31, 2013 and 2012, we had reclamation bonds with federal and state agencies with face amounts of $639,000 and $614,000, respectively, which were partially collateralized by certificates of deposit totaling $406,500 and $381,500.

Accrued_Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2013
Accrued Liabilities, Current [Abstract]	'
Accounts Payable and Accrued Liabilities Disclosure [Text Block]	'
	Note 4: Accrued Liabilities
	Our accrued liabilities were comprised of the following:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Accrued liabilities:
	Credit facility commitment fees	$	63	$	51
	Compensation-related costs		701		755
	Interest expense		69		103
	Accrued dry hole costs		—		269
	Oilfield equipment installment note		—		14
	Total	$	833	$	1,192

Notes_Payable

Notes Payable	12 Months Ended
	Dec. 31, 2013
Notes Payable [Abstract]	'
Debt Disclosure [Text Block]	'
	Note 5: Notes Payable
	On July 8, 2013, we finalized a new, five-year, up to $100 Million Senior Reserve Based Lending Facility with BNP Paribas (Suisse) SA and ING Bank N.V. The initial commitment of the facility amounts to $65 million. We can seek to increase the commitment up to $100 million under certain conditions via an embedded accordion mechanism. Initial proceeds from the new facility were used to repay our previously existing facility. Payment of the credit facility is secured by our assets in Poland and guaranteed by us.
	In consideration of the new credit facility, we paid various arrangement, structuring, legal, and other fees totaling approximately $2.2 million. These fees, along with approximately $399,000 associated with our previous facility, have been capitalized as loan fees and will be amortized over the five-year term of the loan. By virtue of the refinance, we charged approximately $677,000 in unamortized loan fees associated with our previous facility to interest expense during the third quarter of 2013.
	The credit facility calls for a periodic interest rate of three, six, or twelve month-LIBOR, plus an interest margin of 3.75% for the first three years of the facility and 4.00% for the final two years. The facility has a term of five years, with semiannual borrowing base reductions beginning on June 30, 2016. An unused commitment fee of 40% of the applicable interest margin is charged monthly based on the average daily unused portion of the new credit facility. There are no financial covenants associated with the new credit facility. As of December 31, 2013, the total amount drawn under the credit facility was $45 million, and the interest rate was 3.92% per annum.
	Our previous facility was a $55 million reserve-based agreement with The Royal Bank of Scotland, ING Bank N.V., and KBC Bank NV. The previous facility called for a periodic interest rate of LIBOR, plus an interest margin of 4.0%, and had a term of five years, with semiannual borrowing base reductions of $11 million each beginning on June 30, 2013. Accordingly, our borrowing base was reduced to $44 million on that date. Loan fees of approximately $257,000 associated with our existing credit facility were amortized and charged to interest expense during the first half of 2013.
	Our notes payable is stated at book value, which approximated its fair value at December 31, 2013.  Estimated fair values for notes payable have been determined based on borrowing rates currently available to us for bank loans with similar terms and maturities and are based on Level 3 criteria in the FASB’s fair value hierarchy.
	The following table provides a summary of changes in notes payable:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Beginning balance	$	40,000	$	40,000
	Payments of notes payable		-40,000		—
	Proceeds from borrowing		45,000		—
	Ending balance	$	45,000	$	40,000
	At December 31, 2013, the aggregate amounts of our contractually obligated principal payment commitments associated with our notes payable for the next five years are as follows:
		Total		2014		2015		2016		2017		2018
		(in thousands)
	Credit facility principal	$	45,000	$	—	$	—	$	6,000	$	26,000	$	13,000
	The borrowing base is redetermined twice a year, based on reserve volumes and values estimated by independent engineers as of the last day of the prior year. Our last redetermination was completed in December 2013, with no change in the borrowing base amount.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies Disclosure [Text Block]	'
	Note 6: Commitments and Contingencies
	Due to the nature of our business, certain legal or administrative proceedings may arise from time to time in the ordinary course of business.  In our opinion, there are no material pending legal proceedings to which we are a party or of which any of our property is the subject.  While the outcome of such legal matters cannot be predicted with certainty, we do not expect them to have a material adverse effect on our financial condition, results of operations, or cash flows.

Fair_Value_Measurements_and_Ma

Fair Value Measurements and Marketable Securities	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures [Text Block]	'
	Note 7:  Fair Value Measurements and Marketable Securities
	The accounting standard for fair value measurements provides a framework for measuring fair value and requires expanded disclosures regarding fair value measurements.  Fair value is defined as the price that would be received for an asset or the exit price that would be paid to transfer a liability in the principal or most advantageous market in an orderly transaction between market participants on the measurement date.   The accounting standard established a fair value hierarchy that requires an entity to maximize the use of observable inputs, where available.  The following summarizes the three levels of inputs required as well as the assets and liabilities that we value using those levels of inputs.
		⋅	Level 1:  Unadjusted, quoted prices in active markets for identical assets and liabilities.
		⋅	Level 2:  Observable inputs other than those included in Level 1.  For example, quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in inactive markets.
		⋅	Level 3:  Unobservable inputs reflecting management’s own assumptions about the inputs used in pricing the asset or liability.
	A review of fair value hierarchy classifications is conducted on a quarterly basis.  Changes in the observability of valuation inputs may result in a reclassification for certain financial assets or liabilities.  We had no Level 3 assets as of December 31, 2013 or 2012.
	Recurring Fair Value
	The following tables set forth the financial assets that we measured at fair value on a recurring basis by level within the fair value hierarchy.  We classify assets measured at fair value in their entirety based on the lowest level of input that is significant to their fair value measurement.
	Assets measured at fair value on a recurring basis consisted of the following:
			December 31,
			2013		Level 1(1)		Level 2(2)		Level 3(3)
			(in thousands)
	Cash equivalents:
	Money market funds		$	130	$	130	$	—	$	—
			December 31,
			2012		Level 1(1)		Level 2(2)		Level 3(3)
		(in thousands)
	Cash equivalents:
	Money market funds		$	1,127	$	1,127	$	—	$	—
	_______________
		-1	Quoted prices in active markets for identical assets.
		-2	Significant other observable inputs.
		-3	Significant unobservable inputs.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Tax Disclosure [Text Block]	'
	Note 8: Income Taxes
	We recognized no income tax benefit from the losses generated during 2013, 2012, and 2011. The components of the net deferred tax asset are as follows:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Deferred tax liability:
	Property and equipment basis differences	$	-1,630	$	-1,374
	Deferred tax asset:
	Net operating loss carryforwards:
	United States		24,799		33,118
	Poland		4,655		1,015
	Oil and gas properties		3,355		5,009
	Accrued interest expense		11,927		10,117
	Foreign exchange translation losses		4,013		4,865
	Options issued for services		831		423
	Asset retirement obligation		452		389
	Valuation allowance		-48,402		-53,562
	Total	$	—	$	—
	Accounting standards require that a valuation allowance be provided if it is more likely than not that some portion or all of a deferred tax asset will not be realized. Our ability to realize the benefit of our deferred tax asset will depend on the generation of future taxable income through profitable operations through expansion of our oil and gas producing activities. The risks associated with generating future taxable income are considerable, resulting in our conclusion that a full valuation allowance be provided at December 31, 2013, 2012, and 2011. Due to the full valuation allowance, our effective income tax rate for all three years was zero percent.
	During the year ended December 31, 2013, we decreased our valuation allowance by $5.2 million. We increased our valuation allowance by $3.0 million and $2.6 million for the years ended December 31, 2012 and 2011, respectively.
	The income tax provision differs from the amount computed by applying the U.S. federal income tax rate of 35% to net income (loss) before income taxes for the following reasons:
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Effective Tax Rate Reconciliation:
	Federal income tax provision (benefit) at statutory rates	$	-4,130	$	1,441	$	-9,983
	Increase (decrease) due to stock-based compensation		240		-259		154
	Increase (decrease) due to differences in foreign tax rates		-2,200		-3,586		1,392
	Decrease due to state and local taxes, net of federal benefit		-278		-354		-203
	Increase (decrease) due to the effect of exchange rate fluctuations		-1,728		-2,118		2,792
	Increase due to expiring and/or unavailable net operating losses		13,256		1,860		3,282
	Change in valuation allowance		-5,160		3,016		2,566
	Total	$	—	$	—	$	—
	United States NOL
	At December 31, 2013, we had net operating loss (“NOL”) carryforwards in the United States of approximately $96.8 million available to offset future taxable income. The carryforwards begin to expire in 2018 and will fully expire in 2033. The application of the NOL carryforwards against future taxable income in the United States may become subject to an annual limitation if there is a change in ownership.
	Polish NOL
	As of December 31, 2013, we had NOL carryforwards in Poland totaling approximately $24.5 million. The NOL carryforwards will be fully expired in 2018. The normal carryforward period in Poland is five years. However, in any given year, no more than 50% of the NOL carryforward may be applied against Polish income in succeeding years.
	The following table lists the years of expiration for our net operating losses:
		United States		Poland
		(in thousands)
	Year of NOL expiration:
	2018	$	6,145	$	24,503
	2019		2,938		—
	2020		2,717		—
	2021		2,243		—
	2022 and thereafter		82,716		—
	The domestic and foreign components of our net income (loss) are as follows:
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Domestic	$	-9,223	$	-9,963	$	-6,602
	Foreign		-2,577		14,081		-21,922
	Total	$	-11,800	$	4,118	$	-28,524
	No provision for deferred U.S. income taxes has been made for undistributed earnings of foreign subsidiaries because they were considered to be indefinitely reinvested outside the United States.  The distribution of these earnings in the form of dividends or otherwise may subject the company to U.S. federal and state income taxes and, possibly, foreign withholding taxes.  However, because of the complexities of U.S. taxation of foreign earnings, it is not practicable to estimate the amount of additional tax that might be payable on any eventual remittance of these earnings to the U.S.

Stockholders_Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2013
Stockholders' Equity Note [Abstract]	'
Stockholders' Equity Note Disclosure [Text Block]	'
	Note 9: Stockholders’ Equity
	We have a Stock Bonus Plan under section 401(k) of the Internal Revenue Code covering all of our employees. We have made discretionary contributions of 162,402, 138,748, and 106,301 shares of our stock to employees under this Plan and have recorded $0.7 million,  $0.7 million, and $0.7 million of expenses associated with these contributions for the years ended December 31, 2013, 2012, and 2011, respectively.
	We issued 6,500, 0, and 9,500 shares in 2013, 2012, and 2011, respectively, to consultants for services.
	During 2011, we sold 6,900,000 shares of common stock in a registered public offering at a price of $7.00 per share, resulting in net proceeds, after offering costs, of $45.0 million. Option holders exercised options with cash to purchase 96,799 shares of common stock in 2011, which resulted in proceeds of approximately $0.8 million. Option holders exercised options to purchase an additional 485,000 shares of common stock at a price of $8.37 per share by surrendering currently owned shares to pay the exercise price. As a result of this exercise, we issued 65,571 incremental shares.
	We have a stockholder rights plan, adopted in 2007, that may have the effect of discouraging unsolicited takeover proposals. The rights issued under the stockholder rights plan would cause substantial dilution to a person or group that attempts to acquire us on terms not approved in advance by our board of directors. In addition, our articles of incorporation and bylaws contain provisions that may discourage unsolicited takeover proposals that our stockholders may consider to be in their best interests.

Stock_Options_Warrants_and_Res

Stock Options, Warrants, and Restricted Stock	12 Months Ended
	Dec. 31, 2013
Disclosure Of Compensation Related Costs, Share-Based Payments [Abstract]	'
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	'
	Note 10: Stock Options, Warrants, and Restricted Stock
	Equity Compensation Plans
	Our equity compensation consists of annual stock option and award plans that have been adopted by the board of directors and subsequently approved by the stockholders at an annual meeting.
	The following table summarizes information regarding our stock option and award plans as of December 31, 2013:
				Weighted			Number
		Number		Average			of Options
		of Shares		Exercise Price			Available
		Authorized		of Outstanding			for Future
		Under Plan		Options			Issuance
	Equity compensation plans approved by stockholders:
	2011 Incentive Plan	4,447,962		$	4.22		1,579,701
	Total	4,447,962		$	4.22		1,579,701
	All stock option and award plans are administered by the Compensation Committee, consisting of the independent members of the board of directors. At its discretion, the Compensation Committee may grant stock, incentive stock options, or nonqualified options to any employee, including officers. The granted options have a term of ten years and vest in three equal annual installments. Under terms of the stock option award plans, we may also issue restricted stock.
	Stock Options
	The following table summarizes option activity:
		Year Ended December 31,
		2013						2012							2011
					Weighted							Weighted					Weighted
					Average							Average					Average
		Number of			Exercise			Number of				Exercise			Number of		Exercise
		Options			Price			Options				Price			Options		Price
	Options outstanding:
	Beginning of year		1,275,299		$	4.65				668,129		$	5.31			832,332	$	8.42
	Granted		648,058			3.38				642,170			4.25			636,509		5.06
	Exercised		—			—				—			—			-581,799		8.35
	Cancelled		-11,485			4.5				—			—			-3,380		5.06
	Expired		—			—				-35,000			9.89			-215,533		8.37
	End of year		1,911,872			4.22				1,275,299			4.65			668,129		5.31
	Exercisable at year-end		631,749			4.79				211,063			5.06			35,000		9.89
	The following table summarizes information about stock options outstanding as of December 31, 2013:
		Outstanding							Exercisable
				Weighted
				Average		Weighted					Weighted
		Number		Remaining		Average			Number		Average
	Exercise	of Options		Contractual Life		Exercise			of Options		Exercise
	Price Range	Outstanding		(in years)		Price			Exercisable		Price
	$3.38 - $4.24	648,058		9.88		$	3.38		—		$	—
	4.25 - 5.05	634,290		8.88			4.25		211,446			4.25
	5.06 - 5.06	629,524		7.69			5.06		420,303			5.06
	Total	1,911,872		8.84			4.22		631,749			4.79
	The aggregate intrinsic value of outstanding stock options at December 31, 2013, was $181,456.
	Restricted Stock
	The following table summarizes restricted stock activity:
		Number of Shares
		Year Ended December 31,
		2013		2012		2011
	Unvested restricted stock outstanding:
	Beginning of year	655,099		687,912		746,398
	Issued	324,033		321,086		318,252
	Forfeited	-6,157		-564		-7,100
	Vested	-332,919		-353,335		-369,638
	End of year	640,056		655,099		687,912
	The aggregate intrinsic value of unvested restricted stock at December 31, 2013, was $2.3 million. The aggregate intrinsic value represents the total pretax intrinsic value, based on our stock price of $3.66 as of December 31, 2013, which would have been received by the restricted stock award holders had all restricted stock awards been vested as of that date. The weighted average period over which stock compensation expense related to the restricted stock awards will be recognized is 2.19 years.
	Stock Compensation Expense
	The following tables summarize the quantity of restricted stock awards, total deferred compensation expense arising from those awards, and annual compensation expense for each annual equity award that is included in stock compensation expense:
	Year			Total Deferred			Stock Compensation Expense
	Ended	Number of		Compensation			(thousands)
	Dec. 31,	Shares		(thousands)			2013			2012			2011
	2013	324,033		$	1,095		$	47		$	-		$	-
	2012	321,086			1,365			452			59			-
	2011	318,252			1,610			531			534			157
	2010	373,500			2,260			720			747			749
	2009	379,500			1,044			-			334			345
2008	367,000			1,006			-			-			320
Total	2,083,371		$	8,380		$	1,750		$	1,674		$	1,571
The following tables summarize the quantity of stock option awards, total deferred compensation expense arising from those awards, and annual compensation expense for each annual equity award that is included in stock compensation expense:
Year			Total Deferred			Stock Compensation Expense
Ended	Number of		Compensation			(thousands)
Dec. 31,	Options		(thousands)			2013			2012			2011
2013	648,058		$	1,084		$	45		$	-		$	-
2012	642,170			1,421			471			60			-
2011	636,509			1,781			587			591			173
Total	1,926,737		$	4,286		$	1,103		$	651		$	173
The following table summarizes the assumptions used in determining Black-Scholes valuations for stock option grants made:
Year									Calculated
Ended	Expected Life				Expected		Risk Free		Stock Option
Dec. 31,	(Years)		Volatility		Dividend Yield		Interest Rate		Value per Share
2013	4		65	%	0	%	1.01	%	$	1.67
2012	4		70		0		0.49			2.21
2011	4		75		0		0.69			2.8

Business_Segments

Business Segments	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Reporting Disclosure [Text Block]	'
	Note 11:  Business Segments
	We operate within two business segments of the oil and gas industry: exploration and production (“E&P”) and oilfield services.  Revenues associated with our E&P activities are comprised of oil and gas sales from our producing properties in Poland and oil sales from our producing properties in the United States.  During the last three years, essentially all sales of oil and gas in Poland were made to PGNiG or its affiliated companies.  Over 95% of our oil sales in the United States were to Cenex during 2013, 2012, and 2011.  Gas sales in Poland are pursuant to long-term sales contracts that obligate the buyer to purchase all gas produced.  Individual oil sales are negotiated with PGNiG-affiliated entities and are not subject to sales contracts.  We believe the purchasers of our oil production in the United States could be replaced, if necessary, without a loss in revenue.
	E&P operating costs are comprised of: (1) exploration costs (geological and geophysical costs, exploratory dry holes, and proved property and nonproducing leasehold impairments); and (2) lease operating costs (lease operating expenses and production taxes).  Substantially all exploration costs are related to our operations in Poland.  The majority of lease operating costs are related to our domestic production.
	Revenues associated with our oilfield services segment are comprised of contract drilling and well-servicing fees generated by our oilfield-servicing equipment in Montana.  Oilfield-servicing costs are comprised of direct costs associated with our oilfield services.
	DD&A directly associated with a particular business segment is disclosed within that business segment.  We do not allocate current assets, corporate DD&A, general and administrative costs, amortization of deferred compensation, interest income, interest expense, other income, or other expense to our operating business segments for management and business segment reporting purposes.  All material intercompany transactions between our business segments are eliminated for management and business segment reporting purposes.
	Information on our operations by business segment is summarized as follows:
		Year Ended December 31, 2013
		(in thousands)
						Oilfield
		Exploration & Production				Services		Total
		U.S.		Poland
	Operations summary:
	Revenues	$	3,861	$	29,450	$	1,218	$	34,529
	Lease operating expense		-2,314		-1,366		—		-3,680
	Oilfield services costs		—		—		-1,179		-1,179
	Exploration expense		-303		-20,489		—		-20,792
	Impairment expense		-24		-6,105		—		-6,129
	Accretion expense		-55		-35		—		-90
	DD&A expense		-236		-3,344		-956		-4,536
	Operating income (loss)	$	929	$	-1,889	$	-917	$	-1,877
	Identifiable net property and equipment:
	Unproved properties	$	—	$	2,404	$	—	$	2,404
	Proved properties		2,713		68,286		—		70,999
	Equipment and other		—		49		2,657		2,706
	Total	$	2,713	$	70,739	$	2,657	$	76,109
	Net Capital Expenditures:
	Property and equipment	$	819	$	27,207	$	1,083	$	29,109
	Total	$	819	$	27,207	$	1,083	$	29,109
		Year Ended December 31, 2012
		(in thousands)
						Oilfield
		Exploration & Production				Services		Total
		U.S.		Poland
	Operations summary:
	Revenues	$	4,117	$	30,344	$	2,137	$	36,598
	Lease operating expense		-2,403		-1,228		—		-3,631
	Oilfield services costs		—		—		-1,610		-1,610
	Exploration expense		-475		-23,320		—		-23,795
	Impairment expense		-1,775		-787		—		-2,562
	Accretion expense		-39		-24		—		-63
	Loss on asset sale		-49		—		—		-49
	DD&A expense		-146		-2,954		-1,109		-4,209
	Operating income (loss)	$	-770	$	2,031	$	-582	$	679
	Identifiable net property and equipment:
	Unproved properties	$	24	$	2,313	$	—	$	2,337
	Proved properties		2,330		49,852		—		52,182
	Equipment and other		—		10		2,510		2,520
	Total	$	2,354	$	52,175	$	2,510	$	57,039
	Net Capital Expenditures:
	Property and equipment	$	967	$	23,402	$	693	$	25,062
	Total	$	967	$	23,402	$	693	$	25,062
		Year Ended December 31, 2011
		(in thousands)
						Oilfield
		Exploration & Production				Services		Total
		U.S.		Poland
	Operations summary:
	Revenues	$	4,687	$	25,120	$	5,631	$	35,438
	Lease operating expense		-2,846		-988		—		-3,834
	Oilfield services costs		—		—		-4,458		-4,458
	Exploration expense		-74		-16,544		—		-16,618
	Impairment expense		—		-72		—		-72
	Accretion expense		-44		-24		—		-68
Asset retirement obligation gain		52		—		—		52
DD&A expense		-107		-2,242		-984		-3,333
Operating income	$	1,668	$	5,250	$	189	$	7,107
Identifiable net property and equipment:
Unproved properties	$	628	$	2,854	$	—	$	3,482
Proved properties		2,952		38,490		—		41,442
Equipment and other		—		19		2,926		2,945
Total	$	3,580	$	41,363	$	2,926	$	47,869
Net Capital Expenditures:
Property and equipment	$	2,539	$	13,613	$	1,195	$	17,347
Total	$	2,539	$	13,613	$	1,195	$	17,347
A reconciliation of the segment information to the consolidated totals follows:
	Year Ended December 31,
	2013		2012		2011
	(in thousands)
Revenues:
Reportable segments	$	34,529	$	36,598	$	35,438
Non reportable segments		—		—		—
Total revenues	$	34,529	$	36,598	$	35,438
Net loss:
Operating income (loss), reportable segments	$	-1,877	$	679	$	7,107
Expense or (revenue) adjustments:
Corporate DD&A expense		-37		-30		-64
General and administrative costs (G&A)		-8,836		-8,369		-8,396
Stock compensation (G&A)		-2,853		-2,325		-1,744
Total net operating loss		-13,603		-10,045		-3,097
Non operating income:
Interest income (net of interest expense) and other income		-3,164		-2,129		-1,979
Foreign exchange gain (loss)		4,967		16,292		-23,448
Net (loss) income	$	-11,800	$	4,118	$	-28,524
Net property and equipment:
Reportable segments	$	76,109	$	57,039	$	47,869
Corporate assets		27		50		27
Net property and equipment	$	76,136	$	57,089	$	47,896
Property and equipment capital expenditures:
Reportable segments	$	29,109	$	25,062	$	17,347
Corporate assets		—		42		25
Total property and equipment capital expenditures	$	29,109	$	25,104	$	17,372

Quarterly_Financial_Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Data [Abstract]	'
Quarterly Financial Information [Text Block]	'
	Note 12: Quarterly Financial Data (Unaudited)
	Summary quarterly information for 2013 and 2012 is as follows:
		Quarter Ended
			December 31		September 30		June 30		March 31
			(in thousands, except per share amounts)
	2013:00:00
	Revenues	$	8,610	$	8,228	$	8,203	$	9,488
	Net operating loss		-1,308		-3,721		-6,832		-1,742
	Net income (loss)		3,810		6,462		-10,629		-11,443
	Basic and diluted net income (loss) per common share	$	0.07	$	0.12	$	-0.2	$	-0.22
	2012:00:00
	Revenues	$	9,886	$	9,552	$	8,578	$	8,582
	Net operating income (loss)		-4,206		-7,987		1,425		723
	Net income (loss)		-436		1,989		-12,115		14,680
	Basic and diluted net income (loss) per common share	$	-0.01	$	0.04	$	-0.23	$	0.28

Disclosure_about_Oil_and_Gas_P

Disclosure about Oil and Gas Properties and Producing Activities	12 Months Ended
	Dec. 31, 2013
Oil and Gas Delivery Commitments and Contracts Additional Information [Abstract]	'
Oil And Gas Exploration And Production Industries Disclosures [Text Block]	'
	Disclosure about Oil and Gas Properties and Producing Activities (Unaudited)
	Capitalized Oil and Gas Property Costs
	Capitalized costs relating to oil and gas exploration and production activities are summarized as follows:
			United States			Poland		Total
						(in thousands)
	Year Ended December 31, 2013:
	Proved properties		$	6,600		$	78,644	$	85,244
	Unproved properties			—			2,404		2,404
	Total gross properties			6,600			81,048		87,648
	Less accumulated depreciation, depletion, and amortization			-3,887			-10,358		-14,245
			$	2,713		$	70,690	$	73,403
	Year Ended December 31, 2012:
	Proved properties		$	5,981		$	57,840	$	63,821
	Unproved properties			24			2,312		2,336
	Total gross properties			6,005			60,152		66,157
	Less accumulated depreciation, depletion, and amortization			-3,650			-7,988		-11,638
			$	2,355		$	52,164	$	54,519
	Results of Operations
	Results of operations are reflected in Note 11, Business Segments. There is no tax provision because we are not likely to pay, and have not received any benefit from, any federal or local income taxes due to our operating losses. Total production costs (in thousands) for 2013, 2012, and 2011 were $3,680, $3,631, and $3,834, respectively.
	Property Acquisition, Exploration, and Development Activities
	Costs incurred in property acquisition, exploration, and development activities, whether capitalized or expensed, are summarized as follows:
			United States			Poland		Total
						(in thousands)
	Year ended December 31, 2013:
	Acquisition of unproved properties		$	—		$	1,043	$	1,043
	Exploration costs			303			37,697		38,000
	Development costs			864			8,902		9,766
	Total		$	1,167		$	47,642	$	48,809
	Year ended December 31, 2012:
	Acquisition of unproved properties		$	134		$	1	$	135
	Exploration costs			405			31,976		32,381
	Development costs			903			2,300		3,203
	Total		$	1,442		$	34,277	$	35,719
	Year ended December 31, 2011:
	Acquisition of unproved properties		$	604		$	65	$	669
	Exploration costs			1,406			26,844		28,250
	Development costs			558			3,059		3,617
	Total		$	2,568		$	29,968	$	32,536
	Impairment of Oil and Gas Properties
	We recorded impairment charges in our E&P segment related to oil and gas properties as follows:
			2013			2012		2011
			(in thousands)
	Impairment of properties		$	6,129		$	2,562	$	72
	Exploratory Dry Hole Costs
	Total dry hole costs (in thousands) of $6,678 in 2013 were principally related to the Mieczewo-1K and Plawce-2 wells in Poland. Dry hole costs of $12,711 in 2012 were principally related to the Kutno-2 well drilled in Poland and one Alberta Bakken well drilled in Montana. Dry hole costs of $1,328 in 2011 were principally related to the Machnatka-1 well drilled in Poland.
	Summary Oil and Gas Reserve Data (Unaudited)
	The following disclosures about our crude oil and natural gas reserves and exploration and production activities are in accordance with GAAP for disclosures about oil- and gas-producing activities and Securities and Exchange Commission rules for oil and gas reporting disclosures.
	Reserves
	There are numerous uncertainties inherent in estimating quantities of proved crude oil and natural gas reserves. Crude oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be precisely measured. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, and production subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserves estimates are often different from the quantities of crude oil and natural gas that are ultimately recovered.
	Definitions
	The following definitions apply to the terms used in this disclosure:
	Reserves Estimate—The determination of an estimate of a quantity of oil or gas reserves that are thought to exist at a certain date, considering existing prices and reservoir conditions.
	Proved Oil and Gas Reserves—Proved oil and gas reserves are those quantities of oil and gas that by analysis of geoscience and engineering data can be estimated with reasonable certainty to be economically producible-from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations-prior to the expiration of the contracts providing the right to operate, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.
	Developed Oil and Gas Reserves—Proved developed oil and gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared with the cost of a new well.
	Undeveloped Oil and Gas Reserves—Proved undeveloped oil and gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage or from existing wells where a relatively major expenditure is required for recompletion or production facilities.
	For complete definitions of proved natural gas, natural gas liquids, and crude oil reserves, refer to SEC Regulation S-X, Rule 4-10(a)(6), (22), and (31).
	Reserves Estimates Preparation
	Estimates of our proved Polish reserves were prepared by RPS Energy, an independent engineering firm in the United Kingdom. Estimates of our proved domestic reserves were prepared by Hohn Engineering, an independent engineering firm in Billings, Montana. The technical personnel responsible for calculating the reserve estimates at both RPS Energy and Hohn Engineering meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. Both RPS Energy and Hohn Engineering are independent firms of petroleum engineers, geologists, geophysicists, and petrophysicists; they do not own an interest in our properties and are not employed on a contingent-fee basis.
	Proved Developed Reserves:
	The following unaudited summary of proved developed reserve quantity information, including annual beginning and ending volumes by year, represents estimates only and should not be construed as exact:
			Crude Oil				Natural Gas
			United States		Poland		United States	Poland
			(in thousand barrels of oil)				(in million cubic feet)
December 31, 2013:
Beginning of year		594		—		—	22,367
End of year		461		—		—	41,219
December 31, 2012:
Beginning of year		639		—		—	31,987
End of year		594		—		—	22,367
December 31, 2011:
Beginning of year		639		—		—	31,683
End of year		639		—		—	31,987
Proved Undeveloped Reserves:
The following unaudited summary of proved undeveloped reserve quantity information, including annual beginning and ending volumes by year, represents estimates only and should not be construed as exact:
		Crude Oil				Natural Gas
		United States		Poland		United States	Poland
		(in thousand barrels of oil)				(in million cubic feet)
December 31, 2013:
Beginning of year		—		—		—	21,754
End of year		—		—		—	793
December 31, 2012:
Beginning of year		—		—		—	17,649
End of year		—		—		—	21,754
December 31, 2011:
Beginning of year		—		—		—	8,276
End of year		—		—		—	17,649
Total Proved Reserves:
The following unaudited summary of proved reserve quantity information represents estimates only and should not be construed as exact:
		Crude Oil				Natural Gas
		United States		Poland		United States	Poland
		(in thousand barrels of oil)				(in million cubic feet)
December 31, 2013:
Beginning of year		594		—		—	44,121
Extensions or discoveries(1)		—		—		—	3,947
Revisions of previous estimates(2)		-84		—		—	-1,909
Production		-49		—		—	-4,147
End of year		461		—		—	42,012
December 31, 2012:
Beginning of year		639		—		—	49,636
Extensions or discoveries(3)		—		—		—	2,313
Revisions of previous estimates(4)		9		—		—	-3,371
Production		-54		—		—	-4,457
End of year		594		—		—	44,121
December 31, 2011:
Beginning of year		639		—		—	39,959
Extensions or discoveries(5)		—		—		—	12,245
Revisions of previous estimates(6)		56		—		—	1,492
Production		-56		—		—	-4,060
End of year		639		—		—	49,636
_______________
	-1	Volume increase in Poland attributable to new Szymanowice-1 well drilled during 2013.
	-2	Downward oil revisions in the United States attributable to higher than previously estimated production declines. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Lisewo-1 well based on new pressure data and at the Grabowka wells due to lower than anticipated production.
	-3	Volume increase in Poland attributable to Komorze-3K well drilled during 2012.
	-4	Upward oil revisions in the United States attributable to lower average operating costs during 2012 compared to 2011 operating costs. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Zaniemysl and KSK wells based on new pressure data.
	-5	Volume increase in Poland attributable to Lisewo-1 well drilled during 2011.
	-6	Upward oil revisions in the United States attributable to higher average oil prices during 2011 compared to average 2010 oil prices. Upward gas revisions in Poland due to the increase of proved reserves calculated at the Roszkow well based on new pressure data.
Standardized Measure of Discounted Future Net Cash Flows (“SMOG”) and Changes Therein Relating to Proved Oil Reserves (Unaudited)
Certain information concerning the assumptions used in computing the valuation of proved reserves and their inherent limitations are discussed below. We believe such information is essential for a proper understanding and assessment of the data presented. The assumptions used to compute the proved reserve valuation do not necessarily reflect our expectations of actual revenues to be derived from those reserves or their present worth. Assigning monetary values to the reserve quantity estimation process does not reduce the subjective and ever-changing nature of such reserve estimates. Additional subjectivity occurs when determining present values because the rate of producing the reserves must be estimated. In addition to errors inherent in predicting the future, variations from the expected production rates also could result directly or indirectly from factors outside our control, such as unintentional delays in development, environmental concerns, and changes in prices or regulatory controls. The reserve valuation assumes that all reserves will be disposed of by production. However, if reserves are sold in place, additional economic considerations also could affect the amount of cash eventually realized. Future development and production costs are computed by estimating expenditures to be incurred in developing and producing the proved oil reserves at the end of the period, based on period-end costs and assuming continuation of existing economic conditions. A discount rate of 10% per year was used to reflect the timing of the future net cash flows. The future net cash flows for our Polish reserves are based on gas sales contracts we have with PGNiG. The average prices used to calculate year-end reserve values were $6.82 and $6.60 per Mcf and $78.18 and $78.14 per barrel for 2013 and 2012, respectively.
The components of SMOG are detailed below:
		United States			Poland		Total
		(in thousands)
December 31, 2013:
Future cash flows		$	36,077		$	286,680	$	322,757
Future production costs			-22,113			-33,660		-55,773
Future development costs			—			-17,830		-17,830
Future income tax expense			—			-11,300		-11,300
Future net cash flows			13,964			223,890		237,854
10% annual discount for estimated timing of cash flows			-5,760			-80,292		-86,052
Discounted net future cash flows		$	8,204		$	143,598	$	151,802
December 31, 2012:
Future cash flows		$	46,449		$	291,160	$	337,609
Future production costs			-28,171			-21,020		-49,191
Future development costs			—			-25,620		-25,620
Future income tax expense			—			-30,570		-30,570
Future net cash flows			18,278			213,950		232,228
10% annual discount for estimated timing of cash flows			-7,848			-66,777		-74,625
Discounted net future cash flows		$	10,430		$	147,173	$	157,603
December 31, 2011:
Future cash flows		$	54,036		$	319,840	$	373,876
Future production costs			-32,396			-22,020		-54,416
Future development costs			—			-17,240		-17,240
Future income tax expense			—			-40,868		-40,868
Future net cash flows			21,640			239,712		261,352
10% annual discount for estimated timing of cash flows			-9,377			-82,408		-91,785
Discounted net future cash flows		$	12,263		$	157,304	$	169,567
The principal sources of changes in SMOG are detailed below:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
SMOG sources:
Balance, beginning of year		$	157,603		$	169,567	$	127,337
Sale of oil and gas produced, net of production costs			-29,631			-30,830		-25,973
Net changes in prices and production costs			-2,456			4,385		20,809
Acquisition of minerals in place			—			—		—
Extensions and discoveries, net of future costs			6,020			4,570		38,210
Changes in estimated future development costs			-773			-7,358		-4,951
Previously estimated development costs incurred during the year			8,902			2,277		3,059
Revisions in previous quantity estimates			-9,210			-13,508		6,060
Accretion of discount			15,760			16,957		12,734
Net change in income taxes			13,495			5,769		-7,384
Changes in rates of production and other			-7,908			5,774		-334
Balance, end of year		$	151,802		$	157,603	$	169,567

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Basis Of Presentation [Abstract]	'
Consolidation, Policy [Policy Text Block]	'
	Principles of Consolidation
	The consolidated financial statements include the accounts of FX Energy, Inc., and its wholly owned subsidiaries and its undivided interests in Poland. All significant intercompany accounts and transactions have been eliminated in consolidation. At December 31, 2013, we owned 100% of the voting common stock or other equity securities of our subsidiaries.
Cash and Cash Equivalents, Policy [Policy Text Block]	'
	Cash and Cash Equivalents
	We consider all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. We determine the appropriate classification of our investments in cash and cash equivalents at the time of purchase and reevaluate such designation at each balance sheet date.
Fair Value Of Financial Instruments and Nonfinancial Assets and Liabilities [Policy Text Block]	'
	Fair Value of Financial Instruments and Nonfinancial Assets and Liabilities
	The carrying amounts of our financial instruments, including cash and cash equivalents, accounts receivable, accounts payable, and accrued liabilities, approximate fair value because of their generally short maturities. The accounting standards for fair value measurements provide for fair value measurements of all nonfinancial assets and nonfinancial liabilities not recognized or disclosed at fair value in the financial statements on a recurring basis.
Concentration Risk, Credit Risk, Policy [Policy Text Block]	'
	Concentration of Credit Risk
	The majority of our receivables are within the oil and gas industry, primarily from the purchasers of our oil and gas and fees generated from oilfield services and our industry partners. Substantially all of our Polish receivables are with PGNiG or one of its affiliates, and substantially all of our domestic receivables are with Cenex, a regional refiner and marketer. The receivables are not collateralized. To date, we have experienced minimal bad debts and have no allowance for doubtful accounts at December 31, 2013 and 2012. The majority of our cash and cash equivalents are held by four financial institutions in Utah, Montana, and Poland.
Inventory, Policy [Policy Text Block]	'
	Inventory
	Inventory consists primarily of tubular goods and production-related equipment and is valued at the lower of average cost or market.
Oil and Gas Properties Policy [Policy Text Block]	'
	Oil and Gas Properties
	We follow the successful-efforts method of accounting for our oil and gas operations. Under this method of accounting, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether an individual well has found proved reserves. If it is determined that an exploratory well has not found proved reserves, if the determination that proved reserves have been found cannot be made within one year, or if we are not making sufficient progress assessing the reserves and the economic and operating viability of the project, the costs of the well are expensed. The costs of development wells are capitalized whether productive or nonproductive. Geological and geophysical costs on exploratory prospects and the costs of carrying and retaining unproved properties are expensed as incurred. An impairment charge is provided to the extent that capitalized costs of unproved properties, on a field-by-field basis, are not considered to be realizable. Depreciation, depletion, and amortization (“DD&A”) of capitalized costs of proved oil and gas properties is provided on a field-by-field basis using the units-of-production method. The computation of DD&A takes into consideration the anticipated proceeds from equipment salvage. An impairment loss is recorded if the net capitalized costs of proved oil and gas properties exceed the aggregate undiscounted future net revenues determined on a field-by-field basis. The impairment loss recognized equals the excess of net capitalized costs over the related discounted future net cash flows determined on field-by-field basis. Gains and losses are recognized on sales of entire interests in proved and unproved properties. Sales of partial interests are generally treated as a recovery of costs and any resulting gain or loss is recorded as other income.
	Total dry hole costs (in thousands) of $6,678 in 2013 were principally related to the Mieczewo-1K and Plawce-2 wells in Poland.  Dry hole costs of $12,711 in 2012 were principally related to the Kutno-2 well drilled in Poland and one Alberta Bakken well drilled in Montana.  Dry hole costs of $1,328 in 2011 were principally related to the Machnatka-1 well drilled in Poland.
	During 2013, we recorded impairments of oil and gas properties of $6.1 million. We relinquished certain concessions in Poland, impairing the remaining capitalized costs of $1.0 million. In addition, we impaired approximately $4.5 million of prior-year costs associated with our Plawce-2 well following its unsuccessful fracture stimulation, along with approximately $200,000 of prior-year costs associated with our Mieczewo-1K well. Finally, our Zaniemysl-3 well ceased production during 2013, causing us to charge its remaining net book value of $367,000 to impairment expense.
	During 2012, we recorded impairments of oil and gas properties of $2.6 million. We relinquished certain concessions in Poland, impairing the remaining capitalized costs of $787,000. In Montana, we determined that our Alberta Bakken-related wells and leases were not prospective for hydrocarbon potential. We impaired the remaining capitalized costs of $1.8 million. The $7.0 million of impairment of oil and gas properties on the statements of cash flows includes both the $2.6 million of impairment recognized, as well as $4.4 million of exploration costs capitalized in 2011 related to the Kutno-1 dry hole, which were recognized in the third quarter of 2012. During 2011, we relinquished certain concessions in Poland and  impaired the remaining capitalized costs of $72,000.
	The following table reflects the net changes in capitalized exploratory well costs, which are capitalized pending the determination of proved reserves:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Beginning balance at January 1	$	11,160		$	9,965	$	3,614
	Additions to capitalized exploratory well costs
	pending the determination of proved reserves		13,022			6,984		9,965
	Reclassifications to wells, facilities, and equipment
	based on the determination of proved reserves		—			—		-3,614
	Capitalized exploratory well costs charged to expense		-4,941			-5,789		—
	Ending balance at December 31	$	19,241		$	11,160	$	9,965
	The 2013 additions include costs associated with our Tuchola-3K, Tuchola-4K, and Gorka-Duchowna-1 wells in Poland. The costs associated with the Plawce-2 well were charged to expense following an unsuccessful fracture stimulation in 2013. The following table shows the capitalized costs, by well, at December 31, 2013, along with the year for which the costs of each well were incurred:
							Total at
		Drilling Costs					December 31,
		2013			2012		2013
		(in thousands)
	Well:
	Tuchola-4K	$	290		$	—	$	290
	Tuchola-3K		7,513			1,467		8,980
	Gorka-Duchowna-1		4,747			—		4,747
	Frankowo-1		472			4,752		5,224
	Total cost	$	13,022		$	6,219	$	19,241
	The 2012 additions include costs associated with our Mieczewo-1K, Tuchola-3K, Plawce-2, and Frankowo-1 wells in Poland. The Mieczewo-1K and Tuchola-3K wells were drilling at year-end 2012. The Plawce-2 well was drilled in 2011 and was fracture stimulated during the first half of 2013. The Frankowo-1 well is currently being evaluated for future potential. The exploratory wells costs charged to expense during 2012 included costs at our Kutno-2 well in Poland along with costs associated with all Alberta Bakken test wells drilled in Montana. The 2011 activity included costs associated with the Plawce-1 and Kutno-2 wells in Poland and our first three Alberta Bakken tests in Montana. All five wells were either in progress or being evaluated or tested at the end of 2011.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	Other Property and Equipment
	Other property and equipment, including oilfield-servicing equipment, is stated at cost. Depreciation of other property and equipment is calculated using the straight-line method over the estimated useful lives (ranging from three to 40 years) of the respective assets. The costs of normal maintenance and repairs are charged to expense as incurred. Material expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of other property and equipment sold, or otherwise disposed of, and the related accumulated depreciation are removed from the accounts, and any gain or loss is reflected in current operations.
	The historical cost of other property and equipment, presented on a gross basis with accumulated depreciation, is summarized as follows:
							Estimated
		December 31,					Useful Life
		2013			2012		(in years)
		(in thousands)
	Other property and equipment:
	Drilling rigs	$	9,797		$	8,872	6
	Other vehicles		414			412	5
	Building		293			139	40
	Office equipment and furniture		1,353			1,294	3 to 6
	Total cost		11,857			10,717
	Accumulated depreciation		-9,125			-8,147
	Net other property and equipment	$	2,732		$	2,570
Supplemental Disclosure Of Cash Flows Information [Policy Text Block]	'
	Supplemental Disclosure of Cash Flows Information
	Noncash investing and financing transactions not reflected in the consolidated statements of cash flows include the following:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Noncash investing transactions:
	Additions to properties included in current liabilities	$	2,999		$	3,374	$	3,409
	Cash paid for interest:
	Cash paid during the year for interest		2,111			1,983		1,596
	Cash paid for interest in 2013, 2012, and 2011 (in thousands) includes $270, $454, and $858, respectively, in commitment and other fees on our expanded credit facility.
Revenue Recognition, Policy [Policy Text Block]	'
	Revenue Recognition
	Revenues associated with oil and gas sales are recorded when title passes, which is upon delivery to the pipeline or other purchaser, and are net of royalties and value-added taxes. Oilfield service revenues are recognized when the related service is performed.
Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]	'
	Stock-Based Compensation
	We maintain several stock-based incentive plans.  Under these plans, we may issue options or restricted stock awards.  Options are granted at an option price equal to the market value of the stock at the date of grant, have a term of ten years, and vest in three equal annual installments.  Restricted stock awards have similar terms and vesting requirements.   Accounting standards require stock-based compensation costs to be measured at the grant date, based on the estimated fair value of the award, and recognized as expense over the employee’s requisite service period.
Income Tax, Policy [Policy Text Block]	'
	Income Taxes
	Deferred income taxes are provided for the differences between the tax bases of assets or liabilities and their reported amounts in the consolidated financial statements. Such differences may result in taxable or deductible amounts in future years when the asset or liability is recovered or settled, respectively.
	We did not have any unrecognized tax benefits at December 31, 2013. We are subject to audit in the United States by the Internal Revenue Service and various states for the prior three years and in Poland by Polish tax authorities for the prior five years. We do not believe there will be any material changes in our unrecognized tax positions over the next 12 months. Our policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax expense. No tax-related interest expense or penalties were recognized during the year ended December 31, 2013.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	New Accounting Standards
	In December 2011, the Financial Accounting Standards Board (“FASB”) issued new standards that require an entity to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position.   The new standards were effective for annual periods beginning on or after January 1, 2013.   We evaluated the provisions of the new standards and determined that they did not have a significant effect on financial position, cash flow, or current or future earnings or operations.
	We have reviewed all other recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our consolidated results of operations, financial position, and cash flows. Based on that review, we believe that none of these pronouncements will have a significant effect on financial position, cash flow, or current or future earnings or operations.
Foreign Currency Transactions and Translations Policy [Policy Text Block]	'
	Foreign Operations
	The functional currency of our Polish subsidiary is the Polish zloty. The functional currency for the Polish subsidiary affects the amounts reported for Polish assets, liabilities, revenues, and expenses from those that would be reported if we used the U.S. dollar as the functional currency. The differences depend on changes in period-average and period-end exchange rates. Translation adjustments result from the process of translating the Polish subsidiary’s financial statements into the U.S. dollar reporting currency. Translation adjustments are not included in determining net income but are reported separately and accumulated in other comprehensive income. The accounting basis of the assets and liabilities of FX Energy Poland, our wholly owned subsidiary, is adjusted to reflect the difference between the exchange rate when the asset or liability was first recorded and the exchange rate on the date of the change. We record a cumulative translation adjustment (“CTA”) on our balance sheet to reflect those basis differences. At December 31, 2013 and 2012, the CTA balance was $15.0 million and $18.0 million, respectively. Because of the fluctuation in exchange rates between reporting periods and changes in certain account balances, the CTA will change from period to period.
	During 2013, we recorded foreign currency transaction gains of approximately $5.0 million attributable to decreases in the amount of Polish zlotys necessary for FX Energy Poland to satisfy outstanding intercompany dollar-denominated loans and unpaid interest to FX Energy, Inc., as well as dollar-denominated notes payable held by FX Energy Poland. There was a corresponding debit to other comprehensive income for the gains attributable to the dollar-denominated loans, notes payable, and unpaid interest, which was then offset by translation adjustments of approximately $2.0 million related to our other balance sheet accounts as discussed above.
	During 2013, we converted approximately $45 million of loans between FX Energy Poland and FX Energy, Inc., to equity. The conversion was necessary in order to make future interest payments from FX Energy Poland to FX Energy, Inc., tax deductible in Poland. The total amount of outstanding intercompany loans and accrued interest at December 31, 2013, was approximately $56 million and $63 million, respectively.
	During 2012, we recorded foreign currency transaction gains of approximately $16.3 million attributable to decreases in the amount of Polish zlotys necessary for FX Energy Poland to satisfy outstanding intercompany dollar-denominated loans and unpaid interest to FX Energy, Inc., as well as dollar-denominated notes payable held by FX Energy Poland. There was a corresponding debit to other comprehensive income for the gains attributable to the dollar-denominated loans, notes payable, and unpaid interest, which was then offset by translation adjustments of approximately $5.4 million related to our other balance sheet accounts as discussed above. The total amount of outstanding intercompany loans and accrued interest at December 31, 2012, was approximately $106 million and $53 million, respectively.
	During 2011, we recorded foreign currency transaction losses of approximately $23.5 million. We recorded a loss of approximately $23.4 million attributable to increases in the amount of Polish zlotys necessary for FX Energy Poland to satisfy outstanding intercompany dollar-denominated loans and unpaid interest to FX Energy, Inc., as well as dollar-denominated notes payable held by FX Energy Poland. There was a corresponding credit to other comprehensive income for the losses attributable to the dollar-denominated loans, notes payable, and unpaid interest, which was then offset by translation adjustments of approximately $8.6 million related to our other balance sheet accounts as discussed above. The total amount of outstanding intercompany loans and accrued interest at December 31, 2011, was approximately $111 million and $43 million, respectively.
	The following table provides a summary of changes in CTA:
		Year Ended December 31,
		2013			2012
		(in thousands)
	Beginning balance	$	18,027		$	28,964
	Decrease related to losses (gains)
	on dollar-denominated loans and notes payable		-4,986			-16,289
	Increase related to translation adjustments		1,984			5,352
	Ending balance	$	15,025		$	18,027
	Future transaction gains or losses may be significant given the amount of dollar-denominated intercompany loans and notes payable and the volatility of exchange rates. Future translation adjustments will also vary in concert with changes in exchange rates. These gains, losses, and adjustments are noncash items for U.S. reporting purposes and have no impact on our actual zloty-based revenues and expenditures in Poland.
	We enter into various operating agreements in Poland denominated in the Polish zloty, which is subject to exchange-rate fluctuations. We do not use derivative financial instruments for trading or speculative purposes.
Use of Estimates, Policy [Policy Text Block]	'
	Use of Estimates
	The preparation of the consolidated financial statements in conformity with Generally Accepted Accounting Principles, or   “GAAP,” requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenue and expense during the reporting period. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our financial statements. The most significant estimates regarding these financial statements relate to the provision for income taxes, including uncertain tax positions, stock-based compensation, future development and abandonment costs, estimates to certain oil and gas revenues and expenses, and estimates of proved oil and natural gas reserve quantities used to calculate depletion, depreciation, and impairment of proved oil and natural gas properties and equipment.
Earnings Per Share, Policy [Policy Text Block]	'
	Net Income (Loss) per Share
	Basic earnings per share is computed by dividing the net loss applicable to common shares by the weighted average number of common shares outstanding. Diluted earnings per share is computed by dividing the net income (loss) by the sum of the weighted average number of common shares and the effect of dilutive unexercised stock options, warrants, unvested restricted stock, and convertible preferred stock or debt.
	Outstanding options, warrants, and unvested restricted stock as of December 31, 2013, 2012, and 2011, were as follows:
		Options, Warrants, and
		Unvested Restricted Stock		Price Range
	Balance sheet date:
	31-Dec-13	2,551,928			$0.00-$5.06
	31-Dec-12	1,930,398			0.00-5.06
	31-Dec-11	1,356,041			0.00-10.65
	The above options, warrants, and unvested restricted stock were not included in the computation of diluted earnings per share for the years presented because the effect would have been antidilutive.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Basis Of Presentation [Abstract]	'
Capitalized Exploratory Well Costs, Roll Forward [Table Text Block]	'
	The following table reflects the net changes in capitalized exploratory well costs, which are capitalized pending the determination of proved reserves:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Beginning balance at January 1	$	11,160		$	9,965	$	3,614
	Additions to capitalized exploratory well costs
	pending the determination of proved reserves		13,022			6,984		9,965
	Reclassifications to wells, facilities, and equipment
	based on the determination of proved reserves		—			—		-3,614
	Capitalized exploratory well costs charged to expense		-4,941			-5,789		—
	Ending balance at December 31	$	19,241		$	11,160	$	9,965
Schedule of Aging of Capitalized Exploratory Well Costs [Table Text Block]	'
	The following table shows the capitalized costs, by well, at December 31, 2013, along with the year for which the costs of each well were incurred:
							Total at
		Drilling Costs					December 31,
		2013			2012		2013
		(in thousands)
	Well:
	Tuchola-4K	$	290		$	—	$	290
	Tuchola-3K		7,513			1,467		8,980
	Gorka-Duchowna-1		4,747			—		4,747
	Frankowo-1		472			4,752		5,224
	Total cost	$	13,022		$	6,219	$	19,241
Property, Plant and Equipment [Table Text Block]	'
	The historical cost of other property and equipment, presented on a gross basis with accumulated depreciation, is summarized as follows:
							Estimated
		December 31,					Useful Life
		2013			2012		(in years)
		(in thousands)
	Other property and equipment:
	Drilling rigs	$	9,797		$	8,872	6
	Other vehicles		414			412	5
	Building		293			139	40
	Office equipment and furniture		1,353			1,294	3 to 6
	Total cost		11,857			10,717
	Accumulated depreciation		-9,125			-8,147
	Net other property and equipment	$	2,732		$	2,570
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	'
	Noncash investing and financing transactions not reflected in the consolidated statements of cash flows include the following:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Noncash investing transactions:
	Additions to properties included in current liabilities	$	2,999		$	3,374	$	3,409
	Cash paid for interest:
	Cash paid during the year for interest		2,111			1,983		1,596
Schedule Of Changes In Cumulative Transaction Adjustment [Table Text Block]	'
	The following table provides a summary of changes in CTA:
		Year Ended December 31,
		2013			2012
		(in thousands)
	Beginning balance	$	18,027		$	28,964
	Decrease related to losses (gains)
	on dollar-denominated loans and notes payable		-4,986			-16,289
	Increase related to translation adjustments		1,984			5,352
	Ending balance	$	15,025		$	18,027
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	'
	Outstanding options, warrants, and unvested restricted stock as of December 31, 2013, 2012, and 2011, were as follows:
		Options, Warrants, and
		Unvested Restricted Stock		Price Range
	Balance sheet date:
	31-Dec-13	2,551,928			$0.00-$5.06
	31-Dec-12	1,930,398			0.00-5.06
	31-Dec-11	1,356,041			0.00-10.65

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Asset Retirement Obligations [Table Text Block]	'
	Following is a reconciliation of the yearly changes in the asset retirement obligation:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Asset retirement obligations:
	Beginning balance	$	1,431	$	1,184
	Current year additions		164		—
	Current year revisions		-64		408
	Liabilities settled		-25		-43
	Changes in classification from long-term to short-term		—		-267
	Foreign exchange adjustments		24		86
	Accretion expense		90		63
	Ending balance	$	1,620	$	1,431

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Accrued Liabilities, Current [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
	Our accrued liabilities were comprised of the following:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Accrued liabilities:
	Credit facility commitment fees	$	63	$	51
	Compensation-related costs		701		755
	Interest expense		69		103
	Accrued dry hole costs		—		269
	Oilfield equipment installment note		—		14
	Total	$	833	$	1,192

Notes_Payable_Tables

Notes Payable (Tables)	12 Months Ended
	Dec. 31, 2013
Notes Payable [Abstract]	'
Schedule of Accounts Payable and Accrued Liabilities [Table Text Block]	'
	The following table provides a summary of changes in notes payable:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Beginning balance	$	40,000	$	40,000
	Payments of notes payable		-40,000		—
	Proceeds from borrowing		45,000		—
	Ending balance	$	45,000	$	40,000
Schedule Of Contractually Obligated Principal Payment Commitments [Table Text Block]	'
	At December 31, 2013, the aggregate amounts of our contractually obligated principal payment commitments associated with our notes payable for the next five years are as follows:
		Total		2014		2015		2016		2017		2018
		(in thousands)
	Credit facility principal	$	45,000	$	—	$	—	$	6,000	$	26,000	$	13,000

Fair_Value_Measurements_and_Ma1

Fair Value Measurements and Marketable Securities (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value, Assets Measured on Recurring Basis [Table Text Block]	'
	Assets measured at fair value on a recurring basis consisted of the following:
			December 31,
			2013		Level 1(1)		Level 2(2)		Level 3(3)
			(in thousands)
	Cash equivalents:
	Money market funds		$	130	$	130	$	—	$	—
			December 31,
			2012		Level 1(1)		Level 2(2)		Level 3(3)
		(in thousands)
	Cash equivalents:
	Money market funds		$	1,127	$	1,127	$	—	$	—
	_______________
		-1	Quoted prices in active markets for identical assets.
		-2	Significant other observable inputs.
		-3	Significant unobservable inputs.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	We recognized no income tax benefit from the losses generated during 2013, 2012, and 2011. The components of the net deferred tax asset are as follows:
		Year Ended December 31,
		2013		2012
		(in thousands)
	Deferred tax liability:
	Property and equipment basis differences	$	-1,630	$	-1,374
	Deferred tax asset:
	Net operating loss carryforwards:
	United States		24,799		33,118
	Poland		4,655		1,015
	Oil and gas properties		3,355		5,009
	Accrued interest expense		11,927		10,117
	Foreign exchange translation losses		4,013		4,865
	Options issued for services		831		423
	Asset retirement obligation		452		389
	Valuation allowance		-48,402		-53,562
	Total	$	—	$	—
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	The income tax provision differs from the amount computed by applying the U.S. federal income tax rate of 35% to net income (loss) before income taxes for the following reasons:
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Effective Tax Rate Reconciliation:
	Federal income tax provision (benefit) at statutory rates	$	-4,130	$	1,441	$	-9,983
	Increase (decrease) due to stock-based compensation		240		-259		154
	Increase (decrease) due to differences in foreign tax rates		-2,200		-3,586		1,392
	Decrease due to state and local taxes, net of federal benefit		-278		-354		-203
	Increase (decrease) due to the effect of exchange rate fluctuations		-1,728		-2,118		2,792
	Increase due to expiring and/or unavailable net operating losses		13,256		1,860		3,282
	Change in valuation allowance		-5,160		3,016		2,566
	Total	$	—	$	—	$	—
Schedule Of Net Operating Loss Carryforward Expiration [Table Text Block]	'
	The following table lists the years of expiration for our net operating losses:
		United States		Poland
		(in thousands)
	Year of NOL expiration:
	2018	$	6,145	$	24,503
	2019		2,938		—
	2020		2,717		—
	2021		2,243		—
	2022 and thereafter		82,716		—
Schedule Of Domestic and Foreign Net Income (Loss) [Table Text Block]	'
	The domestic and foreign components of our net income (loss) are as follows:
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Domestic	$	-9,223	$	-9,963	$	-6,602
	Foreign		-2,577		14,081		-21,922
	Total	$	-11,800	$	4,118	$	-28,524

Stock_Options_Warrants_and_Res1

Stock Options, Warrants, and Restricted Stock (Tables)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule of Share-based Compensation, Stock Options and Stock Appreciation Rights Award Activity [Table Text Block]	'
	The following table summarizes information regarding our stock option and award plans as of December 31, 2013:
				Weighted			Number
		Number		Average			of Options
		of Shares		Exercise Price			Available
		Authorized		of Outstanding			for Future
		Under Plan		Options			Issuance
	Equity compensation plans approved by stockholders:
	2011 Incentive Plan	4,447,962		$	4.22		1,579,701
	Total	4,447,962		$	4.22		1,579,701
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	'
	The following table summarizes option activity:
		Year Ended December 31,
		2013						2012							2011
					Weighted							Weighted					Weighted
					Average							Average					Average
		Number of			Exercise			Number of				Exercise			Number of		Exercise
		Options			Price			Options				Price			Options		Price
	Options outstanding:
	Beginning of year		1,275,299		$	4.65				668,129		$	5.31			832,332	$	8.42
	Granted		648,058			3.38				642,170			4.25			636,509		5.06
	Exercised		—			—				—			—			-581,799		8.35
	Cancelled		-11,485			4.5				—			—			-3,380		5.06
	Expired		—			—				-35,000			9.89			-215,533		8.37
	End of year		1,911,872			4.22				1,275,299			4.65			668,129		5.31
	Exercisable at year-end		631,749			4.79				211,063			5.06			35,000		9.89
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, by Exercise Price Range [Table Text Block]	'
	The following table summarizes information about stock options outstanding as of December 31, 2013:
		Outstanding							Exercisable
				Weighted
				Average		Weighted					Weighted
		Number		Remaining		Average			Number		Average
	Exercise	of Options		Contractual Life		Exercise			of Options		Exercise
	Price Range	Outstanding		(in years)		Price			Exercisable		Price
	$3.38 - $4.24	648,058		9.88		$	3.38		—		$	—
	4.25 - 5.05	634,290		8.88			4.25		211,446			4.25
	5.06 - 5.06	629,524		7.69			5.06		420,303			5.06
	Total	1,911,872		8.84			4.22		631,749			4.79
Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]	'
	The following table summarizes restricted stock activity:
		Number of Shares
		Year Ended December 31,
		2013		2012		2011
	Unvested restricted stock outstanding:
	Beginning of year	655,099		687,912		746,398
	Issued	324,033		321,086		318,252
	Forfeited	-6,157		-564		-7,100
	Vested	-332,919		-353,335		-369,638
	End of year	640,056		655,099		687,912
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	'
	The following table summarizes the assumptions used in determining Black-Scholes valuations for stock option grants made:
	Year									Calculated
	Ended	Expected Life				Expected		Risk Free		Stock Option
	Dec. 31,	(Years)		Volatility		Dividend Yield		Interest Rate		Value per Share
	2013	4		65	%	0	%	1.01	%	$	1.67
	2012	4		70		0		0.49			2.21
	2011	4		75		0		0.69			2.8
Restricted Stock [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule of Share-based Compensation, Restricted Stock Units Award Activity [Table Text Block]	'
	The following tables summarize the quantity of restricted stock awards, total deferred compensation expense arising from those awards, and annual compensation expense for each annual equity award that is included in stock compensation expense:
	Year			Total Deferred			Stock Compensation Expense
	Ended	Number of		Compensation			(thousands)
	Dec. 31,	Shares		(thousands)			2013			2012			2011
	2013	324,033		$	1,095		$	47		$	-		$	-
	2012	321,086			1,365			452			59			-
	2011	318,252			1,610			531			534			157
	2010	373,500			2,260			720			747			749
	2009	379,500			1,044			-			334			345
	2008	367,000			1,006			-			-			320
	Total	2,083,371		$	8,380		$	1,750		$	1,674		$	1,571
Employee Stock Option [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule of Share-based Compensation, Restricted Stock Units Award Activity [Table Text Block]	'
	The following tables summarize the quantity of stock option awards, total deferred compensation expense arising from those awards, and annual compensation expense for each annual equity award that is included in stock compensation expense:
	Year			Total Deferred			Stock Compensation Expense
	Ended	Number of		Compensation			(thousands)
	Dec. 31,	Options		(thousands)			2013			2012			2011
	2013	648,058		$	1,084		$	45		$	-		$	-
	2012	642,170			1,421			471			60			-
	2011	636,509			1,781			587			591			173
	Total	1,926,737		$	4,286		$	1,103		$	651		$	173

Business_Segments_Tables

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	Information on our operations by business segment is summarized as follows:
		Year Ended December 31, 2013
		(in thousands)
						Oilfield
		Exploration & Production				Services		Total
		U.S.		Poland
	Operations summary:
	Revenues	$	3,861	$	29,450	$	1,218	$	34,529
	Lease operating expense		-2,314		-1,366		—		-3,680
	Oilfield services costs		—		—		-1,179		-1,179
	Exploration expense		-303		-20,489		—		-20,792
	Impairment expense		-24		-6,105		—		-6,129
	Accretion expense		-55		-35		—		-90
	DD&A expense		-236		-3,344		-956		-4,536
	Operating income (loss)	$	929	$	-1,889	$	-917	$	-1,877
	Identifiable net property and equipment:
	Unproved properties	$	—	$	2,404	$	—	$	2,404
	Proved properties		2,713		68,286		—		70,999
	Equipment and other		—		49		2,657		2,706
	Total	$	2,713	$	70,739	$	2,657	$	76,109
	Net Capital Expenditures:
	Property and equipment	$	819	$	27,207	$	1,083	$	29,109
	Total	$	819	$	27,207	$	1,083	$	29,109
		Year Ended December 31, 2012
		(in thousands)
						Oilfield
		Exploration & Production				Services		Total
		U.S.		Poland
	Operations summary:
	Revenues	$	4,117	$	30,344	$	2,137	$	36,598
	Lease operating expense		-2,403		-1,228		—		-3,631
	Oilfield services costs		—		—		-1,610		-1,610
	Exploration expense		-475		-23,320		—		-23,795
	Impairment expense		-1,775		-787		—		-2,562
	Accretion expense		-39		-24		—		-63
	Loss on asset sale		-49		—		—		-49
	DD&A expense		-146		-2,954		-1,109		-4,209
	Operating income (loss)	$	-770	$	2,031	$	-582	$	679
	Identifiable net property and equipment:
	Unproved properties	$	24	$	2,313	$	—	$	2,337
	Proved properties		2,330		49,852		—		52,182
	Equipment and other		—		10		2,510		2,520
	Total	$	2,354	$	52,175	$	2,510	$	57,039
	Net Capital Expenditures:
	Property and equipment	$	967	$	23,402	$	693	$	25,062
	Total	$	967	$	23,402	$	693	$	25,062
		Year Ended December 31, 2011
		(in thousands)
						Oilfield
		Exploration & Production				Services		Total
		U.S.		Poland
	Operations summary:
	Revenues	$	4,687	$	25,120	$	5,631	$	35,438
	Lease operating expense		-2,846		-988		—		-3,834
	Oilfield services costs		—		—		-4,458		-4,458
	Exploration expense		-74		-16,544		—		-16,618
	Impairment expense		—		-72		—		-72
	Accretion expense		-44		-24		—		-68
	Asset retirement obligation gain		52		—		—		52
	DD&A expense		-107		-2,242		-984		-3,333
	Operating income	$	1,668	$	5,250	$	189	$	7,107
	Identifiable net property and equipment:
	Unproved properties	$	628	$	2,854	$	—	$	3,482
Proved properties		2,952		38,490		—		41,442
Equipment and other		—		19		2,926		2,945
Total	$	3,580	$	41,363	$	2,926	$	47,869
Net Capital Expenditures:
Property and equipment	$	2,539	$	13,613	$	1,195	$	17,347
Total	$	2,539	$	13,613	$	1,195	$	17,347
Reconciliation Of Segment Information To Consolidated [Table Text Block]	'
	A reconciliation of the segment information to the consolidated totals follows:
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Revenues:
	Reportable segments	$	34,529	$	36,598	$	35,438
	Non reportable segments		—		—		—
	Total revenues	$	34,529	$	36,598	$	35,438
	Net loss:
	Operating income (loss), reportable segments	$	-1,877	$	679	$	7,107
	Expense or (revenue) adjustments:
	Corporate DD&A expense		-37		-30		-64
	General and administrative costs (G&A)		-8,836		-8,369		-8,396
	Stock compensation (G&A)		-2,853		-2,325		-1,744
	Total net operating loss		-13,603		-10,045		-3,097
	Non operating income:
	Interest income (net of interest expense) and other income		-3,164		-2,129		-1,979
	Foreign exchange gain (loss)		4,967		16,292		-23,448
	Net (loss) income	$	-11,800	$	4,118	$	-28,524
	Net property and equipment:
	Reportable segments	$	76,109	$	57,039	$	47,869
	Corporate assets		27		50		27
	Net property and equipment	$	76,136	$	57,089	$	47,896
	Property and equipment capital expenditures:
	Reportable segments	$	29,109	$	25,062	$	17,347
	Corporate assets		—		42		25
	Total property and equipment capital expenditures	$	29,109	$	25,104	$	17,372

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Data [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	Summary quarterly information for 2013 and 2012 is as follows:
		Quarter Ended
			December 31		September 30		June 30		March 31
			(in thousands, except per share amounts)
	2013:00:00
	Revenues	$	8,610	$	8,228	$	8,203	$	9,488
	Net operating loss		-1,308		-3,721		-6,832		-1,742
	Net income (loss)		3,810		6,462		-10,629		-11,443
	Basic and diluted net income (loss) per common share	$	0.07	$	0.12	$	-0.2	$	-0.22
	2012:00:00
	Revenues	$	9,886	$	9,552	$	8,578	$	8,582
	Net operating income (loss)		-4,206		-7,987		1,425		723
	Net income (loss)		-436		1,989		-12,115		14,680
	Basic and diluted net income (loss) per common share	$	-0.01	$	0.04	$	-0.23	$	0.28

Disclosure_about_Oil_and_Gas_P1

Disclosure about Oil and Gas Properties and Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Oil and Gas Delivery Commitments and Contracts Additional Information [Abstract]	'
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	'
	Capitalized costs relating to oil and gas exploration and production activities are summarized as follows:
			United States			Poland		Total
						(in thousands)
	Year Ended December 31, 2013:
	Proved properties		$	6,600		$	78,644	$	85,244
	Unproved properties			—			2,404		2,404
	Total gross properties			6,600			81,048		87,648
	Less accumulated depreciation, depletion, and amortization			-3,887			-10,358		-14,245
			$	2,713		$	70,690	$	73,403
	Year Ended December 31, 2012:
	Proved properties		$	5,981		$	57,840	$	63,821
	Unproved properties			24			2,312		2,336
	Total gross properties			6,005			60,152		66,157
	Less accumulated depreciation, depletion, and amortization			-3,650			-7,988		-11,638
			$	2,355		$	52,164	$	54,519
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	'
	Costs incurred in property acquisition, exploration, and development activities, whether capitalized or expensed, are summarized as follows:
			United States			Poland		Total
						(in thousands)
	Year ended December 31, 2013:
	Acquisition of unproved properties		$	—		$	1,043	$	1,043
	Exploration costs			303			37,697		38,000
	Development costs			864			8,902		9,766
	Total		$	1,167		$	47,642	$	48,809
	Year ended December 31, 2012:
	Acquisition of unproved properties		$	134		$	1	$	135
	Exploration costs			405			31,976		32,381
	Development costs			903			2,300		3,203
	Total		$	1,442		$	34,277	$	35,719
	Year ended December 31, 2011:
	Acquisition of unproved properties		$	604		$	65	$	669
	Exploration costs			1,406			26,844		28,250
	Development costs			558			3,059		3,617
	Total		$	2,568		$	29,968	$	32,536
Impairment Of Oil and Gas Properties [Table Text Block]	'
	We recorded impairment charges in our E&P segment related to oil and gas properties as follows:
			2013			2012		2011
			(in thousands)
	Impairment of properties		$	6,129		$	2,562	$	72
Schedule Of Proved Developed Oil and Gas Reserve Quantities [Table Text Block]	'
	The following unaudited summary of proved developed reserve quantity information, including annual beginning and ending volumes by year, represents estimates only and should not be construed as exact:
			Crude Oil				Natural Gas
			United States		Poland		United States	Poland
			(in thousand barrels of oil)				(in million cubic feet)
	December 31, 2013:
	Beginning of year		594		—		—	22,367
	End of year		461		—		—	41,219
	December 31, 2012:
	Beginning of year		639		—		—	31,987
	End of year		594		—		—	22,367
	December 31, 2011:
	Beginning of year		639		—		—	31,683
	End of year		639		—		—	31,987
Schedule Of Proved Undeveloped Oil And Gas Reserve Quantities [Table Text Block]	'
	The following unaudited summary of proved undeveloped reserve quantity information, including annual beginning and ending volumes by year, represents estimates only and should not be construed as exact:
			Crude Oil				Natural Gas
			United States		Poland		United States	Poland
			(in thousand barrels of oil)				(in million cubic feet)
	December 31, 2013:
	Beginning of year		—		—		—	21,754
	End of year		—		—		—	793
	December 31, 2012:
	Beginning of year		—		—		—	17,649
	End of year		—		—		—	21,754
	December 31, 2011:
	Beginning of year		—		—		—	8,276
	End of year		—		—		—	17,649
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	'
	The following unaudited summary of proved reserve quantity information represents estimates only and should not be construed as exact:
			Crude Oil				Natural Gas
			United States		Poland		United States	Poland
			(in thousand barrels of oil)				(in million cubic feet)
	December 31, 2013:
	Beginning of year		594		—		—	44,121
	Extensions or discoveries(1)		—		—		—	3,947
	Revisions of previous estimates(2)		-84		—		—	-1,909
	Production		-49		—		—	-4,147
	End of year		461		—		—	42,012
	December 31, 2012:
	Beginning of year		639		—		—	49,636
	Extensions or discoveries(3)		—		—		—	2,313
	Revisions of previous estimates(4)		9		—		—	-3,371
	Production		-54		—		—	-4,457
	End of year		594		—		—	44,121
	December 31, 2011:
	Beginning of year		639		—		—	39,959
	Extensions or discoveries(5)		—		—		—	12,245
	Revisions of previous estimates(6)		56		—		—	1,492
	Production		-56		—		—	-4,060
	End of year		639		—		—	49,636
	_______________
		-1	Volume increase in Poland attributable to new Szymanowice-1 well drilled during 2013.
		-2	Downward oil revisions in the United States attributable to higher than previously estimated production declines. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Lisewo-1 well based on new pressure data and at the Grabowka wells due to lower than anticipated production.
		-3	Volume increase in Poland attributable to Komorze-3K well drilled during 2012.
		-4	Upward oil revisions in the United States attributable to lower average operating costs during 2012 compared to 2011 operating costs. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Zaniemysl and KSK wells based on new pressure data.
		-5	Volume increase in Poland attributable to Lisewo-1 well drilled during 2011.
		-6	Upward oil revisions in the United States attributable to higher average oil prices during 2011 compared to average 2010 oil prices. Upward gas revisions in Poland due to the increase of proved reserves calculated at the Roszkow well based on new pressure data.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	'
	The components of SMOG are detailed below:
			United States			Poland		Total
			(in thousands)
	December 31, 2013:
	Future cash flows		$	36,077		$	286,680	$	322,757
	Future production costs			-22,113			-33,660		-55,773
	Future development costs			—			-17,830		-17,830
	Future income tax expense			—			-11,300		-11,300
	Future net cash flows			13,964			223,890		237,854
	10% annual discount for estimated timing of cash flows			-5,760			-80,292		-86,052
	Discounted net future cash flows		$	8,204		$	143,598	$	151,802
	December 31, 2012:
	Future cash flows		$	46,449		$	291,160	$	337,609
	Future production costs			-28,171			-21,020		-49,191
	Future development costs			—			-25,620		-25,620
	Future income tax expense			—			-30,570		-30,570
	Future net cash flows			18,278			213,950		232,228
	10% annual discount for estimated timing of cash flows			-7,848			-66,777		-74,625
	Discounted net future cash flows		$	10,430		$	147,173	$	157,603
	December 31, 2011:
	Future cash flows		$	54,036		$	319,840	$	373,876
	Future production costs			-32,396			-22,020		-54,416
	Future development costs			—			-17,240		-17,240
	Future income tax expense			—			-40,868		-40,868
	Future net cash flows			21,640			239,712		261,352
	10% annual discount for estimated timing of cash flows			-9,377			-82,408		-91,785
	Discounted net future cash flows		$	12,263		$	157,304	$	169,567
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	'
	The principal sources of changes in SMOG are detailed below:
			Year Ended December 31,
			2013			2012		2011
			(in thousands)
	SMOG sources:
	Balance, beginning of year		$	157,603		$	169,567	$	127,337
	Sale of oil and gas produced, net of production costs			-29,631			-30,830		-25,973
	Net changes in prices and production costs			-2,456			4,385		20,809
	Acquisition of minerals in place			—			—		—
	Extensions and discoveries, net of future costs			6,020			4,570		38,210
	Changes in estimated future development costs			-773			-7,358		-4,951
	Previously estimated development costs incurred during the year			8,902			2,277		3,059
	Revisions in previous quantity estimates			-9,210			-13,508		6,060
	Accretion of discount			15,760			16,957		12,734
	Net change in income taxes			13,495			5,769		-7,384
	Changes in rates of production and other			-7,908			5,774		-334
	Balance, end of year		$	151,802		$	157,603	$	169,567

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Increase Decrease in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Line Items]	'	'	'
Beginning balance at January 1	$11,160	$9,965	$3,614
Additions to capitalized exploratory well costs pending the determination of proved reserves	13,022	6,984	9,965
Reclassifications to wells, facilities and equipment based on the determination of proved reserves	0	0	-3,614
Capitalized exploratory well costs charged to expense	-4,941	-5,789	0
Ending balance at December 31	$19,241	$11,160	$9,965

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details 1) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	$19,241	$11,160	$9,965	$3,614
Drilling Costs [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	13,022	6,219	'	'
Tuchola-Four Well [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	290	'	'	'
Tuchola-Four Well [Member] | Drilling Costs [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	290	0	'	'
Tuchola-Three Well [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	8,980	'	'	'
Tuchola-Three Well [Member] | Drilling Costs [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	7,513	1,467	'	'
Gorka Duchowna Well [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	4,747	'	'	'
Gorka Duchowna Well [Member] | Drilling Costs [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	4,747	0	'	'
Frankowo-One Well [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	5,224	'	'	'
Frankowo-One Well [Member] | Drilling Costs [Member]	'	'	'	'
Projects with Exploratory Well Costs Capitalized [Line Items]	'	'	'	'
Capitalized Costs, Well	$472	$4,752	'	'

Summary_of_Significant_Account5

Summary of Significant Accounting Policies (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Other property and equipment:	'	'
Total cost	$11,857	$10,717
Accumulated depreciation	-9,125	-8,147
Net other property and equipment	2,732	2,570
Minimum [Member]	'	'
Other property and equipment:	'	'
Estimated Useful Life (in years)	'3 years	'
Maximum [Member]	'	'
Other property and equipment:	'	'
Estimated Useful Life (in years)	'40 years	'
Drilling Rigs [Member]	'	'
Other property and equipment:	'	'
Total cost	9,797	8,872
Estimated Useful Life (in years)	'6 years	'
Other Vehicles [Member]	'	'
Other property and equipment:	'	'
Total cost	414	412
Estimated Useful Life (in years)	'5 years	'
Building [Member]	'	'
Other property and equipment:	'	'
Total cost	293	139
Estimated Useful Life (in years)	'40 years	'
Office Equipment [Member]	'	'
Other property and equipment:	'	'
Total cost	$1,353	$1,294
Office Equipment [Member] | Minimum [Member]	'	'
Other property and equipment:	'	'
Estimated Useful Life (in years)	'3 years	'
Office Equipment [Member] | Maximum [Member]	'	'
Other property and equipment:	'	'
Estimated Useful Life (in years)	'6 years	'

Summary_of_Significant_Account6

Summary of Significant Accounting Policies (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Noncash investing transactions:	'	'	'
Additions to properties included in current liabilities	$2,999	$3,374	$3,409
Cash paid for interest:	'	'	'
Cash paid during the year for interest	$2,111	$1,983	$1,596

Summary_of_Significant_Account7

Summary of Significant Accounting Policies (Details 4) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cumulative Translation Adjustment Summary [Line Items]	'	'	'
Beginning balance	$18,027	$28,964	'
Decrease related to losses (gains) on dollar-denominated loans and notes payable	-4,986	-16,289	23,400
Increase related to translation adjustments	1,984	5,352	8,600
Ending balance	$15,025	$18,027	$28,964

Summary_of_Significant_Account8

Summary of Significant Accounting Policies (Details 5) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'
Options, Warrants, and Unvested Restricted Stock	2,551,928	1,930,398	1,356,041
Minimum [Member]	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'
Price Range (in dollars per share)	0	0	0
Maximum [Member]	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'
Price Range (in dollars per share)	5.06	5.06	10.65

Summary_of_Significant_Account9

Summary of Significant Accounting Policies (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Summary Of Significant Account Policies [Line Items]	'	'	'
Noncontrolling Interest, Ownership Percentage By Parent	100.00%	'	'
Impairment Of Oil and Gas Properties	$6,129,000	$2,562,000	$72,000
Property, Plant and Equipment, Depreciation Methods	'straight-line method	'	'
Debt Related Commitment Fees and Debt Issuance Costs	270,000	454,000	858,000
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net Of Tax	15,025,000	18,027,000	28,964,000
Cumulative Translation Adjustment, Net Of Tax, Period Increase (Decrease)	1,984,000	5,352,000	8,600,000
Foreign Currency Transaction Loss, Before Tax	5,000,000	16,300,000	23,500,000
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss), Before Reclassification and Tax	-4,986,000	-16,289,000	23,400,000
Intercompany Loans Outstanding, Amount	56,000,000	106,000,000	111,000,000
Intercompany Loans Interest Outstanding Amount	63,000,000	53,000,000	43,000,000
Tangible Asset Impairment Charges	6,129,000	6,979,000	72,000
Results of Operations, Exploration Expense	'	4,400,000	'
Interest Payable, Current	69,000	103,000	'
FX Energy Poland [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Conversion Of Loan To Equity	45,000,000	'	'
Short-term Debt, Total	56,000,000	'	'
Interest Payable, Current	63,000,000	'	'
Plawce Two Well [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Impairment Of Oil and Gas Properties	4,500,000	'	'
Mieczewo Well [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Impairment Of Oil and Gas Properties	200,000	'	'
Zaniemysl Three Well [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Tangible Asset Impairment Charges	367,000	'	'
Poland [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Impairment Of Oil and Gas Properties	1,000,000	787,000	'
Results Of Operations, Dry Hole Costs	6,678,000	12,711,000	1,328,000
Montana [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Impairment Of Oil and Gas Properties	'	$1,800,000	'
Maximum [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Estimated Useful Life (in years)	'40 years	'	'
Maximum [Member] | Office Equipment [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Estimated Useful Life (in years)	'6 years	'	'
Minimum [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Estimated Useful Life (in years)	'3 years	'	'
Minimum [Member] | Office Equipment [Member]	'	'	'
Summary Of Significant Account Policies [Line Items]	'	'	'
Estimated Useful Life (in years)	'3 years	'	'

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset retirement obligations:	'	'	'
Beginning balance	$1,431	$1,184	'
Current year additions	164	0	'
Current year revisions	-64	408	'
Liabilities settled	-25	-43	'
Changes in classification from long-term to short-term	0	-267	'
Foreign exchange adjustments	24	86	'
Accretion expense	90	63	68
Ending balance	$1,620	$1,431	$1,184

Asset_Retirement_Obligation_De1

Asset Retirement Obligation (Details Textual) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligation [Line Items]	'	'	'
Asset Retirement Obligation, Accretion Expense	$90	$63	$68

Other_Assets_Details_Textual

Other Assets (Details Textual) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Certificates Of Deposit, At Carrying Value	$406,000	$382,000
Reclamation Bonds [Member]	'	'
Debt Instrument, Face Amount	639,000	614,000
Certificates Of Deposit, At Carrying Value	$406,500	$381,500

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accrued liabilities:	'	'
Credit facility commitment fees	$63	$51
Compensation-related costs	701	755
Interest expense	69	103
Accrued dry hole costs	0	269
Oilfield equipment installment note	0	14
Total	$833	$1,192

Notes_Payable_Details

Notes Payable (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Debt Instrument [Line Items]	'	'	'
Beginning balance	$40,000	$40,000	'
Payments of notes payable	-40,000	0	-35,000
Proceeds from borrowing	42,964	0	40,000
Ending balance	$45,000	$40,000	$40,000

Notes_Payable_Details_1

Notes Payable (Details 1) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Line of Credit Facility, Annual Principal Payment	$45,000
Year 2014 [Member]	'
Line of Credit Facility, Annual Principal Payment	0
Year 2015 [Member]	'
Line of Credit Facility, Annual Principal Payment	0
Year 2016 [Member]	'
Line of Credit Facility, Annual Principal Payment	6,000
Year 2017 [Member]	'
Line of Credit Facility, Annual Principal Payment	26,000
Year 2018 [Member]	'
Line of Credit Facility, Annual Principal Payment	$13,000

Notes_Payable_Details_Textual

Notes Payable (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2010
Senior Reserve Based Lending Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt Instrument, Description Of Variable Rate Basis	'LIBOR, plus an interest margin of 3.75%	'
Debt Instrument Maturity Period	'5 years	'
Debt Instrument, Frequency Of Periodic Payment	'semiannual	'
Debt Instrument, Date Of First Required Payment	30-Jun-16	'
Debt Instrument, Fee Amount	$2,200,000	'
Line of Credit Facility, Maximum Borrowing Capacity	100,000,000	'
Line of Credit Facility, Current Borrowing Capacity	65,000,000	'
Line Of Credit Facility Additional Borrowing Capacity	100,000,000	'
Debt Instrument, Unused Borrowing Capacity, Description	'An unused commitment fee of 40% of the applicable interest margin	'
Line of Credit Facility, Commitment Fee Percentage	4.00%	'
Letter of Credit [Member]	'	'
Debt Instrument [Line Items]	'	'
Senior Notes, Noncurrent	'	55,000,000
Debt Instrument, Description Of Variable Rate Basis	'	'LIBOR, plus an interest margin of 4.0%
Debt Instrument Maturity Period	'	'5 years
Debt Instrument, Frequency Of Periodic Payment	'	'semiannual
Debt Instrument, Periodic Payment, Principal	'	11,000,000
Debt Instrument, Date Of First Required Payment	'	30-Jun-13
Interest Expense, Debt	257,000	'
Debt Instrument, Interest Rate During Period	3.92%	'
Debt Instrument, Fee Amount	399,000	'
Line of Credit Facility, Maximum Borrowing Capacity	45,000,000	'
Unamortized Loan Commitment and Origination Fees and Unamortized Discounts or Premiums	677,000	'
Line of Credit Facility, Decrease, Forgiveness	$44,000,000	'

Fair_Value_Measurements_and_Ma2

Fair Value Measurements and Marketable Securities (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Cash equivalents:	'		'
Money market funds	$130		$1,127
Fair Value, Inputs, Level 1 [Member]	'		'
Cash equivalents:	'		'
Money market funds	130	[1]	1,127	[1]
Fair Value, Inputs, Level 2 [Member]	'		'
Cash equivalents:	'		'
Money market funds	0	[2]	0	[2]
Fair Value, Inputs, Level 3 [Member]	'		'
Cash equivalents:	'		'
Money market funds	$0	[3]	$0	[3]
[1]	Quoted prices in active markets for identical assets.
[2]	Significant other observable inputs.
[3]	Significant unobservable inputs.

Income_Taxes_Details

Income Taxes (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Deferred tax liability:	'	'
Property and equipment basis differences	($1,630)	($1,374)
Deferred tax asset:	'	'
Oil and gas properties	3,355	5,009
Accrued interest expense	11,927	10,117
Foreign exchange translation losses	4,013	4,865
Options issued for services	831	423
Asset retirement obligation	452	389
Valuation allowance	-48,402	-53,562
Total	0	0
United States [Member]	'	'
Deferred tax asset:	'	'
Net operating loss carryforwards:	24,799	33,118
Poland [Member]	'	'
Deferred tax asset:	'	'
Net operating loss carryforwards:	$4,655	$1,015

Income_Taxes_Details_1

Income Taxes (Details 1) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Effective Tax Rate Reconciliation:	'	'	'
Federal income tax provision (benefit) at statutory rates	($4,130)	$1,441	($9,983)
Increase (decrease) due to stock-based compensation	240	-259	154
Increase (decrease) due to differences in foreign tax rates	-2,200	-3,586	1,392
Decrease due to state and local taxes, net of federal benefit	-278	-354	-203
Increase (decrease) due to the effect of exchange rate fluctuations	-1,728	-2,118	2,792
Increase due to expiring and/or unavailable net operating losses	13,256	1,860	3,282
Change in valuation allowance	-5,160	3,016	2,566
Total	$0	$0	$0

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
United States [Member]	'
Year of NOL expiration:	'
2018	$6,145
2019	2,938
2020	2,717
2021	2,243
2022 and thereafter	82,716
Poland [Member]	'
Year of NOL expiration:	'
2018	24,503
2019	0
2020	0
2021	0
2022 and thereafter	$0

Income_Taxes_Details_3

Income Taxes (Details 3) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	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, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Taxes [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Net income (loss)	$3,810	$6,462	($10,629)	($11,443)	($436)	$1,989	($12,115)	$14,680	($11,800)	$4,118	($28,524)
Domestic [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Taxes [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Net income (loss)	'	'	'	'	'	'	'	'	-9,223	-9,963	-6,602
Foreign [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Taxes [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Net income (loss)	'	'	'	'	'	'	'	'	($2,577)	$14,081	($21,922)

Income_Taxes_Details_Textual

Income Taxes (Details Textual) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Taxes [Line Items]	'	'	'
Effective Income Tax Rate Reconciliation, Percent, Total	35.00%	'	'
Valuation Allowance, Deferred Tax Asset, Change in Amount	($5.20)	$3	$2.60
United States [Member]	'	'	'
Income Taxes [Line Items]	'	'	'
Operating Loss Carryforwards	96.8	'	'
Operating Loss Carryforwards Expiration Period	'The carryforwards begin to expire in 2018 and will fully expire in 2033.	'	'
Poland [Member]	'	'	'
Income Taxes [Line Items]	'	'	'
Operating Loss Carryforwards	$24.50	'	'
Operating Loss Carryforwards Expiration Period	'The NOL carryforwards will be fully expired in 2018. The normal carryforward period in Poland is five years. However, in any given year, no more than 50% of the NOL carryforward may be applied against Polish income in succeeding years.	'	'

Stockholders_Equity_Details_Te

Stockholders' Equity (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stockholders' Equity [Line Items]	'	'	'
Proceeds From Issuance Of Common Stock	$0	$0	$45,041,000
Share Based Compensation Arrangement By Share Based Payment Award Options Exercised In Period	0	0	581,799
Share-Based Compensation Arrangements By Share-Based Payment Award, Options, Exercises In Period, Weighted Average Exercise Price	$0	$0	$8.35
Stock Issued During Period, Shares, Employee Benefit Plan	162,402	138,748	106,301
Stock Issued During Period, Shares, Issued For Services	6,500	0	9,500
Defined Contribution Plan, Employer Discretionary Contribution Amount	700,000	700,000	700,000
Employee Stock Option [Member]	'	'	'
Stockholders' Equity [Line Items]	'	'	'
Share Based Compensation Arrangement By Share Based Payment Award Options Exercised In Period	'	'	96,799
Proceeds From Stock Options Exercised	'	'	800,000
Share-Based Compensation Arrangements By Share-Based Payment Award, Options, Exercises In Period, Weighted Average Exercise Price	'	'	$8.37
Share Based Compensation Arrangement By Share Based Payment Award Incremental Shares Issued	'	'	65,571
Public Offering [Member]	'	'	'
Stockholders' Equity [Line Items]	'	'	'
Stock Issued During Period, Shares, New Issues	'	'	6,900,000
Stock Issued During Period Issue Price Per Share	'	'	$7
Proceeds From Issuance Of Common Stock	'	'	$45,000,000

Stock_Options_Warrants_and_Res2

Stock Options, Warrants, and Restricted Stock (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Equity compensation plans approved by stockholders:	'	'	'	'
Number of Shares Authorized Under Plan	4,447,962	'	'	'
Weighted Average Exercise Price of Outstanding Options	$4.22	$4.65	$5.31	$8.42
Number of Options Available for Future Issuance	1,579,701	'	'	'
Incentive Plan 2011 [Member]	'	'	'	'
Equity compensation plans approved by stockholders:	'	'	'	'
Number of Shares Authorized Under Plan	4,447,962	'	'	'
Weighted Average Exercise Price of Outstanding Options	$4.22	'	'	'
Number of Options Available for Future Issuance	1,579,701	'	'	'

Stock_Options_Warrants_and_Res3

Stock Options, Warrants, and Restricted Stock (Details 1) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Options outstanding:	'	'	'
Number of Options, Beginning of year	1,275,299	668,129	832,332
Number of Options, Granted	648,058	642,170	636,509
Number of Options, Exercised	0	0	-581,799
Number of Options, Cancelled	-11,485	0	-3,380
Number of Options, Expired	0	-35,000	-215,533
Number of Options, End of year	1,911,872	1,275,299	668,129
Number of Options, Exercisable at year-end	631,749	211,063	35,000
Weighted Average Exercise Price, Beginning of year	$4.65	$5.31	$8.42
Weighted Average Exercise Price, Granted	$3.38	$4.25	$5.06
Weighted Average Exercise Price, Exercised	$0	$0	$8.35
Weighted Average Exercise Price, Cancelled	$4.50	$0	$5.06
Weighted Average Exercise Price, Expired	$0	$9.89	$8.37
Weighted Average Exercise Price, End of year	$4.22	$4.65	$5.31
Weighted Average Exercise Price, Exercisable at year-end	$4.79	$5.06	$9.89

Stock_Options_Warrants_and_Res4

Stock Options, Warrants, and Restricted Stock (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Number of Options Outstanding	1,911,872	1,275,299	668,129	832,332
Weighted Average Remaining Contractual Life (in years)	'8 years 10 months 2 days	'	'	'
Weighted Average Exercise Price, Outstanding	$4.22	$4.65	$5.31	$8.42
Number of Options Exercisable	631,749	211,063	35,000	'
Weighted Average Exercise Price, Exercisable	$4.79	$5.06	$9.89	'
Exercise Price Range $3.38 - $4.24 [Member]	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Number of Options Outstanding	648,058	'	'	'
Weighted Average Remaining Contractual Life (in years)	'9 years 10 months 17 days	'	'	'
Weighted Average Exercise Price, Outstanding	$3.38	'	'	'
Number of Options Exercisable	0	'	'	'
Weighted Average Exercise Price, Exercisable	$0	'	'	'
Exercise Price Range $4.25 - $5.05 [Member]	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Number of Options Outstanding	634,290	'	'	'
Weighted Average Remaining Contractual Life (in years)	'8 years 10 months 17 days	'	'	'
Weighted Average Exercise Price, Outstanding	$4.25	'	'	'
Number of Options Exercisable	211,446	'	'	'
Weighted Average Exercise Price, Exercisable	$4.25	'	'	'
Exercise Price Range $5.06 - $5.06 [Member]	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Number of Options Outstanding	629,524	'	'	'
Weighted Average Remaining Contractual Life (in years)	'7 years 8 months 8 days	'	'	'
Weighted Average Exercise Price, Outstanding	$5.06	'	'	'
Number of Options Exercisable	420,303	'	'	'
Weighted Average Exercise Price, Exercisable	$5.06	'	'	'

Stock_Options_Warrants_and_Res5

Stock Options, Warrants, and Restricted Stock (Details 3)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Unvested restricted stock outstanding:	'	'	'
Number of Shares, Beginning of year	655,099	687,912	746,398
Number of Shares, Issued	324,033	321,086	318,252
Number of Shares, Forfeited	-6,157	-564	-7,100
Number of Shares, Vested	-332,919	-353,335	-369,638
Number of Shares, End of year	640,056	655,099	687,912

Stock_Options_Warrants_and_Res6

Stock Options, Warrants, and Restricted Stock (Details 4) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation, Total	$2,853	$2,325	$1,744
Restricted Stock [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	2,083,371	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	8,380	'	'
Share-based Compensation, Total	1,750	1,674	1,571
Restricted Stock [Member] | 2013 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	324,033	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,095	'	'
Share-based Compensation, Total	47	0	0
Restricted Stock [Member] | 2012 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	321,086	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,365	'	'
Share-based Compensation, Total	452	59	0
Restricted Stock [Member] | 2011 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	318,252	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,610	'	'
Share-based Compensation, Total	531	534	157
Restricted Stock [Member] | 2010 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	373,500	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	2,260	'	'
Share-based Compensation, Total	720	747	749
Restricted Stock [Member] | 2009 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	379,500	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,044	'	'
Share-based Compensation, Total	0	334	345
Restricted Stock [Member] | 2008 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	367,000	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,006	'	'
Share-based Compensation, Total	$0	$0	$320

Stock_Options_Warrants_and_Res7

Stock Options, Warrants, and Restricted Stock (Details 5) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation, Total	$2,853	$2,325	$1,744
Employee Stock Option [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	1,926,737	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	4,286	'	'
Share-based Compensation, Total	1,103	651	173
Employee Stock Option [Member] | 2013 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	648,058	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,084	'	'
Share-based Compensation, Total	45	0	0
Employee Stock Option [Member] | 2012 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	642,170	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,421	'	'
Share-based Compensation, Total	471	60	0
Employee Stock Option [Member] | 2011 [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period	636,509	'	'
Deferred Compensation Share-based Arrangements, Liability, Current	1,781	'	'
Share-based Compensation, Total	$587	$591	$173

Stock_Options_Warrants_and_Res8

Stock Options, Warrants, and Restricted Stock (Details 6) (USD $)	12 Months Ended
	Dec. 31, 2013
2013 [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Expected Life (Years)	'4 years
Volatility	65.00%
Expected Dividend Yield	0.00%
Risk Free Interest Rate	1.01%
Calculated Stock Option Value per Share	$1.67
2012 [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Expected Life (Years)	'4 years
Volatility	70.00%
Expected Dividend Yield	0.00%
Risk Free Interest Rate	0.49%
Calculated Stock Option Value per Share	$2.21
2011 [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Expected Life (Years)	'4 years
Volatility	75.00%
Expected Dividend Yield	0.00%
Risk Free Interest Rate	0.69%
Calculated Stock Option Value per Share	$2.80

Stock_Options_Warrants_and_Res9

Stock Options, Warrants, and Restricted Stock (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Share-Based Compensation Arrangement By Share-Based Payment Award, Options, Vested and Expected To Vest, Outstanding, Aggregate Intrinsic Value	$181,456
Share-Based Compensation Arrangement By Share-Based Payment Award Other Options Unvested Outstanding Aggregate Intrinsic Value	$2,300,000
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Nonvested, Intrinsic Value	$3.66
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Outstanding, Weighted Average Remaining Contractual Terms	'2 years 2 months 8 days

Business_Segments_Details

Business Segments (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	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, 2013	Dec. 31, 2012	Dec. 31, 2011
Operations summary:	'	'	'	'	'	'	'	'	'	'	'
Revenues	$8,610	$8,228	$8,203	$9,488	$9,886	$9,552	$8,578	$8,582	$34,529	$36,598	$35,438
Lease operating expenses	'	'	'	'	'	'	'	'	-3,680	-3,631	-3,834
Oilfield services costs	'	'	'	'	'	'	'	'	-1,179	-1,610	-4,458
Exploration expense	'	'	'	'	'	'	'	'	-20,792	-23,795	-16,618
Impairment expense	'	'	'	'	'	'	'	'	-6,129	-2,562	-72
Accretion expense	'	'	'	'	'	'	'	'	-90	-63	-68
Loss on asset sale	'	'	'	'	'	'	'	'	0	-49	0
Asset retirement obligation gain	'	'	'	'	'	'	'	'	0	0	52
DD&A expense	'	'	'	'	'	'	'	'	-4,573	-4,239	-3,397
Operating income (loss)	'	'	'	'	'	'	'	'	-1,877	679	7,107
Identifiable net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Unproved properties	2,404	'	'	'	2,337	'	'	'	2,404	2,337	3,482
Proved properties	85,244	'	'	'	63,821	'	'	'	85,244	63,821	41,442
Equipment and other	2,706	'	'	'	2,520	'	'	'	2,706	2,520	2,945
Total	76,136	'	'	'	57,089	'	'	'	76,136	57,089	47,869
Net Capital Expenditures:	'	'	'	'	'	'	'	'	'	'	'
Property and equipment	29,109	'	'	'	25,062	'	'	'	29,109	25,062	17,347
Total	29,109	'	'	'	25,062	'	'	'	29,109	25,062	17,347
Poland [Member]	'	'	'	'	'	'	'	'	'	'	'
Operations summary:	'	'	'	'	'	'	'	'	'	'	'
Impairment expense	'	'	'	'	'	'	'	'	-1,000	-787	'
Exploration and Production [Member] | United States [Member]	'	'	'	'	'	'	'	'	'	'	'
Operations summary:	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	3,861	4,117	4,687
Lease operating expenses	'	'	'	'	'	'	'	'	-2,314	-2,403	-2,846
Oilfield services costs	'	'	'	'	'	'	'	'	0	0	0
Exploration expense	'	'	'	'	'	'	'	'	-303	-475	-74
Impairment expense	'	'	'	'	'	'	'	'	-24	-1,775	0
Accretion expense	'	'	'	'	'	'	'	'	-55	-39	-44
Loss on asset sale	'	'	'	'	'	'	'	'	'	-49	'
Asset retirement obligation gain	'	'	'	'	'	'	'	'	'	'	52
DD&A expense	'	'	'	'	'	'	'	'	-236	-146	-107
Operating income (loss)	'	'	'	'	'	'	'	'	929	-770	1,668
Identifiable net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Unproved properties	0	'	'	'	24	'	'	'	0	24	628
Proved properties	2,713	'	'	'	2,330	'	'	'	2,713	2,330	2,952
Equipment and other	0	'	'	'	0	'	'	'	0	0	0
Total	2,713	'	'	'	2,354	'	'	'	2,713	2,354	3,580
Net Capital Expenditures:	'	'	'	'	'	'	'	'	'	'	'
Property and equipment	819	'	'	'	967	'	'	'	819	967	2,539
Total	819	'	'	'	967	'	'	'	819	967	2,539
Exploration and Production [Member] | Poland [Member]	'	'	'	'	'	'	'	'	'	'	'
Operations summary:	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	29,450	30,344	25,120
Lease operating expenses	'	'	'	'	'	'	'	'	-1,366	-1,228	-988
Oilfield services costs	'	'	'	'	'	'	'	'	0	0	0
Exploration expense	'	'	'	'	'	'	'	'	-20,489	-23,320	-16,544
Impairment expense	'	'	'	'	'	'	'	'	-6,105	-787	-72
Accretion expense	'	'	'	'	'	'	'	'	-35	-24	-24
Loss on asset sale	'	'	'	'	'	'	'	'	'	0	'
Asset retirement obligation gain	'	'	'	'	'	'	'	'	'	'	0
DD&A expense	'	'	'	'	'	'	'	'	-3,344	-2,954	-2,242
Operating income (loss)	'	'	'	'	'	'	'	'	-1,889	2,031	5,250
Identifiable net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Unproved properties	2,404	'	'	'	2,313	'	'	'	2,404	2,313	2,854
Proved properties	68,286	'	'	'	49,852	'	'	'	68,286	49,852	38,490
Equipment and other	49	'	'	'	10	'	'	'	49	10	19
Total	70,739	'	'	'	52,175	'	'	'	70,739	52,175	41,363
Net Capital Expenditures:	'	'	'	'	'	'	'	'	'	'	'
Property and equipment	27,207	'	'	'	23,402	'	'	'	27,207	23,402	13,613
Total	27,207	'	'	'	23,402	'	'	'	27,207	23,402	13,613
Oilfield Services [Member]	'	'	'	'	'	'	'	'	'	'	'
Operations summary:	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	1,218	2,137	5,631
Lease operating expenses	'	'	'	'	'	'	'	'	0	0	0
Oilfield services costs	'	'	'	'	'	'	'	'	-1,179	-1,610	-4,458
Exploration expense	'	'	'	'	'	'	'	'	0	0	0
Impairment expense	'	'	'	'	'	'	'	'	0	0	0
Accretion expense	'	'	'	'	'	'	'	'	0	0	0
Loss on asset sale	'	'	'	'	'	'	'	'	'	0	'
Asset retirement obligation gain	'	'	'	'	'	'	'	'	'	'	0
DD&A expense	'	'	'	'	'	'	'	'	-956	-1,109	-984
Operating income (loss)	'	'	'	'	'	'	'	'	-917	-582	189
Identifiable net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Unproved properties	0	'	'	'	0	'	'	'	0	0	0
Proved properties	0	'	'	'	0	'	'	'	0	0	0
Equipment and other	2,657	'	'	'	2,510	'	'	'	2,657	2,510	2,926
Total	2,657	'	'	'	2,510	'	'	'	2,657	2,510	2,926
Net Capital Expenditures:	'	'	'	'	'	'	'	'	'	'	'
Property and equipment	1,083	'	'	'	693	'	'	'	1,083	693	1,195
Total	$1,083	'	'	'	$693	'	'	'	$1,083	$693	$1,195

Business_Segments_Details_1

Business Segments (Details 1) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	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, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Total revenues	$8,610	$8,228	$8,203	$9,488	$9,886	$9,552	$8,578	$8,582	$34,529	$36,598	$35,438
Operating income (loss), reportable segments	'	'	'	'	'	'	'	'	-1,877	679	7,107
Expense or (revenue) adjustments:	'	'	'	'	'	'	'	'	'	'	'
DD&A expense	'	'	'	'	'	'	'	'	-4,573	-4,239	-3,397
General and administrative costs (G&A)	'	'	'	'	'	'	'	'	-8,836	-8,369	-8,396
Stock compensation (G&A)	'	'	'	'	'	'	'	'	-2,853	-2,325	-1,744
Total net operating loss	-1,308	-3,721	-6,832	-1,742	-4,206	-7,987	1,425	723	-13,603	-10,045	-3,097
Non operating income:	'	'	'	'	'	'	'	'	'	'	'
Interest income (net of interest expense) and other income	'	'	'	'	'	'	'	'	-3,164	-2,129	-1,979
Foreign exchange gain (loss)	'	'	'	'	'	'	'	'	4,967	16,292	-23,448
Net (loss) income	3,810	6,462	-10,629	-11,443	-436	1,989	-12,115	14,680	-11,800	4,118	-28,524
Net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Net property and equipment	76,136	'	'	'	57,089	'	'	'	76,136	57,089	47,869
Property and equipment capital expenditures:	'	'	'	'	'	'	'	'	'	'	'
Total	29,109	'	'	'	25,062	'	'	'	29,109	25,062	17,347
Reportable Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Total revenues	'	'	'	'	'	'	'	'	34,529	36,598	35,438
Net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Net property and equipment	76,109	'	'	'	57,039	'	'	'	76,109	57,039	47,869
Property and equipment capital expenditures:	'	'	'	'	'	'	'	'	'	'	'
Total	29,109	'	'	'	25,062	'	'	'	29,109	25,062	17,347
Non-reportable segments [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues:	'	'	'	'	'	'	'	'	'	'	'
Total revenues	'	'	'	'	'	'	'	'	0	0	0
Corporate [Member]	'	'	'	'	'	'	'	'	'	'	'
Net property and equipment:	'	'	'	'	'	'	'	'	'	'	'
Net property and equipment	27	'	'	'	50	'	'	'	27	50	27
Property and equipment capital expenditures:	'	'	'	'	'	'	'	'	'	'	'
Total	$0	'	'	'	$42	'	'	'	$0	$42	$25

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	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, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Data [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenues	$8,610	$8,228	$8,203	$9,488	$9,886	$9,552	$8,578	$8,582	$34,529	$36,598	$35,438
Net operating income (loss)	-1,308	-3,721	-6,832	-1,742	-4,206	-7,987	1,425	723	-13,603	-10,045	-3,097
Net income (loss)	$3,810	$6,462	($10,629)	($11,443)	($436)	$1,989	($12,115)	$14,680	($11,800)	$4,118	($28,524)
Basic and diluted net income (loss) per common share	$0.07	$0.12	($0.20)	($0.22)	($0.01)	$0.04	($0.23)	$0.28	($0.22)	$0.08	($0.57)

Disclosure_about_Oil_and_Gas_P2

Disclosure about Oil and Gas Properties and Producing Activities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'
Proved properties	$85,244	$63,821
Unproved properties	2,404	2,336
Total gross properties	87,648	66,157
Less accumulated depreciation, depletion and amortization	-14,245	-11,638
Capitalized Costs, Oil and Gas Producing Activities, Net	73,403	54,519
United States [Member]	'	'
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'
Proved properties	6,600	5,981
Unproved properties	0	24
Total gross properties	6,600	6,005
Less accumulated depreciation, depletion and amortization	-3,887	-3,650
Capitalized Costs, Oil and Gas Producing Activities, Net	2,713	2,355
Poland [Member]	'	'
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'
Proved properties	78,644	57,840
Unproved properties	2,404	2,312
Total gross properties	81,048	60,152
Less accumulated depreciation, depletion and amortization	-10,358	-7,988
Capitalized Costs, Oil and Gas Producing Activities, Net	$70,690	$52,164

Disclosure_about_Oil_and_Gas_P3

Disclosure about Oil and Gas Properties and Producing Activities (Details 1) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'
Acquisition of unproved properties	$1,043	$135	$669
Exploration costs	38,000	32,381	28,250
Development costs	9,766	3,203	3,617
Total	48,809	35,719	32,536
United States [Member]	'	'	'
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'
Acquisition of unproved properties	0	134	604
Exploration costs	303	405	1,406
Development costs	864	903	558
Total	1,167	1,442	2,568
Poland [Member]	'	'	'
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'
Acquisition of unproved properties	1,043	1	65
Exploration costs	37,697	31,976	26,844
Development costs	8,902	2,300	3,059
Total	$47,642	$34,277	$29,968

Disclosure_about_Oil_and_Gas_P4

Disclosure about Oil and Gas Properties and Producing Activities (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Oil and Gas Delivery Commitments and Contracts [Line Items]	'	'	'
Impairment of properties	$6,129	$2,562	$72

Disclosure_about_Oil_and_Gas_P5

Disclosure about Oil and Gas Properties and Producing Activities (Details 3) (Oil) (Oil [Member])	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
	MBoe	MBoe	MBoe	MBoe
United States [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Developed Reserves (BOE), Beginning of year (In thousand barrels of oil)	461	594	639	639
Proved Developed Reserves (BOE), End of year (In thousand barrels of oil)	461	594	639	639
Poland [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Developed Reserves (BOE), Beginning of year (In thousand barrels of oil)	0	0	0	0
Proved Developed Reserves (BOE), End of year (In thousand barrels of oil)	0	0	0	0

Disclosure_about_Oil_and_Gas_P6

Disclosure about Oil and Gas Properties and Producing Activities (Details 3) (Gas) (Natural Gas [Member])	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
	MMcf	MMcf	MMcf	MMcf
United States [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Developed Reserves Beginning of the year (Volume) (In million cubic feet)	0	0	0	0
Proved Developed Reserves End of the year (Volume) (In million cubic feet)	0	0	0	0
Poland [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Developed Reserves Beginning of the year (Volume) (In million cubic feet)	41,219	22,367	31,987	31,683
Proved Developed Reserves End of the year (Volume) (In million cubic feet)	41,219	22,367	31,987	31,683

Disclosure_about_Oil_and_Gas_P7

Disclosure about Oil and Gas Properties and Producing Activities (Details 4) (Oil) (Oil [Member])	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
	MBoe	MBoe	MBoe	MBoe
United States [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Undeveloped Reserves (BOE) Beginning of the years (Volume) (In thousand barrels of oil)	0	0	0	0
Proved Undeveloped Reserves (BOE) End of the years (Volume) (In thousand barrels of oil)	0	0	0	0
Poland [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Undeveloped Reserves (BOE) Beginning of the years (Volume) (In thousand barrels of oil)	0	0	0	0
Proved Undeveloped Reserves (BOE) End of the years (Volume) (In thousand barrels of oil)	0	0	0	0

Disclosure_about_Oil_and_Gas_P8

Disclosure about Oil and Gas Properties and Producing Activities (Details 4) (Gas) (Natural Gas [Member])	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
	MMcf	MMcf	MMcf	MMcf
United States [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Undeveloped Reserves Beginning of the years (Volume) (In million cubic feet)	0	0	0	0
Proved Undeveloped Reserves End of the years (Volume) (In million cubic feet)	0	0	0	0
Poland [Member]	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'
Proved Undeveloped Reserves Beginning of the years (Volume) (In million cubic feet)	793	21,754	17,649	8,276
Proved Undeveloped Reserves End of the years (Volume) (In million cubic feet)	793	21,754	17,649	8,276

Disclosure_about_Oil_and_Gas_P9

Disclosure about Oil and Gas Properties and Producing Activities (Details 5) (Oil) (Oil [Member])	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
	MBbls		MBbls		MBbls
United States [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning of year	594		639		639
Extensions or discoveries	0	[1]	0	[2]	0	[3]
Revisions of previous estimates	-84	[4]	9	[5]	56	[6]
Production	-49		-54		-56
End of year	461		594		639
Poland [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning of year	0		0		0
Extensions or discoveries	0	[1]	0	[2]	0	[3]
Revisions of previous estimates	0	[4]	0	[5]	0	[6]
Production	0		0		0
End of year	0		0		0
[1]	Volume increase in Poland attributable to new Szymanowice-1 well drilled during 2013.
[2]	Volume increase in Poland attributable to Komorze-3K well drilled during 2012.
[3]	Volume increase in Poland attributable to Lisewo-1 well drilled during 2011.
[4]	Downward oil revisions in the United States attributable to higher than previously estimated production declines. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Lisewo-1 well based on new pressure data and at the Grabowka wells due to lower than anticipated production.
[5]	Upward oil revisions in the United States attributable to lower average operating costs during 2012 compared to 2011 operating costs. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Zaniemysl and KSK wells based on new pressure data.
[6]	Upward oil revisions in the United States attributable to higher average oil prices during 2011 compared to average 2010 oil prices. Upward gas revisions in Poland due to the increase of proved reserves calculated at the Roszkow well based on new pressure data.

Recovered_Sheet1

Disclosure about Oil and Gas Properties and Producing Activities (Details 5) (Gas) (Natural Gas [Member])	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
	MMcf		MMcf		MMcf
United States [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning of year	0		0		0
Extensions or discoveries	0	[1]	0	[2]	0	[3]
Revisions of previous estimates	0	[4]	0	[5]	0	[6]
Production	0		0		0
End of year	0		0		0
Poland [Member]	'		'		'
Reserve Quantities [Line Items]	'		'		'
Beginning of year	44,121		49,636		39,959
Extensions or discoveries	3,947	[1]	2,313	[2]	12,245	[3]
Revisions of previous estimates	-1,909	[4]	-3,371	[5]	1,492	[6]
Production	-4,147		-4,457		-4,060
End of year	42,012		44,121		49,636
[1]	Volume increase in Poland attributable to new Szymanowice-1 well drilled during 2013.
[2]	Volume increase in Poland attributable to Komorze-3K well drilled during 2012.
[3]	Volume increase in Poland attributable to Lisewo-1 well drilled during 2011.
[4]	Downward oil revisions in the United States attributable to higher than previously estimated production declines. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Lisewo-1 well based on new pressure data and at the Grabowka wells due to lower than anticipated production.
[5]	Upward oil revisions in the United States attributable to lower average operating costs during 2012 compared to 2011 operating costs. Downward gas revisions in Poland due to the reduction of proved reserves calculated at the Zaniemysl and KSK wells based on new pressure data.
[6]	Upward oil revisions in the United States attributable to higher average oil prices during 2011 compared to average 2010 oil prices. Upward gas revisions in Poland due to the increase of proved reserves calculated at the Roszkow well based on new pressure data.

Recovered_Sheet2

Disclosure about Oil and Gas Properties and Producing Activities (Details 6) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'
Future cash flows	$322,757	$337,609	$373,876
Future production costs	-55,773	-49,191	-54,416
Future development costs	-17,830	-25,620	-17,240
Future income tax expense	-11,300	-30,570	-40,868
Future net cash flows	237,854	232,228	261,352
10% annual discount for estimated timing of cash flows	-86,052	-74,625	-91,785
Discounted net future cash flows	151,802	157,603	169,567
United States [Member]	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'
Future cash flows	36,077	46,449	54,036
Future production costs	-22,113	-28,171	-32,396
Future development costs	0	0	0
Future income tax expense	0	0	0
Future net cash flows	13,964	18,278	21,640
10% annual discount for estimated timing of cash flows	-5,760	-7,848	-9,377
Discounted net future cash flows	8,204	10,430	12,263
Poland [Member]	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'
Future cash flows	286,680	291,160	319,840
Future production costs	-33,660	-21,020	-22,020
Future development costs	-17,830	-25,620	-17,240
Future income tax expense	-11,300	-30,570	-40,868
Future net cash flows	223,890	213,950	239,712
10% annual discount for estimated timing of cash flows	-80,292	-66,777	-82,408
Discounted net future cash flows	$143,598	$147,173	$157,304

Recovered_Sheet3

Disclosure about Oil and Gas Properties and Producing Activities (Details 7) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
SMOG sources:	'	'	'
Balance, beginning of year	$157,603	$169,567	$127,337
Sale of oil and gas produced, net of production costs	-29,631	-30,830	-25,973
Net changes in prices and production costs	-2,456	4,385	20,809
Acquisition of minerals in place	0	0	0
Extensions and discoveries, net of future costs	6,020	4,570	38,210
Changes in estimated future development costs	-773	-7,358	-4,951
Previously estimated development costs incurred during the year	8,902	2,277	3,059
Revisions in previous quantity estimates	-9,210	-13,508	6,060
Accretion of discount	15,760	16,957	12,734
Net change in income taxes	13,495	5,769	-7,384
Changes in rates of production and other	-7,908	5,774	-334
Balance, end of year	$151,802	$157,603	$169,567

Recovered_Sheet4

Disclosure about Oil and Gas Properties and Producing Activities (Details Textual) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Oil and Gas Delivery Commitments and Contracts [Line Items]	'	'	'
Lease operating expenses	$3,680	$3,631	$3,834
Net Cash Flows Discount Rate Percentage	10.00%	'	'
Average Prices To Calculate Year End Reserve Values (Volume)	6.82	6.6	'
Average Prices To Calculate Year End Reserve Values (BOE)	78.18	78.14	'
Poland [Member]	'	'	'
Oil and Gas Delivery Commitments and Contracts [Line Items]	'	'	'
Results of Operations, Dry Hole Costs	$6,678	$12,711	$1,328