TransAtlantic Petroleum (TAT) 10-K 13 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Mar. 07, 2014	Jun. 28, 2013
Document And Entity Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Trading Symbol	'TAT	'	'
Entity Registrant Name	'TRANSATLANTIC PETROLEUM LTD.	'	'
Entity Central Index Key	'0001092289	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Filer Category	'Accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	37,402,698	'
Entity Public Float	'	'	$147.70

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$12,881	$14,768
Accounts receivable	'	'
Oil and natural gas sales, net	30,619	34,158
Joint interest and other, net	15,348	18,192
Related party	1,004	419
Prepaid and other current assets	5,072	2,339
Deferred income taxes	2,239	1,895
Assets held for sale	536	1,619
Total current assets	67,699	73,390
Oil and natural gas properties (successful efforts method)	'	'
Proved	260,857	231,498
Unproved	54,392	68,938
Equipment and other property	39,916	35,747
Property and equipment, gross	355,165	336,183
Less accumulated depreciation, depletion and amortization	-104,193	-80,031
Property and equipment, net	250,972	256,152
Other long-term assets:	'	'
Other assets	8,880	8,195
Note receivable - related party	11,500	11,500
Goodwill	7,535	9,021
Total other assets	27,915	28,716
Total assets	346,586	358,258
Current liabilities:	'	'
Accounts payable	16,712	12,864
Accounts payable - related party	23,090	15,634
Accrued liabilities	20,658	29,972
Derivative liabilities	3,737	3,908
Asset retirement obligations	610	818
Loan payable	43,284	'
Liabilities held for sale	7,559	8,416
Total current liabilities	115,650	71,612
Long-term liabilities:	'	'
Asset retirement obligations	10,286	11,140
Accrued liabilities	6,487	7,548
Deferred income taxes	16,134	16,483
Loan payable	26,482	32,766
Derivative liabilities	4,230	4,882
Total long-term liabilities	63,619	72,819
Total liabilities	179,269	144,431
Commitments and contingencies	'	'
Shareholders' equity:	'	'
Common shares, $0.10 par value, 100,000,000 shares authorized, 37,340,206 issued and outstanding as of December 31, 2013 and 36,874,859 as of December 31, 2012	3,734	3,687
Additional paid-in capital	542,091	537,962
Accumulated other comprehensive loss	-64,985	-28,012
Accumulated deficit	-313,523	-299,810
Total shareholders' equity	167,317	213,827
Total liabilities and shareholders' equity	$346,586	$358,258

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Statement Of Financial Position [Abstract]	'	'
Common shares, par value	$0.10	$0.10
Common shares, shares authorized	100,000,000	100,000,000
Common shares, issued	37,340,206	36,874,859
Common shares, outstanding	37,340,206	36,874,859

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Loss) (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 natural gas sales	$127,270	$134,113	$124,162
Sales of purchased natural gas	2,581	7,882	2,668
Other	976	1,913	2,075
Total revenues	130,827	143,908	128,905
Costs and expenses:	'	'	'
Production	18,602	17,804	18,475
Exploration, abandonment and impairment	27,333	39,993	60,952
Costs of purchased natural gas	2,247	7,694	2,645
Seismic and other exploration	14,009	5,040	11,542
Revaluation of contingent consideration	-5,000	'	6,000
General and administrative	29,020	33,947	36,305
Depreciation, depletion and amortization	41,322	28,215	39,008
Accretion of asset retirement obligations	508	710	1,142
Total costs and expenses	128,041	133,403	176,069
Operating income (loss)	2,786	10,505	-47,164
Other (expense) income:	'	'	'
Interest and other expense	-3,929	-8,340	-13,665
Interest and other income	1,340	2,418	1,089
Loss on commodity derivative contracts	-2,698	-5,548	-8,426
Foreign exchange (loss) gain	-9,663	1,083	-11,973
Total other expense	-14,950	-10,387	-32,975
(Loss) income from continuing operations before income taxes	-12,164	118	-80,139
Current income tax expense	-128	-4,674	-2,386
Deferred income tax (expense) benefit	-979	-1,817	4,951
Net (loss) income from continuing operations	-13,271	-6,373	-77,574
Loss from discontinued operations before income taxes	-442	-5,083	-39,114
Gain on disposal of discontinued operations	'	35,999	'
Income tax provision	'	-8,297	-4,255
Net (loss) income from discontinued operations	-442	22,619	-43,369
Net (loss) income	-13,713	16,246	-120,943
Other comprehensive (loss) income:	'	'	'
Foreign currency translation adjustment	-36,973	22,224	-52,069
Comprehensive (loss) income	($50,686)	$38,470	($173,012)
Basic net income (loss) per common share:	'	'	'
Continuing operations	($0.36)	($0.17)	($2.18)
Discontinued operations	($0.01)	$0.62	($1.22)
Weighted average common shares outstanding	37,069	36,742	35,597
Diluted net income (loss) per common share:	'	'	'
Continuing operations	($0.36)	($0.17)	($2.18)
Discontinued operations	($0.01)	$0.62	($1.22)
Weighted average common and common equivalent shares outstanding	37,069	36,742	35,597

Consolidated_Statements_of_Equ

Consolidated Statements of Equity (USD $)	Total	Common Shares [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Loss [Member]	Accumulated Deficit [Member]
In Thousands, except Share data
Beginning balance at Dec. 31, 2010	$276,057	$3,364	$465,973	$1,833	($195,113)
Beginning balance, shares at Dec. 31, 2010	'	33,644,000	'	'	'
Issuance of common shares	66,037	274	65,763	'	'
Issuance of common shares (in shares)	'	2,742,000	'	'	'
Exercise of warrants	96	1	95	'	'
Exercise of warrants (in shares)	'	8,000	'	'	'
Exercise of stock options	628	8	620	'	'
Exercise of stock options (in shares)	84,000	85,000	'	'	'
Issuance of restricted stock units	'	11	-11	'	'
Issuance of restricted stock units, shares	'	100,000	'	'	'
Tax withholding on restricted stock units	-210	'	-210	'	'
Share-based compensation	1,677	'	1,677	'	'
Foreign currency translation adjustment	-52,069	'	'	-52,069	'
Net (loss) income	-120,943	'	'	'	-120,943
Ending balance at Dec. 31, 2011	171,273	3,658	533,907	-50,236	-316,056
Ending balance, shares at Dec. 31, 2011	'	36,579,000	'	'	'
Issuance of common shares (in shares)	'	'	'	'	'
Exercise of stock options	664	8	656	'	'
Exercise of stock options (in shares)	81,000	81,000	'	'	'
Issuance of restricted stock units	'	21	-21	'	'
Issuance of restricted stock units, shares	'	215,000	'	'	'
Tax withholding on restricted stock units	-147	'	-147	'	'
Share-based compensation	3,567	'	3,567	'	'
Foreign currency translation adjustment	22,224	'	'	22,224	'
Net (loss) income	16,246	'	'	'	16,246
Ending balance at Dec. 31, 2012	213,827	3,687	537,962	-28,012	-299,810
Ending balance, shares at Dec. 31, 2012	'	36,875,000	'	'	'
Issuance of common shares	2,500	35	2,465	'	'
Issuance of common shares (in shares)	'	351,000	'	'	'
Exercise of stock options (in shares)	'	'	'	'	'
Issuance of restricted stock units	'	12	-12	'	'
Issuance of restricted stock units, shares	'	114,000	'	'	'
Tax withholding on restricted stock units	-40	'	-40	'	'
Share-based compensation	1,716	'	1,716	'	'
Foreign currency translation adjustment	-36,973	'	'	-36,973	'
Net (loss) income	-13,713	'	'	'	-13,713
Ending balance at Dec. 31, 2013	$167,317	$3,734	$542,091	($64,985)	($313,523)
Ending balance, shares at Dec. 31, 2013	'	37,340,000	'	'	'

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
Operating activities:	'	'	'
Net (loss) income	($13,713)	$16,246	($120,943)
Adjustment for net loss (income) from discontinued operations	442	-22,619	43,369
Net loss from continuing operations	-13,271	-6,373	-77,574
Adjustments to reconcile net loss to net cash provided by operating activities from continuing operations:	'	'	'
Share-based compensation	1,716	2,559	1,212
Foreign currency loss	8,620	3,843	14,690
Loss on commodity derivative contracts	2,698	5,548	8,426
Cash settlement on commodity derivative contracts	-3,521	-3,829	-4,854
Amortization of loan financing costs	510	1,991	1,630
Deferred income tax expense (benefit)	979	1,817	-4,951
Inventory write down	'	1,390	'
Amortization of warrants - related party	'	'	1,972
Exploration, abandonment and impairment	27,333	39,993	60,952
Depreciation, depletion and amortization	41,322	28,215	39,008
Accretion of asset retirement obligations	508	710	1,142
Revaluation of contingent consideration	-5,000	'	6,000
Changes in operating assets and liabilities, net of effect of acquisitions:	'	'	'
Accounts receivable	-2,353	-6,872	-4,985
Prepaid expenses and other assets	-34	-1,149	-4,492
Accounts payable and accrued liabilities	9,269	1,503	21,145
Net cash provided by operating activities from continuing operations	68,776	69,346	59,321
Net cash used in operating activities from discontinued operations	-1,426	-25,769	-10,602
Net cash provided by operating activities	67,350	43,577	48,719
Investing activities:	'	'	'
Acquisitions, net of cash	'	'	-747
Additions to oil and natural gas properties	-94,266	-70,189	-77,027
Additions to equipment and other properties	-10,653	-668	-2,648
Restricted cash	-190	949	5,132
Net cash used in investing activities from continuing operations	-105,109	-69,908	-75,290
Net cash provided by (used in) investing activities from discontinued operations	1,016	156,149	-4,761
Net cash (used in) provided by investing activities	-104,093	86,241	-80,051
Financing activities:	'	'	'
Exercise of stock options and warrants	'	664	722
Tax withholding on restricted stock units	-40	-147	-210
Loan proceeds	66,785	25,967	35,967
Loan proceeds - related party	'	11,000	'
Loan repayment	-29,785	-78,931	-18,024
Loan repayment - related party	'	-84,000	'
Loan financing costs	'	-250	'
Net cash provided by (used in) financing activities from continuing operations	36,960	-125,697	18,455
Net cash used in financing activities from discontinued operations	'	-5,049	-5,068
Net cash provided by (used in) financing activities	36,960	-130,746	13,387
Effect of exchange rate changes on cash	-2,104	580	-1,615
Net decrease in cash and cash equivalents	-1,887	-348	-19,560
Cash and cash equivalents, beginning of year	14,768	15,116	34,676
Cash and cash equivalents, end of year	12,881	14,768	15,116
Supplemental disclosures:	'	'	'
Cash paid for interest	3,091	6,946	10,106
Cash paid for income taxes	2,387	5,596	7,729
Supplemental non-cash investing and financing activities:	'	'	'
Note receivable - related party from sale of oilfield services business	'	11,500	'
Issuance of common shares for acquisitions	'	'	66,037
Repayment of short-term credit facility from refinancing	'	'	30,000
Issuance of common shares - amendment to purchase agreement	$2,500	'	'

General

General	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
General	'
	1. General
	Nature of operations
	TransAtlantic Petroleum Ltd. (together with its subsidiaries, “we,” “us,” “our,” the “Company” or “TransAtlantic”) is an international oil and natural gas company engaged in acquisition, exploration, development and production. We have focused our operations in countries that have established yet underexplored petroleum systems, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates and tax rates to exploration and production companies. As of December 31, 2013, we held interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of March 1, 2014, approximately 40% of our outstanding common shares were beneficially owned by N. Malone Mitchell 3rd, our chief executive officer and chairman of our board of directors.
	Basis of presentation
	Our consolidated financial statements are expressed in U.S. Dollars and have been prepared by management in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”). All amounts in these notes to the consolidated financial statements are in U.S. Dollars unless otherwise indicated. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews estimates, including those related to fair value measurements associated with acquisitions and financial derivatives, the recoverability and impairment of long-lived assets and goodwill, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.
	Revision of prior period financial statements
	During the three months ended March 31, 2013, we identified and corrected errors previously reported on our consolidated statements of cash flows. As a result, we increased the “Exploration, abandonment and impairment” sub-caption, which is an adjustment to reconcile net income (loss) to net cash provided by operating activities, and increased the cash used in investing activities related to “Additions to oil and natural gas properties” by $17.4 million and $8.3 million for the years ended December 31, 2012 and 2011, respectively, as we previously did not include the cash portion of additions to oil and natural gas properties in investing activities for dry hole expenses that were recognized in the same period as the related cash disbursed. These amounts had also been excluded from the adjustment to reconcile net income (loss) to net cash provided by operating activities.
	We assessed the materiality of the errors in accordance with the U.S. Securities and Exchange Commission (the “SEC”) guidance on considering the effects of prior period misstatements based on an analysis of quantitative and qualitative factors. Based on this analysis, we determined that the errors were immaterial to each of the prior reporting periods affected and, therefore, amendments of reports previously filed with the SEC were not required. Accordingly, we have reflected the correction of these prior period errors in the periods in which they originated and revised our consolidated statement of cash flows for the years ended December 31, 2012 and 2011 in this Annual Report on Form 10-K.
	The following shows the effect of the out-of-period errors on our consolidated statements of cash flows for the years ended December 31, 2012 and 2011 (in thousands):
		As Reported			Correction			As Revised
	For the year ended December 31, 2012
	Operating activities:
	Exploration, abandonment and impairment	$	22,617		$	17,376		$	39,993
	Net cash provided by operating activities from continuing operations		51,970			17,376			69,346
	Net cash provided by operating activities		26,201			17,376			43,577
	Investing activities:
	Additions to oil and natural gas properties		(52,813	)		(17,376	)		(70,189	)
	Net cash used in investing activities from continuing operations		(52,532	)		(17,376	)		(69,908	)
	Net cash provided by (used in) investing activities	$	103,617		$	(17,376	)	$	86,241
	For the year ended December 31, 2011
	Operating activities:
	Exploration, abandonment and impairment	$	52,638		$	8,314		$	60,952
	Net cash provided by operating activities from continuing operations		51,007			8,314			59,321
	Net cash provided by operating activities		40,405			8,314			48,719
	Investing activities:
	Additions to oil and natural gas properties		(68,713	)		(8,314	)		(77,027	)
	Net cash used in investing activities from continuing operations		(66,976	)		(8,314	)		(75,290	)
	Net cash used in investing activities	$	(71,737	)	$	(8,314	)	$	(80,051	)

Significant_accounting_policie

Significant accounting policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant accounting policies	'
	2. Significant accounting policies
	Basis of preparation
	Our reporting standard for the presentation of our consolidated financial statements is U.S. GAAP. The consolidated financial statements include the accounts of the Company and all majority owned, controlled subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation.
	Reverse stock split
	On March 4, 2014, the Company’s shareholders approved a 1-for-10 reverse stock split, which became effective March 6, 2014. Pursuant to the reverse stock split, all shareholders of record received one common share for each ten common shares owned (subject to minor adjustments as a result of fractional shares). The reverse stock split reduced the issued and outstanding common shares from 374,026,984 to 37,402,698. U.S. GAAP requires that the reverse stock split be applied retrospectively to all periods presented. As a result, all common share transactions described herein have been adjusted to reflect the 1-for-10 reverse stock split.
	Cash and cash equivalents
	Cash and cash equivalents include term deposits and investments with original maturities of three months or less at the date of acquisition. 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 and marketable securities at the time of purchase and reevaluate such designation at each balance sheet date.
	Commodity derivative instruments
	Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 815, Derivatives and Hedging (“ASC 815”), requires derivative instruments to be recognized as either assets or liabilities in the balance sheet at fair value. We do not designate our derivative financial instruments as hedging instruments and, as a result, we recognize the change in a derivative contract’s fair value currently in earnings as a component of other (expense) income.
	Fair value measurements
	We follow ASC 820, Fair Value Measurements and Disclosures (“ASC 820”). This standard defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. ASC 820 does not require any new fair value measurements, but applies to assets and liabilities that are required to be recorded at fair value under other accounting standards.
	ASC 820 characterizes inputs used in determining fair value according to a hierarchy that prioritizes those inputs based upon the degree to which they are observable. The three levels of the fair value measurement hierarchy are as follows:
		Level 1:	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities.
		Level 2:	Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.
		Level 3:	Measured based on prices or valuation models that required inputs that are both significant to the fair value measurement and less observable for objective sources (i.e., supported by little or no market activity).
	As required by ASC 820, financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values takes into account the market for our financial assets and liabilities, the associated credit risk and other factors as required by ASC 820. We consider active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
	Foreign currency remeasurement and translation
	The functional currency of our subsidiaries in Turkey, Bulgaria, Romania, and Morocco is the New Turkish Lira (“TRY”), the Bulgarian Lev, the Romanian New Leu and the Moroccan Dirham, respectively. We follow ASC 830, Foreign Currency Matters (“ASC 830”). ASC 830 requires the assets, liabilities, and results of operations of a foreign operation to be measured using the functional currency of that foreign operation. Exchange gains or losses from remeasuring transactions and monetary accounts in a currency other than the functional currency are included in earnings.
	For certain subsidiaries, translation adjustments result from the process of translating the functional currency of subsidiary financial statements into the U.S. Dollar reporting currency. These translation adjustments are reported separately and accumulated in the consolidated balance sheets as a component of accumulated other comprehensive loss.
	Oil and natural gas properties
	In accordance with the successful efforts method of accounting for oil and natural gas properties, costs of productive wells, developmental dry holes and productive leases are capitalized into appropriate groups of properties based on geographical and geological similarities. Acquisition costs of proved properties are amortized using the unit-of-production method based on total proved reserves, and exploration well costs and additional development costs are amortized using the unit-of-production method based on proved developed reserves. Proceeds from the sale of properties are credited to property costs, and a gain or loss is recognized when a significant portion of an amortization base is sold or abandoned.
	Exploration costs, such as exploratory geological and geophysical costs, delay rentals and exploration overhead, are charged to expense as incurred. Exploratory drilling costs, including the cost of stratigraphic test wells, are initially capitalized but charged to exploration expense if and when the well is determined to be non-productive. The determination of an exploratory well’s ability to produce must be made within one year from the completion of drilling activities. The acquisition costs of unproved acreage are initially capitalized and are carried at cost, net of accumulated impairment provisions, until such leases are transferred to proved properties or charged to exploration expense as impairments of unproved properties.
	Equipment and other property
	Equipment and other property are stated at cost, and inventory is stated at weighted average cost which does not exceed replacement cost. Depreciation is calculated using the straight-line method over the estimated useful lives (ranging from 3 to 7 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 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 earnings.
	Impairment of long-lived assets
	We follow the provisions of ASC 360, Property, Plant, and Equipment (“ASC 360”). ASC 360 requires that our long-lived assets be assessed for potential impairment of their carrying values whenever events or changes in circumstances indicate such impairment may have occurred. Proved oil and natural gas properties are evaluated by field for potential impairment. An impairment on proved properties is recognized when the estimated undiscounted future net cash flows of a field are less than its carrying value. If an impairment occurs, the carrying value of the impaired field is reduced to its estimated fair value, which is generally estimated using a discounted cash flow approach.
	Unproved oil and natural gas properties do not have producing properties and are valued on acquisition by management, with the assistance of an independent expert when necessary. As reserves are proved through the successful completion of exploratory wells, the cost is transferred to proved properties. The cost of the remaining unproved basis is periodically evaluated by management to assess whether the value of a property has diminished. To do this assessment, management considers (i) estimated potential reserves and future net revenues from an independent expert, (ii) the Company’s history in exploring the area, (iii) the Company’s future drilling plans per its capital drilling program prepared by the Company’s reservoir engineers and operations management and (iv) other factors associated with the area. Impairment is taken on the unproved property value if it is determined that the costs are not likely to be recoverable. The valuation is subjective and requires management to make estimates and assumptions which, with the passage of time, may prove to be materially different from actual results.
	Goodwill
	In accordance with ASC 350, Intangibles-Goodwill and Other (“ASC 350”), goodwill is not amortized, but is tested for impairment on an annual basis at December 31, or more frequently as impairment indicators arise. ASC 350 permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. We assessed the qualitative factors at December 31, 2013 and, based upon the results of the qualitative assessment, we determined that it was not necessary to perform the two-step goodwill impairment test and that our goodwill was not impaired. All of our goodwill is attributable to our Turkey operating segment.
	Joint interest activities
	Certain of our exploration, development and production activities are conducted jointly with other entities and, accordingly, the consolidated financial statements reflect only our proportionate interest in such activities.
	Asset retirement obligations
	We recognize a liability for the fair value of all legal obligations associated with the retirement of tangible, long-lived assets and capitalize an equal amount as a cost of the asset. The cost associated with the abandonment obligation is included in the computation of depreciation, depletion and amortization. The liability accretes until we settle the obligation. We use a credit-adjusted risk-free interest rate in our calculation of asset retirement obligations.
	Revenue recognition
	Revenue from the sale of crude oil and natural gas is recognized upon delivery to the purchaser when title passes. During the years ended December 31, 2013, 2012 and 2011, we sold $87.2 million, $91.8 million and $84.3 million, respectively, of oil to Türkiye Petrol Rafinerileri A.Ş. (“TUPRAS”), a privately owned oil refinery in Turkey, which represented approximately 66.7%, 63.8% and 65.3% of our total revenues, respectively.
	Share-based compensation
	We follow ASC 718, Compensation—Stock Compensation (“ASC 718”), which requires the measurement and recognition of compensation expense for all share-based payment awards, including restricted stock units, based on estimated grant date fair values. Restricted stock units are valued using the market price of our common shares on the date of grant. We record compensation expense, net of estimated forfeitures, over the requisite service period.
	Income taxes
	We follow the asset and liability method prescribed by ASC 740, Income Taxes (“ASC 740”). Under this method of accounting for income taxes, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. Under ASC 740, the effect on deferred tax assets and liabilities of a change in enacted tax rates is recognized in earnings in the period that includes the enactment date.
	In connection with our acquisition Amity Oil International Pty Ltd (“Amity”) and Petrogas Petrol Gaz ve Petrokimya Ürünleri Inşaat Sanayi ve Ticaret A.Ş. (“Petrogas”) in August 2010, at December 31, 2012, we recognized a liability due to an uncertain tax position related to the transfer of Petrogas shares to Amity prior to the acquisition (see Note 11). We do not believe there will be any material changes in our unrecognized tax positions over the next twelve months. Our policy is that we recognize interest and penalties accrued on any unrecognized tax positions as a component of income tax expense.
	We are a Bermuda exempted company, and under current Bermuda law, we are not subject to tax on profits, income or dividends, nor is there any capital gains tax applicable to us in Bermuda.
	Comprehensive income
	ASC 220, Comprehensive Income, establishes standards for reporting and displaying comprehensive income and its components (revenue, expenses, gains and losses) in a full set of general-purpose financial statements.
	Business combinations
	We follow ASC 805, Business Combinations (“ASC 805”), and ASC 810-10-65, Consolidation (“ASC 810-10-65”). ASC 805 requires most identifiable assets, liabilities, non-controlling interests, and goodwill acquired in a business combination to be recorded at “fair value.” The statement applies to all business combinations, including combinations among mutual entities and combinations by contract alone. Under ASC 805, all business combinations are accounted for by applying the acquisition method.
	Per share information
	Basic per share amounts are calculated using the weighted average common shares outstanding during the year, excluding unvested restricted stock units. We use the treasury stock method to determine the dilutive effect of stock options and other dilutive instruments. Under the treasury stock method, only “in the money” dilutive instruments impact the diluted calculations in computing diluted earnings per share. Diluted calculations reflect the weighted average incremental common shares that would be issued upon exercise of dilutive options assuming the proceeds would be used to repurchase shares at average market prices for the period.

New_accounting_pronouncements

New accounting pronouncements	12 Months Ended
	Dec. 31, 2013
Accounting Changes And Error Corrections [Abstract]	'
New accounting pronouncements	'
	3. New accounting pronouncements
	In February 2013, FASB issued ASU 2013-02, New Disclosures for Items Reclassified Out of Accumulated Other Comprehensive Income (“ASU 2013-02”). ASU 2013-02 requires reclassification adjustments for items that are reclassified out of accumulated other comprehensive income to net income to be presented in the statements where the components of net income and the components of other comprehensive income are presented or in the footnotes to the financial statements. Additionally, the amendment requires cross-referencing to other disclosures currently required for other reclassification items. The amendments were effective for interim and annual reporting periods beginning after December 15, 2012. We adopted the provisions of ASU 2013-02 as of January 1, 2013. The adoption of ASU 2013-02 did not have a material impact on our consolidated financial statements.
	We have reviewed 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 current or future earnings or operations.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Acquisitions	'
	4. Acquisitions
	TBNG
	On June 7, 2011, TransAtlantic Worldwide, Ltd. (“TransAtlantic Worldwide”) acquired Thrace Basin Natural Gas (Turkiye) Corporation (“TBNG”) in exchange for cash consideration of $10.5 million and the issuance of 1,850,000 of our common shares (at a deemed price of $20.50 per common share). Of the $10.5 million cash consideration, $10.0 million was paid in November 2010 as an option fee and applied to the purchase price. We engaged independent valuation experts to assist in the determination of the fair value of the assets and liabilities acquired in the acquisition. The following tables summarize the consideration paid in the acquisition and the final recognized amounts of assets acquired and liabilities assumed that have been recognized at the acquisition date:
	Consideration:
			(in thousands)
	Cash consideration, net of purchase price adjustments		$	10,504
	Issuance of 1,850,000 common shares			37,925
	Fair value of total consideration transferred		$	48,429
	Acquisition-Related Costs:
	Included in general and administrative expenses on our consolidated statements of comprehensive income (loss) for the year ended December 31, 2011		$	1,013
	Recognized Amounts of Identifiable Assets Acquired and Liabilities Assumed at Acquisition:
	Assets:
	Cash		$	1,845
	Accounts receivable			19,997
	Restricted cash			4,931
	Total financial assets			26,773
	Other current assets, consisting primarily of prepaid expenses			3,272
	Deferred tax asset			722
	Oil and natural gas properties:
	Proved properties			14,526
	Unproved properties			16,131
	Land and buildings			2,601
	Drilling services equipment and vehicles			19,512
	Total oil and natural gas properties and other equipment			52,770
	Liabilities:
	Accounts payable, consisting of normal trade obligations			5,960
	Other current liabilities			5,596
	Asset retirement obligation			6,480
	Deferred tax liability			2,523
	Bank loans			14,549
	Total liabilities			35,108
	Total identifiable net assets		$	48,429
	As of the date of acquisition, the fair value of the accounts receivable that were acquired was $20.0 million, consisting of a gross amount of $23.5 million, of which $3.5 million is not expected to be collected.
	We finalized our purchase accounting in December 2011, resulting in additional accrued liabilities, increases in unproved properties and adjustments to deferred tax liabilities.
	The results of operations of TBNG are included in our consolidated statement of comprehensive income (loss) beginning June 7, 2011. The revenues and loss of TBNG included in our consolidated statement of comprehensive income (loss) for the year ended December 31, 2011 were:
			Revenue			Loss
			(in thousands)
	Actual from June 7, 2011 through December 31, 2011		$	13,466		$	(4,651	)
	Direct
	On February 18, 2011, TransAtlantic Worldwide acquired Direct Petroleum Morocco, Inc. (“Direct Morocco”) and Anschutz Morocco Corporation (“Anschutz”), and our wholly owned subsidiary TransAtlantic Petroleum Cyprus Limited acquired Direct Petroleum Bulgaria EOOD (“Direct Bulgaria”) pursuant to a Purchase Agreement (the “Purchase Agreement”) with Direct Petroleum, Inc. (“Direct”), for cash consideration of $2.4 million and the issuance of 892,448 of our common shares (at a deemed price of $31.50 per common share) to Direct, in a private placement, for total consideration of $34.5 million. At the time of the acquisition, Direct Morocco and Anschutz owned a 50% working interest in the Ouezzane-Tissa and Asilah exploration permits in Morocco, and Direct Bulgaria owned 100% of the working interests in the A-Lovech and Aglen exploration permits in Bulgaria.
	The following tables summarize the consideration paid in the acquisition of Direct Morocco, Anschutz and Direct Bulgaria and the final recognized amounts of assets acquired and liabilities assumed which have been recognized at the acquisition date:
	Consideration:
			(in thousands)
	Cash consideration, net of purchase price adjustments		$	2,408
	Issuance of 892,448 common shares			28,112
	Contingent consideration liabilities			4,000
	Fair value of total consideration transferred		$	34,520
	The Purchase Agreement provided that if certain post-closing milestones were achieved, we would issue additional consideration to Direct equal to: (i) $10.0 million worth of our common shares if the Deventci-R2 well in Bulgaria was a commercial success and (ii) $10.0 million worth of our common shares if Direct Bulgaria received a production concession for a specified area in Bulgaria. The fair value of these contingent consideration liabilities represents our best estimate of the amounts to be paid as additional consideration. Subsequent changes in the fair value of the contingent consideration liabilities are reflected in our consolidated statements of comprehensive income (loss). The fair value of these contingent consideration liabilities was $2.5 million at December 31, 2013 and $10.0 million at December 31, 2012. The change in the contingent consideration liabilities since the acquisition date is included under the caption “Revaluation of contingent consideration” on our consolidated statements of comprehensive income (loss) for the years ended December 31, 2013, 2012, and 2011. In July 2013, we amended the Purchase Agreement, which resulted in changes in the contingent consideration liability (see Note 15).
	Acquisition-Related Costs:
			(in thousands)
	Included in general and administrative expenses on our consolidated statements of comprehensive income (loss) for the year ended December 31, 2011		$	117
	Recognized Amounts of Identifiable Assets Acquired and Liabilities
	Assumed at Acquisition:
			(in thousands)
	Assets:
	Cash		$	320
	Accounts receivable			57
	Total financial assets			377
	Other current assets, consisting primarily of prepaid expenses			146
	Oil and natural gas properties:
	Proved properties			1,200
	Unproved properties			32,840
	Other equipment			79
Total oil and natural gas properties and other equipment			34,119
Liabilities:
Accounts payable, consisting of normal trade obligations			122
Total identifiable net assets		$	34,520
The results of operations of Direct Morocco, Anschutz and Direct Bulgaria are included in our consolidated statement of comprehensive income (loss) beginning February 18, 2011, the closing date of the acquisition.
The amounts of revenue and loss of Direct Morocco, Anschutz and Direct Bulgaria included in our consolidated statement of comprehensive income (loss) for the year ended December 31, 2011 are shown below:
		Revenue			Loss
		(in thousands)
Continuing operations		$	483		$	(30,749	)(1)
Discontinued operations			—			(7,021	)
Total from February 18, 2011 through December 31, 2011		$	483		$	(37,770	)
	-1	See Note 6, Property and equipment, for a discussion of the impairment of our properties in Bulgaria.
Pro forma results of operations
The following table presents the unaudited pro forma results of operations for the year ended December 31, 2011 as though the acquisitions of Direct Morocco, Anschutz, Direct Bulgaria and TBNG had occurred as of January 1, 2011 (in thousands, except per share amounts):
		2011
Total revenues		$	139,999
Loss from continuing operations before income taxes			(82,856	)
Loss from continuing operations			(80,834	)
Loss from discontinued operations			(45,071	)
Net loss			(125,905	)
Net loss per common share from continuing operations
Basic		$	(2.21	)
Diluted		$	(2.21	)
Net loss per common share from discontinued operations
Basic		$	(1.23	)
Diluted		$	(1.23	)

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2013
Goodwill And Intangible Assets Disclosure [Abstract]	'
Goodwill	'
	5. Goodwill
	Goodwill represents the excess of the purchase price of a business over the estimated fair value of the assets acquired and liabilities assumed. We have goodwill on acquisitions where we anticipated access to potential exploration and producing opportunities. All of our goodwill is attributable to our Turkey operating segment. Goodwill was as follows at December 31, 2013 and 2012:
		2013			2012
		(in thousands)
	Goodwill at January 1,	$	9,021		$	8,514
	Foreign exchange change effect		(1,486	)		507
	Goodwill at December 31,	$	7,535		$	9,021

Property_and_equipment

Property and equipment	12 Months Ended
	Dec. 31, 2013
Property Plant And Equipment [Abstract]	'
Property and equipment	'
	6. Property and equipment
	Oil and natural gas properties
	The following table sets forth the capitalized costs under the successful efforts method for oil and natural gas properties:
		December 31, 2013			December 31, 2012
		(in thousands)
	Oil and natural gas properties, proved:
	Turkey	$	260,232		$	229,462
	Bulgaria		625			2,036
	Total oil and natural gas properties, proved		260,857			231,498
	Oil and natural gas properties, unproved:
	Turkey		51,273			68,938
	Bulgaria		3,119			—
	Total oil and natural gas properties, unproved		54,392			68,938
	Gross oil and natural gas properties		315,249			300,436
	Accumulated depletion		(96,958	)		(74,099	)
	Net oil and natural gas properties	$	218,291		$	226,337
	At December 31, 2013 and 2012, we excluded $1.5 million and $1.8 million of costs, respectively, from the depletion calculation for development wells in progress and for costs on fields currently not in production.
	At December 31, 2013, the capitalized costs of our oil and natural gas properties included $35.5 million relating to acquisition costs of proved properties, which are being amortized by the unit-of-production method using total proved reserves, and $126.9 million relating to well costs, and additional development costs, which are being amortized by the unit-of-production method using proved developed reserves.
	At December 31, 2012, the capitalized costs of our oil and natural gas properties included $49.5 million relating to acquisition costs of proved properties, which are being amortized by the unit-of-production method using total proved reserves, and $105.3 million relating to well costs, and additional development costs, which are being amortized by the unit-of-production method using proved developed reserves.
	Dry hole costs
	During the years ended December 31, 2013, 2012 and 2011, we recorded $16.0 million, $24.7 million, and $26.8 million of exploratory dry hole costs, respectively. Of the $16.0 million of dry hole costs incurred during the year ended December 31, 2013, approximately $10.0 million was related to cash spent during 2013.
	Impairment and abandonment
	Unproved oil and natural gas properties that are individually significant are periodically assessed for impairment, and a loss is recognized at the time of impairment. Capitalized costs related to proved oil and natural gas properties, including wells and related equipment and facilities, are evaluated for impairment based on our analysis of undiscounted future net cash flows. If undiscounted future net cash flows are insufficient to recover the net capitalized costs related to proved properties, then we recognize an impairment charge in income equal to the difference between the carrying value and the estimated fair value of the properties. We categorize the measurement of fair value of these assets as Level 3 inputs. Estimated fair values are determined using discounted cash flow models. The discounted cash flow models include management’s estimates of future oil and natural gas production, operating and development costs, and discount rates.
	During the year ended December 31, 2013, we recorded $11.3 million in impairment and abandonment charges on our proved and unproved properties, primarily related to our Senova and Malkara licenses.
	During the year ended December 31, 2012, we recorded $6.7 million in impairment charges on our proved properties, of which $2.7 million was due to downward revisions in natural gas reserves in our Alpullu field. We recorded a $8.4 million impairment on our unproved oil and natural gas properties during the year ended December 31, 2012. Of this amount, $5.2 million was attributable to exploration license acquisition costs for the Banarli license.
	During the year ended December 31, 2011, we recorded a $30.2 million impairment on our unproved oil and natural gas properties. Of this amount, $25.9 million was attributable to our Bulgarian properties. We impaired our Bulgarian properties following the enactment by the Bulgarian Parliament of legislation which banned fracture stimulation in the Republic of Bulgaria. We also recorded $14.6 million in impairment charges on two of our proved properties in Turkey, primarily due to downward revisions in natural gas reserves in the Alpullu and Edirne fields.
	Capitalized cost greater than one year
	As of December 31, 2013, we had $2.6 million of exploratory well costs capitalized for the Kazanci-5 well, which we spud in September 2012. We recently finished a long-term pressure build up on the current completion and have identified potential pay up-hole. We are evaluating, with our partners, whether to test another unconventional zone or to move up to the conventional pay and establish production.
	Equipment and other property
	The historical cost of equipment and other property, presented on a gross basis with accumulated depreciation, is summarized as follows:
		December 31,
		2013			2012
		(in thousands)
	Other equipment	$	2,678		$	2,013
	Inventory		24,318			20,517
	Gas gathering system and facilities		4,485			5,369
	Vehicles		321			131
	Leasehold improvements, office equipment and software		8,114			7,717
	Gross equipment and other property		39,916			35,747
	Accumulated depreciation		(7,235	)		(5,932	)
	Net equipment and other property	$	32,681		$	29,815
	We classify our materials and supply inventory, including steel tubing and casing, as a long-term asset because such materials will ultimately be classified as a long-term asset when the material is used in the drilling of a well.
	At December 31, 2013, we excluded $24.3 million of inventory and $0.7 million of software from depreciation, as the inventory and software had not been placed into service. At December 31, 2012, we excluded $20.5 million of inventory from depreciation as the inventory had not been placed into service.

Commodity_derivative_instrumen

Commodity derivative instruments	12 Months Ended
	Dec. 31, 2013
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Commodity derivative instruments	'
	7. Commodity derivative instruments
	We use collar derivative contracts to economically hedge against the variability in cash flows associated with the forecasted sale of a portion of our future oil production. We have not designated the derivative contracts as hedges for accounting purposes, and accordingly, we record the derivative contracts at fair value and recognize changes in fair value in earnings as they occur.
	To the extent that a legal right of offset exists, we net the value of our derivative contracts with the same counterparty in our consolidated balance sheets. All of our oil derivative contracts are settled based upon Brent crude oil pricing. We recognize gains and losses related to these contracts on a fair value basis in our consolidated statements of comprehensive income (loss) under the caption “Loss on commodity derivative contracts.” Settlements of derivative contracts are included in operating activities on our consolidated statements of cash flows under the caption “Cash settlement on commodity derivative contracts.” We are required under our amended and restated credit facility (the “Amended and Restated Credit Facility”) with BNP Paribas (Suisse) SA (“BNP Paribas”) and Standard Bank Plc (“Standard Bank”), to hedge between 30% and 75% of our anticipated production volumes in the Selmo and Arpatepe oil fields in Turkey.
	During the years ended December 31, 2013, 2012 and 2011, we recorded net losses on commodity derivative contracts of $2.7 million, $5.5 million, and $8.4 million respectively.
	At December 31, 2013, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below:
	Fair Value of Derivative Instruments as of December 31, 2013
	Type	Period				Quantity				Weighted				Weighted				Estimated Fair
						(Bbl/day)				Average				Average				Value of Liability
										Minimum				Maximum Price
										Price (per Bbl)				(per Bbl)
																		(in thousands)
	Collar		January 1, 2014—December 31, 2014				622			$	80.83			$	118.07			$	(387	)
																		$	(387	)
				Collars												Additional Call
	Type	Period		Quantity				Weighted				Weighted				Weighted				Estimated Fair
				(Bbl/day)				Average				Average				Average				Value of
								Minimum				Maximum				Maximum				Liability
								Price				Price				Price
								(per Bbl)				(per Bbl)				(per Bbl)
																				(in thousands)
	Three-way collar contract	January 1, 2014—December 31, 2014			726			$	85			$	97.13			$	162.13			$	(3,350	)
	Three-way collar contract	January 1, 2015—December 31, 2015			1,016			$	85			$	91.88			$	151.88				(4,230	)
																				$	(7,580	)
	At December 31, 2012, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below:
	Fair Value of Derivative Instruments as of December 31, 2012
	Type	Period				Quantity				Weighted				Weighted				Estimated Fair
						(Bbl/day)				Average				Average				Value of
										Minimum				Maximum Price				Liability
										Price (per Bbl)				(per Bbl)
																		(in thousands)
	Collar		January 1, 2013—December 31, 2013				775			$	82.26			$	121.36			$	(253	)
	Collar		January 1, 2014—December 31, 2014				622			$	80.83			$	118.07				(292	)
																		$	(545	)
						Collars												Additional Call
	Type	Period				Quantity				Weighted				Weighted				Weighted				Estimated Fair
						(Bbl/day)				Average				Average				Average				Value of
										Minimum				Maximum				Maximum				Liability
										Price				Price				Price
										(per Bbl)				(per Bbl)				(per Bbl)
																						(in thousands)
	Three-way collar contract		January 1, 2013—December 31, 2013				831			$	85			$	97.13			$	162.13			$	(3,655	)
	Three-way collar contract		January 1, 2014—December 31, 2014				726			$	85			$	97.13			$	162.13				(2,150	)
	Three-way collar contract		January 1, 2015—December 31, 2015				1,016			$	85			$	91.88			$	151.88				(2,440	)
																						$	(8,245	)

Asset_retirement_obligations

Asset retirement obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset retirement obligations	'
	8. Asset retirement obligations
	As part of our development of oil and natural gas properties, we incur asset retirement obligations (“ARO”). Our ARO results from our responsibility to abandon and reclaim our net share of all working interest properties and facilities. At December 31, 2013, the net present value of our total ARO was estimated to be $10.9 million, with the undiscounted value being $18.5 million. Total ARO at December 31, 2013 shown in the table below consists of amounts for future plugging and abandonment liabilities on our wellbores and facilities based on third-party estimates of such costs, adjusted for inflation at a rate of approximately 6.2% per annum for Turkey and 2.5% for Bulgaria. These values are discounted to present value using our credit-adjusted risk-free rate of 5.75% per annum for the years ended December 31, 2013 and 2012. The following table summarizes the changes in our ARO for the years ended December 31, 2013 and 2012:
			2013			2012
			(in thousands)
	Asset retirement obligation January 1,		$	11,958		$	13,534
	Change in estimates(1)			(7	)		(3,868	)
	Liabilities settled			(296	)		(110	)
	Foreign exchange change effect			(2,258	)		793
	Additions			991			899
	Accretion expense			508			710
	Asset retirement obligation at December 31,			10,896			11,958
	Less: current portion			610			818
	Long-term portion		$	10,286		$	11,140
		-1	For 2013 and 2012, we used cost estimates provided by third-party engineers.
	Our ARO is measured using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging costs, remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs.

Loans_payable

Loans payable	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Loans payable	'
	9. Loans payable
	As of the dates indicated, our third-party debt consisted of the following:
		December 31,		December 31,
		2013		2012
		(in thousands)
	Floating Rate Debt
	Amended and Restated Credit Facility	$	49,766	$	32,766
	TBNG credit facility (short-term)		20,000		—
	Loans payable		69,766		32,766
	Less: current portion		43,284		—
	Long-term portion	$	26,482	$	32,766
	Amended and Restated Credit Facility
	On May 18, 2011, DMLP, Ltd. (“DMLP”), TransAtlantic Exploration Mediterranean International Pty Ltd (“TEMI”), Talon Exploration, Ltd. (“Talon Exploration”), TransAtlantic Turkey, Ltd. (“TransAtlantic Turkey”) and Petrogas (collectively, and together with Amity, the “Borrowers”) entered into the Amended and Restated Credit Facility. Each of the Borrowers is our wholly owned subsidiary. In July 2011, Amity executed a joinder agreement and became a borrower under the Amended and Restated Credit Facility. The Amended and Restated Credit Facility is guaranteed by us and each of TransAtlantic Petroleum (USA) Corp. and TransAtlantic Worldwide.
	The Amended and Restated Credit Facility matures on the earlier of (i) May 18, 2016 or (ii) the last date of the borrowing base calculation period that immediately precedes the date that the semi-annual report of Standard Bank and the Borrowers determines that the aggregate amount of hydrocarbons to be produced from the borrowing base assets in Turkey are less than 25% of the amount of hydrocarbons to be produced from the borrowing base assets shown in the initial report prepared by Standard Bank and the Borrowers. The Amended and Restated Credit Facility bears various letter of credit sub-limits, including among other things, sub-limits of up to (i) $10.0 million, (ii) the aggregate available unused and uncancelled portion of the lenders’ commitments or (iii) any amount borrowed from an individual lender to the extent it exceeds the aggregate amount of such lender’s individual commitment.
	Loans under the Amended and Restated Credit Facility accrue interest at a rate of three-month LIBOR plus 5.50% per annum (5.74% at December 31, 2013). The Borrowers are also required to pay (i) a commitment fee payable quarterly in arrears at a per annum rate equal to (a) 2.20% per annum of the unused and uncancelled portion of the aggregate commitments that is less than or equal to the maximum available amount under the Amended and Restated Credit Facility, and (b) 1.10% per annum of the unused and uncancelled portion of the aggregate commitments that exceed the maximum available amount under the Amended and Restated Credit Facility and is not available to be borrowed, (ii) on the date of issuance of any letter of credit, a fronting fee in an amount equal to 0.25% of the original maximum amount to be drawn under such letter of credit and (iii) a per annum letter of credit fee for each letter of credit issued equal to the face amount of such letter of credit multiplied by (a) 1.0% for any letter of credit that is cash collateralized or backed by a standby letter of credit issued by a financial institution acceptable to Standard Bank or (b) 5.50% for all other letters of credit.
	In November 2012, we entered into an amendment to the Amended and Restated Credit Facility. The amendment, among other things, reduced the commitment fee rates and extended the first commitment reduction date from September 30, 2012 to December 31, 2013. In addition, the amendment provided for a scheduled quarterly reduction of the commitment amount beginning on December 31, 2013, when the commitment amount will be reduced to $67.5 million, and ending on March 31, 2016, when the commitment amount will reach zero.
	Availability under the Amended and Restated Credit Facility is subject to a borrowing base. The borrowing base was re-determined semi-annually on April 1st and October 1st of each year prior to September 30, 2012, and is now re-determined quarterly on January 1st, April 1st, July 1st and October 1st of each year. Following our borrowing base redetermination on October 1, 2012, the borrowing base at December 31, 2012 was $59.7 million. Following our borrowing base redetermination on October 1, 2013, the borrowing base is currently $50.6 million. In June 2012, we used a portion of the net proceeds from the sale of our oilfield services business to pay down approximately $45.2 million in outstanding indebtedness under the Amended and Restated Credit Facility.
	At December 31, 2013, we had borrowed $49.8 million under the Amended and Restated Credit Facility.
	We are currently in the process of refinancing the Amended and Restated Credit Facility. In January 2014, we executed a mandate letter with two financial institutions. We expect to complete the refinancing in the second quarter of 2014. If we are unable to complete the refinancing of our Amended and Restated Credit Facility, we would curtail certain discretionary expenditures, and believe our resulting cash flow from operations and existing cash on hand are sufficient to conduct our operations through 2014 and meet our contractual obligations.
	At December 31, 2013, we were not in compliance with Section 8.17(a) of our Amended and Restated Credit Facility, which requires the Borrowers to maintain a current ratio of not less than 1.10:1.0. The lenders have granted the Borrowers a waiver on the current ratio requirement through March 31, 2015.
	TBNG credit facility
	On June 18, 2013, TBNG entered into a 78.8 million TRY (approximately $36.9 million at December 31, 2013) unsecured line of credit with a Turkish bank, of which 60 million TRY is available in cash for TBNG and 18.8 million TRY is available in the form of non-cash bank guarantees and letters of credit for TBNG and several other of our wholly owned subsidiaries operating in Turkey. The interest rate is established at the time of each borrowing. We have made two borrowings under this credit facility, on October 9, 2013 and November 5, 2013, each of which has a one-year term at a fixed interest rate of 4.6% per annum. At maturity, we expect to renew the borrowings for one additional year at then current market interest rates. As of December 31, 2013, we had borrowed $20.0 million under this credit facility.

Shareholders_equity

Shareholders' equity	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Shareholders' equity	'
	10. Shareholders’ equity
	July 2013 share issuance
	In July 2013, we issued 351,074 common shares at a deemed price of $7.12 per common share to Direct (see Note 15).
	June 2011 share issuance
	In June 2011, we issued 1,850,000 common shares at a deemed price of $20.50 per common share in a private placement to an accredited investor in connection with the acquisition of TBNG.
	February 2011 share issuance
	In February 2011, we issued 892,448 common shares at a deemed price of $31.50 per common share in a private placement to an accredited investor in connection with the acquisition of Direct Morocco, Anschutz and Direct Bulgaria.
	Restricted stock units
	Under our 2009 Long-Term Incentive Plan (the “Incentive Plan”), we award restricted stock units (“RSUs”) and other share-based compensation to certain of our directors, officers, employees and consultants. Each RSU is equal in value to one of our common shares on the grant date. Upon vesting, an award recipient is entitled to a number of common shares equal to the number of vested RSUs. The RSU awards can only be settled in common shares. As a result, RSUs are classified as equity. At the grant date, we make an estimate of the forfeitures expected to occur during the vesting period and record compensation cost, net of the estimated forfeitures, over the requisite service period. The current forfeiture rate is estimated to be 10%.
	Under the Incentive Plan, RSUs vest over specified periods of time ranging from immediately to four years. RSUs are deemed full value awards and their value is equal to the market price of our common shares on the grant date. ASC 718 requires that the Incentive Plan be approved in order to establish a grant date. Under ASC 718, the approval date for the Incentive Plan was February 9, 2009, the date our board of directors approved the Incentive Plan.
	In connection with the sale of our oilfield services business, we accelerated the vesting of RSUs for employees of this business, and we recognized $1.0 million in share-based compensation expense during the three months ended June 30, 2012. Total share-based compensation of approximately $1.7 million and $3.6 million with respect to awards of RSUs was recorded for the years ended December 31, 2013 and 2012, respectively. As of December 31, 2013, we had approximately $1.3 million of unrecognized compensation expense related to unvested RSUs, which is expected to be recognized over a weighted average period of 1.4 years.
	The following table sets forth RSU activity for the year ended December 31, 2013:
		Number of			Weighted
		RSUs			Average Grant
		(in thousands)			Date Fair Value
					Per RSU
	Unvested RSUs outstanding at December 31, 2012		315		$	12.46
	Granted		172			7.1
	Forfeited		(62	)		10.2
	Vested		(129	)		14.53
	Unvested RSUs outstanding at December 31, 2013		296		$	8.91
	Stock option plan
	Our Amended and Restated Stock Option Plan (2006) (the “Option Plan”) terminated on June 16, 2009. All outstanding awards issued under the Option Plan remained in full force and effect. As of December 31, 2013, there were no options outstanding under the Option Plan. All options previously outstanding under the Option Plan had a five-year term.
	The fair value of stock options is determined using the Black-Scholes Model and is recognized over the service period of the stock option. All stock options are fully vested; therefore, no share-based compensation expense for stock option awards was recorded for the years ended December 31, 2013, 2012 and 2011. We did not grant any stock options during the years ended December 31, 2013, 2012 and 2011.
	Details of stock option activity for the years ended December 31, 2013, 2012 and 2011 are presented below.
		2013						2012					2011
		Number of			Weighted			Number of			Weighted		Number of			Weighted
		Options			Average			Options			Average		Options			Average
		(in thousands)			Exercise			(in thousands)			Exercise		(in thousands)			Exercise
					Price						Price					Price
					Per						Per					Per
					Share						Share					Share
	Outstanding at January 1,		16		$	12.3			114		$	9.07		211		$	8.6
	Granted		—			—			—			—		—			—
	Expired		(16	)		12.3			(17	)		10		(13	)		12.96
	Exercised		—			—			(81	)		8.24		(84	)		7.39
	Outstanding at December 31,		—		$	—			16		$	12.3		114		$	9.07
	Exercisable at December 31,		—		$	—			16		$	12.3		114		$	9.07
	Earnings per share
	We account for earnings per share in accordance with ASC Subtopic 260-10, Earnings Per Share (“ASC 260-10”). ASC 260-10 requires companies to present two calculations of earnings per share: basic and diluted. Basic earnings per common share for the years ended December 31, 2013, 2012 and 2011 equals net income divided by the weighted average shares outstanding during the periods. Weighted average shares outstanding are equal to the weighted average of all shares outstanding for the period, excluding RSUs. Diluted earnings per common share for the years ended December 31, 2013, 2012 and 2011 are computed in the same manner as basic earnings per common share after assuming the issuance of common shares for all potentially dilutive common share equivalents, which includes stock options, RSUs and warrants, whether exercisable or not. The computation of diluted earnings per common share excluded 758,586, 959,438 and 2,075,213 antidilutive common share equivalents from the years ended December 31, 2013, 2012 and 2011, respectively.
	The following table presents the basic and diluted earnings per common share computations:
		2013			2012			2011
	(in thousands, except per share amounts)
	Net loss from continuing operations	$	(13,271	)	$	(6,373	)	$	(77,574	)
	Net (loss) income from discontinued operations	$	(442	)	$	22,619		$	(43,369	)
	Basic net (loss) income per common share:
	Shares:
	Weighted average common shares outstanding		37,069			36,742			35,597
	Basic net (loss) income per common share:
	Continuing operations	$	(0.36	)	$	(0.17	)	$	(2.18	)
	Discontinued operations	$	(0.01	)	$	0.62		$	(1.22	)
	Diluted net (loss) income per common share:
	Shares:
	Weighted average common shares and common equivalent shares outstanding		37,069			36,742			35,597
	Diluted net (loss) income per common share:
	Continuing operations	$	(0.36	)	$	(0.17	)	$	(2.18	)
	Discontinued operations	$	(0.01	)	$	0.62		$	(1.22	)
	Additionally, we had a contingent liability at December 31, 2013 of approximately $2.5 million that is payable in our common shares. At the December 31, 2013 closing price of our common shares, this liability represented 294,117 common shares that could be potentially dilutive to future earnings per share calculations.

Income_taxes

Income taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income taxes	'
	11. Income taxes
	The income tax provision differs from the amount that would be obtained by applying the Bermuda statutory income tax rate of 0% for 2013, 2012 and 2011 to loss for the year as follows:
		2013			2012			2011
		(in thousands)
	Statutory tax rate		0	%		0	%		0	%
	Income (loss) from continuing operations before income taxes	$	(12,164	)	$	118		$	(80,139	)
	Increase (decrease) resulting from:
	Foreign tax rate differentials		(1,443	)		8,607			(11,173	)
	Change in valuation allowance		982			(2,026	)		6,871
	Expiration of non-capital tax loss carryovers		1,367			1,601			1,198
	Other		201			(1,691	)		539
	Total	$	1,107		$	6,491		$	(2,565	)
	The components of the net deferred income tax liability at December 31, 2013 and 2012 were as follows:
		2013			2012
		(in thousands)
	Deferred tax assets
	Unrealized derivative losses	$	1,594		$	1,758
	Timing of accruals		1,043			1,251
	Non-capital loss carryovers		25,868			28,455
	Valuation Allowance		(28,404	)		(29,059	)
	Total deferred tax assets		101			2,405
	Deferred tax liabilities
	Property and equipment	$	(13,093	)	$	(16,993	)
	Total deferred tax liabilities		(13,093	)		(16,993	)
	Net deferred tax liabilities	$	(12,992	)	$	(14,588	)
	Components of net deferred tax liabilities
	Current assets	$	2,239		$	1,895
	Non-current assets		903			—
	Non-current liabilities		(16,134	)		(16,483	)
	Net deferred tax liabilities	$	(12,992	)	$	(14,588	)
	We have accumulated losses or resource-related deductions available for income tax purposes in Turkey, Romania, Bulgaria and the United States. As of December 31, 2013, we had non-capital tax losses in Turkey of approximately 134.0 million TRY (approximately $62.8 million), which will begin expiring in 2014; non-capital tax losses in Romania of approximately 24.9 million Romanian New Leu (approximately $7.7 million), which will begin expiring in 2014; non-capital losses in Bulgaria of approximately 5.8 million Bulgarian Lev (approximately $4.1 million), which will begin expiring in 2014; and non-capital tax losses in the United States of approximately $26.1 million, which will begin expiring in 2018.
	Effective October 1, 2009, we continued to the jurisdiction of Bermuda. We have determined that no taxes were payable upon the continuance. However, our tax filing positions are still subject to review by taxation authorities who may successfully challenge our interpretation of the applicable tax legislation and regulations, with the result that additional taxes could be payable by us.
	We file income tax returns in the United States, Turkey, Romania, Bulgaria, Morocco and Cyprus, with Turkey being the only jurisdiction with significant amounts of taxes due. Income tax returns filed in Turkey for years before 2008 are no longer subject to examination. The Turkish Ministry of Finance is currently conducting tax audits on two of our Turkish subsidiaries, Amity and TBNG, for the years ended December 31, 2010 and 2012, respectively. The Turkish Ministry of Finance recently began an audit of our Turkish subsidiary, TEMI, for the year ended December 31, 2010.
	In connection with our acquisition of Amity and Petrogas in August 2010, at December 31, 2012, we recognized a liability due to an uncertain tax position related to the transfer of Petrogas shares to Amity prior to the acquisition. Pursuant to the Amity share purchase agreement, we are indemnified from any tax liability arising in Turkey or Australia as a result of the transfer of the Petrogas shares for a period of up to six years from the sale date at an amount up to 50% of the purchase price of $96.3 million and, therefore, have recorded a corresponding receivable in other long-term assets.
	As of December 31, 2013 the liability and receivable consisted of taxes of $3.3 million, penalties of $0.7 million and interest of $1.8 million. During the years ended December 31, 2013 and 2012, the Company recorded interest of $0.5 million and $1.3 million, respectively.
	As of December 31, 2013, there were no material uncertain tax positions for which the total amounts of unrecognized tax benefits will significantly increase or decrease within the next 12 months.

Segment_information

Segment information	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment information	'
	12. Segment information
	In accordance with ASC 280, Segment Reporting (“ASC 280”), we have two reportable geographic segments: Turkey and Bulgaria. Summarized financial information from continuing operations concerning our geographic segments is shown in the following tables:
			Corporate			Turkey			Bulgaria			Total
			(in thousands)
	For the year ended December 31, 2013
	Total revenues		$	—		$	130,701		$	126		$	130,827
	Production			5			18,384			213			18,602
	Exploration, abandonment and impairment			—			27,116			217			27,333
	Cost of purchased natural gas			—			2,247			—			2,247
	Seismic and other exploration			100			13,909			—			14,009
	Revaluation of contingent consideration			—			—			(5,000	)		(5,000	)
	General and administrative			12,685			16,068			267			29,020
	Depreciation, depletion and amortization			69			41,196			57			41,322
	Accretion of asset retirement obligations			—			475			33			508
	Total costs and expenses			12,859			119,395			(4,213	)		128,041
	Operating (loss) income			(12,859	)		11,306			4,339			2,786
	Interest and other expense			—			(3,929	)		—			(3,929	)
	Interest and other income			284			1,056			—			1,340
	Loss on commodity derivative contracts			—			(2,698	)		—			(2,698	)
	Foreign exchange (loss) gain			(9	)		(9,664	)		10			(9,663	)
	Income (loss) from continuing operations before income taxes			(12,584	)		(3,929	)		4,349			(12,164	)
	Income tax provision			—			(1,107	)		—			(1,107	)
	Net (loss) income from continuing operations		$	(12,584	)	$	(5,036	)	$	4,349		$	(13,271	)
	Total assets as of December 31, 2013		$	14,070		$	321,749		$	10,231		$	346,050	(1)
	Goodwill as of December 31, 2013		$	—		$	7,535		$	—		$	7,535
	Capital expenditures		$	1,003		$	96,206		$	2,742		$	99,951
	For the year ended December 31, 2012
	Total revenues		$	—		$	143,650		$	258		$	143,908
	Production			169			17,328			307			17,804
	Exploration, abandonment and impairment			285			39,708			—			39,993
	Cost of purchased natural gas			—			7,694			—			7,694
	Seismic and other exploration			304			4,726			10			5,040
	General and administrative			10,982			20,603			2,362			33,947
	Depreciation, depletion and amortization			30			28,092			93			28,215
	Accretion of asset retirement obligations			—			679			31			710
	Total costs and expenses			11,770			118,830			2,803			133,403
	Operating (loss) income			(11,770	)		24,820			(2,545	)		10,505
	Interest and other expense			(1,890	)		(6,450	)		—			(8,340	)
	Interest and other income			308			2,110			—			2,418
	Loss on commodity derivative contracts			—			(5,548	)		—			(5,548	)
	Foreign exchange gain (loss)			79			1,054			(50	)		1,083
	Income (loss) from continuing operations before income taxes			(13,273	)		15,986			(2,595	)		118
	Income tax provision			—			(6,491	)		—			(6,491	)
	Net income (loss) from continuing operations		$	(13,273	)	$	9,495		$	(2,595	)	$	(6,373	)
	Total assets as of December 31, 2012		$	14,930		$	339,752		$	1,957		$	356,639	(1)
	Goodwill as of December 31, 2012		$	—		$	9,021		$	—		$	9,021
	Capital expenditures		$	—		$	80,957		$	867		$	81,824
	For the year ended December 31, 2011
	Total revenues		$	66		$	128,356		$	483		$	128,905
	Production			359			17,484			632			18,475
	Exploration, abandonment and impairment			2			37,008			23,942			60,952
	Cost of purchased natural gas			—			2,645			—			2,645
	Seismic and other exploration			1,801			9,657			84			11,542
	Revaluation of contingent consideration			—			—			6,000			6,000
	General and administrative			14,714			21,585			6			36,305
	Depreciation, depletion and amortization			127			38,389			492			39,008
	Accretion of asset retirement obligations			—			1,131			11			1,142
	Total costs and expenses			17,003			127,899			31,167			176,069
	Operating (loss) income			(16,937	)		457			(30,684	)		(47,164	)
	Interest and other (expense) income			(6,784	)		(6,878	)		(3	)		(13,665	)
	Interest and other income			27			914			148			1,089
	Loss on commodity derivative contracts			—			(8,426	)		—			(8,426	)
	Foreign exchange loss			(23	)		(11,740	)		(210	)		(11,973	)
Loss from continuing operations before income taxes			(23,717	)		(25,673	)		(30,749	)		(80,139	)
Income tax benefit			—			2,565			—			2,565
Net loss from continuing operations		$	(23,717	)	$	(23,108	)	$	(30,749	)	$	(77,574	)
Total assets as of December 31, 2011		$	3,716		$	313,754		$	4,164		$	321,634	(1)
Goodwill as of December 31, 2011		$	—		$	8,514		$	—		$	8,514
Capital expenditures		$	—		$	117,071		$	35,369		$	152,440
-1	Excludes assets from our discontinued Moroccan operations and oilfield services business of $0.5 million, $1.6 million, and $127.2 million at December 31, 2013, 2012 and 2011, respectively.

Financial_instruments

Financial instruments	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Financial instruments	'
	13. Financial instruments
	Interest rate risk
	We are exposed to interest rate risk as a result of our variable rate short-term cash holdings and borrowings under the Amended and Restated Credit Facility.
	Foreign currency risk
	We have underlying foreign currency exchange rate exposure. Our currency exposures relate to transactions denominated in the Bulgarian Lev, European Union Euro, and TRY. We are also subject to foreign currency exposures resulting from translating the functional currency of our subsidiary financial statements into the U.S. Dollar reporting currency. We have not used foreign currency forward contracts to manage exchange rate fluctuations. At December 31, 2013, we had 22.8 million TRY (approximately $10.7 million) in cash and cash equivalents, which exposes us to exchange rate risk based on fluctuations in the value of the TRY.
	Commodity price risk
	We are exposed to fluctuations in commodity prices for oil and natural gas. Commodity prices are affected by many factors, including but not limited to, supply and demand. At December 31, 2013 and 2012, we were a party to commodity derivative contracts.
	Concentration of credit risk
	The majority of our receivables are within the oil and natural gas industry, primarily from our industry partners and from government agencies. Included in receivables are amounts due from Turkiye Petrolleri Anonim Ortakligi (“TPAO”), the national oil company of Turkey, Zorlu Dogal Gaz Ithalat Ihracat ve Toptan Ticaret A.S. (“Zorlu”), a privately owned natural gas distributor in Turkey, and TUPRAS, which purchase the majority of our oil and natural gas production. The receivables are not collateralized. To date, we have experienced minimal bad debts and have no allowance for doubtful accounts. The majority of our cash and cash equivalents are held by three financial institutions in the United States and Turkey.
	Fair value measurements
	Cash and cash equivalents, receivables, accounts payable, accrued liabilities, and the TBNG credit facility were each estimated to have a fair value approximating the carrying amount at December 31, 2013 and 2012 due to the short maturity of those instruments. Indebtedness under the Amended and Restated Credit Facility was estimated to have a fair value approximating the carrying amount at December 31, 2013 and 2012 since the interest rate is generally market sensitive.
	The financial assets and liabilities measured on a recurring basis at December 31, 2013 and 2012 consisted of our commodity derivative contracts. Fair values for options are based on counterparty market prices. The counterparties use market standard valuation methodologies incorporating market inputs for volatility and risk free interest rates in arriving at a fair value for each option contract. Prices are verified by us using analytical tools. There are no performance obligations related to the call options purchased to hedge our oil production.
	We utilize independent third-party pricing services to determine the fair values of derivative contracts. The independent third party determines fair values using models based on a range of observable market inputs, including pricing models, quoted market prices of publicly traded securities with similar duration and yield, time value, yield curve, prepayment spreads, default rates and discounted cash flow and the values for these contracts are disclosed in Level 2 of the fair value hierarchy. Generally, we obtain a single price or quote per instrument from independent third parties to assist in establishing the fair value of these contracts. We review prices received from service providers for unusual fluctuations to ensure that the prices represent a reasonable estimate of fair value.
	The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2013:
		Fair Value Measurement Classification
		Quoted Prices in		Significant Other			Significant		Total
		Active Markets for		Observable Inputs			Unobservable Inputs
		Identical Assets or		(Level 2)			(Level 3)
		Liabilities
		(Level 1)
		(in thousands)
	Liabilities:
	Commodity derivative contracts	$	—	$	(7,967	)	$	—	$	(7,967	)
	Total	$	—	$	(7,967	)	$	—	$	(7,967	)
	The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2012:
		Fair Value Measurement Classification
		Quoted Prices in		Significant Other			Significant		Total
		Active Markets for		Observable Inputs			Unobservable Inputs
		Identical Assets or		(Level 2)			(Level 3)
		Liabilities
		(Level 1)
		(in thousands)
	Liabilities:
	Commodity derivative contracts	$	—	$	(8,790	)	$	—	$	(8,790	)
	Total	$	—	$	(8,790	)	$	—	$	(8,790	)

Commitments

Commitments	12 Months Ended
	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'
Commitments	'
	14. Commitments
	Our aggregate annual commitments, other than our loans payable, as of December 31, 2013 were as follows:
			Payments Due by Year
		Total	2014	2015	2016	2017	2018	Thereafter
		(in thousands)
	Leases and other	$5,602	$2,546	$903	$299	$99	$33	$1,722
	Normal operations purchase arrangements are excluded from the table as they are discretionary or being performed under contracts which are cancelable immediately or with a 30-day notice period.
	We lease office space in Dallas, Texas, Bulgaria and Turkey. We also lease apartments in Turkey and Dallas, as well as operations yards in Turkey. Rent expense for the years ended December 31, 2013, 2012 and 2011 was $3.3 million, $3.5 million and $3.4 million, respectively.

Contingencies

Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'
Contingencies	'
	15. Contingencies
	Selmo
	We are involved in litigation with persons who claim ownership of a portion of the surface at the Selmo oil field in Turkey. These cases are being vigorously defended by TEMI and Turkish governmental authorities. We do not have enough information to estimate the potential additional operating costs we would incur in the event the purported surface owners’ claims are ultimately successful. Any adjustment arising out of the claims will be recorded when it becomes probable and measurable.
	Morocco
	In the second quarter of 2012, we were notified that the Moroccan government may seek to recover approximately $5.5 million in contractual obligations under our Tselfat exploration permit work program. In February 2013, the Moroccan government drew down our $1.0 million bank guarantee that was put in place to ensure our performance of the Tselfat exploration permit work program. Although we believe that the bank guarantee satisfies our contractual obligations, we recorded $5.0 million in accrued liabilities relating to our Tselfat exploration permit during 2012 for this contingency.
	Aglen
	In the second quarter of 2012, we were notified that the Bulgarian government may seek to recover approximately $2.0 million in contractual obligations under our Aglen exploration permit work program. Due to the Bulgarian government’s January 2012 ban on fracture stimulation and related activities, the government recognized a force majeure event under the terms of the exploration permit. Although we invoked force majeure, we have recorded $2.0 million in accrued liabilities relating to our Aglen exploration permit during 2012 for this contractual obligation.
	Direct Petroleum
	In July 2013, we entered into a second amendment (the “Amendment”) to the Purchase Agreement with Direct. Pursuant to the Amendment, we issued 351,074 common shares to Direct as partial payment of certain liquidated damages due under the Purchase Agreement. The number of shares was calculated by dividing $2.5 million by the volume weighted average price per share of our common shares on the NYSE MKT for the ten trading days prior to July 2, 2013.
	The parties also agreed that Direct is not eligible for any liquidated damages relating to the coring of the Etropole shale formation, which resulted in the reversal of the $5.0 million contingent liability recorded in 2011, which we recognized in our consolidated statement of comprehensive income (loss) under the caption “Revaluation of contingent consideration.”
	The Amendment sets forth a new obligation to drill and test the Deventci-R2 well by May 1, 2014. In the event that we do not meet the drilling and testing obligations by May 1, 2014, the Amendment requires us to issue an additional $2.5 million in common shares (the “Additional Liquidated Damages”) to Direct. As such, the $2.5 million contingent liability, recorded in 2011, remained as of December 31, 2013. In addition, the Amendment provides that we will issue $7.5 million in common shares, less the Additional Liquidated Damages, if any, if the Deventci-R2 well is a commercial success (as defined in the Purchase Agreement) on or prior to May 1, 2016. We will record any provision for this contingent consideration when it is estimable and probable. As of December 31, 2013, we did not record a contingent liability for this contingent consideration.
	Additionally, the Amendment provides that if the Bulgarian government issues a production concession over the Stefenetz Concession Area, Direct will be entitled to a payment of $10.0 million in common shares, or a pro rata amount if the production concession is less than 200,000 acres. We do not have enough information to estimate the potential contingent liability we would incur in the event the Bulgarian government issues a production concession over the Stefenetz Concession Area. Any adjustment will be recorded when it becomes probable and estimable.

Related_party_transactions

Related party transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related party transactions	'
	16. Related party transactions
	Equity transactions
	On September 1, 2010, we issued 730,000 common share purchase warrants to Dalea Partners, LP (“Dalea”) pursuant to a credit agreement with Dalea. The common share purchase warrants had an exercise price of $60.00 per share, and expired on September 1, 2013. Dalea is an affiliate of Mr. Mitchell.
	Sale of oilfield services business
	On June 13, 2012, we closed the sale of our oilfield services business, which was substantially comprised of our wholly owned subsidiaries Viking International Limited (“Viking International”) and Viking Geophysical Services, Ltd. (“Viking Geophysical”), to a joint venture owned by Dalea and funds advised by Abraaj Investment Management Limited for an aggregate purchase price of $168.5 million, consisting of approximately $157.0 million in cash and a $11.5 million promissory note from Dalea. The promissory note is payable five years from the date of issuance or earlier upon the occurrence of certain specified events, including an initial public offering by the joint venture. Upon the consummation of an initial public offering by the joint venture and the prior approval of Dalea, we can elect to convert the outstanding balance of the promissory note, including accrued interest, into the number of shares offered in the initial public offering equal to such outstanding balance divided by the per share purchase price paid by the public in the initial public offering. The promissory note bears interest at a rate of 3.0% per annum and is guaranteed by Mr. Mitchell.
	Service transactions
	Effective May 1, 2008, we entered into a service agreement, as amended (the “Service Agreement”), with Longfellow Energy, LP (“Longfellow”), Viking Drilling LLC (“Viking Drilling”), MedOil Supply, LLC and Riata Management, LLC (“Riata Management”). Mr. Mitchell and his wife own 100% of Riata Management. In addition, Mr. Mitchell, his wife and his children indirectly own 100% of Longfellow. Riata Management owns 100% of MedOil Supply, LLC. Dalea owns 85% of Viking Drilling. Under the terms of the Service Agreement, we pay, or are paid, for the actual cost of the services rendered plus the actual cost of reasonable expenses on a monthly basis.
	Effective January 1, 2011, our wholly-owned subsidiary, TEMI, entered into an accommodation agreement under which it leased rooms, flats and office space at a resort hotel owned by Gundem Turizm Yatirim ve Isletme A.S. (“Gundem”), a Turkish company controlled by Mr. Mitchell. Under the accommodation agreement, TEMI leases six rooms at the hotel and pays the TRY equivalent of $6,000 per month.
	On August 23, 2011, the Company’s wholly-owned subsidiary, TransAtlantic Petroleum (USA) Corp. (“TransAtlantic USA”), entered into an office lease with Longfellow to lease approximately 5,300 square feet of corporate office space in Addison, Texas. The initial lease term under the lease commenced on July 1, 2013, the date that TransAtlantic USA subleased a portion of its previous office space in Dallas, Texas (the “Commencement Date”). The lease expires five years after the Commencement Date, unless earlier terminated in accordance with the lease. During the initial lease term, TransAtlantic USA will pay monthly rent of $6,625 to Longfellow plus, utilities, real property taxes and liability insurance. Prior to the Commencement Date, no rent, utilities, real property taxes and/or liability insurance were required to be paid to Longfellow under the lease.
	On June 13, 2012, we entered into separate master services agreements with each of Viking International, Viking Petrol Sahasi Hizmetleri AS (“VOS”) and Viking Geophysical in connection with the sale of our oilfield services business to a joint venture owned by Dalea and funds managed by Abraaj Investment Management Limited. Pursuant to the master services agreements with Viking International and VOS, we are entitled to receive certain oilfield services and materials, including, but not limited to, drilling rigs and fracture stimulation that are needed for our operations in Bulgaria and Turkey. Pursuant to the master services agreement with Viking Geophysical, we are also entitled to receive geophysical services and materials that are needed for our operations in those countries. Each master services agreement is for a five-year term. Currently, we can contract for services and materials on a firm basis and, to the extent that we do not contract for all of their services or materials, Viking International, VOS and Viking Geophysical are allowed to contract with third parties for any remaining capacity.
	On June 13, 2012, we entered into a transition services agreement with Viking Services Management, Ltd. (“Viking Management”) in connection with the sale of our oilfield services business to a joint venture owned by Dalea and funds managed by Abraaj Investment Management Limited. Pursuant to the transition services agreement, we agreed to provide certain administrative services, including, but not limited to, continued use of certain of our employees and independent contractors, a guarantee of a lease for flats in Turkey, Turkish tax or legal advice and services, office space in Istanbul, Turkey, information technology support and certain software or licenses to Viking Management. In addition, Viking Management agreed to cause its subsidiaries to provide us with the continued use of certain office space in Tekirdag, Turkey. In the third quarter of 2012, we entered into an addendum to the transition services agreement whereby Viking Management agreed to cause its subsidiaries to provide us with the continued use of certain equipment yards in the Thrace Basin and in southwestern Turkey. The addendum will terminate on April 1, 2014. The transition services agreement has a two-year term. Viking Management agreed to use commercially reasonable efforts to eliminate its need for such services as soon as practicable following the entry into the agreement.
	On April 5, 2013 (the “First Floor Commencement Date”), TransAtlantic USA entered into an office lease with Longfellow to lease approximately 4,700 square feet of additional corporate office space in Addison, Texas. The initial lease term commenced on the First Floor Commencement Date and expires five years after the First Floor Commencement Date, unless earlier terminated in accordance with the lease. For the first year of the lease, TransAtlantic USA will pay monthly rent of $7,533 to Longfellow plus, utilities, real property taxes and liability insurance.
	For the years ended December 31, 2013 and 2012, we incurred capital and operating expenditures of $85.7 million and $73.8 million, respectively, related to our various related party agreements.
	The following table summarizes related party accounts receivable and accounts payable as of December 31, 2013 and December 31, 2012:
		December 31,		December 31,
		2013		2012
		(in thousands)
	Related party accounts receivable:
	Viking International master services agreement	$	939	$	313
	Riata Management Service Agreement		65		—
	Dalea promissory note		—		106
	Total related party accounts receivable	$	1,004	$	419
	Related party accounts payable:
	Viking International master services agreement	$	15,956	$	15,467
	Viking Geophysical master services agreement		6,800		—
	Riata Management Service Agreement		334		167
	Total related party accounts payable	$	23,090	$	15,634

Discontinued_operations

Discontinued operations	12 Months Ended
	Dec. 31, 2013
Discontinued Operations And Disposal Groups [Abstract]	'
Discontinued operations	'
	17. Discontinued operations
	Discontinued operations in Morocco
	On June 27, 2011, we decided to discontinue our operations in Morocco. We have substantially completed the process of winding down our operations in Morocco. We have presented the Moroccan segment operating results as discontinued operations for all periods presented.
	Discontinued operations of oilfield services business
	On June 13, 2012, we closed the sale of our oilfield services business, which was substantially comprised of our wholly owned subsidiaries Viking International and Viking Geophysical, to a joint venture owned by Dalea and funds advised by Abraaj Investment Management Limited for an aggregate purchase price of $168.5 million, consisting of approximately $157.0 million in cash and a $11.5 million promissory note from Dalea. The transaction was approved by a special committee of our board of directors after the receipt of a fairness opinion solely for the benefit of the special committee, which was subject to certain assumptions and limitations as provided in such opinion. The promissory note is payable five years from the date of issuance or earlier upon the occurrence of certain specified events, including an initial public offering by the joint venture. Upon the consummation of an initial public offering by the joint venture and the prior approval of Dalea, we can elect to convert the outstanding balance of the promissory note, including accrued interest, into the number of shares offered in the initial public offering equal to such outstanding balance divided by the per share purchase price paid by the public in the initial public offering. The promissory note bears interest at a rate of 3.0% per annum and is guaranteed by Mr. Mitchell. We used a portion of the net proceeds from the sale to pay off our $73.0 million credit agreement with Dalea, our $11.0 million credit facility with Dalea, our $0.9 million promissory note with Viking Drilling and our $1.8 million credit agreement with a Turkish bank. In addition, we used a portion of the net proceeds from the sale of our oilfield services business to pay down approximately $45.2 million in outstanding indebtedness under our Amended and Restated Credit Facility. We have presented the oilfield services segment operating results as discontinued operations for the years ended December 31, 2013 and 2012.
	The assets and liabilities held for sale at December 31, 2013 and 2012 were as follows:
		December 31,			December 31,
		2013			2012
		(in thousands)
	Cash	$	23		$	93
	Other assets (1)		513			1,526
	Total assets held for sale	$	536		$	1,619
	Accrued expenses and other liabilities		7,559			8,416
	Total liabilities held for sale	$	7,559		$	8,416
	(1) Other assets consist primarily of $0.5 million and $1.5 million of restricted cash at December 31, 2013 and December 31, 2012, respectively.
	Our operating results from discontinued operations for the years ended December 31, 2013, 2012 and 2011 are summarized as follows:
		2013			2012			2011
		(in thousands)
	Total revenues	$	—		$	19,956		$	28,419
	Total costs and expenses		(505	)		(24,682	)		(70,265	)
	Total other income (expense)		63			(357	)		2,732
	Loss from discontinued operations before income taxes		(442	)		(5,083	)		(39,114	)
	Gain on disposal of discontinued operations		—			35,999			—
	Income tax provision		—			(8,297	)		(4,255	)
	Net (loss) income from discontinued operations	$	(442	)	$	22,619		$	(43,369	)

Subsequent_events

Subsequent events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent events	'
	18. Subsequent events
	Reverse Stock Split. On March 4, 2014, the Company’s shareholders approved a 1-for-10 reverse stock split, which became effective March 6, 2014. Pursuant to the reverse stock split, all shareholders of record received one common share for each ten common shares owned (subject to minor adjustments as a result of fractional shares). The reverse stock split reduced the issued and outstanding common shares from 374,026,984 to 37,402,698. U.S. GAAP requires that the reverse stock split be applied retrospectively to all periods presented. As a result, all common share transactions described herein have been adjusted to reflect the 1-for-10 reverse stock split.
	Idil Farm-Out. In February 2014, our wholly owned subsidiary, TransAtlantic Turkey, and Selsinsan Petrol Maden T.O. San ve Tic. Ltd. Sti. (“Selsinsan”) entered into a farm-out agreement with Onshore Petroleum Company AS (“Onshore”), a private oil and gas company. Pursuant to the agreement, Onshore will fund 100% of our initial exploration well, up to $3.5 million, on the Idil license in southeastern Turkey. Expenses over $3.5 million will be split equally between us and Onshore. In exchange, TransAtlantic Turkey and Selsinsan will assign Onshore a 50% interest in the Idil license.

General_Policies

General (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Nature of operations	'
	Nature of operations
	TransAtlantic Petroleum Ltd. (together with its subsidiaries, “we,” “us,” “our,” the “Company” or “TransAtlantic”) is an international oil and natural gas company engaged in acquisition, exploration, development and production. We have focused our operations in countries that have established yet underexplored petroleum systems, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates and tax rates to exploration and production companies. As of December 31, 2013, we held interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of March 1, 2014, approximately 40% of our outstanding common shares were beneficially owned by N. Malone Mitchell 3rd, our chief executive officer and chairman of our board of directors.
Basis of presentation	'
	Basis of presentation
	Our consolidated financial statements are expressed in U.S. Dollars and have been prepared by management in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”). All amounts in these notes to the consolidated financial statements are in U.S. Dollars unless otherwise indicated. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews estimates, including those related to fair value measurements associated with acquisitions and financial derivatives, the recoverability and impairment of long-lived assets and goodwill, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.
Revision of prior period financial statements	'
	Revision of prior period financial statements
	During the three months ended March 31, 2013, we identified and corrected errors previously reported on our consolidated statements of cash flows. As a result, we increased the “Exploration, abandonment and impairment” sub-caption, which is an adjustment to reconcile net income (loss) to net cash provided by operating activities, and increased the cash used in investing activities related to “Additions to oil and natural gas properties” by $17.4 million and $8.3 million for the years ended December 31, 2012 and 2011, respectively, as we previously did not include the cash portion of additions to oil and natural gas properties in investing activities for dry hole expenses that were recognized in the same period as the related cash disbursed. These amounts had also been excluded from the adjustment to reconcile net income (loss) to net cash provided by operating activities.
	We assessed the materiality of the errors in accordance with the U.S. Securities and Exchange Commission (the “SEC”) guidance on considering the effects of prior period misstatements based on an analysis of quantitative and qualitative factors. Based on this analysis, we determined that the errors were immaterial to each of the prior reporting periods affected and, therefore, amendments of reports previously filed with the SEC were not required. Accordingly, we have reflected the correction of these prior period errors in the periods in which they originated and revised our consolidated statement of cash flows for the years ended December 31, 2012 and 2011 in this Annual Report on Form 10-K.
Basis of preparation	'
	Basis of preparation
	Our reporting standard for the presentation of our consolidated financial statements is U.S. GAAP. The consolidated financial statements include the accounts of the Company and all majority owned, controlled subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation.
Reverse stock split	'
	Reverse stock split
	On March 4, 2014, the Company’s shareholders approved a 1-for-10 reverse stock split, which became effective March 6, 2014. Pursuant to the reverse stock split, all shareholders of record received one common share for each ten common shares owned (subject to minor adjustments as a result of fractional shares). The reverse stock split reduced the issued and outstanding common shares from 374,026,984 to 37,402,698. U.S. GAAP requires that the reverse stock split be applied retrospectively to all periods presented. As a result, all common share transactions described herein have been adjusted to reflect the 1-for-10 reverse stock split.
Cash and cash equivalents	'
	Cash and cash equivalents
	Cash and cash equivalents include term deposits and investments with original maturities of three months or less at the date of acquisition. 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 and marketable securities at the time of purchase and reevaluate such designation at each balance sheet date.
Commodity derivative instruments	'
	Commodity derivative instruments
	Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 815, Derivatives and Hedging (“ASC 815”), requires derivative instruments to be recognized as either assets or liabilities in the balance sheet at fair value. We do not designate our derivative financial instruments as hedging instruments and, as a result, we recognize the change in a derivative contract’s fair value currently in earnings as a component of other (expense) income.
Fair value measurements	'
	Fair value measurements
	We follow ASC 820, Fair Value Measurements and Disclosures (“ASC 820”). This standard defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. ASC 820 does not require any new fair value measurements, but applies to assets and liabilities that are required to be recorded at fair value under other accounting standards.
	ASC 820 characterizes inputs used in determining fair value according to a hierarchy that prioritizes those inputs based upon the degree to which they are observable. The three levels of the fair value measurement hierarchy are as follows:
		Level 1:	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities.
		Level 2:	Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.
		Level 3:	Measured based on prices or valuation models that required inputs that are both significant to the fair value measurement and less observable for objective sources (i.e., supported by little or no market activity).
	As required by ASC 820, financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values takes into account the market for our financial assets and liabilities, the associated credit risk and other factors as required by ASC 820. We consider active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
Foreign currency remeasurement and translation	'
	Foreign currency remeasurement and translation
	The functional currency of our subsidiaries in Turkey, Bulgaria, Romania, and Morocco is the New Turkish Lira (“TRY”), the Bulgarian Lev, the Romanian New Leu and the Moroccan Dirham, respectively. We follow ASC 830, Foreign Currency Matters (“ASC 830”). ASC 830 requires the assets, liabilities, and results of operations of a foreign operation to be measured using the functional currency of that foreign operation. Exchange gains or losses from remeasuring transactions and monetary accounts in a currency other than the functional currency are included in earnings.
	For certain subsidiaries, translation adjustments result from the process of translating the functional currency of subsidiary financial statements into the U.S. Dollar reporting currency. These translation adjustments are reported separately and accumulated in the consolidated balance sheets as a component of accumulated other comprehensive loss.
Oil and natural gas properties	'
	Oil and natural gas properties
	In accordance with the successful efforts method of accounting for oil and natural gas properties, costs of productive wells, developmental dry holes and productive leases are capitalized into appropriate groups of properties based on geographical and geological similarities. Acquisition costs of proved properties are amortized using the unit-of-production method based on total proved reserves, and exploration well costs and additional development costs are amortized using the unit-of-production method based on proved developed reserves. Proceeds from the sale of properties are credited to property costs, and a gain or loss is recognized when a significant portion of an amortization base is sold or abandoned.
	Exploration costs, such as exploratory geological and geophysical costs, delay rentals and exploration overhead, are charged to expense as incurred. Exploratory drilling costs, including the cost of stratigraphic test wells, are initially capitalized but charged to exploration expense if and when the well is determined to be non-productive. The determination of an exploratory well’s ability to produce must be made within one year from the completion of drilling activities. The acquisition costs of unproved acreage are initially capitalized and are carried at cost, net of accumulated impairment provisions, until such leases are transferred to proved properties or charged to exploration expense as impairments of unproved properties.
Equipment and other property	'
	Equipment and other property
	Equipment and other property are stated at cost, and inventory is stated at weighted average cost which does not exceed replacement cost. Depreciation is calculated using the straight-line method over the estimated useful lives (ranging from 3 to 7 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 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 earnings.
Impairment of long-lived assets	'
	Impairment of long-lived assets
	We follow the provisions of ASC 360, Property, Plant, and Equipment (“ASC 360”). ASC 360 requires that our long-lived assets be assessed for potential impairment of their carrying values whenever events or changes in circumstances indicate such impairment may have occurred. Proved oil and natural gas properties are evaluated by field for potential impairment. An impairment on proved properties is recognized when the estimated undiscounted future net cash flows of a field are less than its carrying value. If an impairment occurs, the carrying value of the impaired field is reduced to its estimated fair value, which is generally estimated using a discounted cash flow approach.
	Unproved oil and natural gas properties do not have producing properties and are valued on acquisition by management, with the assistance of an independent expert when necessary. As reserves are proved through the successful completion of exploratory wells, the cost is transferred to proved properties. The cost of the remaining unproved basis is periodically evaluated by management to assess whether the value of a property has diminished. To do this assessment, management considers (i) estimated potential reserves and future net revenues from an independent expert, (ii) the Company’s history in exploring the area, (iii) the Company’s future drilling plans per its capital drilling program prepared by the Company’s reservoir engineers and operations management and (iv) other factors associated with the area. Impairment is taken on the unproved property value if it is determined that the costs are not likely to be recoverable. The valuation is subjective and requires management to make estimates and assumptions which, with the passage of time, may prove to be materially different from actual results.
Goodwill	'
	Goodwill
	In accordance with ASC 350, Intangibles-Goodwill and Other (“ASC 350”), goodwill is not amortized, but is tested for impairment on an annual basis at December 31, or more frequently as impairment indicators arise. ASC 350 permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. We assessed the qualitative factors at December 31, 2013 and, based upon the results of the qualitative assessment, we determined that it was not necessary to perform the two-step goodwill impairment test and that our goodwill was not impaired. All of our goodwill is attributable to our Turkey operating segment.
Joint interest activities	'
	Joint interest activities
	Certain of our exploration, development and production activities are conducted jointly with other entities and, accordingly, the consolidated financial statements reflect only our proportionate interest in such activities.
Asset retirement obligations	'
	Asset retirement obligations
	We recognize a liability for the fair value of all legal obligations associated with the retirement of tangible, long-lived assets and capitalize an equal amount as a cost of the asset. The cost associated with the abandonment obligation is included in the computation of depreciation, depletion and amortization. The liability accretes until we settle the obligation. We use a credit-adjusted risk-free interest rate in our calculation of asset retirement obligations.
Revenue recognition	'
	Revenue recognition
	Revenue from the sale of crude oil and natural gas is recognized upon delivery to the purchaser when title passes. During the years ended December 31, 2013, 2012 and 2011, we sold $87.2 million, $91.8 million and $84.3 million, respectively, of oil to Türkiye Petrol Rafinerileri A.Ş. (“TUPRAS”), a privately owned oil refinery in Turkey, which represented approximately 66.7%, 63.8% and 65.3% of our total revenues, respectively.
Share-based compensation	'
	Share-based compensation
	We follow ASC 718, Compensation—Stock Compensation (“ASC 718”), which requires the measurement and recognition of compensation expense for all share-based payment awards, including restricted stock units, based on estimated grant date fair values. Restricted stock units are valued using the market price of our common shares on the date of grant. We record compensation expense, net of estimated forfeitures, over the requisite service period.
Income taxes	'
	Income taxes
	We follow the asset and liability method prescribed by ASC 740, Income Taxes (“ASC 740”). Under this method of accounting for income taxes, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. Under ASC 740, the effect on deferred tax assets and liabilities of a change in enacted tax rates is recognized in earnings in the period that includes the enactment date.
	In connection with our acquisition Amity Oil International Pty Ltd (“Amity”) and Petrogas Petrol Gaz ve Petrokimya Ürünleri Inşaat Sanayi ve Ticaret A.Ş. (“Petrogas”) in August 2010, at December 31, 2012, we recognized a liability due to an uncertain tax position related to the transfer of Petrogas shares to Amity prior to the acquisition (see Note 11). We do not believe there will be any material changes in our unrecognized tax positions over the next twelve months. Our policy is that we recognize interest and penalties accrued on any unrecognized tax positions as a component of income tax expense.
	We are a Bermuda exempted company, and under current Bermuda law, we are not subject to tax on profits, income or dividends, nor is there any capital gains tax applicable to us in Bermuda.
Comprehensive income	'
	Comprehensive income
	ASC 220, Comprehensive Income, establishes standards for reporting and displaying comprehensive income and its components (revenue, expenses, gains and losses) in a full set of general-purpose financial statements.
Business combinations	'
	Business combinations
	We follow ASC 805, Business Combinations (“ASC 805”), and ASC 810-10-65, Consolidation (“ASC 810-10-65”). ASC 805 requires most identifiable assets, liabilities, non-controlling interests, and goodwill acquired in a business combination to be recorded at “fair value.” The statement applies to all business combinations, including combinations among mutual entities and combinations by contract alone. Under ASC 805, all business combinations are accounted for by applying the acquisition method.
Per share information	'
	Per share information
	Basic per share amounts are calculated using the weighted average common shares outstanding during the year, excluding unvested restricted stock units. We use the treasury stock method to determine the dilutive effect of stock options and other dilutive instruments. Under the treasury stock method, only “in the money” dilutive instruments impact the diluted calculations in computing diluted earnings per share. Diluted calculations reflect the weighted average incremental common shares that would be issued upon exercise of dilutive options assuming the proceeds would be used to repurchase shares at average market prices for the period.
Earnings per share	'
	Earnings per share
	We account for earnings per share in accordance with ASC Subtopic 260-10, Earnings Per Share (“ASC 260-10”). ASC 260-10 requires companies to present two calculations of earnings per share: basic and diluted. Basic earnings per common share for the years ended December 31, 2013, 2012 and 2011 equals net income divided by the weighted average shares outstanding during the periods. Weighted average shares outstanding are equal to the weighted average of all shares outstanding for the period, excluding RSUs. Diluted earnings per common share for the years ended December 31, 2013, 2012 and 2011 are computed in the same manner as basic earnings per common share after assuming the issuance of common shares for all potentially dilutive common share equivalents, which includes stock options, RSUs and warrants, whether exercisable or not. The computation of diluted earnings per common share excluded 758,586, 959,438 and 2,075,213 antidilutive common share equivalents from the years ended December 31, 2013, 2012 and 2011, respectively.

General_Tables

General (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Effect of Out-of-Period Errors on Consolidated Statement of Cash Flows	'
	The following shows the effect of the out-of-period errors on our consolidated statements of cash flows for the years ended December 31, 2012 and 2011 (in thousands):
		As Reported			Correction			As Revised
	For the year ended December 31, 2012
	Operating activities:
	Exploration, abandonment and impairment	$	22,617		$	17,376		$	39,993
	Net cash provided by operating activities from continuing operations		51,970			17,376			69,346
	Net cash provided by operating activities		26,201			17,376			43,577
	Investing activities:
	Additions to oil and natural gas properties		(52,813	)		(17,376	)		(70,189	)
	Net cash used in investing activities from continuing operations		(52,532	)		(17,376	)		(69,908	)
	Net cash provided by (used in) investing activities	$	103,617		$	(17,376	)	$	86,241
	For the year ended December 31, 2011
	Operating activities:
	Exploration, abandonment and impairment	$	52,638		$	8,314		$	60,952
	Net cash provided by operating activities from continuing operations		51,007			8,314			59,321
	Net cash provided by operating activities		40,405			8,314			48,719
	Investing activities:
	Additions to oil and natural gas properties		(68,713	)		(8,314	)		(77,027	)
	Net cash used in investing activities from continuing operations		(66,976	)		(8,314	)		(75,290	)
	Net cash used in investing activities	$	(71,737	)	$	(8,314	)	$	(80,051	)

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013
Consolidated Results of Operation	'
	The revenues and loss of TBNG included in our consolidated statement of comprehensive income (loss) for the year ended December 31, 2011 were:
			Revenue			Loss
			(in thousands)
	Actual from June 7, 2011 through December 31, 2011		$	13,466		$	(4,651	)
	The amounts of revenue and loss of Direct Morocco, Anschutz and Direct Bulgaria included in our consolidated statement of comprehensive income (loss) for the year ended December 31, 2011 are shown below:
			Revenue			Loss
			(in thousands)
	Continuing operations		$	483		$	(30,749	)(1)
	Discontinued operations			—			(7,021	)
	Total from February 18, 2011 through December 31, 2011		$	483		$	(37,770	)
		-1	See Note 6, Property and equipment, for a discussion of the impairment of our properties in Bulgaria.
Unaudited Pro Forma Results of Operations	'
	The following table presents the unaudited pro forma results of operations for the year ended December 31, 2011 as though the acquisitions of Direct Morocco, Anschutz, Direct Bulgaria and TBNG had occurred as of January 1, 2011 (in thousands, except per share amounts):
			2011
	Total revenues		$	139,999
	Loss from continuing operations before income taxes			(82,856	)
	Loss from continuing operations			(80,834	)
	Loss from discontinued operations			(45,071	)
	Net loss			(125,905	)
	Net loss per common share from continuing operations
	Basic		$	(2.21	)
	Diluted		$	(2.21	)
	Net loss per common share from discontinued operations
	Basic		$	(1.23	)
	Diluted		$	(1.23	)
Thrace Basin Natural Gas (Turkiye) Corporation [Member]	'
Consideration Paid in Acquisition and Final Recognized Amounts of Assets Acquired and Liabilities Assumed	'
	The following tables summarize the consideration paid in the acquisition and the final recognized amounts of assets acquired and liabilities assumed that have been recognized at the acquisition date:
	Consideration:
			(in thousands)
	Cash consideration, net of purchase price adjustments		$	10,504
	Issuance of 1,850,000 common shares			37,925
	Fair value of total consideration transferred		$	48,429
	Acquisition-Related Costs:
	Included in general and administrative expenses on our consolidated statements of comprehensive income (loss) for the year ended December 31, 2011		$	1,013
	Recognized Amounts of Identifiable Assets Acquired and Liabilities Assumed at Acquisition:
	Assets:
	Cash		$	1,845
	Accounts receivable			19,997
	Restricted cash			4,931
	Total financial assets			26,773
	Other current assets, consisting primarily of prepaid expenses			3,272
	Deferred tax asset			722
	Oil and natural gas properties:
	Proved properties			14,526
	Unproved properties			16,131
	Land and buildings			2,601
	Drilling services equipment and vehicles			19,512
	Total oil and natural gas properties and other equipment			52,770
	Liabilities:
	Accounts payable, consisting of normal trade obligations			5,960
	Other current liabilities			5,596
	Asset retirement obligation			6,480
	Deferred tax liability			2,523
	Bank loans			14,549
	Total liabilities			35,108
	Total identifiable net assets		$	48,429
Direct Petroleum Bulgaria EOOD [Member]	'
Consideration Paid in Acquisition and Final Recognized Amounts of Assets Acquired and Liabilities Assumed	'
	The following tables summarize the consideration paid in the acquisition of Direct Morocco, Anschutz and Direct Bulgaria and the final recognized amounts of assets acquired and liabilities assumed which have been recognized at the acquisition date:
	Consideration:
			(in thousands)
	Cash consideration, net of purchase price adjustments		$	2,408
	Issuance of 892,448 common shares			28,112
	Contingent consideration liabilities			4,000
	Fair value of total consideration transferred		$	34,520
	The Purchase Agreement provided that if certain post-closing milestones were achieved, we would issue additional consideration to Direct equal to: (i) $10.0 million worth of our common shares if the Deventci-R2 well in Bulgaria was a commercial success and (ii) $10.0 million worth of our common shares if Direct Bulgaria received a production concession for a specified area in Bulgaria. The fair value of these contingent consideration liabilities represents our best estimate of the amounts to be paid as additional consideration. Subsequent changes in the fair value of the contingent consideration liabilities are reflected in our consolidated statements of comprehensive income (loss). The fair value of these contingent consideration liabilities was $2.5 million at December 31, 2013 and $10.0 million at December 31, 2012. The change in the contingent consideration liabilities since the acquisition date is included under the caption “Revaluation of contingent consideration” on our consolidated statements of comprehensive income (loss) for the years ended December 31, 2013, 2012, and 2011. In July 2013, we amended the Purchase Agreement, which resulted in changes in the contingent consideration liability (see Note 15).
	Acquisition-Related Costs:
			(in thousands)
	Included in general and administrative expenses on our consolidated statements of comprehensive income (loss) for the year ended December 31, 2011		$	117
	Recognized Amounts of Identifiable Assets Acquired and Liabilities
	Assumed at Acquisition:
			(in thousands)
	Assets:
	Cash		$	320
	Accounts receivable			57
	Total financial assets			377
	Other current assets, consisting primarily of prepaid expenses			146
	Oil and natural gas properties:
	Proved properties			1,200
	Unproved properties			32,840
	Other equipment			79
	Total oil and natural gas properties and other equipment			34,119
	Liabilities:
	Accounts payable, consisting of normal trade obligations			122
	Total identifiable net assets		$	34,520

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill And Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill	'
	All of our goodwill is attributable to our Turkey operating segment. Goodwill was as follows at December 31, 2013 and 2012:
		2013			2012
		(in thousands)
	Goodwill at January 1,	$	9,021		$	8,514
	Foreign exchange change effect		(1,486	)		507
	Goodwill at December 31,	$	7,535		$	9,021

Property_and_equipment_Tables

Property and equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property Plant And Equipment [Abstract]	'
Capitalized Costs under Successful Efforts Method for Oil and Natural Gas Properties	'
	The following table sets forth the capitalized costs under the successful efforts method for oil and natural gas properties:
		December 31, 2013			December 31, 2012
		(in thousands)
	Oil and natural gas properties, proved:
	Turkey	$	260,232		$	229,462
	Bulgaria		625			2,036
	Total oil and natural gas properties, proved		260,857			231,498
	Oil and natural gas properties, unproved:
	Turkey		51,273			68,938
	Bulgaria		3,119			—
	Total oil and natural gas properties, unproved		54,392			68,938
	Gross oil and natural gas properties		315,249			300,436
	Accumulated depletion		(96,958	)		(74,099	)
	Net oil and natural gas properties	$	218,291		$	226,337
Historical Cost of Equipment and Other Property on Gross Basis with Accumulated Depreciation	'
	The historical cost of equipment and other property, presented on a gross basis with accumulated depreciation, is summarized as follows:
		December 31,
		2013			2012
		(in thousands)
	Other equipment	$	2,678		$	2,013
	Inventory		24,318			20,517
	Gas gathering system and facilities		4,485			5,369
	Vehicles		321			131
	Leasehold improvements, office equipment and software		8,114			7,717
	Gross equipment and other property		39,916			35,747
	Accumulated depreciation		(7,235	)		(5,932	)
	Net equipment and other property	$	32,681		$	29,815

Commodity_derivative_instrumen1

Commodity derivative instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Fair Value of Derivative Instruments of Future Crude Oil Production	'
	At December 31, 2013, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below:
	Fair Value of Derivative Instruments as of December 31, 2013
	Type	Period				Quantity				Weighted				Weighted				Estimated Fair
						(Bbl/day)				Average				Average				Value of Liability
										Minimum				Maximum Price
										Price (per Bbl)				(per Bbl)
																		(in thousands)
	Collar		January 1, 2014—December 31, 2014				622			$	80.83			$	118.07			$	(387	)
																		$	(387	)
				Collars												Additional Call
	Type	Period		Quantity				Weighted				Weighted				Weighted				Estimated Fair
				(Bbl/day)				Average				Average				Average				Value of
								Minimum				Maximum				Maximum				Liability
								Price				Price				Price
								(per Bbl)				(per Bbl)				(per Bbl)
																				(in thousands)
	Three-way collar contract	January 1, 2014—December 31, 2014			726			$	85			$	97.13			$	162.13			$	(3,350	)
	Three-way collar contract	January 1, 2015—December 31, 2015			1,016			$	85			$	91.88			$	151.88				(4,230	)
																				$	(7,580	)
	At December 31, 2012, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below:
	Fair Value of Derivative Instruments as of December 31, 2012
	Type	Period				Quantity				Weighted				Weighted				Estimated Fair
						(Bbl/day)				Average				Average				Value of
										Minimum				Maximum Price				Liability
										Price (per Bbl)				(per Bbl)
																		(in thousands)
	Collar		January 1, 2013—December 31, 2013				775			$	82.26			$	121.36			$	(253	)
	Collar		January 1, 2014—December 31, 2014				622			$	80.83			$	118.07				(292	)
																		$	(545	)
						Collars												Additional Call
	Type	Period				Quantity				Weighted				Weighted				Weighted				Estimated Fair
						(Bbl/day)				Average				Average				Average				Value of
										Minimum				Maximum				Maximum				Liability
										Price				Price				Price
										(per Bbl)				(per Bbl)				(per Bbl)
																						(in thousands)
	Three-way collar contract		January 1, 2013—December 31, 2013				831			$	85			$	97.13			$	162.13			$	(3,655	)
	Three-way collar contract		January 1, 2014—December 31, 2014				726			$	85			$	97.13			$	162.13				(2,150	)
	Three-way collar contract		January 1, 2015—December 31, 2015				1,016			$	85			$	91.88			$	151.88				(2,440	)
																						$	(8,245	)

Asset_retirement_obligations_T

Asset retirement obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Changes in Asset Retirement Obligations	'
	The following table summarizes the changes in our ARO for the years ended December 31, 2013 and 2012:
			2013			2012
			(in thousands)
	Asset retirement obligation January 1,		$	11,958		$	13,534
	Change in estimates(1)			(7	)		(3,868	)
	Liabilities settled			(296	)		(110	)
	Foreign exchange change effect			(2,258	)		793
	Additions			991			899
	Accretion expense			508			710
	Asset retirement obligation at December 31,			10,896			11,958
	Less: current portion			610			818
	Long-term portion		$	10,286		$	11,140
		-1	For 2013 and 2012, we used cost estimates provided by third-party engineers.

Loans_payable_Tables

Loans payable (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt	'
	As of the dates indicated, our third-party debt consisted of the following:
		December 31,		December 31,
		2013		2012
		(in thousands)
	Floating Rate Debt
	Amended and Restated Credit Facility	$	49,766	$	32,766
	TBNG credit facility (short-term)		20,000		—
	Loans payable		69,766		32,766
	Less: current portion		43,284		—
	Long-term portion	$	26,482	$	32,766

Shareholders_equity_Tables

Shareholders' equity (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Restricted Stock Units Activity	'
	The following table sets forth RSU activity for the year ended December 31, 2013:
		Number of			Weighted
		RSUs			Average Grant
		(in thousands)			Date Fair Value
					Per RSU
	Unvested RSUs outstanding at December 31, 2012		315		$	12.46
	Granted		172			7.1
	Forfeited		(62	)		10.2
	Vested		(129	)		14.53
	Unvested RSUs outstanding at December 31, 2013		296		$	8.91
Details of Stock Option Activity	'
	Details of stock option activity for the years ended December 31, 2013, 2012 and 2011 are presented below.
		2013						2012					2011
		Number of			Weighted			Number of			Weighted		Number of			Weighted
		Options			Average			Options			Average		Options			Average
		(in thousands)			Exercise			(in thousands)			Exercise		(in thousands)			Exercise
					Price						Price					Price
					Per						Per					Per
					Share						Share					Share
	Outstanding at January 1,		16		$	12.3			114		$	9.07		211		$	8.6
	Granted		—			—			—			—		—			—
	Expired		(16	)		12.3			(17	)		10		(13	)		12.96
	Exercised		—			—			(81	)		8.24		(84	)		7.39
	Outstanding at December 31,		—		$	—			16		$	12.3		114		$	9.07
	Exercisable at December 31,		—		$	—			16		$	12.3		114		$	9.07
Basic and Diluted Earnings Per Common Share Computations	'
	The following table presents the basic and diluted earnings per common share computations:
		2013			2012			2011
	(in thousands, except per share amounts)
	Net loss from continuing operations	$	(13,271	)	$	(6,373	)	$	(77,574	)
	Net (loss) income from discontinued operations	$	(442	)	$	22,619		$	(43,369	)
	Basic net (loss) income per common share:
	Shares:
	Weighted average common shares outstanding		37,069			36,742			35,597
	Basic net (loss) income per common share:
	Continuing operations	$	(0.36	)	$	(0.17	)	$	(2.18	)
	Discontinued operations	$	(0.01	)	$	0.62		$	(1.22	)
	Diluted net (loss) income per common share:
	Shares:
	Weighted average common shares and common equivalent shares outstanding		37,069			36,742			35,597
	Diluted net (loss) income per common share:
	Continuing operations	$	(0.36	)	$	(0.17	)	$	(2.18	)
	Discontinued operations	$	(0.01	)	$	0.62		$	(1.22	)

Income_taxes_Tables

Income taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Reconciliation of Bermuda Income Tax Expense to Actual Income Tax Expense	'
	The income tax provision differs from the amount that would be obtained by applying the Bermuda statutory income tax rate of 0% for 2013, 2012 and 2011 to loss for the year as follows:
		2013			2012			2011
		(in thousands)
	Statutory tax rate		0	%		0	%		0	%
	Income (loss) from continuing operations before income taxes	$	(12,164	)	$	118		$	(80,139	)
	Increase (decrease) resulting from:
	Foreign tax rate differentials		(1,443	)		8,607			(11,173	)
	Change in valuation allowance		982			(2,026	)		6,871
	Expiration of non-capital tax loss carryovers		1,367			1,601			1,198
	Other		201			(1,691	)		539
	Total	$	1,107		$	6,491		$	(2,565	)
Components of Net Deferred Income Tax Liability	'
	The components of the net deferred income tax liability at December 31, 2013 and 2012 were as follows:
		2013			2012
		(in thousands)
	Deferred tax assets
	Unrealized derivative losses	$	1,594		$	1,758
	Timing of accruals		1,043			1,251
	Non-capital loss carryovers		25,868			28,455
	Valuation Allowance		(28,404	)		(29,059	)
	Total deferred tax assets		101			2,405
	Deferred tax liabilities
	Property and equipment	$	(13,093	)	$	(16,993	)
	Total deferred tax liabilities		(13,093	)		(16,993	)
	Net deferred tax liabilities	$	(12,992	)	$	(14,588	)
	Components of net deferred tax liabilities
	Current assets	$	2,239		$	1,895
	Non-current assets		903			—
	Non-current liabilities		(16,134	)		(16,483	)
	Net deferred tax liabilities	$	(12,992	)	$	(14,588	)

Segment_information_Tables

Segment information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Financial Information of Geographic Segments	'
	Summarized financial information from continuing operations concerning our geographic segments is shown in the following tables:
			Corporate			Turkey			Bulgaria			Total
			(in thousands)
	For the year ended December 31, 2013
	Total revenues		$	—		$	130,701		$	126		$	130,827
	Production			5			18,384			213			18,602
	Exploration, abandonment and impairment			—			27,116			217			27,333
	Cost of purchased natural gas			—			2,247			—			2,247
	Seismic and other exploration			100			13,909			—			14,009
	Revaluation of contingent consideration			—			—			(5,000	)		(5,000	)
	General and administrative			12,685			16,068			267			29,020
	Depreciation, depletion and amortization			69			41,196			57			41,322
	Accretion of asset retirement obligations			—			475			33			508
	Total costs and expenses			12,859			119,395			(4,213	)		128,041
	Operating (loss) income			(12,859	)		11,306			4,339			2,786
	Interest and other expense			—			(3,929	)		—			(3,929	)
	Interest and other income			284			1,056			—			1,340
	Loss on commodity derivative contracts			—			(2,698	)		—			(2,698	)
	Foreign exchange (loss) gain			(9	)		(9,664	)		10			(9,663	)
	Income (loss) from continuing operations before income taxes			(12,584	)		(3,929	)		4,349			(12,164	)
	Income tax provision			—			(1,107	)		—			(1,107	)
	Net (loss) income from continuing operations		$	(12,584	)	$	(5,036	)	$	4,349		$	(13,271	)
	Total assets as of December 31, 2013		$	14,070		$	321,749		$	10,231		$	346,050	(1)
	Goodwill as of December 31, 2013		$	—		$	7,535		$	—		$	7,535
	Capital expenditures		$	1,003		$	96,206		$	2,742		$	99,951
	For the year ended December 31, 2012
	Total revenues		$	—		$	143,650		$	258		$	143,908
	Production			169			17,328			307			17,804
	Exploration, abandonment and impairment			285			39,708			—			39,993
	Cost of purchased natural gas			—			7,694			—			7,694
	Seismic and other exploration			304			4,726			10			5,040
	General and administrative			10,982			20,603			2,362			33,947
	Depreciation, depletion and amortization			30			28,092			93			28,215
	Accretion of asset retirement obligations			—			679			31			710
	Total costs and expenses			11,770			118,830			2,803			133,403
	Operating (loss) income			(11,770	)		24,820			(2,545	)		10,505
	Interest and other expense			(1,890	)		(6,450	)		—			(8,340	)
	Interest and other income			308			2,110			—			2,418
	Loss on commodity derivative contracts			—			(5,548	)		—			(5,548	)
	Foreign exchange gain (loss)			79			1,054			(50	)		1,083
	Income (loss) from continuing operations before income taxes			(13,273	)		15,986			(2,595	)		118
	Income tax provision			—			(6,491	)		—			(6,491	)
	Net income (loss) from continuing operations		$	(13,273	)	$	9,495		$	(2,595	)	$	(6,373	)
	Total assets as of December 31, 2012		$	14,930		$	339,752		$	1,957		$	356,639	(1)
	Goodwill as of December 31, 2012		$	—		$	9,021		$	—		$	9,021
	Capital expenditures		$	—		$	80,957		$	867		$	81,824
	For the year ended December 31, 2011
	Total revenues		$	66		$	128,356		$	483		$	128,905
	Production			359			17,484			632			18,475
	Exploration, abandonment and impairment			2			37,008			23,942			60,952
	Cost of purchased natural gas			—			2,645			—			2,645
	Seismic and other exploration			1,801			9,657			84			11,542
	Revaluation of contingent consideration			—			—			6,000			6,000
	General and administrative			14,714			21,585			6			36,305
	Depreciation, depletion and amortization			127			38,389			492			39,008
	Accretion of asset retirement obligations			—			1,131			11			1,142
	Total costs and expenses			17,003			127,899			31,167			176,069
	Operating (loss) income			(16,937	)		457			(30,684	)		(47,164	)
	Interest and other (expense) income			(6,784	)		(6,878	)		(3	)		(13,665	)
	Interest and other income			27			914			148			1,089
	Loss on commodity derivative contracts			—			(8,426	)		—			(8,426	)
	Foreign exchange loss			(23	)		(11,740	)		(210	)		(11,973	)
	Loss from continuing operations before income taxes			(23,717	)		(25,673	)		(30,749	)		(80,139	)
Income tax benefit			—			2,565			—			2,565
Net loss from continuing operations		$	(23,717	)	$	(23,108	)	$	(30,749	)	$	(77,574	)
Total assets as of December 31, 2011		$	3,716		$	313,754		$	4,164		$	321,634	(1)
Goodwill as of December 31, 2011		$	—		$	8,514		$	—		$	8,514
Capital expenditures		$	—		$	117,071		$	35,369		$	152,440
-1	Excludes assets from our discontinued Moroccan operations and oilfield services business of $0.5 million, $1.6 million, and $127.2 million at December 31, 2013, 2012 and 2011, respectively.

Financial_instruments_Tables

Financial instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Valuation of Financial Assets and Liabilities	'
	The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2013:
		Fair Value Measurement Classification
		Quoted Prices in		Significant Other			Significant		Total
		Active Markets for		Observable Inputs			Unobservable Inputs
		Identical Assets or		(Level 2)			(Level 3)
		Liabilities
		(Level 1)
		(in thousands)
	Liabilities:
	Commodity derivative contracts	$	—	$	(7,967	)	$	—	$	(7,967	)
	Total	$	—	$	(7,967	)	$	—	$	(7,967	)
	The following table summarizes the valuation of our financial assets and liabilities as of December 31, 2012:
		Fair Value Measurement Classification
		Quoted Prices in		Significant Other			Significant		Total
		Active Markets for		Observable Inputs			Unobservable Inputs
		Identical Assets or		(Level 2)			(Level 3)
		Liabilities
		(Level 1)
		(in thousands)
	Liabilities:
	Commodity derivative contracts	$	—	$	(8,790	)	$	—	$	(8,790	)
	Total	$	—	$	(8,790	)	$	—	$	(8,790	)

Commitments_Tables

Commitments (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'
Aggregate Annual Commitments Other Than Debt	'
	Our aggregate annual commitments, other than our loans payable, as of December 31, 2013 were as follows:
			Payments Due by Year
		Total	2014	2015	2016	2017	2018	Thereafter
		(in thousands)
	Leases and other	$5,602	$2,546	$903	$299	$99	$33	$1,722

Related_party_transactions_Tab

Related party transactions (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Accounts Receivable and Accounts Payable	'
	The following table summarizes related party accounts receivable and accounts payable as of December 31, 2013 and December 31, 2012:
		December 31,		December 31,
		2013		2012
		(in thousands)
	Related party accounts receivable:
	Viking International master services agreement	$	939	$	313
	Riata Management Service Agreement		65		—
	Dalea promissory note		—		106
	Total related party accounts receivable	$	1,004	$	419
	Related party accounts payable:
	Viking International master services agreement	$	15,956	$	15,467
	Viking Geophysical master services agreement		6,800		—
	Riata Management Service Agreement		334		167
	Total related party accounts payable	$	23,090	$	15,634

Discontinued_operations_Tables

Discontinued operations (Tables)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations And Disposal Groups [Abstract]	'
Assets and Liabilities Held for Sale	'
	The assets and liabilities held for sale at December 31, 2013 and 2012 were as follows:
		December 31,			December 31,
		2013			2012
		(in thousands)
	Cash	$	23		$	93
	Other assets (1)		513			1,526
	Total assets held for sale	$	536		$	1,619
	Accrued expenses and other liabilities		7,559			8,416
	Total liabilities held for sale	$	7,559		$	8,416
	(1) Other assets consist primarily of $0.5 million and $1.5 million of restricted cash at December 31, 2013 and December 31, 2012, respectively.
Operating Results from Discontinued Operations	'
	Our operating results from discontinued operations for the years ended December 31, 2013, 2012 and 2011 are summarized as follows:
		2013			2012			2011
		(in thousands)
	Total revenues	$	—		$	19,956		$	28,419
	Total costs and expenses		(505	)		(24,682	)		(70,265	)
	Total other income (expense)		63			(357	)		2,732
	Loss from discontinued operations before income taxes		(442	)		(5,083	)		(39,114	)
	Gain on disposal of discontinued operations		—			35,999			—
	Income tax provision		—			(8,297	)		(4,255	)
	Net (loss) income from discontinued operations	$	(442	)	$	22,619		$	(43,369	)

General_Additional_Information

General - Additional Information (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified		Error Correction to Statements of Cash Flows [Member]	Error Correction to Statements of Cash Flows [Member]
Nature Of Business [Line Items]	'	'	'
Percentage of common shares owned	40.00%	'	'
Increase in exploration, abandonment and impairment due to revision and out of period adjustments	'	$17.40	$8.30

General_Summary_of_Effect_of_O

General - Summary of Effect of Out-of-Period Errors on Consolidated Statement of Cash Flows (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating activities:	'	'	'
Exploration, abandonment and impairment	$27,333	$39,993	$60,952
Net cash provided by operating activities from continuing operations	68,776	69,346	59,321
Net cash provided by operating activities	67,350	43,577	48,719
Investing activities:	'	'	'
Additions to oil and natural gas properties	-94,266	-70,189	-77,027
Net cash used in investing activities from continuing operations	-105,109	-69,908	-75,290
Net cash provided by (used in) investing activities	-104,093	86,241	-80,051
As Reported [Member]	'	'	'
Operating activities:	'	'	'
Exploration, abandonment and impairment	'	22,617	52,638
Net cash provided by operating activities from continuing operations	'	51,970	51,007
Net cash provided by operating activities	'	26,201	40,405
Investing activities:	'	'	'
Additions to oil and natural gas properties	'	-52,813	-68,713
Net cash used in investing activities from continuing operations	'	-52,532	-66,976
Net cash provided by (used in) investing activities	'	103,617	-71,737
Error Correction to Statements of Cash Flows [Member]	'	'	'
Operating activities:	'	'	'
Exploration, abandonment and impairment	'	17,376	8,314
Net cash provided by operating activities from continuing operations	'	17,376	8,314
Net cash provided by operating activities	'	17,376	8,314
Investing activities:	'	'	'
Additions to oil and natural gas properties	'	-17,376	-8,314
Net cash used in investing activities from continuing operations	'	-17,376	-8,314
Net cash provided by (used in) investing activities	'	($17,376)	($8,314)

Recovered_Sheet1

Significant Accounting Policies - Additional information (Detail) (USD $)	12 Months Ended			0 Months Ended	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 04, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013
				Subsequent Event [Member]	Sales Revenue, Goods, Net [Member]	Sales Revenue, Goods, Net [Member]	Sales Revenue, Goods, Net [Member]	Minimum [Member]	Maximum [Member]
					Revenue from Rights Concentration Risk [Member]	Revenue from Rights Concentration Risk [Member]	Revenue from Rights Concentration Risk [Member]
Significant Accounting Policies [Line Items]	'	'	'	'	'	'	'	'	'
Reverse stock splits number of shares outstanding stock converted into one share of common stock	'	'	'	10	'	'	'	'	'
Issued and outstanding common shares before stock splits	'	'	'	374,026,984	'	'	'	'	'
Issued and outstanding common shares after stock splits	'	'	'	37,402,698	'	'	'	'	'
Effective date of stock split	'	'	'	6-Mar-14	'	'	'	'	'
Determination of exploratory well's ability to produce, term	'1 year	'	'	'	'	'	'	'	'
Equipment and other property, estimated useful lives	'	'	'	'	'	'	'	'3 years	'7 years
Sales revenue, crude oil and natural gas	$87.20	$91.80	$84.30	'	'	'	'	'	'
Concentration Risk, Percentage	'	'	'	'	66.70%	63.80%	65.30%	'	'

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2011	Jun. 07, 2011	Nov. 30, 2010	Feb. 18, 2011	Feb. 18, 2011	Feb. 18, 2011
			If the Deventci-R2 well in Bulgaria is a commercial success [Member]	If Direct Bulgaria receives a production concession for a specified area in Bulgaria [Member]	Thrace Basin Natural Gas (Turkiye) Corporation [Member]	Thrace Basin Natural Gas (Turkiye) Corporation [Member]	Direct Petroleum Bulgaria EOOD [Member]	Direct Petroleum Bulgaria EOOD [Member]	Direct Petroleum Bulgaria EOOD [Member]
								Unused and uncancelled portion of aggregate commitments that exceed maximum available amount [Member]	Direct Morocco and Anschutz [Member]
									Unused and uncancelled portion of aggregate commitments that is less than or equal to maximum available amount [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'
Cash consideration, net of purchase price adjustments	'	'	'	'	$10,504,000	'	$2,408,000	'	'
Common shares issued	'	'	'	'	1,850,000	'	892,448	'	'
Common shares issued, price per share	'	'	'	'	$20.50	'	$31.50	'	'
Options fees paid applied to purchase price	'	'	'	'	'	10,000,000	'	'	'
Accounts receivable	'	'	'	'	20,000,000	'	'	'	'
Accounts receivable, gross value	'	'	'	'	23,500,000	'	'	'	'
Accounts receivable, doubtful debt allowance	'	'	'	'	3,500,000	'	'	'	'
Fair value of total consideration transferred	'	'	'	'	48,429,000	'	34,520,000	'	'
Percentage of working interest owned	'	'	'	'	'	'	'	100.00%	50.00%
Worth of common shares issuable if certain post-closing milestones achieved	'	'	10,000,000	10,000,000	'	'	'	'	'
Contingent consideration, fair value	$2,500,000	$10,000,000	'	'	'	'	$4,000,000	'	'

Acquisitions_Consideration_Pai

Acquisitions - Consideration Paid in Acquisition and Final Recognized Amounts of Assets Acquired and Liabilities Assumed, Thrace Basin Natural Gas Corporation (Detail) (Thrace Basin Natural Gas (Turkiye) Corporation [Member], USD $)	0 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Jul. 07, 2011	Jun. 07, 2011	Dec. 31, 2011
Thrace Basin Natural Gas (Turkiye) Corporation [Member]	'	'	'
Business Combination, Separately Recognized Transactions [Line Items]	'	'	'
Cash consideration, net of purchase price adjustments	'	$10,504	'
Value of common shares issued	'	37,925	'
Fair value of total consideration transferred	'	48,429	'
Acquisition related costs included in general and administrative expenses	'	'	1,013
Cash	1,845	'	'
Accounts receivable	19,997	'	'
Restricted cash	4,931	'	'
Total financial assets	26,773	'	'
Other current assets, consisting primarily of prepaid expenses	3,272	'	'
Deferred tax asset	722	'	'
Proved properties	14,526	'	'
Unproved properties	16,131	'	'
Land and buildings	2,601	'	'
Drilling services equipment and vehicles	19,512	'	'
Total oil and natural gas properties and other equipment	52,770	'	'
Accounts payable, consisting of normal trade obligations	5,960	'	'
Other current liabilities	5,596	'	'
Asset retirement obligation	6,480	'	'
Deferred tax liability	2,523	'	'
Bank loans	14,549	'	'
Total liabilities	35,108	'	'
Total identifiable net assets	$48,429	'	'

Acquisitions_Consideration_Pai1

Acquisitions - Consideration Paid in Acquisition and Final Recognized Amounts of Assets Acquired and Liabilities Assumed, Thrace Basin Natural Gas Corporation (Parenthetical) (Detail) (Thrace Basin Natural Gas (Turkiye) Corporation [Member])	0 Months Ended
	Jun. 07, 2011
Thrace Basin Natural Gas (Turkiye) Corporation [Member]	'
Business Combination, Separately Recognized Transactions [Line Items]	'
Common shares issued	1,850,000

Acquisitions_Consolidated_Resu

Acquisitions - Consolidated Results of Operation (Detail) (USD $)	7 Months Ended	10 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2011	Dec. 31, 2011	Dec. 31, 2011
	Thrace Basin Natural Gas (Turkiye) Corporation [Member]	Direct Morocco, Anschutz and Direct Bulgaria [Member]	Direct Morocco, Anschutz and Direct Bulgaria [Member]	Direct Morocco, Anschutz and Direct Bulgaria [Member]
			Continuing Operations [Member]	Discontinued Operation [Member]
Business Acquisition [Line Items]	'	'	'	'
Revenue	$13,466	$483	$483	'
Loss	($4,651)	($37,770)	($30,749)	($7,021)

Acquisitions_Consideration_Pai2

Acquisitions - Consideration Paid in Acquisition and Final Recognized Amounts of Assets Acquired and Liabilities Assumed, Direct Petroleum Bulgaria (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Feb. 18, 2011	Dec. 31, 2011
In Thousands, unless otherwise specified			Direct Petroleum Bulgaria EOOD [Member]	Direct Petroleum Bulgaria EOOD [Member]
Business Combination, Separately Recognized Transactions [Line Items]	'	'	'	'
Cash consideration, net of purchase price adjustments	'	'	$2,408	'
Value of common shares issued	'	'	28,112	'
Contingent consideration liabilities	2,500	10,000	4,000	'
Fair value of total consideration transferred	'	'	34,520	'
Acquisition related costs included in general and administrative expenses	'	'	'	117
Assets:	'	'	'	'
Cash	'	'	320	'
Accounts receivable	'	'	57	'
Total financial assets	'	'	377	'
Other current assets, consisting primarily of prepaid expenses	'	'	146	'
Oil and natural gas properties:	'	'	'	'
Proved properties	'	'	1,200	'
Unproved properties	'	'	32,840	'
Other equipment	'	'	79	'
Total oil and natural gas properties and other equipment	'	'	34,119	'
Liabilities:	'	'	'	'
Accounts payable, consisting of normal trade obligations	'	'	122	'
Total identifiable net assets	'	'	$34,520	'

Acquisitions_Consideration_Pai3

Acquisitions - Consideration Paid in Acquisition and Final Recognized Amounts of Assets Acquired and Liabilities Assumed, Direct Petroleum Bulgaria (Parenthetical) (Detail) (Direct Petroleum Bulgaria EOOD [Member])	0 Months Ended
	Feb. 18, 2011
Direct Petroleum Bulgaria EOOD [Member]	'
Business Combination, Separately Recognized Transactions [Line Items]	'
Common shares issued	892,448

Acquisitions_Unaudited_Pro_For

Acquisitions - Unaudited Pro Forma Results of Operations (Detail) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2011
Business Combinations [Abstract]	'
Total revenues	$139,999
Loss from continuing operations before income taxes	-82,856
Loss from continuing operations	-80,834
Loss from discontinued operations	-45,071
Net loss	($125,905)
Net loss per common share from continuing operations	'
Basic	($2.21)
Diluted	($2.21)
Net loss per common share from discontinued operations	'
Basic	($1.23)
Diluted	($1.23)

Goodwill_Schedule_of_Goodwill_

Goodwill - Schedule of Goodwill (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Business Combinations [Abstract]	'	'
Goodwill, Beginning balance	$9,021	$8,514
Foreign exchange change effect	-1,486	507
Goodwill, Ending balance	$7,535	$9,021

Property_and_Equipment_Capital

Property and Equipment - Capitalized Costs under Successful Efforts Method for Oil and Natural Gas Properties (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Oil and natural gas properties, proved	$260,857	$231,498
Oil and natural gas properties, unproved	54,392	68,938
Gross oil and natural gas properties	315,249	300,436
Accumulated depletion	-96,958	-74,099
Net oil and natural gas properties	218,291	226,337
Turkey [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Oil and natural gas properties, proved	260,232	229,462
Oil and natural gas properties, unproved	51,273	68,938
Bulgaria [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Oil and natural gas properties, proved	625	2,036
Oil and natural gas properties, unproved	$3,119	'

Property_and_Equipment_Additio

Property and Equipment - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'	'	'
Proved development wells excluded from depletion	$1.50	$1.80	'
Acquisition costs of proved properties	35.5	49.5	'
Well costs and additional development costs	126.9	105.3	'
Exploratory dry hole costs	16	24.7	26.8
Cash spent against exploratory dry hole cost	10	'	'
Proved properties [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Impairment charge on proved and unproved properties	11.3	6.7	14.6
Number of properties impaired	'	'	2
Proved properties [Member] | Bulgaria [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Impairment charge on proved and unproved properties	'	'	25.9
Unproved Properties [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Impairment charge on proved and unproved properties	11.3	8.4	30.2
Revisions in natural gas reserves, Alpullu field [Member] | Proved properties [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Impairment charge on proved and unproved properties	'	2.7	'
Banarli license [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Impairment charge on proved and unproved properties	'	5.2	'
Software [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property plant and equipment excluded from depreciation	0.7	'	'
Inventory [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property plant and equipment excluded from depreciation	24.3	20.5	'
Kazanci-5 well [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Exploratory drilling costs capitalized	$2.60	'	'

Property_and_Equipment_Histori

Property and Equipment - Historical Cost of Equipment and Other Property on Gross Basis with Accumulated Depreciation (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	$39,916	$35,747
Accumulated depreciation	-7,235	-5,932
Net equipment and other property	32,681	29,815
Other equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	2,678	2,013
Inventory [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	24,318	20,517
Gas gathering system and facilities [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	4,485	5,369
Vehicles [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	321	131
Leasehold improvements, office equipment and software [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	$8,114	$7,717

Recovered_Sheet2

Commodity Derivative Instruments - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'	'	'
Net gain (loss) on sale of commodity derivative contracts	$2.70	$5.50	$8.40

Recovered_Sheet3

Commodity Derivative Instruments - Fair Value of Derivative Instruments of Future Crude Oil Production (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Estimated Fair Value of Liability	($387)	($545)
Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Estimated Fair Value of Liability	-7,580	-8,245
January 1, 2013 - December 31, 2013 [Member] | Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	'	775
Collars Weighted Average Minimum Price (per Bbl)	'	82.26
Additional Call Weighted Average Maximum Price (per Bbl)	'	121.36
Estimated Fair Value of Liability	'	-253
January 1, 2013 - December 31, 2013 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	'	831
Collars Weighted Average Minimum Price (per Bbl)	'	85
Additional Call Weighted Average Maximum Price (per Bbl)	'	97.13
Estimated Fair Value of Liability	'	-3,655
January 1, 2013 - December 31, 2013 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	'	162.13
January 1, 2014 - December 31, 2014 [Member] | Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	622	622
Collars Weighted Average Minimum Price (per Bbl)	80.83	80.83
Additional Call Weighted Average Maximum Price (per Bbl)	118.07	118.07
Estimated Fair Value of Liability	-387	-292
January 1, 2014 - December 31, 2014 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	726	726
Collars Weighted Average Minimum Price (per Bbl)	85	85
Additional Call Weighted Average Maximum Price (per Bbl)	97.13	97.13
Estimated Fair Value of Liability	-3,350	-2,150
January 1, 2014 - December 31, 2014 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	162.13	162.13
January 1, 2015-December 31, 2015 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	1,016	1,016
Collars Weighted Average Minimum Price (per Bbl)	85	85
Additional Call Weighted Average Maximum Price (per Bbl)	91.88	91.88
Estimated Fair Value of Liability	($4,230)	($2,440)
January 1, 2015-December 31, 2015 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	151.88	151.88

Asset_retirement_obligations_A

Asset retirement obligations - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligations [Line Items]	'	'	'
Asset retirement obligation, net present value	$10,896,000	$11,958,000	$13,534,000
Asset retirement obligation, undiscounted value	$18,500,000	'	'
Credit-adjusted risk-free rate used to discount asset retirement obligation	5.75%	5.75%	'
Turkey [Member]	'	'	'
Asset Retirement Obligations [Line Items]	'	'	'
Inflation rate per annum used to adjust asset retirement obligation	6.20%	'	'
Bulgaria [Member]	'	'	'
Asset Retirement Obligations [Line Items]	'	'	'
Inflation rate per annum used to adjust asset retirement obligation	2.50%	'	'

Asset_retirement_obligations_C

Asset retirement obligations - Changes in Asset Retirement Obligations (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Asset Retirement Obligation Disclosure [Abstract]	'		'		'
Asset retirement obligations at beginning of period	$11,958		$13,534		'
Change in estimates	-7	[1]	-3,868	[1]	'
Liabilities settled	-296		-110		'
Foreign exchange change effect	-2,258		793		'
Additions	991		899		'
Accretion expense	508		710		1,142
Asset retirement obligations at end of period	10,896		11,958		13,534
Less: current portion	610		818		'
Long-term portion	$10,286		$11,140		'
[1]	For 2013 and 2012, we used cost estimates provided by third-party engineers.

Loans_Payable_Debt_Detail

Loans Payable - Debt (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Total third-party debt	$69,766	$32,766
short-term third-party debt	43,284	'
Long-term third-party debt	26,482	32,766
Amended and Restated Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Total third-party debt	49,766	32,766
Long-term third-party debt	49,766	'
TBNG credit facility (short term) [Member]	'	'
Debt Instrument [Line Items]	'	'
Total third-party debt	$20,000	'

Loans_Payable_Additional_Infor

Loans Payable - Additional Information (Detail)

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Nov. 05, 2013

Oct. 09, 2013

Dec. 31, 2012

Nov. 05, 2013

Oct. 09, 2013

Dec. 31, 2013

Jun. 18, 2013

Jun. 18, 2013

Jun. 18, 2013

Jul. 30, 2012

Dec. 31, 2013

Oct. 02, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

USD ($)

USD ($)

TBNG credit facility (short term) [Member]

TBNG credit facility (short term) [Member]

TBNG credit facility (short term) [Member]

TBNG credit facility (short term) [Member]

TBNG credit facility (short term) [Member]

TBNG credit facility (short term) [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

Amended and Restated Credit Facility [Member]

CreditFacility

CreditFacility

USD ($)

TRY

Cash [Member]

Letter of Credit [Member]

USD ($)

USD ($)

USD ($)

USD ($)

Unused and uncancelled portion of aggregate commitments that is less than or equal to maximum available amount [Member]

Unused and uncancelled portion of aggregate commitments that exceed maximum available amount [Member]

Collateralized or backed by standby letter of credit issued [Member]

Other letters of credit [Member]

TRY

Bank Guarantees [Member]

TRY

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt maturity date

'

'

'

'

'

'

'

'

'

'

'

18-May-16

'

'

'

'

'

'

Debt maturity date description

'

'

'

'

'

'

'

'

'

'

'

'The Amended and Restated Credit Facility matures on the earlier of (i) May 18, 2016 or (ii) the last date of the borrowing base calculation period that immediately precedes the date that the semi-annual report of Standard Bank and the Borrowers determines that the aggregate amount of hydrocarbons to be produced from the borrowing base assets in Turkey are less than 25% of the amount of hydrocarbons to be produced from the borrowing base assets shown in the initial report prepared by Standard Bank and the Borrowers

'

'

'

'

'

'

Borrowings under credit facility

$20,000,000

'

'

'

'

'

'

'

'

'

'

$10,000,000

'

'

'

'

'

'

Debt instrument above LIBOR interest rate

'

'

'

'

'

'

'

'

'

'

'

5.50%

'

'

'

'

'

'

Debt instrument interest rate at period end

'

'

'

'

'

'

'

'

'

'

'

5.74%

'

'

'

'

'

'

Commitment fee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.20%

1.10%

'

'

Letter of credit, fronting fee

'

'

'

'

'

'

'

'

'

'

'

0.25%

'

'

'

'

'

'

Letter of credit fee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

5.50%

Line of credit facility amount of commitment

67,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility amount of commitment at future specified date

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing under amended and restated credit facility

'

'

'

'

'

'

36,900,000

78,800,000

60,000,000

18,800,000

'

'

50,600,000

59,700,000

'

'

'

'

Pay down of debt

'

'

'

'

'

'

'

'

'

'

45,200,000

'

'

'

'

'

'

'

Loan payable, Long-Term

$26,482,000

'

'

$32,766,000

'

'

'

'

'

'

'

$49,766,000

'

'

'

'

'

'

Current ratio to be maintained by borrowers

'

'

'

'

'

'

'

'

'

'

'

1.1

'

'

'

'

'

'

Line of Credit Facility, Initiation Date

'

'

'

'

'

'

18-Jun-13

'

'

'

'

'

'

'

'

'

'

'

Number of borrowings under credit facility

'

'

'

'

2

2

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility term

'

'

'

'

'1 year

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility stated interest rate

'

4.60%

4.60%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Renewed borrowing period

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shareholders_Equity_Additional

Shareholders Equity - Additional Information (Detail) (USD $)	1 Months Ended			12 Months Ended				3 Months Ended	12 Months Ended
	Jul. 31, 2013	Jun. 30, 2011	Feb. 28, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Jun. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
								Restricted stock units [Member]	Restricted stock units [Member]	Restricted stock units [Member]	Restricted stock units [Member]
											Maximum [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Issuance of common shares	351,074	1,850,000	892,448	'	'	'	'	'	'	'	'
Issuance of common shares, price per share	$7.12	$20.50	$31.50	'	'	'	'	'	'	'	'
Estimated forfeiture rate of RSUs	'	'	'	'	'	'	'	'	10.00%	'	'
Restricted stock unit, vesting period	'	'	'	'	'	'	'	'	'	'	'4 years
Share-based compensation expense	'	'	'	'	'	'	'	$1,000,000	$1,700,000	$3,600,000	'
Unrecognized compensation expense	'	'	'	'	'	'	'	'	1,300,000	'	'
Unrecognized compensation expense recognition period	'	'	'	'	'	'	'	'	'1 year 4 months 24 days	'	'
Options previously outstanding, term	'	'	'	'5 years	'	'	'	'	'	'	'
Number of options outstanding	'	'	'	0	16,000	114,000	211,000	'	'	'	'
Share-based compensation expense, stock option	'	'	'	0	0	0	'	'	'	'	'
Share based awards anti-dilutive	'	'	'	758,586	959,438	2,075,213	'	'	'	'	'
Contingent liability	'	'	'	$2,500,000	'	'	'	'	'	'	'
Common shares potentially dilutive	'	'	'	294,117	'	'	'	'	'	'	'

Shareholders_equity_Restricted

Shareholders' equity - Restricted Stock Unit Activity (Detail) (Restricted stock units [Member], USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013
Restricted stock units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Unvested RSUs outstanding, beginning balance	315
Granted	172
Forfeited	-62
Vested	-129
Unvested RSUs outstanding, ending balance	296
Unvested RSUs, weighted average grant date fair value Per RSU, beginning balance	$12.46
Granted, weighted average grant date fair value Per RSU	$7.10
Forfeited, weighted average grant date fair value Per RSU	$10.20
Vested, weighted average grant date fair value Per RSU	$14.53
Unvested RSUs weighted average grant date fair value Per RSU, ending balance	$8.91

Shareholders_equity_Details_of

Shareholders' equity - Details of Stock Options Activity (Detail) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Equity [Abstract]	'	'	'
Number of Options, Outstanding, Beginning Balance	16	114	211
Number of Options, Granted	'	'	'
Number of Options, Expired	-16	-17	-13
Number of Options, Exercised	'	-81	-84
Number of Options, Outstanding Ending balance	0	16	114
Number of Options, Exercisable	'	16	114
Outstanding, Weighted Average Exercise Price Per Share, Beginning balance	$12.30	$9.07	$8.60
Granted, Weighted Average Exercise Price Per Share	'	'	'
Expired, Weighted Average Exercise Price Per Share	$12.30	$10	$12.96
Exercised, Weighted Average Exercise Price Per Share	'	$8.24	$7.39
Outstanding, Weighted Average Exercise Price Per Share, Ending balance	'	$12.30	$9.07
Exercisable, Weighted Average Exercise Price Per Share	'	$12.30	$9.07

Shareholders_equity_Basic_and_

Shareholders' equity - Basic and Diluted Earnings Per Common Share Computations (Detail) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Equity [Abstract]	'	'	'
Net loss from continuing operations	($13,271)	($6,373)	($77,574)
Net (loss) income from discontinued operations	($442)	$22,619	($43,369)
Weighted average common shares outstanding	37,069	36,742	35,597
Continuing operations	($0.36)	($0.17)	($2.18)
Discontinued operations	($0.01)	$0.62	($1.22)
Weighted average common shares and common equivalent shares outstanding	37,069	36,742	35,597
Continuing operations	($0.36)	($0.17)	($2.18)
Discontinued operations	($0.01)	$0.62	($1.22)

Income_Taxes_Reconciliation_of

Income Taxes - Reconciliation of Bermuda Income Tax Expense to Actual Income Tax Expense (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Disclosure [Abstract]	'	'	'
Statutory tax rate	0.00%	0.00%	0.00%
Income (loss) from continuing operations before income taxes	($12,164)	$118	($80,139)
Increase (decrease) resulting from:	'	'	'
Foreign tax rate differentials	-1,443	8,607	-11,173
Change in valuation allowance	982	-2,026	6,871
Expiration of non-capital tax loss carryovers	1,367	1,601	1,198
Other	201	-1,691	539
Total	$1,107	$6,491	($2,565)

Income_Taxes_Components_of_Net

Income Taxes - Components of Net Deferred Income Tax Liability (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Deferred tax assets	'	'
Unrealized derivative losses	$1,594	$1,758
Timing of accruals	1,043	1,251
Non-capital loss carryovers	25,868	28,455
Valuation Allowance	-28,404	-29,059
Total deferred tax assets	101	2,405
Deferred tax liabilities	'	'
Property and equipment	-13,093	-16,993
Total deferred tax liabilities	-13,093	-16,993
Net deferred tax liabilities	-12,992	-14,588
Components of net deferred tax liabilities	'	'
Current assets	2,239	1,895
Non-current assets	903	'
Non-current liabilities	-16,134	-16,483
Net deferred tax liabilities	($12,992)	($14,588)

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail)	12 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
	USD ($)	USD ($)	Amity and Petrogas [Member]	Amity and Petrogas [Member]	Turkey [Member]	Turkey [Member]	Romania [Member]	Romania [Member]	Bulgaria [Member]	Bulgaria [Member]	U.S
			USD ($)	Maximum [Member]	USD ($)	TRY	USD ($)	RON	USD ($)	BGN	USD ($)
Income Tax [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Non-capital tax losses	'	'	'	'	$62.80	134	$7.70	24.9	$4.10	5.8	$26.10
Non-capital tax losses, expiration date	'	'	'	'	'2014	'2014	'2014	'2014	'2014	'2014	'2018
Tax indemnification period	'	'	'6 years	'	'	'	'	'	'	'	'
Tax indemnification percentage on purchase price	'	'	'	50.00%	'	'	'	'	'	'	'
Purchase price of acquired entity	'	'	96.3	'	'	'	'	'	'	'	'
Unrecognized tax benefits, tax portion	3.3	'	'	'	'	'	'	'	'	'	'
Unrecognized tax benefits, tax penalties	0.7	'	'	'	'	'	'	'	'	'	'
Unrecognized tax benefits, interest portion on tax	1.8	'	'	'	'	'	'	'	'	'	'
Unrecognized tax benefits, interest on income taxes expense	$0.50	$1.30	'	'	'	'	'	'	'	'	'

Segment_Information_Additional

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2013
	Segment
Segment Reporting [Abstract]	'
Number of reportable geographic segments	2

Segment_Information_Financial_

Segment Information - Financial Information of Geographic Segments (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Segment Reporting Information [Line Items]	'		'		'
Total revenues	$130,827		$143,908		$128,905
Production	18,602		17,804		18,475
Exploration, abandonment and impairment	27,333		39,993		60,952
Cost of purchased natural gas	2,247		7,694		2,645
Seismic and other exploration	14,009		5,040		11,542
Revaluation of contingent consideration	-5,000		'		6,000
General and administrative	29,020		33,947		36,305
Depreciation, depletion and amortization	41,322		28,215		39,008
Accretion of asset retirement obligations	508		710		1,142
Total costs and expenses	128,041		133,403		176,069
Operating (loss) income	2,786		10,505		-47,164
Interest and other expense	-3,929		-8,340		-13,665
Interest and other income	1,340		2,418		1,089
Loss on commodity derivative contracts	-2,698		-5,548		-8,426
Foreign exchange (loss) gain	-9,663		1,083		-11,973
(Loss) income from continuing operations before income taxes	-12,164		118		-80,139
Income tax provision	-1,107		-6,491		2,565
Net (loss) income from continuing operations	-13,271		-6,373		-77,574
Total assets	346,050	[1]	356,639	[1]	321,634	[1]
Goodwill	7,535		9,021		8,514
Capital expenditures	99,951		81,824		152,440
Corporate, Non-Segment [Member]	'		'		'
Segment Reporting Information [Line Items]	'		'		'
Total revenues	'		'		66
Production	5		169		359
Exploration, abandonment and impairment	'		285		2
Cost of purchased natural gas	'		'		'
Seismic and other exploration	100		304		1,801
Revaluation of contingent consideration	'		'		'
General and administrative	12,685		10,982		14,714
Depreciation, depletion and amortization	69		30		127
Accretion of asset retirement obligations	'		'		'
Total costs and expenses	12,859		11,770		17,003
Operating (loss) income	-12,859		-11,770		-16,937
Interest and other expense	'		-1,890		-6,784
Interest and other income	284		308		27
Loss on commodity derivative contracts	'		'		'
Foreign exchange (loss) gain	-9		79		-23
(Loss) income from continuing operations before income taxes	-12,584		-13,273		-23,717
Income tax provision	'		'		'
Net (loss) income from continuing operations	-12,584		-13,273		-23,717
Total assets	14,070		14,930		3,716
Goodwill	'		'		'
Capital expenditures	1,003		'		'
Operating Segments [Member] | Turkey [Member]	'		'		'
Segment Reporting Information [Line Items]	'		'		'
Total revenues	130,701		143,650		128,356
Production	18,384		17,328		17,484
Exploration, abandonment and impairment	27,116		39,708		37,008
Cost of purchased natural gas	2,247		7,694		2,645
Seismic and other exploration	13,909		4,726		9,657
Revaluation of contingent consideration	'		'		'
General and administrative	16,068		20,603		21,585
Depreciation, depletion and amortization	41,196		28,092		38,389
Accretion of asset retirement obligations	475		679		1,131
Total costs and expenses	119,395		118,830		127,899
Operating (loss) income	11,306		24,820		457
Interest and other expense	-3,929		-6,450		-6,878
Interest and other income	1,056		2,110		914
Loss on commodity derivative contracts	-2,698		-5,548		-8,426
Foreign exchange (loss) gain	-9,664		1,054		-11,740
(Loss) income from continuing operations before income taxes	-3,929		15,986		-25,673
Income tax provision	-1,107		-6,491		2,565
Net (loss) income from continuing operations	-5,036		9,495		-23,108
Total assets	321,749		339,752		313,754
Goodwill	7,535		9,021		8,514
Capital expenditures	96,206		80,957		117,071
Operating Segments [Member] | Bulgaria [Member]	'		'		'
Segment Reporting Information [Line Items]	'		'		'
Total revenues	126		258		483
Production	213		307		632
Exploration, abandonment and impairment	217		'		23,942
Cost of purchased natural gas	'		'		'
Seismic and other exploration	'		10		84
Revaluation of contingent consideration	-5,000		'		6,000
General and administrative	267		2,362		6
Depreciation, depletion and amortization	57		93		492
Accretion of asset retirement obligations	33		31		11
Total costs and expenses	-4,213		2,803		31,167
Operating (loss) income	4,339		-2,545		-30,684
Interest and other expense	'		'		-3
Interest and other income	'		'		148
Loss on commodity derivative contracts	'		'		'
Foreign exchange (loss) gain	10		-50		-210
(Loss) income from continuing operations before income taxes	4,349		-2,595		-30,749
Income tax provision	'		'		'
Net (loss) income from continuing operations	4,349		-2,595		-30,749
Total assets	10,231		1,957		4,164
Goodwill	'		'		'
Capital expenditures	$2,742		$867		$35,369
[1]	Excludes assets from our discontinued Moroccan operations and oilfield services business of $0.5 million, $1.6 million, and $127.2 million at December 31, 2013, 2012 and 2011, respectively.

Segment_Information_Financial_1

Segment Information - Financial Information of Geographic Segments (Parenthetical) (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Segment Reporting [Abstract]	'	'	'
Assets from discontinued operations and services	$0.50	$1.60	$127.20

Financial_Instruments_Addition

Financial Instruments - Additional Information (Detail)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2013	Dec. 31, 2013
In Thousands, unless otherwise specified	USD ($)	USD ($)	USD ($)	USD ($)	Foreign Currency Risk [Member]	Foreign Currency Risk [Member]
					USD ($)	TRY
Fair Value Disclosures [Line Items]	'	'	'	'	'	'
Foreign Currency exchange rate risk	$12,881	$14,768	$15,116	$34,676	$10,700	22,800

Financial_Instruments_Valuatio

Financial Instruments - Valuation of Financial Assets and Liabilities (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	($7,967)	($8,790)
Derivative Financial Instruments (commodity) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	-7,967	-8,790
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	'	'
Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) [Member] | Derivative Financial Instruments (commodity) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	'	'
Significant Other Observable Inputs (Level 2) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	-7,967	-8,790
Significant Other Observable Inputs (Level 2) [Member] | Derivative Financial Instruments (commodity) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	-7,967	-8,790
Significant Unobservable Inputs (Level 3) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	'	'
Significant Unobservable Inputs (Level 3) [Member] | Derivative Financial Instruments (commodity) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	'	'

Commitments_Aggregate_Annual_C

Commitments - Aggregate Annual Commitments Other Than Debt (Detail) (Leases and other [Member], USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Leases and other [Member]	'
Other Commitments [Line Items]	'
Total	$5,602
2014	2,546
2015	903
2016	299
2017	99
2018	33
Thereafter	$1,722

Commitments_Additional_Informa

Commitments - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Commitments And Contingencies Disclosure [Abstract]	'	'	'
Normal operations purchase arrangements, notice period	'30 days	'	'
Rent expense	$3.30	$3.50	$3.40

Contingencies_Additional_Infor

Contingencies - Additional Information (Detail) (USD $)	3 Months Ended	12 Months Ended
	Jun. 30, 2012	Dec. 31, 2013	Dec. 31, 2011
Loss Contingencies [Line Items]	'	'	'
Accrued liabilities relating to our Tselfat exploration permit	$5,000,000	'	'
Accrued liabilities	2,000,000	'	'
Contingent liability Reversed	'	-5,000,000	6,000,000
Stefenetz Concession Area [Member] | Amendment [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Stock issued, non cash consideration, value	'	10,000,000	'
Area of land leased under the production	'	200,000	'
Bulgaria [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Recovery of contractual obligations	2,000,000	'	'
Direct Petroleum [Member] | Amendment [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Stock issued, non cash consideration, shares	'	351,074	'
Stock issued, non cash consideration, value	'	2,500,000	'
Direct Petroleum [Member] | Etropole Shale [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Contingent liability Reversed	'	5,000,000	'
Direct Petroleum [Member] | Deventci-R2 [Member] | Amendment [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Contingent liability Reversed	'	2,500,000	'
Contingency, Purchase obligation	'	7,500,000	'
Contingency, Purchase obligation, additional liquidated damages	'	2,500,000	'
Contingent liability	'	0	'
Moroccan Government [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Recovery of contractual obligations	5,500,000	'	'
Bank guarantee	'	$1,000,000	'

Related_Party_Transactions_Add

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

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Jun. 13, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 23, 2011

Aug. 23, 2011

Apr. 05, 2013

Sep. 01, 2010

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Longfellow [Member]

Longfellow [Member]

Longfellow [Member]

Dalea [Member]

Dalea [Member]

Mitchell, his wife and his children [Member]

Mitchell, his wife and his children [Member]

MedOil Supply, LLC [Member]

TransAtlantic Turkey, Ltd [Member]

Viking Oilfield Services Services Agreement [Member]

Viking International master service agreement [Member]

sqft

Second Floor [Member]

First Floor Commencement Date [Member]

Viking Drilling [Member]

Riata Management [Member]

Longfellow [Member]

Riata Management [Member]

Lease agreement with Gundem [Member]

sqft

Room

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common share purchase warrants issued

'

'

'

'

'

'

730,000

'

'

'

'

'

'

'

Common share purchase warrants issued, expiration date

'

'

'

'

'

'

1-Sep-13

'

'

'

'

'

'

'

Common share purchase warrants, exercise price

'

'

'

'

'

'

60

'

'

'

'

'

'

'

Sale of business, aggregate sales price

$168,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash received from sale of business

157,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate purchase price in promissory note

11,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Promissory note payable, term

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Promissory note, interest rate

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of ownership interest owned by related party

'

'

'

'

'

'

'

85.00%

100.00%

100.00%

100.00%

'

'

'

Number of rooms leased

'

'

'

'

'

'

'

'

'

'

'

6

'

'

Amount due to related party

'

'

'

'

'

'

'

'

'

'

'

6,000

'

'

Lease agreement area, additional office space leased

'

'

'

5,300

'

4,700

'

'

'

'

'

'

'

'

Lease expiration period

'

'

'

'5 years

'

'5 years

'

'

'

'

'

'

'

'

Lease rent payable

'

'

'

6,625

0

7,533

'

'

'

'

'

'

'

'

Service agreement term

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'5 years

Capital and operating expenditures

'

$85,700,000

$73,800,000

'

'

'

'

'

'

'

'

'

'

'

Related_Party_Transactions_Rel

Related Party Transactions - Related Party Accounts Receivable and Accounts Payable (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	$1,004	$419
Total related party accounts payable	23,090	15,634
Viking International master service agreement [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	939	313
Total related party accounts payable	15,956	15,467
Riata Management Service Agreement [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	65	'
Total related party accounts payable	334	167
Dalea [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	'	106
Viking Geophysical master services agreement [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts payable	$6,800	'

Discontinued_Operations_Additi

Discontinued Operations - Additional Information (Detail) (USD $)	0 Months Ended	12 Months Ended
	Jun. 13, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Sale of business, aggregate sales price	$168,500,000	'	'	'
Cash received from sale of business	157,000,000	'	'	'
Aggregate purchase price in promissory note	11,500,000	'	'	'
Promissory note payable, term	'5 years	'	'	'
Promissory note, interest rate	3.00%	'	'	'
Pay down of debt	'	29,785,000	78,931,000	18,024,000
Credit agreement with Dalea [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Pay down of debt	73,000,000	'	'	'
Dalea Credit Agreement [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Pay down of debt	11,000,000	'	'	'
Promissory note with Viking Drilling [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Pay down of debt	900,000	'	'	'
Credit agreement with a Turkish bank [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Pay down of debt	1,800,000	'	'	'
Amended and Restated Credit Facility [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Pay down of debt	$45,200,000	'	'	'

Discontinued_Operations_Assets

Discontinued Operations - Assets and Liabilities Held for Sale (Detail) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Discontinued Operations And Disposal Groups [Abstract]	'		'
Cash	$23		$93
Other assets	513	[1]	1,526	[1]
Total assets held for sale	536		1,619
Accrued expenses and other liabilities	7,559		8,416
Total liabilities held for sale	$7,559		$8,416
[1]	Other assets consist primarily of $0.5 million and $1.5 million of restricted cash at December 31, 2013 and December 31, 2012, respectively.

Discontinued_Operations_Assets1

Discontinued Operations - Assets and Liabilities Held for Sale (Parenthetical) (Detail) (Other Assets [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Other Assets [Member]	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'
Restricted Cash	$0.50	$1.50

Discontinued_Operations_Operat

Discontinued Operations - Operating Results from Discontinued Operations (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Discontinued Operations And Disposal Groups [Abstract]	'	'	'
Total revenues	'	$19,956	$28,419
Total costs and expenses	-505	-24,682	-70,265
Total other income (expense)	63	-357	2,732
Loss from discontinued operations before income taxes	-442	-5,083	-39,114
Gain on disposal of discontinued operations	'	35,999	'
Income tax provision	'	-8,297	-4,255
Net (loss) income from discontinued operations	($442)	$22,619	($43,369)

Subsequent_events_Additional_I

Subsequent events - Additional Information (Detail) (Subsequent Event [Member], USD $)	0 Months Ended	1 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 04, 2014	Feb. 28, 2014
Subsequent Event [Member]	'	'
Subsequent Event [Line Items]	'	'
Reverse stock splits number of shares outstanding stock converted into one share of common stock	10	'
Issued and outstanding common shares before stock splits	374,026,984	'
Issued and outstanding common shares after stock splits	37,402,698	'
Effective date of stock split	6-Mar-14	'
Exploration expense	'	$3,500
Percentage of fund for initial exploration	'	100.00%
Ownership percentage	'	50.00%