TransAtlantic Petroleum (TAT) 10-Q 7 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 01, 2014
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Trading Symbol	'TAT	'
Entity Registrant Name	'TRANSATLANTIC PETROLEUM LTD.	'
Entity Central Index Key	'0001092289	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	37,479,956

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$5,161	$12,881
Accounts receivable	'	'
Oil and natural gas sales, net	38,796	30,619
Joint interest and other	5,974	15,348
Related party	192	1,004
Prepaid and other current assets	3,242	5,072
Deferred income taxes	2,666	2,239
Assets held for sale	29	536
Total current assets	56,060	67,699
Oil and natural gas properties (successful efforts method)	'	'
Proved	298,369	260,857
Unproved	61,957	54,392
Equipment and other property	41,285	39,916
Property and equipment, gross	401,611	355,165
Less accumulated depreciation, depletion and amortization	-127,761	-104,193
Property and equipment, net	273,850	250,972
Other long-term assets:	'	'
Other assets	9,973	8,880
Note receivable - related party	11,500	11,500
Goodwill	7,574	7,535
Total other assets	29,047	27,915
Total assets	358,957	346,586
Current liabilities:	'	'
Accounts payable	13,002	16,712
Accounts payable - related party	7,697	23,090
Accrued liabilities	16,477	20,658
Derivative liabilities	8,279	3,737
Asset retirement obligations	397	610
Loan payable	28,288	43,284
Liabilities held for sale	7,533	7,559
Total current liabilities	81,673	115,650
Long-term liabilities:	'	'
Asset retirement obligations	10,830	10,286
Accrued liabilities	6,785	6,487
Deferred income taxes	19,018	16,134
Loan payable	59,766	26,482
Derivative liabilities	5,716	4,230
Total long-term liabilities	102,115	63,619
Total liabilities	183,788	179,269
Commitments and contingencies	'	'
Shareholders' equity:	'	'
Common shares, $0.10 par value, 100,000,000 shares authorized; 37,447,909 shares issued and outstanding as of June 30, 2014 and 37,340,206 shares issued and outstanding as of December 31, 2013	3,745	3,734
Additional paid-in capital	542,725	542,091
Accumulated other comprehensive loss	-63,188	-64,985
Accumulated deficit	-308,113	-313,523
Total shareholders' equity	175,169	167,317
Total liabilities and shareholders' equity	$358,957	$346,586

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Statement Of Financial Position [Abstract]	'	'
Common shares, par value	$0.10	$0.10
Common shares, authorized	100,000,000	100,000,000
Common shares, issued	37,447,909	37,340,206
Common shares, outstanding	37,447,909	37,340,206

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Loss) (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Oil and natural gas sales	$40,441	$29,455	$73,425	$62,180
Sales of purchased natural gas	491	719	1,036	1,525
Other	129	342	246	855
Total revenues	41,061	30,516	74,707	64,560
Costs and expenses:	'	'	'	'
Production	4,666	3,328	8,797	8,855
Exploration, abandonment and impairment	3,775	11,885	7,916	15,749
Cost of purchased natural gas	440	619	925	1,331
Seismic and other exploration	892	1,090	4,186	1,333
Revaluation of contingent consideration	'	-5,000	-2,500	-5,000
General and administrative	7,460	6,893	14,012	14,416
Depreciation, depletion and amortization	12,588	9,581	22,678	18,557
Accretion of asset retirement obligations	106	124	204	253
Total costs and expenses	29,927	28,520	56,218	55,494
Operating income	11,134	1,996	18,489	9,066
Other (expense) income:	'	'	'	'
Interest and other expense	-1,769	-955	-2,972	-1,845
Interest and other income	327	307	600	682
(Loss) gain on commodity derivative contracts	-9,522	4,278	-8,560	3,502
Foreign exchange gain (loss)	2,494	-2,543	1,150	-3,030
Total other (expense) income	-8,470	1,087	-9,782	-691
Income from continuing operations before income taxes	2,664	3,083	8,707	8,375
Current income tax expense	-838	-528	-907	-1,867
Deferred income tax (expense) benefit	-389	348	-2,370	-573
Net income from continuing operations	1,437	2,903	5,430	5,935
Net loss from discontinued operations	0	0	-20	-93
Net income	1,437	2,903	5,410	5,842
Other comprehensive income (loss):	'	'	'	'
Foreign currency translation adjustment	5,092	-13,543	1,797	-16,379
Comprehensive income (loss)	$6,529	($10,640)	$7,207	($10,537)
Basic net income per common share:	'	'	'	'
Continuing operations	$0.04	$0.08	$0.15	$0.16
Discontinued operations	$0	$0	$0	$0
Weighted average common shares outstanding	37,411	36,893	37,402	36,891
Diluted net income per common share:	'	'	'	'
Continuing operations	$0.04	$0.08	$0.15	$0.16
Discontinued operations	$0	$0	$0	$0
Weighted average common and common equivalent shares outstanding	37,411	36,893	37,402	36,891

Consolidated_Statements_of_Equ

Consolidated Statements of Equity (Unaudited) (USD $)	Total	Common Shares [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Loss [Member]	Accumulated Deficit [Member]
In Thousands
Beginning balance at Dec. 31, 2013	$167,317	$3,734	$542,091	($64,985)	($313,523)
Beginning balance, shares at Dec. 31, 2013	'	37,340	'	'	'
Issuance of restricted stock units	'	11	-11	'	'
Issuance of restricted stock units, shares	'	108	'	'	'
Share-based compensation	713	'	713	'	'
Tax withholding on restricted stock units	-68	'	-68	'	'
Foreign currency translation adjustments	1,797	'	'	1,797	'
Net income	5,410	'	'	'	5,410
Ending balance at Jun. 30, 2014	$175,169	$3,745	$542,725	($63,188)	($308,113)
Ending balance, shares at Jun. 30, 2014	'	37,448	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (Unaudited) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Operating activities:	'	'
Net income	$5,410	$5,842
Adjustment for net loss from discontinued operations	20	93
Net income from continuing operations	5,430	5,935
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Share-based compensation	713	881
Foreign currency loss	74	2,138
Loss (gain) on commodity derivative contracts	8,560	-3,502
Cash settlement on commodity derivative contracts	-2,533	-1,736
Amortization of loan financing costs	764	256
Deferred income tax expense	2,370	573
Exploration, abandonment and impairment	7,916	15,749
Depreciation, depletion and amortization	22,678	18,557
Accretion of asset retirement obligations	204	253
Revaluation of contingent consideration	-2,500	-5,000
Changes in operating assets and liabilities:	'	'
Accounts receivable	2,215	10,432
Prepaid expenses and other assets	2,056	141
Accounts payable and accrued liabilities	-6,487	11,045
Net cash provided by operating activities from continuing operations	41,460	55,722
Net cash used in operating activities from discontinued operations	-64	-1,071
Net cash provided by operating activities	41,396	54,651
Investing activities:	'	'
Additions to oil and natural gas properties	-62,993	-52,320
Additions to equipment and other properties	-2,589	-7,925
Restricted cash	'	-206
Net cash used in investing activities from continuing operations	-65,582	-60,451
Net cash provided by investing activities from discontinued operations	500	1,016
Net cash used in investing activities	-65,082	-59,435
Financing activities:	'	'
Tax withholding on restricted stock units	-68	'
Loan proceeds	26,092	22,885
Loan repayment	-7,804	-15,885
Loan financing costs	-2,176	'
Net cash provided by financing activities from continuing operations	16,044	7,000
Effect of exchange rate changes on cash	-78	-1,064
Net (decrease) increase in cash and cash equivalents	-7,720	1,152
Cash and cash equivalents, beginning of period	12,881	14,768
Cash and cash equivalents, end of period	5,161	15,920
Supplemental disclosures:	'	'
Cash paid for interest	1,212	1,539
Cash paid for taxes	'	1,448
Supplemental non-cash financing activities:	'	'
Repayment of amended and restated credit facility from refinancing	$49,766	'

General

General	6 Months Ended
	Jun. 30, 2014
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, have stable governments, 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. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of August 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.
	Certain information and footnote disclosures normally included in the consolidated financial statements prepared in accordance with U.S. GAAP have been condensed or omitted in this Form 10-Q pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). These consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Form 10-K for the year ended December 31, 2013.

Recent_accounting_pronouncemen

Recent accounting pronouncements	6 Months Ended
	Jun. 30, 2014
Text Block [Abstract]	'
Recent accounting pronouncements	'
	2. Recent accounting pronouncements
	In April 2014, the Financial Accounting Standard Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, Reporting Discontinued Operations and Disclosures of Components of an Entity (“ASU 2014-08”). ASU 2014-08 revises the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have (or will have) a major effect on an entity’s operations and financial results, removing the lack of continuing involvement criteria and requiring discontinued operations reporting for the disposal of an equity method investment that meets the definition of discontinued operations. The update also requires expanded disclosures for discontinued operations, including disclosure of pretax profit or loss of an individually significant component of an entity that does not qualify for discontinued operations reporting. The update is effective prospectively to all periods beginning after December 15, 2014. Currently, we do not expect the adoption of ASU 2014-08 to have a material impact on our consolidated financial statements or results of operations.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). ASU 2014-09 amends the existing accounting standards for revenue recognition and is based on the principle that revenue should be recognized to depict the transfer of goods or services to a customer at an amount that reflects the consideration a company expects to receive in exchange for those goods or services. The update is effective for periods beginning after December 15, 2016. We are currently assessing the potential impact of ASU 2014-09 on our consolidated financial statements and results of operations.
	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.

Property_and_equipment

Property and equipment	6 Months Ended
	Jun. 30, 2014
Property Plant And Equipment [Abstract]	'
Property and equipment	'
	3. Property and equipment
	Oil and natural gas properties
	The following table sets forth the capitalized costs under the successful efforts method for our oil and natural gas properties as of:
		June 30, 2014			December 31, 2013
		(in thousands)
	Oil and natural gas properties, proved:
	Turkey	$	297,748		$	260,232
	Bulgaria		621			625
	Total oil and natural gas properties, proved		298,369			260,857
	Oil and natural gas properties, unproved:
	Turkey		57,502			51,273
	Bulgaria		4,455			3,119
	Total oil and natural gas properties, unproved		61,957			54,392
	Gross oil and natural gas properties		360,326			315,249
	Accumulated depletion		(119,373	)		(96,958	)
	Net oil and natural gas properties	$	240,953		$	218,291
	At June 30, 2014 and December 31, 2013, we excluded $0.7 million and $1.5 million, respectively, from the depletion calculation for proved development wells currently in progress and for costs associated with fields currently not in production.
	At June 30, 2014, the capitalized costs of our oil and natural gas properties, net of accumulated depletion, included $32.6 million relating to acquisition costs of proved properties, which are being depleted by the unit-of-production method using total proved reserves, and $146.2 million relating to well costs and additional development costs, which are being depleted by the unit-of-production method using proved developed reserves.
	At December 31, 2013, the capitalized costs of our oil and natural gas properties, net of accumulated depletion, included $35.5 million relating to acquisition costs of proved properties, which are being depleted 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 depleted by the unit-of-production method using proved developed reserves.
	Impairment and dry hole costs
	During the three and six months ended June 30, 2014, we recorded $3.8 million and $7.9 million of impairment and exploratory dry hole costs, respectively. Of the $7.9 million of costs incurred during the six months ended June 30, 2014, $3.5 million related to impairment on one well in the first quarter of 2014 and $2.8 million related to impairment of the Kazanci-5 well in the second quarter of 2014. Of the $7.9 million of costs incurred during the six months ended June 30, 2014, $1.4 million was cash spent during the period.
	Capitalized cost greater than one year
	As of June 30, 2014, we had $1.7 million of exploratory well costs capitalized for the Hayrabolu-10 well, which we spud in February 2013. The Hayrabolu-10 well continues to be evaluated for completion pending more analysis and comparable well results.
	Equipment and other property
	The historical cost of equipment and other property, presented on a gross basis with accumulated depreciation, is summarized as follows:
		June 30, 2014			December 31, 2013
		(in thousands)
	Other equipment	$	3,944		$	2,678
	Inventory		24,811			24,318
	Gas gathering system and facilities		4,508			4,485
	Vehicles		347			321
	Leasehold improvements, office equipment and software		7,675			8,114
	Gross equipment and other property		41,285			39,916
	Accumulated depreciation		(8,388	)		(7,235	)
	Net equipment and other property	$	32,897		$	32,681
	We classify our materials and supply inventory, including steel tubing and casing, as long-term assets because such materials will ultimately be classified as long-term assets when the material is used in the drilling of a well.
	At June 30, 2014, we excluded $24.8 million of inventory and $1.2 million of software from depreciation as the inventory and software had not been placed into service. 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.

Asset_retirement_obligations

Asset retirement obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset retirement obligations	'
	4. Asset retirement obligations
	The following table summarizes the changes in our asset retirement obligations (“ARO”) for the six months ended June 30, 2014 and for the year ended December 31, 2013:
		June 30, 2014			December 31, 2013
		(in thousands)
	Asset retirement obligations at beginning of period	$	10,896		$	11,958
	Change in estimates		—			(7	)
	Liabilities settled		(212	)		(296	)
	Foreign exchange change effect		53			(2,258	)
	Additions		286			991
	Accretion expense		204			508
	Asset retirement obligations at end of period		11,227			10,896
	Less: current portion		397			610
	Long-term portion	$	10,830		$	10,286
	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.

Commodity_derivative_instrumen

Commodity derivative instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Commodity derivative instruments	'
	5. 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) gain 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 senior secured credit facility (the “Senior Credit Facility”) with BNP Paribas (Suisse) SA (“BNP Paribas”) and the International Finance Corporation (“IFC”) to hedge at least 30% of our anticipated oil production volumes in Turkey.
	In May 2014, we novated our existing commodity derivative contracts with Standard Bank Plc (“Standard Bank”) and BNP Paribas and entered into new commodity derivative contracts with BNP Paribas. During the three months ended June 30, 2014, we recognized a $0.7 million realized loss on the unwinding of these commodity derivative contracts, which is included in our consolidated statement of comprehensive income (loss) under the caption “(Loss) gain on commodity derivative contracts”.
	During the three months ended June 30, 2014 and 2013, we recorded a net loss on commodity derivative contracts of $9.5 million and a net gain of $4.3 million, respectively. During the six months ended June 30, 2014 and 2013, we recorded a net loss on commodity derivative contracts of $8.6 million and a net gain of $3.5 million, respectively.
	At June 30, 2014 and December 31, 2013, we had outstanding contracts with respect to our future crude oil production as set forth in the tables below:
	Fair Value of Derivative Instruments as of June 30, 2014
	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		July 1, 2014—December 31, 2014		1,770	$	85	$	97.25	$	(4,758	)
	Collar		January1, 2015—December 31, 2015		1,410	$	85	$	97.25		(6,027	)
										$	(10,785	)
				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, 2016—December 31, 2016		1,066	$	85	$	97.25	$	114.25		$	(2,057	)
	Three-way collar contract		January 1, 2017—December 31, 2017		888	$	85	$	97.25	$	114.25			(851	)
	Three-way collar contract		January 1, 2018—December 31, 2018		726	$	85	$	97.25	$	114.25			(282	)
	Three-way collar contract		January 1, 2019—March 31, 2019		663	$	85	$	97.25	$	114.25			(20	)
													$	(3,210	)
	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	)
	Balance sheet presentation
	The following table summarizes both: (i) the gross fair value of our commodity derivative instruments by the appropriate balance sheet classification even when the commodity derivative instruments are subject to netting arrangements and qualify for net presentation in our consolidated balance sheets at June 30, 2014 and December 31, 2013, and (ii) the net recorded fair value as reflected on our consolidated balance sheets at June 30, 2014 and December 31, 2013.
				As of June 30, 2014
	Underlying commodity	Location on Balance Sheet		Gross		Gross		Net Amount of
				Amount of		Amount		Liabilities
				Recognized		Offset in the		Presented in the
				Liabilities		Consolidated		Consolidated
						Balance		Balance Sheet
						Sheet
				(in thousands)
	Crude oil		Current liabilities	$	8,279	$	—	$	8,279
	Crude oil		Long-term liabilities	$	5,716	$	—	$	5,716
				As of December 31, 2013
	Underlying commodity	Location on Balance Sheet		Gross		Gross		Net Amount of
				Amount of		Amount		Liabilities
				Recognized		Offset in the		Presented in the
				Liabilities		Consolidated		Consolidated
						Balance		Balance Sheet
				Sheet
			(in thousands)
Crude oil		Current liabilities	$	3,737	$	—	$	3,737
Crude oil		Long-term liabilities	$	4,230	$	—	$	4,230

Loan_payable

Loan payable	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Loan payable	'
	6. Loan payable
	As of the dates indicated, our third-party debt consisted of the following:
			June 30,		December 31,
			2014		2013
	Floating Rate Debt		(in thousands)
	Amended and Restated Credit Facility		$	—	$	49,766
	Senior Credit Facility			59,766		—
	TBNG credit facility			26,700		20,000
	Unsecured lines of credit			1,588		—
	Loan payable			88,054		69,766
	Less: current portion			28,288		43,284
	Long-term portion		$	59,766	$	26,482
	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 Petrol Gaz ve Petrokimya Ürünleri Inşaat Sanayi ve Ticaret A.Ş. (“Petrogas”) (collectively, and together with Amity Oil International Pty Ltd (“Amity”), the “Borrowers”) entered into an amended and restated credit facility (the “Amended and Restated Credit Facility”) with Standard Bank and BNP Paribas. 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 was guaranteed by us and each of TransAtlantic Petroleum (USA) Corp. and TransAtlantic Worldwide, Ltd. (“TransAtlantic Worldwide”). On May 6, 2014, we entered into the new Senior Credit Facility and, on May 15, 2014, we repaid the Amended and Restated Credit Facility in full and it was terminated.
	Senior Credit Facility
	On May 6, 2014, the Borrowers entered into the Senior Credit Facility with BNP Paribas and IFC. Each of the Borrowers is our wholly owned subsidiary. The Senior Credit Facility is guaranteed by us and each of TransAtlantic Petroleum (USA) Corp. and TransAtlantic Worldwide (each, a “Guarantor”).
	The amount drawn under the Senior Credit Facility may not exceed the lesser of (i) $150.0 million, (ii) the borrowing base amount at such time, (iii) the aggregate commitments of all lenders at such time, and (iv) any amount borrowed from an individual lender to the extent it exceeds the aggregate amount of such lender’s individual commitment. The lenders have an initial aggregate commitment of $80.0 million, with individual commitments of $40.0 million each. The Company has the ability to increase the commitments up to an aggregate of $150.0 million by March 31, 2016. On the first day of each fiscal quarter commencing April 1, 2016, the lenders’ commitments are subject to reduction in an amount equal to 7.69% of the aggregate commitments in effect on April 1, 2016.
	The borrowing base amount is re-determined semi-annually on April 1st and October 1st of each year, beginning April 1, 2015. The current borrowing base is $74.6 million. The borrowing base amount equals, for any calculation date, the lowest of:
		•		the debt value which results in the field life coverage ratio for such calculation date being 1.50 to 1.00; and
		•		the debt value which results in the loan life coverage ratio for such calculation date being 1.30 to 1.00.
	The Senior Credit Facility matures on the earlier of (i) March 31, 2019, or (ii) the last date of the borrowing base calculation period that immediately precedes the date that the semi-annual banking case of BNP Paribas 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 banking case prepared by BNP Paribas and the Borrowers. The Senior 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 Senior Credit Facility accrue interest at a rate of three-month LIBOR plus 5.00% per annum (5.23% at June 30, 2014). The Borrowers are also required to pay (i) a commitment fee payable quarterly in arrears at a per annum rate equal to (a) 2.00% 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 Senior Credit Facility, and (b) 1.00% per annum of the unused and uncancelled portion of the aggregate commitments that exceed the maximum available amount under the Senior 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 BNP Paribas or (b) 5.00% for all other letters of credit.
	The Senior Credit Facility is secured by a pledge of (i) the local collection accounts and offshore collection accounts of each of the Borrowers, (ii) the receivables payable to each of the Borrowers, (iii) the shares of each Borrower and (iv) substantially all of the present and future assets of the Borrowers.
	The Borrowers are required to comply with certain financial and non-financial covenants under the Senior Credit Facility, including maintaining the following financial ratios during the four most recently completed fiscal quarters occurring on or after March 31, 2014:
		•		ratio of combined current assets to combined current liabilities of not less than 1.10 to 1.00;
		•		ratio of EBITDAX (less non-discretionary capital expenditures) to aggregate amounts payable under the Senior Credit Facility of not less than 1.50 to 1.00;
		•		ratio of EBITDAX (less non-discretionary capital expenditures) to interest expense of not less than 4.00 to 1.00; and
		•		ratio of total debt to EBITDAX of less than 2.50 to 1.00.
	The Senior Credit Facility defines EBITDAX as net income (excluding extraordinary items) plus, to the extent deducted in calculating such net income, (i) interest expense (excluding interest paid-in-kind, or non-cash interest expense and interest incurred on certain subordinated intercompany debt or interest on equity recapitalized into subordinated debt), (ii) income tax expense, (iii) depreciation, depletion and amortization expense, (iv) amortization of intangibles and organization costs, (v) any extraordinary, unusual or non-recurring non-cash expenses or losses, (vi) expenses incurred in connection with oil and gas exploration activities entered into in the ordinary course of business (including related drilling, completion, geological and geophysical costs), (vii) transaction costs, expenses and fees incurred in connection with the negotiation, execution and delivery of the Senior Credit Facility and the related loan documents, minus, to the extent included in calculating net income, (a) any extraordinary, unusual or non-recurring income or gains (including, gains on the sales of assets outside of the ordinary course of business) and (b) any other non-cash income or gains.
	Pursuant to the terms of the Senior Credit Facility, until amounts under the Senior Credit Facility are repaid, each of the Borrowers shall not, and shall cause each of its subsidiaries not to, in each case subject to certain exceptions (i) incur indebtedness or create any liens, (ii) enter into any agreements that prohibit the ability of any Borrower or its subsidiaries to create any liens, (iii) enter into any merger, consolidation or amalgamation, liquidate or dissolve, (iv) dispose of any property or business, (v) pay any dividends, distributions or similar payments to shareholders, (vi) make certain types of investments, (vii) enter into any transactions with an affiliate, (viii) enter into a sale and leaseback arrangement, (ix) engage in any business or business activity, own any assets or assume any liabilities or obligations except as necessary in connection with, or reasonably related to, its business as an oil and natural gas exploration and production company or operate or carry on business in any jurisdiction outside of Turkey or its jurisdiction of formation, (x) change its organizational documents, (xi) permit its fiscal year to end on a day other than December 31st or change its method of determining fiscal quarters, or alter the accounting principles it uses, (xii) modify certain hydrocarbon licenses and agreements or material contracts, (xiii) enter into any hedge agreement for speculative purposes, (xiv) open or maintain new deposit, securities or commodity accounts, (xv) use the proceeds from any loan in the territories of any country that is not a member of the World Bank, (xvi) incur any expenditure that is not covered by the projections in the most recent corporate cashflow projection, (xvii) modify its social and environmental action plans as determined in conjunction with IFC, (xviii) enter into any transaction or engage in any activity prohibited by the United Nations Security Council, or (xix) engage in any corrupt, fraudulent, coercive, collusive or obstructive practice.
	An event of default under the Senior Credit Facility includes, among other events, failure to pay principal or interest when due, breach of certain covenants and obligations, cross default to other indebtedness, bankruptcy or insolvency, failure to meet the required financial covenant ratios and the occurrence of a material adverse effect. In addition, the occurrence of a change of control is an event of default. A change of control is defined as the occurrence of any of the following: (i) our failure to own, of record and beneficially, all of the equity of the Borrowers or any Guarantor or to exercise, directly or indirectly, day-to-day management and operational control of any Borrower or Guarantor; (ii) the failure by the Borrowers to own or hold, directly or indirectly, all of the interests granted to Borrowers pursuant to certain hydrocarbon licenses designated in the Senior Credit Facility; or (iii) (a) Mr. Mitchell ceases for any reason to be the executive chairman of our board of directors at any time, (b) Mr. Mitchell and certain of his affiliates cease to own of record and beneficially at least 35% of our common shares; or (c) any person or group, excluding Mr. Mitchell and certain of his affiliates, shall become, or obtain rights to become, the beneficial owner, directly or indirectly, of more than 35% of our outstanding common shares entitled to vote for members of our board of directors on a fully-diluted basis; provided, that, if Mr. Mitchell ceases to be executive chairman of our board of directors by reason of his death or disability, such event shall not constitute an event of default unless we have not appointed a successor reasonably acceptable to the lenders within 60 days of the occurrence of such event.
	As of July 1, 2014, we had outstanding borrowings of $59.8 million under the Senior Credit Facility and availability of $14.8 million.
	TBNG credit facility
	On June 18, 2013, our wholly owned subsidiary, Thrace Basin Natural Gas (Turkiye) Corporation (“TBNG”), entered into a 78.8 million New Turkish Lira (“TRY”) (approximately $37.1 million at June 30, 2014) 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 three borrowings under this credit facility, on October 9, 2013, November 5, 2013 and January 22, 2014, 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 June 30, 2014, we had borrowed $26.7 million under this credit facility.
	Unsecured lines of credit
	Our wholly owned subsidiaries operating in Turkey are party to unsecured, non-interest bearing lines of credit with a Turkish bank. At June 30, 2014, we had outstanding borrowings of $1.6 million under these lines of credit.

Contingencies_relating_to_prod

Contingencies relating to production leases and exploration permits	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Contingencies relating to production leases and exploration permits	'
	7. Contingencies relating to production leases and exploration permits
	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, a force majeure event under the terms of the exploration permit was recognized by the government. Although we invoked force majeure, we recorded $2.0 million in general and administrative expense 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 (the “Purchase Agreement”) with Direct Petroleum Exploration, LLC (“Direct”). The Amendment set forth a new obligation to drill and test the Deventci-R2 well by May 1, 2014. We completed the drilling and testing requirements pursuant to the Amendment during April 2014, which resulted in the reversal of the $2.5 million contingent liability recorded in 2011. The reversal is recognized in our consolidated statements of comprehensive income (loss) under the caption “Revaluation of contingent consideration” during the six months ended June 30, 2014.
	In addition, the Amendment provides that we will issue $7.5 million in common shares 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 June 30, 2014, we had not recorded a contingent liability for this contingent consideration. Any adjustment will be recorded when it becomes probable and estimable.
	Additionally, the Amendment provides that if the Bulgarian government issues a production concession over the stefenetz concession area (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.

Shareholders_equity

Shareholders' equity	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Shareholders' equity	'
	8. Shareholders’ equity
	Reverse stock split
	On March 4, 2014, our 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 as of March 4, 2014 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 amounts and transactions herein have been adjusted to reflect the 1-for-10 reverse stock split.
	Restricted stock units
	Share-based compensation expense of approximately $0.3 million and $0.7 million with respect to awards of restricted stock units (“RSUs”) was recorded for the three and six months ended June 30, 2014, respectively. We recorded share-based compensation expense of $0.5 million and $0.9 million for the three and six months ended June 30, 2013, respectively.
	As of June 30, 2014, we had approximately $1.4 million of unrecognized compensation expense related to unvested RSUs, which is expected to be recognized over a weighted average period of 1.7 years.
	Earnings per share
	We account for earnings per share in accordance with Accounting Standards Codification (“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 three and six months ended June 30, 2014 and 2013 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 three and six months ended June 30, 2014 and 2013 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 RSUs. For the three and six months ended June 30, 2014 and 2013, there were no dilutive securities included in the calculation of diluted earnings per share.
	The following table presents the basic and diluted earnings per common share computations:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
	(in thousands, except per share amounts)	2014		2013		2014			2013
	Net income from continuing operations	$	1,437	$	2,903	$	5,430		$	5,935
	Net loss from discontinued operations	$	—	$	—	$	(20	)	$	(93	)
	Basic net income per common share:
	Shares:
	Weighted average shares outstanding		37,411		36,893		37,402			36,891
	Basic net income per common share:
	Continuing operations	$	0.04	$	0.08	$	0.15		$	0.16
	Discontinued operations	$	0	$	0	$	0		$	0
	Diluted net income per common share:
	Shares:
	Weighted average common and common equivalent shares outstanding		37,411		36,893		37,402			36,891
	Diluted net income per common share:
	Continuing operations	$	0.04	$	0.08	$	0.15		$	0.16
	Discontinued operations	$	0	$	0	$	0		$	0

Segment_information

Segment information	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Segment information	'
	9. 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 table:
			Corporate			Turkey		Bulgaria			Total
			(in thousands)
	For the three months ended June 30, 2014
	Total revenues		$	—		$	41,051	$	10		$	41,061
	Income (loss) from continuing operations before income taxes			(3,082	)		5,819		(73	)		2,664
	Capital expenditures		$	64		$	27,540	$	334		$	27,938
	For the three months ended June 30, 2013
	Total revenues		$	2		$	30,486	$	28		$	30,516
	Income (loss) from continuing operations before income taxes			(3,154	)		1,525		4,712			3,083
	Capital expenditures		$	—		$	27,147	$	—		$	27,147
	For the six months ended June 30, 2014
	Total revenues		$	—		$	74,690	$	17		$	74,707
	Income (loss) from continuing operations before income taxes			(6,902	)		13,319		2,290			8,707
	Capital expenditures		$	233		$	49,321	$	1,375		$	50,929
	For the six months ended June 30, 2013
	Total revenues		$	2		$	64,462	$	96		$	64,560
	Income (loss) from continuing operations before income taxes			(6,134	)		9,897		4,612			8,375
	Capital expenditures		$	—		$	45,846	$	—		$	45,846
	Segment assets
	June 30, 2014		$	13,464		$	338,754	$	6,710		$	358,928	(1)
	December 31, 2013		$	14,070		$	321,749	$	10,231		$	346,050	(1)
	Goodwill
	June 30, 2014		$	—		$	7,574	$	—		$	7,574
	December 31, 2013		$	—		$	7,535	$	—		$	7,535
	-1	Excludes assets held for sale from our discontinued Moroccan operations of $29,000 and $536,000 at June 30, 2014 and December 31, 2013, respectively.

Financial_instruments

Financial instruments	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Financial instruments	'
	10. Financial instruments
	Cash and cash equivalents, restricted cash, accounts receivable, accounts payable, accrued liabilities and our loan payable were each estimated to have a fair value approximating the carrying amount at June 30, 2014 and December 31, 2013, due to the short maturity of those 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 Senior Credit Facility.
	Foreign currency risk
	We have underlying foreign currency exchange rate exposure. Our currency exposures relate to transactions denominated in the Canadian Dollar, Bulgarian Lev, European Union Euro, Romanian New Leu, Moroccan Dirham and TRY. We are also subject to foreign currency exposures resulting from translating the functional currency of our foreign subsidiary financial statements into the U.S. Dollar reporting currency. We have not used foreign currency forward contracts to manage exchange rate fluctuations. At June 30, 2014, we had 8.2 million TRY (approximately $3.9 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 June 30, 2014 and December 31, 2013, 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, the national oil company of Turkey, and Turkiye Petrol Rafinerileri A.Ş., a privately owned oil refinery in Turkey, which purchase the majority of our oil production. The receivables are not collateralized. To date, we have experienced minimal bad debts. The majority of our cash and cash equivalents are held by three financial institutions in the United States and Turkey.
	Fair value measurements
	The following table summarizes the valuation of our financial assets and liabilities as of June 30, 2014:
		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:
	Derivative financial instruments (commodity)	$	—	$	(13,995	)	$	—	$	(13,995	)
	Total	$	—	$	(13,995	)	$	—	$	(13,995	)
	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:
	Derivative financial instruments (commodity)	$	—	$	(7,967	)	$	—	$	(7,967	)
	Total	$	—	$	(7,967	)	$	—	$	(7,967	)
	We remeasure our derivative contracts on a recurring basis, with changes flowing through earnings. All other financial instruments are recorded at carrying value. The carrying value of these other financial instruments approximates fair value, as they are subject to short-term floating interest rates that approximate the rates available to us.

Related_party_transactions

Related party transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related party transactions	'
	11. Related party transactions
	The following table summarizes related party accounts receivable and accounts payable as of the dates indicated:
		June 30,		December 31,
		2014		2013
		(in thousands)
	Related party accounts receivable:
	Viking International master services agreement	$	171	$	939
	Riata Management service agreement		21		65
	Total related party accounts receivable	$	192	$	1,004
	Related party accounts payable:
	Viking International master services agreement	$	7,258	$	15,956
	Viking Geophysical master services agreement		18		6,800
	Riata Management service agreement		421		334
	Total related party accounts payable	$	7,697	$	23,090
	For the three and six months ended June 30, 2014 and 2013, we incurred expenditures of $31.6 million and $50.6 million, and $17.5 million and $37.7 million, respectively, related to our various related party agreements.

Discontinued_operations

Discontinued operations	6 Months Ended
	Jun. 30, 2014
Discontinued Operations And Disposal Groups [Abstract]	'
Discontinued operations	'
	12. Discontinued operations
	Discontinued operations in Morocco
	On June 27, 2011, we decided to discontinue our operations in Morocco. We have transferred our oilfield services equipment from Morocco to Turkey and 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.
	The assets and liabilities held for sale are summarized as follows:
		June 30, 2014		December 31, 2013
		(in thousands)
	Cash	$	16	$	23
	Other assets		13		513
	Total assets held for sale	$	29	$	536
	Accrued expenses and other liabilities	$	7,533	$	7,559
	Total liabilities held for sale	$	7,533	$	7,559
	Our operating results from discontinued operations for the three and six months ended June 30, 2014 and 2013 are summarized as follows:
		For the Three Months Ended					For the Six Months Ended
		June 30,					June 30,
		2014		2013			2014			2013
		(in thousands)
	Total revenues	$	—	$	—		$	—		$	—
	Total costs and expenses		—		(52	)		(20	)		(138	)
	Total other income (expense)		—		52			—			45
	Loss from discontinued operations before income taxes		—		—			(20	)		(93	)
	Income tax provision		—		—			—			—
	Net loss from discontinued operations	$	—	$	—		$	(20	)	$	(93	)

General_Policies

General (Policies)	6 Months Ended
	Jun. 30, 2014
Equity [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, have stable governments, 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. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of August 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.
	Certain information and footnote disclosures normally included in the consolidated financial statements prepared in accordance with U.S. GAAP have been condensed or omitted in this Form 10-Q pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). These consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Form 10-K for the year ended December 31, 2013.
Recent accounting pronouncements	'
	Recent accounting pronouncements
	In April 2014, the Financial Accounting Standard Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, Reporting Discontinued Operations and Disclosures of Components of an Entity (“ASU 2014-08”). ASU 2014-08 revises the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have (or will have) a major effect on an entity’s operations and financial results, removing the lack of continuing involvement criteria and requiring discontinued operations reporting for the disposal of an equity method investment that meets the definition of discontinued operations. The update also requires expanded disclosures for discontinued operations, including disclosure of pretax profit or loss of an individually significant component of an entity that does not qualify for discontinued operations reporting. The update is effective prospectively to all periods beginning after December 15, 2014. Currently, we do not expect the adoption of ASU 2014-08 to have a material impact on our consolidated financial statements or results of operations.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). ASU 2014-09 amends the existing accounting standards for revenue recognition and is based on the principle that revenue should be recognized to depict the transfer of goods or services to a customer at an amount that reflects the consideration a company expects to receive in exchange for those goods or services. The update is effective for periods beginning after December 15, 2016. We are currently assessing the potential impact of ASU 2014-09 on our consolidated financial statements and results of operations.
	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.
Earnings per share	'
	Earnings per share
	We account for earnings per share in accordance with Accounting Standards Codification (“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 three and six months ended June 30, 2014 and 2013 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 three and six months ended June 30, 2014 and 2013 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 RSUs. For the three and six months ended June 30, 2014 and 2013, there were no dilutive securities included in the calculation of diluted earnings per share.

Property_and_equipment_Tables

Property and equipment (Tables)	6 Months Ended
	Jun. 30, 2014
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 our oil and natural gas properties as of:
		June 30, 2014			December 31, 2013
		(in thousands)
	Oil and natural gas properties, proved:
	Turkey	$	297,748		$	260,232
	Bulgaria		621			625
	Total oil and natural gas properties, proved		298,369			260,857
	Oil and natural gas properties, unproved:
	Turkey		57,502			51,273
	Bulgaria		4,455			3,119
	Total oil and natural gas properties, unproved		61,957			54,392
	Gross oil and natural gas properties		360,326			315,249
	Accumulated depletion		(119,373	)		(96,958	)
	Net oil and natural gas properties	$	240,953		$	218,291
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:
		June 30, 2014			December 31, 2013
		(in thousands)
	Other equipment	$	3,944		$	2,678
	Inventory		24,811			24,318
	Gas gathering system and facilities		4,508			4,485
	Vehicles		347			321
	Leasehold improvements, office equipment and software		7,675			8,114
	Gross equipment and other property		41,285			39,916
	Accumulated depreciation		(8,388	)		(7,235	)
	Net equipment and other property	$	32,897		$	32,681

Asset_retirement_obligations_T

Asset retirement obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Changes in Asset Retirement Obligations	'
	The following table summarizes the changes in our asset retirement obligations (“ARO”) for the six months ended June 30, 2014 and for the year ended December 31, 2013:
		June 30, 2014			December 31, 2013
		(in thousands)
	Asset retirement obligations at beginning of period	$	10,896		$	11,958
	Change in estimates		—			(7	)
	Liabilities settled		(212	)		(296	)
	Foreign exchange change effect		53			(2,258	)
	Additions		286			991
	Accretion expense		204			508
	Asset retirement obligations at end of period		11,227			10,896
	Less: current portion		397			610
	Long-term portion	$	10,830		$	10,286

Commodity_derivative_instrumen1

Commodity derivative instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Fair Value of Derivative Instruments of Future Crude Oil Production	'
	At June 30, 2014 and December 31, 2013, we had outstanding contracts with respect to our future crude oil production as set forth in the tables below:
	Fair Value of Derivative Instruments as of June 30, 2014
	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		July 1, 2014—December 31, 2014		1,770	$	85	$	97.25	$	(4,758	)
	Collar		January1, 2015—December 31, 2015		1,410	$	85	$	97.25		(6,027	)
										$	(10,785	)
				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, 2016—December 31, 2016		1,066	$	85	$	97.25	$	114.25		$	(2,057	)
	Three-way collar contract		January 1, 2017—December 31, 2017		888	$	85	$	97.25	$	114.25			(851	)
	Three-way collar contract		January 1, 2018—December 31, 2018		726	$	85	$	97.25	$	114.25			(282	)
	Three-way collar contract		January 1, 2019—March 31, 2019		663	$	85	$	97.25	$	114.25			(20	)
													$	(3,210	)
	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	)
Summary of Gross Fair Value of Commodity Derivative Instruments by Balance Sheet Classification	'
	The following table summarizes both: (i) the gross fair value of our commodity derivative instruments by the appropriate balance sheet classification even when the commodity derivative instruments are subject to netting arrangements and qualify for net presentation in our consolidated balance sheets at June 30, 2014 and December 31, 2013, and (ii) the net recorded fair value as reflected on our consolidated balance sheets at June 30, 2014 and December 31, 2013.
				As of June 30, 2014
	Underlying commodity	Location on Balance Sheet		Gross		Gross		Net Amount of
				Amount of		Amount		Liabilities
				Recognized		Offset in the		Presented in the
				Liabilities		Consolidated		Consolidated
						Balance		Balance Sheet
						Sheet
				(in thousands)
	Crude oil		Current liabilities	$	8,279	$	—	$	8,279
	Crude oil		Long-term liabilities	$	5,716	$	—	$	5,716
				As of December 31, 2013
	Underlying commodity	Location on Balance Sheet		Gross		Gross		Net Amount of
				Amount of		Amount		Liabilities
				Recognized		Offset in the		Presented in the
				Liabilities		Consolidated		Consolidated
						Balance		Balance Sheet
						Sheet
				(in thousands)
	Crude oil		Current liabilities	$	3,737	$	—	$	3,737
	Crude oil		Long-term liabilities	$	4,230	$	—	$	4,230

Loan_payable_Tables

Loan payable (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	As of the dates indicated, our third-party debt consisted of the following:
		June 30,		December 31,
		2014		2013
	Floating Rate Debt	(in thousands)
	Amended and Restated Credit Facility	$	—	$	49,766
	Senior Credit Facility		59,766		—
	TBNG credit facility		26,700		20,000
	Unsecured lines of credit		1,588		—
	Loan payable		88,054		69,766
	Less: current portion		28,288		43,284
	Long-term portion	$	59,766	$	26,482

Shareholders_equity_Tables

Shareholders' equity (Tables)	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Basic and Diluted Earnings Per Common Share Computations	'
	The following table presents the basic and diluted earnings per common share computations:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
	(in thousands, except per share amounts)	2014		2013		2014			2013
	Net income from continuing operations	$	1,437	$	2,903	$	5,430		$	5,935
	Net loss from discontinued operations	$	—	$	—	$	(20	)	$	(93	)
	Basic net income per common share:
	Shares:
	Weighted average shares outstanding		37,411		36,893		37,402			36,891
	Basic net income per common share:
	Continuing operations	$	0.04	$	0.08	$	0.15		$	0.16
	Discontinued operations	$	0	$	0	$	0		$	0
	Diluted net income per common share:
	Shares:
	Weighted average common and common equivalent shares outstanding		37,411		36,893		37,402			36,891
	Diluted net income per common share:
	Continuing operations	$	0.04	$	0.08	$	0.15		$	0.16
	Discontinued operations	$	0	$	0	$	0		$	0

Segment_information_Tables

Segment information (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Financial Information of Geographic Segments	'
	Summarized financial information from continuing operations concerning our geographic segments is shown in the following table:
			Corporate			Turkey		Bulgaria			Total
			(in thousands)
	For the three months ended June 30, 2014
	Total revenues		$	—		$	41,051	$	10		$	41,061
	Income (loss) from continuing operations before income taxes			(3,082	)		5,819		(73	)		2,664
	Capital expenditures		$	64		$	27,540	$	334		$	27,938
	For the three months ended June 30, 2013
	Total revenues		$	2		$	30,486	$	28		$	30,516
	Income (loss) from continuing operations before income taxes			(3,154	)		1,525		4,712			3,083
	Capital expenditures		$	—		$	27,147	$	—		$	27,147
	For the six months ended June 30, 2014
	Total revenues		$	—		$	74,690	$	17		$	74,707
	Income (loss) from continuing operations before income taxes			(6,902	)		13,319		2,290			8,707
	Capital expenditures		$	233		$	49,321	$	1,375		$	50,929
	For the six months ended June 30, 2013
	Total revenues		$	2		$	64,462	$	96		$	64,560
	Income (loss) from continuing operations before income taxes			(6,134	)		9,897		4,612			8,375
	Capital expenditures		$	—		$	45,846	$	—		$	45,846
	Segment assets
	June 30, 2014		$	13,464		$	338,754	$	6,710		$	358,928	(1)
	December 31, 2013		$	14,070		$	321,749	$	10,231		$	346,050	(1)
	Goodwill
	June 30, 2014		$	—		$	7,574	$	—		$	7,574
	December 31, 2013		$	—		$	7,535	$	—		$	7,535
	-1	Excludes assets held for sale from our discontinued Moroccan operations of $29,000 and $536,000 at June 30, 2014 and December 31, 2013, respectively.

Financial_instruments_Tables

Financial instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Valuation of Financial Assets and Liabilities	'
	The following table summarizes the valuation of our financial assets and liabilities as of June 30, 2014:
		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:
	Derivative financial instruments (commodity)	$	—	$	(13,995	)	$	—	$	(13,995	)
	Total	$	—	$	(13,995	)	$	—	$	(13,995	)
	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:
	Derivative financial instruments (commodity)	$	—	$	(7,967	)	$	—	$	(7,967	)
	Total	$	—	$	(7,967	)	$	—	$	(7,967	)

Related_party_transactions_Tab

Related party transactions (Tables)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Accounts Receivable and Accounts Payable	'
	The following table summarizes related party accounts receivable and accounts payable as of the dates indicated:
		June 30,		December 31,
		2014		2013
		(in thousands)
	Related party accounts receivable:
	Viking International master services agreement	$	171	$	939
	Riata Management service agreement		21		65
	Total related party accounts receivable	$	192	$	1,004
	Related party accounts payable:
	Viking International master services agreement	$	7,258	$	15,956
	Viking Geophysical master services agreement		18		6,800
	Riata Management service agreement		421		334
	Total related party accounts payable	$	7,697	$	23,090

Discontinued_operations_Tables

Discontinued operations (Tables)	6 Months Ended
	Jun. 30, 2014
Discontinued Operations And Disposal Groups [Abstract]	'
Summary of Assets and Liabilities Held for Sale and Operating Results from Discontinued Operations	'
	The assets and liabilities held for sale are summarized as follows:
		June 30, 2014		December 31, 2013
		(in thousands)
	Cash	$	16	$	23
	Other assets		13		513
	Total assets held for sale	$	29	$	536
	Accrued expenses and other liabilities	$	7,533	$	7,559
	Total liabilities held for sale	$	7,533	$	7,559
	Our operating results from discontinued operations for the three and six months ended June 30, 2014 and 2013 are summarized as follows:
		For the Three Months Ended					For the Six Months Ended
		June 30,					June 30,
		2014		2013			2014			2013
		(in thousands)
	Total revenues	$	—	$	—		$	—		$	—
	Total costs and expenses		—		(52	)		(20	)		(138	)
	Total other income (expense)		—		52			—			45
	Loss from discontinued operations before income taxes		—		—			(20	)		(93	)
	Income tax provision		—		—			—			—
	Net loss from discontinued operations	$	—	$	—		$	(20	)	$	(93	)

General_Additional_Information

General - Additional Information (Detail) (Subsequent Event [Member])	Aug. 01, 2014
Subsequent Event [Member]	'
Nature Of Business [Line Items]	'
Percentage of common shares owned	40.00%

Property_and_Equipment_Capital

Property and Equipment - Capitalized Costs under Successful Efforts Method for Oil and Natural Gas Properties (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Oil and natural gas properties, proved	$298,369	$260,857
Oil and natural gas properties, unproved	61,957	54,392
Gross oil and natural gas properties	360,326	315,249
Accumulated depletion	-119,373	-96,958
Net oil and natural gas properties	240,953	218,291
Turkey [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Oil and natural gas properties, proved	297,748	260,232
Oil and natural gas properties, unproved	57,502	51,273
Bulgaria [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Oil and natural gas properties, proved	621	625
Oil and natural gas properties, unproved	$4,455	$3,119

Property_and_Equipment_Additio

Property and Equipment - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'
Proved development wells excluded from depletion	$0.70	'	$0.70	$1.50
Acquisition costs of proved properties	'	'	32.6	35.5
Well costs and additional development costs	146.2	'	146.2	126.9
Exploratory dry hole costs	3.8	'	7.9	'
Impairment charge on proved properties	2.8	3.5	'	'
Cash spent during the period for dry hole cost	'	'	1.4	'
Hayrabolu-10 well [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Exploratory drilling costs capitalized	1.7	'	1.7	'
Software [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Property plant and equipment excluded from depreciation	1.2	'	1.2	0.7
Inventory [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Property plant and equipment excluded from depreciation	$24.80	'	$24.80	$24.30

Property_and_Equipment_Histori

Property and Equipment - Historical Cost of Equipment and Other Property on Gross Basis with Accumulated Depreciation (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	$41,285	$39,916
Accumulated depreciation	-8,388	-7,235
Net equipment and other property	32,897	32,681
Other equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	3,944	2,678
Inventory [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	24,811	24,318
Gas gathering system and facilities [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	4,508	4,485
Vehicles [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	347	321
Leasehold improvements, office equipment and software [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Gross equipment and other property	$7,675	$8,114

Asset_Retirement_Obligations_C

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Detail) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'	'	'	'	'
Asset retirement obligations at beginning of period	'	'	$10,896	$11,958	$11,958
Change in estimates	'	'	'	'	-7
Liabilities settled	'	'	-212	'	-296
Foreign exchange change effect	'	'	53	'	-2,258
Additions	'	'	286	'	991
Accretion expense	106	124	204	253	508
Asset retirement obligations at end of period	11,227	'	11,227	'	10,896
Less: current portion	397	'	397	'	610
Long-term portion	$10,830	'	$10,830	'	$10,286

Recovered_Sheet1

Commodity Derivative Instruments - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative [Line Items]	'	'	'	'
(Loss) gain on commodity derivative contracts	($9,522,000)	$4,278,000	($8,560,000)	$3,502,000
Net gain (loss) on sale of commodity derivative contracts	-9,500,000	4,300,000	-8,600,000	3,500,000
Bnp Paribas [Member]	'	'	'	'
Derivative [Line Items]	'	'	'	'
(Loss) gain on commodity derivative contracts	($700,000)	'	'	'
Turkey [Member] | Amended and Restated Credit Facility [Member] | Minimum [Member]	'	'	'	'
Derivative [Line Items]	'	'	'	'
Percentage of hedge of anticipated production volume	30.00%	'	30.00%	'

Recovered_Sheet2

Commodity Derivative Instruments - Fair Value of Derivative Instruments of Future Crude Oil Production (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Estimated Fair Value of Liability	($10,785)	'
Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Estimated Fair Value of Liability	'	-387
Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Estimated Fair Value of Liability	-3,210	-7,580
January 1, 2014 - December 31, 2014 [Member] | Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	'	622
Collars Weighted Average Minimum Price (per Bbl)	'	80.83
Additional Call Weighted Average Maximum Price (per Bbl)	'	118.07
Estimated Fair Value of Liability	'	-387
January 1, 2014 - December 31, 2014 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	'	726
Collars Weighted Average Minimum Price (per Bbl)	'	85
Additional Call Weighted Average Maximum Price (per Bbl)	'	97.13
Estimated Fair Value of Liability	'	-3,350
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
July 1, 2014-December 31, 2014 [Member] | Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	1,770	'
Collars Weighted Average Minimum Price (per Bbl)	85	'
Additional Call Weighted Average Maximum Price (per Bbl)	97.25	'
Estimated Fair Value of Liability	-4,758	'
January 1, 2015 - December 31, 2015 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	'	1,016
Collars Weighted Average Minimum Price (per Bbl)	'	85
Additional Call Weighted Average Maximum Price (per Bbl)	'	91.88
Estimated Fair Value of Liability	'	-4,230
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
January 1, 2015 - December 31, 2015 [Member] | Collar [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	1,410	'
Collars Weighted Average Minimum Price (per Bbl)	85	'
Additional Call Weighted Average Maximum Price (per Bbl)	97.25	'
Estimated Fair Value of Liability	-6,027	'
January 1, 2016 - December 31, 2016 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	1,066	'
Collars Weighted Average Minimum Price (per Bbl)	85	'
Additional Call Weighted Average Maximum Price (per Bbl)	97.25	'
Estimated Fair Value of Liability	-2,057	'
January 1, 2016 - December 31, 2016 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	114.25	'
January 1, 2017 - December 31, 2017 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	888	'
Collars Weighted Average Minimum Price (per Bbl)	85	'
Additional Call Weighted Average Maximum Price (per Bbl)	97.25	'
Estimated Fair Value of Liability	-851	'
January 1, 2017 - December 31, 2017 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	114.25	'
January 1, 2018 - December 31, 2018 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	726	'
Collars Weighted Average Minimum Price (per Bbl)	85	'
Additional Call Weighted Average Maximum Price (per Bbl)	97.25	'
Estimated Fair Value of Liability	-282	'
January 1, 2018 - December 31, 2018 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	114.25	'
January 1, 2019 - March 31, 2019 [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Quantity (Bbl/day)	663	'
Collars Weighted Average Minimum Price (per Bbl)	85	'
Additional Call Weighted Average Maximum Price (per Bbl)	97.25	'
Estimated Fair Value of Liability	($20)	'
January 1, 2019 - March 31, 2019 [Member] | Additional Call [Member] | Three-way collar contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Additional Call Weighted Average Maximum Price (per Bbl)	114.25	'

Commodity_Derivative_Instrumen2

Commodity Derivative Instruments - Summary of Gross Fair Value of Commodity Derivative Instruments by Balance Sheet Classification (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Gross Amounts of Recognized Liabilities	$10,785	'
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	8,279	3,737
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	5,716	4,230
Crude Oil [Member] | Long Term Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Gross Amounts of Recognized Liabilities	5,716	4,230
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	5,716	4,230
Derivative [Member] | Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Gross Amounts of Recognized Liabilities	8,279	3,737
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	$8,279	$3,737

Loan_Payable_Debt_Detail

Loan Payable - Debt (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Total third-party debt	$88,054	$69,766
Short-term third-party debt	28,288	43,284
Long-term third-party debt	59,766	26,482
Amended and Restated Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Total third-party debt	0	49,766
Senior Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Total third-party debt	59,766	0
TBNG credit facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Total third-party debt	26,700	20,000
Unsecured lines of credit [Member]	'	'
Debt Instrument [Line Items]	'	'
Total third-party debt	$1,588	$0

Loan_Payable_Additional_Inform

Loan Payable - Additional Information (Detail)

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

6-May-14

Jun. 30, 2014

6-May-14

Dec. 31, 2013

6-May-14

Jun. 30, 2014

6-May-14

6-May-14

Jun. 30, 2014

Jun. 18, 2013

6-May-14

Jun. 30, 2014

Dec. 31, 2013

6-May-14

Jun. 30, 2014

6-May-14

6-May-14

Jun. 18, 2013

6-May-14

Jun. 18, 2013

6-May-14

6-May-14

6-May-14

USD ($)

USD ($)

Senior Credit Facility [Member]

Senior Credit Facility [Member]

Senior Credit Facility [Member]

Senior Credit Facility [Member]

TBNG credit facility [Member]

TBNG credit facility [Member]

Letter Of Credit Cash Collateralized [Member]

Unsecured lines of credit [Member]

Unsecured lines of credit [Member]

Individual Commitments [Member]

5 May 2014 Line Of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter Of Credit Other Than Cash Collateralized [Member]

Cash [Member]

Less Than [Member]

Maximum [Member]

Minimum [Member]

USD ($)

USD ($)

Quarterly [Member]

USD ($)

TRY

Senior Credit Facility [Member]

USD ($)

USD ($)

Senior Credit Facility [Member]

Senior Credit Facility [Member]

USD ($)

Bank Guarantees [Member]

Senior Credit Facility [Member]

TBNG credit facility [Member]

Turkey [Member]

Other Than Mr Mitchell And Affiliates [Member]

Mr Mitchell And Affiliates [Member]

USD ($)

USD ($)

TBNG credit facility [Member]

TRY

TRY

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Initiation Date

'

6-May-14

'

'

'

'

'

'

18-Jun-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Individual commitments

'

'

'

'

'

'

$150,000,000

'

$37,100,000

78,800,000

'

'

'

$40,000,000

'

'

$10,000,000

18,800,000

'

60,000,000

'

'

'

Lenders initial aggregate commitments

'

'

'

'

'

'

80,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum commitments available

'

'

'

'

'

'

150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitments reduction percentage

'

'

'

'

'

'

'

7.69%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Initial borrowing base

'

'

'

'

'

'

'

'

'

'

'

'

'

'

74,600,000

'

'

'

'

'

'

'

'

Field life coverage ratio for debt value calculation

'

'

'

'

'

1.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loan life coverage ratio for debt value calculation

'

'

'

'

'

1.3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maturity date of credit facility

'

31-Mar-19

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accelerated senior credit facility maturity trigger, remaining hydrocarbon percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

Accelerated senior credit facility maturity trigger description

'

'The last date of the borrowing base calculation period that immediately precedes the date that the semi-annual banking case of BNP Paribas 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 banking case prepared by BNP Paribas and the Borrowers.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Description of variable rate basis

'

'

'

'

'

'LIBOR plus 5.00% per annum (5.23% at June 30, 2014)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit, basis spread on variable rate

'

'

'

'

5.00%

5.23%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fee percentage, unused

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fee percentage, unused

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of Fronting Fee

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

0.25%

'

'

5.00%

'

'

'

'

Combined current ratio

'

'

1.1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

EBITDAX to Credit facility ratio

1.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

EBITDAX to interest expense ratio

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total debt to EBITDAX ratio

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage triggering default

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

35.00%

Borrowings under credit facility

'

'

'

'

'

59,800,000

'

'

26,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available borrowings under credit facility

'

'

'

'

'

14,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument Interest rate

'

'

'

'

'

'

'

'

4.60%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding borrowings under lines of credit

'

$88,054,000

'

$69,766,000

'

'

'

'

'

'

'

$1,588,000

$0

'

'

'

'

'

'

'

'

'

'

Recovered_Sheet3

Contingencies Relating to Production Leases and Exploration Permits - Additional Information (Detail) (USD $)	6 Months Ended	3 Months Ended		3 Months Ended			6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2012	Jun. 30, 2012	Jun. 30, 2012	Jun. 30, 2014
	Direct Petroleum [Member]	Amendment [Member]	Amendment [Member]	Bulgaria [Member]	Bulgaria [Member]	Moroccan Government [Member]	Moroccan Government [Member]
	Deventci-R2 [Member]	Stefenetz Concession Area [Member]	Direct Petroleum [Member]		Aglen Exploration Permit Work Program [Member]
		acre	Deventci-R2 [Member]		General and Administrative Expense [Member]
Loss Contingencies [Line Items]	'	'	'	'	'	'	'
Recovery of contractual obligations	'	'	'	$2	'	$5.50	'
Bank guarantee	'	'	'	'	'	'	1
Accrued liabilities relating to our Tselfat exploration permit	'	'	'	'	'	5	'
General and administrative expense	'	'	'	'	2	'	'
Contingent liability reversed	2.5	'	'	'	'	'	'
Contingency, Purchase obligation	'	'	7.5	'	'	'	'
Area of land leased under the production	'	200,000	'	'	'	'	'
Stock issued, non cash consideration, value	'	$10	'	'	'	'	'

Shareholders_Equity_Additional

Shareholders' Equity - Additional Information (Detail) (USD $)	0 Months Ended	3 Months Ended		6 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 04, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'	'	'
Description of the reverse stock split arrangement	'	'	'	'All shareholders of record received one common share for each ten common shares owned (subject to minor adjustments as a result of fractional shares)	'	'
Ratio applied to the conversion of stock split	10	'	'	'	'	'
Common stock shares issued	374,026,984	37,447,909	'	37,447,909	'	37,340,206
Common stock shares outstanding	374,026,984	37,447,909	'	37,447,909	'	37,340,206
Antidilutive securities excluded from computation of earnings per share amount	'	0	0	0	0	'
Reverse Stock Split [Member]	'	'	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'	'	'
Common stock shares issued	37,402,698	'	'	'	'	'
Common stock shares outstanding	37,402,698	'	'	'	'	'
Restricted Stock Units [Member]	'	'	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'	'	'
Share-based compensation expense	'	0.3	0.5	0.7	0.9	'
Unrecognized compensation expense	'	1.4	'	1.4	'	'
Unrecognized compensation expense recognition period	'	'	'	'1 year 8 months 12 days	'	'

Shareholders_Equity_Basic_and_

Shareholders' Equity - Basic and Diluted Earnings Per Common Share Computations (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Equity [Abstract]	'	'	'	'
Net income from continuing operations	$1,437	$2,903	$5,430	$5,935
Net loss from discontinued operations	$0	$0	($20)	($93)
Weighted average shares outstanding	37,411	36,893	37,402	36,891
Continuing operations	$0.04	$0.08	$0.15	$0.16
Discontinued operations	$0	$0	$0	$0
Weighted average common and common equivalent shares outstanding	37,411	36,893	37,402	36,891
Continuing operations	$0.04	$0.08	$0.15	$0.16
Discontinued operations	$0	$0	$0	$0

Segment_Information_Additional

Segment Information - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2014
	Segment
Segment Reporting [Abstract]	'
Number of reportable geographic segments	2

Segment_Information_Financial_

Segment Information - Financial Information of Geographic Segments (Detail) (USD $)	3 Months Ended			6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]	'		'	'		'	'
Total revenues	$41,061		$30,516	$74,707		$64,560	'
Income (loss) from continuing operations before income taxes	2,664		3,083	8,707		8,375	'
Capital expenditures	27,938		27,147	50,929		45,846	'
Segment assets	358,928	[1]	'	358,928	[1]	'	346,050	[1]
Goodwill	7,574		'	7,574		'	7,535
Corporate, Non-Segment [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Total revenues	0		2	0		2	'
Income (loss) from continuing operations before income taxes	-3,082		-3,154	-6,902		-6,134	'
Capital expenditures	64		0	233		0	'
Segment assets	13,464		'	13,464		'	14,070
Goodwill	0		'	0		'	0
Operating Segments [Member] | Turkey [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Total revenues	41,051		30,486	74,690		64,462	'
Income (loss) from continuing operations before income taxes	5,819		1,525	13,319		9,897	'
Capital expenditures	27,540		27,147	49,321		45,846	'
Segment assets	338,754		'	338,754		'	321,749
Goodwill	7,574		'	7,574		'	7,535
Operating Segments [Member] | Bulgaria [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Total revenues	10		28	17		96	'
Income (loss) from continuing operations before income taxes	-73		4,712	2,290		4,612	'
Capital expenditures	334		0	1,375		0	'
Segment assets	6,710		'	6,710		'	10,231
Goodwill	$0		'	$0		'	$0
[1]	Excludes assets held for sale from our discontinued Moroccan operations of $29,000 and $536,000 at June 30, 2014 and December 31, 2013, respectively.

Segment_Information_Financial_1

Segment Information - Financial Information of Geographic Segments (Parenthetical) (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Segment Reporting [Abstract]	'	'
Assets from discontinued operations and services	$29	$536

Financial_Instruments_Addition

Financial Instruments - Additional Information (Detail)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2014	Jun. 30, 2014
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	$5,161	$12,881	$15,920	$14,768	$3,900	8,200

Financial_Instruments_Valuatio

Financial Instruments - Valuation of Financial Assets and Liabilities (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	($13,995)	($7,967)
Derivative Financial Instruments (commodity) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	-13,995	-7,967
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	0	0
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	0	0
Significant Other Observable Inputs (Level 2) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	-13,995	-7,967
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	-13,995	-7,967
Significant Unobservable Inputs (Level 3) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Liabilities, fair value	0	0
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	$0	$0

Related_Party_Transactions_Rel

Related Party Transactions - Related Party Accounts Receivable and Accounts Payable (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	$192	$1,004
Total related party accounts payable	7,697	23,090
Viking International master services agreement [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	171	939
Total related party accounts payable	7,258	15,956
Riata Management service agreement [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts receivable	21	65
Total related party accounts payable	421	334
Viking Geophysical master services agreement [Member]	'	'
Related Party Transaction [Line Items]	'	'
Total related party accounts payable	$18	$6,800

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Related Party Transactions [Abstract]	'	'	'	'
Capital and operating expenditures	$31.60	$17.50	$50.60	$37.70

Discontinued_Operations_Assets

Discontinued Operations - Assets and Liabilities Held for Sale (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Discontinued Operations And Disposal Groups [Abstract]	'	'
Cash	$16	$23
Other assets	13	513
Total assets held for sale	29	536
Accrued expenses and other liabilities	7,533	7,559
Total liabilities held for sale	$7,533	$7,559

Discontinued_Operations_Operat

Discontinued Operations - Operating Results from Discontinued Operations (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Discontinued Operations And Disposal Groups [Abstract]	'	'	'	'
Total revenues	$0	$0	$0	$0
Total costs and expenses	0	-52	-20	-138
Total other income (expense)	0	52	0	45
Loss from discontinued operations before income taxes	0	0	-20	-93
Income tax provision	0	0	0	0
Net loss from discontinued operations	$0	$0	($20)	($93)